10-Q

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 30, 2016

OR

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

For the transition period from              to

________________________

Commission file number	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, LLC (a Florida limited liability company) 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, LLC (a North Carolina limited liability company) 410 South Wilmington Street Raleigh, North Carolina 27601-1748 704-382-3853 56-0165465	1-3543	DUKE ENERGY INDIANA, LLC (an Indiana limited liability company) 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)	Yesx	No ¨	Duke Energy Florida, LLC (Duke Energy Florida)	Yesx	No ¨
Duke Energy Carolinas, LLC (Duke Energy Carolinas)	Yesx	No ¨	Duke Energy Ohio, Inc. (Duke Energy Ohio)	Yesx	No ¨
Progress Energy, Inc. (Progress Energy)	Yesx	No ¨	Duke Energy Indiana, LLC (Duke Energy Indiana)	Yesx	No ¨
Duke Energy Progress, LLC (Duke Energy Progress)	Yesx	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	Yesx	No ¨	Duke Energy Florida	Yesx	No ¨
Duke Energy Carolinas	Yesx	No ¨	Duke Energy Ohio	Yesx	No ¨
Progress Energy	Yesx	No ¨	Duke Energy Indiana	Yesx	No ¨
Duke Energy Progress	Yesx	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 filerx	Accelerated filer ¨	Non-accelerated filer ¨	Smaller reporting company ¨
Duke Energy Carolinas	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨
Progress Energy	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨
Duke Energy Progress	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨
Duke Energy Florida	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨
Duke Energy Ohio	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨
Duke Energy Indiana	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	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 ¨	Nox	Duke Energy Florida	Yes ¨	Nox
Duke Energy Carolinas	Yes ¨	Nox	Duke Energy Ohio	Yes ¨	Nox
Progress Energy	Yes ¨	Nox	Duke Energy Indiana	Yes ¨	Nox
Duke Energy Progress	Yes ¨	Nox

Number of shares of Common stock outstanding at June 30, 2016:

Registrant	Description	Shares
Duke Energy	Common stock, $0.001 par value	688,933,508
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 limited liability company member interests are indirectly owned by Duke Energy.
Duke Energy Florida	All of the registrant's limited liability company member interests are 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 limited liability company member interests are 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 Information
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements
	Duke Energy Corporation Financial Statements	6
	Duke Energy Carolinas, LLC Financial Statements	11
	Progress Energy, Inc. Financial Statements	15
	Duke Energy Progress, LLC Financial Statements	19
	Duke Energy Florida, LLC Financial Statements	23
	Duke Energy Ohio, Inc. Financial Statements	27
	Duke Energy Indiana, LLC Financial Statements	31
	Combined Notes to Condensed Consolidated Financial Statements
	Note 1 – Organization and Basis of Presentation	35
	Note 2 – Acquisitions and Dispositions	38
	Note 3 – Business Segments	39
	Note 4 – Regulatory Matters	42
	Note 5 – Commitments and Contingencies	48
	Note 6 – Debt and Credit Facilities	55
	Note 7 – Goodwill and Intangible Assets	57
	Note 8 – Related Party Transactions	58
	Note 9 – Derivatives and Hedging	59
	Note 10 – Investments in Debt and Equity Securities	64
	Note 11 – Fair Value Measurements	70
	Note 12 – Variable Interest Entities	77
	Note 13 – Common Stock	81
	Note 14 – Stock-Based Compensation	82
	Note 15 – Employee Benefit Plans	82
	Note 16 – Income Taxes	86
	Note 17 – Subsequent Events	88
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	89
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	116
Item 4.	Controls and Procedures	116
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	117
Item 1A.	Risk Factors	117
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	117
Item 6.	Exhibits	118
	Signatures	120

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 and can often be identified by terms and phrases that include “anticipate,” “believe,” “intend,” “estimate,” “expect,” “continue,” “should,” “could,” “may,” “plan,” “project,” “predict,” “will,” “potential,” “forecast,” “target,” “guidance,” “outlook” or other similar terminology. Various factors may cause actual results to be materially different than the suggested outcomes within forward-looking statements; accordingly, there is no assurance that such results will be realized. These factors 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 costs and liabilities to comply with federal and state laws, regulations, and legal requirements related to coal ash remediation, including amounts for required closure of certain ash impoundments, are uncertain and difficult to estimate;

◦ The ability to recover eligible costs, including amounts associated with coal ash impoundment retirement obligations and costs related to significant weather events, and to earn an adequate return on investment through the regulatory process;

◦ The costs of decommissioning Crystal River Unit 3 and other nuclear facilities could prove to be more extensive than amounts estimated and all costs may not be fully recoverable through the regulatory process;

◦ Credit ratings of the Duke Energy Registrants may be different from what is expected;

◦ 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 variations in customer usage patterns, including energy efficiency efforts and use of alternative energy sources, including self-generation and distributed generation technologies;

◦ Federal and state regulations, laws and other efforts designed to promote and expand the use of energy efficiency measures and distributed generation technologies, such as rooftop solar and battery storage, in Duke Energy service territories could result in customers leaving the electric distribution system, excess generation resources as well as stranded costs;

◦ Advancements in technology;

◦ Additional competition in electric markets and continued industry consolidation;

◦ Political, economic and regulatory uncertainty in Brazil and 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, earthquakes and tornadoes;

◦ The ability to successfully operate electric generating facilities and deliver electricity to customers including direct or indirect effects to the company resulting from an incident that affects the U.S. electric grid or generating resources;

◦ The impact on facilities and business from a terrorist attack, cybersecurity threats, data security breaches, and other catastrophic events such as fires, explosions, pandemic health events or other similar occurrences;

◦ 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, interest rate fluctuations, 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;

◦ Construction and development risks associated with the completion of Duke Energy Registrants’ capital investment projects, including risks related to financing, obtaining and complying with terms of permits, meeting construction budgets and schedules, and satisfying operating and environmental performance standards, as well as the ability to recover costs from customers in a timely manner or at all;

◦ 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 successfully complete future merger, acquisition or divestiture plans;

◦ The expected timing and likelihood of completion of the proposed acquisition of Piedmont Natural Gas Company, Inc. (Piedmont), including the timing, receipt and terms and conditions of any required governmental and regulatory approvals of the proposed acquisition that could reduce anticipated benefits or cause the parties to abandon the acquisition, and under certain specified circumstances pay a termination fee of $250 million, as well as the ability to successfully integrate the businesses and realize anticipated benefits and the risk that the credit ratings of the combined company or its subsidiaries may be different from what the companies expect; and

◦ The likelihood, terms and timing of the potential sale of International Energy, excluding the equity investment in National Methanol Company (NMC), could change the presentation of certain assets, liabilities and results of operations as assets held for sale, liabilities associated with assets held for sale, and discontinued operations, respectively.

Additional risks and uncertainties are identified and discussed in the Duke Energy Registrants' reports filed with the SEC and available at the SEC's website at www.sec.gov. 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 and the Duke Energy Registrants expressly disclaim an obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Operations

(Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
(in millions, except per-share amounts)	2016			2015			2016		2015
Operating Revenues
Regulated electric	$	4,965		$	5,090		$	10,018	$	10,547
Nonregulated electric and other	422			403			822		780
Regulated natural gas	97			96			266		327
Total operating revenues	5,484			5,589			11,106		11,654
Operating Expenses
Fuel used in electric generation and purchased power – regulated	1,509			1,721			3,086		3,662
Fuel used in electric generation and purchased power – nonregulated	82			118			140		222
Cost of natural gas	21			26			81		137
Operation, maintenance and other	1,431			1,422			2,920		2,848
Depreciation and amortization	813			790			1,627		1,567
Property and other taxes	293			279			590		543
Impairment charges	195			—			198		—
Total operating expenses	4,344			4,356			8,642		8,979
Gains on Sales of Other Assets and Other, net	5			13			14		27
Operating Income	1,145			1,246			2,478		2,702
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	15			23			23		36
Other income and expenses, net	92			72			171		146
Total other income and expenses	107			95			194		182
Interest Expense	500			403			1,011		806
Income From Continuing Operations Before Income Taxes	752			938			1,661		2,078
Income Tax Expense from Continuing Operations	239			334			452		698
Income From Continuing Operations	513			604			1,209		1,380
(Loss) Income From Discontinued Operations, net of tax	(1		)	(57		)	2		34
Net Income	512			547			1,211		1,414
Less: Net Income Attributable to Noncontrolling Interests	3			4			8		7
Net Income Attributable to Duke Energy Corporation	$	509		$	543		$	1,203	$	1,407
Earnings Per Share – Basic and Diluted
Income from continuing operations attributable to Duke Energy Corporation common stockholders
Basic	$	0.74		$	0.87		$	1.74	$	1.96
Diluted	$	0.74		$	0.87		$	1.74	$	1.96
(Loss) Income from discontinued operations attributable to Duke Energy Corporation common stockholders
Basic	$	—		$	(0.09	)	$	—	$	0.05
Diluted	$	—		$	(0.09	)	$	—	$	0.05
Net income attributable to Duke Energy Corporation common stockholders
Basic	$	0.74		$	0.78		$	1.74	$	2.01
Diluted	$	0.74		$	0.78		$	1.74	$	2.01
Weighted average shares outstanding
Basic	689			692			689		700
Diluted	690			692			689		700

See Notes to Condensed Consolidated Financial Statements

6

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Comprehensive Income

(Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
(in millions)	2016			2015			2016			2015
Net Income	$	512		$	547		$	1,211		$	1,414
Other Comprehensive Income (Loss), net of tax
Foreign currency translation adjustments	58			9			107			(116		)
Pension and OPEB adjustments	2			7			2			2
Net unrealized (losses) gains on cash flow hedges	(11		)	9			(25		)	2
Reclassification into earnings from cash flow hedges	—			1			2			5
Unrealized gains (losses) on available-for-sale securities	3			(3		)	7			(3		)
Other Comprehensive Income (Loss), net of tax	52			23			93			(110		)
Comprehensive Income	564			570			1,304			1,304
Less: Comprehensive Income Attributable to Noncontrolling Interests	6			3			12			2
Comprehensive Income Attributable to Duke Energy Corporation	$	558		$	567		$	1,292		$	1,302

See Notes to Condensed Consolidated Financial Statements

7

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	June 30, 2016			December 31, 2015
ASSETS
Current Assets
Cash and cash equivalents	$	676		$	857
Receivables (net of allowance for doubtful accounts of $23 at 2016 and $18 at 2015)	575			703
Receivables of VIEs (net of allowance for doubtful accounts of $56 at 2016 and $53 at 2015)	1,943			1,748
Inventory	3,627			3,810
Regulatory assets (includes $34 related to VIEs at 2016)	825			877
Other	451			327
Total current assets	8,097			8,322
Investments and Other Assets
Investments in equity method unconsolidated affiliates	613			499
Nuclear decommissioning trust funds	5,966			5,825
Goodwill	16,357			16,343
Other	2,972			3,042
Total investments and other assets	25,908			25,709
Property, Plant and Equipment
Cost	115,143			112,826
Accumulated depreciation and amortization	(38,412		)	(37,665		)
Generation facilities to be retired, net	598			548
Net property, plant and equipment	77,329			75,709
Regulatory Assets and Deferred Debits
Regulatory assets (includes $1,194 related to VIEs at 2016)	11,290			11,373
Other	30			43
Total regulatory assets and deferred debits	11,320			11,416
Total Assets	$	122,654		$	121,156
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	2,221		$	2,400
Notes payable and commercial paper	2,312			3,633
Taxes accrued	467			348
Interest accrued	448			430
Current maturities of long-term debt (includes $197 at 2016 and $125 at 2015 related to VIEs)	2,342			2,074
Regulatory liabilities	332			400
Other	1,784			2,115
Total current liabilities	9,906			11,400
Long-Term Debt (includes $3,383 at 2016 and $2,197 at 2015 related to VIEs)	39,931			37,495
Deferred Credits and Other Liabilities
Deferred income taxes	13,038			12,705
Investment tax credits	492			472
Accrued pension and other post-retirement benefit costs	1,044			1,088
Asset retirement obligations	10,231			10,264
Regulatory liabilities	6,334			6,255
Other	1,730			1,706
Total deferred credits and other liabilities	32,869			32,490
Commitments and Contingencies
Equity
Common stock, $0.001 par value, 2 billion shares authorized; 689 million and 688 million shares outstanding at 2016 and 2015, respectively	1			1
Additional paid-in capital	37,984			37,968
Retained earnings	2,627			2,564
Accumulated other comprehensive loss	(717		)	(806		)
Total Duke Energy Corporation stockholders' equity	39,895			39,727
Noncontrolling interests	53			44
Total equity	39,948			39,771
Total Liabilities and Equity	$	122,654		$	121,156

See Notes to Condensed Consolidated Financial Statements

8

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended
	June 30,
(in millions)	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,211		$	1,414
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,868			1,784
Equity component of AFUDC	(87		)	(82		)
Gains on sales of other assets	(18		)	(29		)
Impairment charges	198			37
Deferred income taxes	285			699
Equity in earnings of unconsolidated affiliates	(23		)	(36		)
Accrued pension and other post-retirement benefit costs	8			36
Contributions to qualified pension plans	—			(132		)
Payments for asset retirement obligations	(263		)	(125		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	199			(29		)
Receivables	(57		)	105
Inventory	178			2
Other current assets	(51		)	(161		)
Increase (decrease) in
Accounts payable	(153		)	(288		)
Taxes accrued	216			(29		)
Other current liabilities	(281		)	(145		)
Other assets	(9		)	(63		)
Other liabilities	(15		)	(79		)
Net cash provided by operating activities	3,206			2,879
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(3,393		)	(3,062		)
Investment expenditures	(136		)	(98		)
Acquisitions	—			(29		)
Purchases of available-for-sale securities	(3,033		)	(2,187		)
Proceeds from sales and maturities of available-for-sale securities	3,059			2,200
Net proceeds from the sale of the Disposal Group	—			2,792
Net proceeds from the sales of equity investments and other assets	2			40
Change in restricted cash	(21		)	(3		)
Other	(86		)	53
Net cash used in investing activities	(3,608		)	(294		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	3,514			574
Issuance of common stock related to employee benefit plans	7			16
Payments for the redemption of long-term debt	(795		)	(1,246		)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	500			287
Payments for the redemption of short-term debt with original maturities greater than 90 days	(492		)	(664		)
Notes payable and commercial paper	(1,349		)	12
Distributions to noncontrolling interests	(3		)	(7		)
Dividends paid	(1,140		)	(1,115		)
Repurchase of common shares	—			(1,500		)
Other	(21		)	(18		)
Net cash provided by (used in) financing activities	221			(3,661		)
Net decrease in cash and cash equivalents	(181		)	(1,076		)
Cash and cash equivalents at beginning of period	857			2,036
Cash and cash equivalents at end of period	$	676		$	960
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	670		$	547

See Notes to Condensed Consolidated Financial Statements

9

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

											Accumulated Other Comprehensive Loss
																	Net Unrealized						Total
											Foreign			Net			Gains (Losses)						Duke Energy
	Common				Additional						Currency			Losses on			on Available-			Pension and			Corporation
	Stock		Common		Paid-in			Retained			Translation			Cash Flow			for-Sale-			OPEB			Stockholders'			Noncontrolling			Total
(in millions)	Shares		Stock		Capital			Earnings			Adjustments			Hedges			Securities			Adjustments			Equity			Interests			Equity
Balance at December 31, 2014	707		$	1	$	39,405		$	2,012		$	(439	)	$	(59	)	$	3		$	(48	)	$	40,875		$	24		$	40,899
Net income	—		—		—			1,407			—			—			—			—			1,407			7			1,414
Other comprehensive (loss) income	—		—		—			—			(111		)	7			(3		)	2			(105		)	(5		)	(110		)
Common stock issuances, including dividend reinvestment and employee benefits	1		—		28			—			—			—			—			—			28			—			28
Stock repurchase	(20	)	—		(1,500		)	—			—			—			—			—			(1,500		)	—			(1,500		)
Common stock dividends	—		—		—			(1,115		)	—			—			—			—			(1,115		)	—			(1,115		)
Distributions to noncontrolling interest in subsidiaries	—		—		—			—			—			—			—			—			—			(7		)	(7		)
Other(a)	—		—		—			(10		)	—			—			—			—			(10		)	18			8
Balance at June 30, 2015	688		$	1	$	37,933		$	2,294		$	(550	)	$	(52	)	$	—		$	(46	)	$	39,580		$	37		$	39,617
Balance at December 31, 2015	688		$	1	$	37,968		$	2,564		$	(692	)	$	(50	)	$	(3	)	$	(61	)	$	39,727		$	44		$	39,771
Net income	—		—		—			1,203			—			—			—			—			1,203			8			1,211
Other comprehensive income (loss)	—		—		—			—			103			(23		)	7			2			89			4			93
Common stock issuances, including dividend reinvestment and employee benefits	1		—		16			—			—			—			—			—			16			—			16
Common stock dividends	—		—		—			(1,140		)	—			—			—			—			(1,140		)	—			(1,140		)
Distributions to noncontrolling interest in subsidiaries	—		—		—			—			—			—			—			—			—			(3		)	(3		)
Balance at June 30, 2016	689		$	1	$	37,984		$	2,627		$	(589	)	$	(73	)	$	4		$	(59	)	$	39,895		$	53		$	39,948

(a) The $18 million change in Noncontrolling Interests is primarily related to an acquisition of majority interest in a solar company for an insignificant amount of cash consideration.

See Notes to Condensed Consolidated Financial Statements

10

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Operating Revenues	$	1,675	$	1,707	$	3,415	$	3,608
Operating Expenses
Fuel used in electric generation and purchased power	389		427		810		1,005
Operation, maintenance and other	476		469		988		958
Depreciation and amortization	275		261		534		510
Property and other taxes	71		67		138		137
Total operating expenses	1,211		1,224		2,470		2,610
Operating Income	464		483		945		998
Other Income and Expenses, net	45		41		82		83
Interest Expense	107		106		214		208
Income Before Income Taxes	402		418		813		873
Income Tax Expense	141		153		281		316
Net Income	$	261	$	265	$	532	$	557
Other Comprehensive Income, net of tax
Reclassification into earnings from cash flow hedges	—		—		1		—
Comprehensive Income	$	261	$	265	$	533	$	557

See Notes to Condensed Consolidated Financial Statements

11

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	June 30, 2016			December 31, 2015
ASSETS
Current Assets
Cash and cash equivalents	$	16		$	13
Receivables (net of allowance for doubtful accounts of $2 at 2016 and $3 at 2015)	112			142
Receivables of VIEs (net of allowance for doubtful accounts of $7 at 2016 and 2015)	696			596
Receivables from affiliated companies	71			107
Notes receivable from affiliated companies	252			163
Inventory	1,169			1,276
Regulatory assets	262			305
Other	86			128
Total current assets	2,664			2,730
Investments and Other Assets
Nuclear decommissioning trust funds	3,133			3,050
Other	916			999
Total investments and other assets	4,049			4,049
Property, Plant and Equipment
Cost	40,285			39,398
Accumulated depreciation and amortization	(13,880		)	(13,521		)
Net property, plant and equipment	26,405			25,877
Regulatory Assets and Deferred Debits
Regulatory assets	2,856			2,766
Other	3			4
Total regulatory assets and deferred debits	2,859			2,770
Total Assets	$	35,977		$	35,426
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	565		$	753
Accounts payable to affiliated companies	173			229
Taxes accrued	137			25
Interest accrued	108			95
Current maturities of long-term debt	468			356
Regulatory liabilities	91			39
Other	400			519
Total current liabilities	1,942			2,016
Long-Term Debt	8,592			7,711
Long-Term Debt Payable to Affiliated Companies	300			300
Deferred Credits and Other Liabilities
Deferred income taxes	6,472			6,146
Investment tax credits	196			199
Accrued pension and other post-retirement benefit costs	96			107
Asset retirement obligations	3,910			3,918
Regulatory liabilities	2,885			2,802
Other	645			621
Total deferred credits and other liabilities	14,204			13,793
Commitments and Contingencies
Equity
Member's equity	10,949			11,617
Accumulated other comprehensive loss	(10		)	(11		)
Total equity	10,939			11,606
Total Liabilities and Equity	$	35,977		$	35,426

See Notes to Condensed Consolidated Financial Statements

12

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended
	June 30,
(in millions)	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	532		$	557
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	673			670
Equity component of AFUDC	(48		)	(48		)
Deferred income taxes	273			184
Accrued pension and other post-retirement benefit costs	2			7
Contributions to qualified pension plans	—			(42		)
Payments for asset retirement obligations	(118		)	(60		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3			—
Receivables	(48		)	45
Receivables from affiliated companies	36			(31		)
Inventory	102			(31		)
Other current assets	24			34
Increase (decrease) in
Accounts payable	(226		)	(200		)
Accounts payable to affiliated companies	(56		)	(13		)
Taxes accrued	188			73
Other current liabilities	28			(33		)
Other assets	22			58
Other liabilities	(14		)	(49		)
Net cash provided by operating activities	1,373			1,121
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,031		)	(954		)
Purchases of available-for-sale securities	(1,395		)	(1,410		)
Proceeds from sales and maturities of available-for-sale securities	1,395			1,410
Notes receivable from affiliated companies	(89		)	(550		)
Other	(41		)	8
Net cash used in investing activities	(1,161		)	(1,496		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	992			496
Payments for the redemption of long-term debt	(1		)	—
Distributions to parent	(1,200		)	(100		)
Other	—			(6		)
Net cash (used in) provided by financing activities	(209		)	390
Net increase in cash and cash equivalents	3			15
Cash and cash equivalents at beginning of period	13			13
Cash and cash equivalents at end of period	$	16		$	28
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	228		$	160

See Notes to Condensed Consolidated Financial Statements

13

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

				Accumulated Other
				Comprehensive Loss
							Net Unrealized
				Net Losses on			Losses on
	Member's			Cash Flow			Available-for-			Total
(in millions)	Equity			Hedges			Sale Securities			Equity
Balance at December 31, 2014	$	10,937		$	(12	)	$	(1	)	$	10,924
Net income	557			—			—			557
Distributions to parent	(100		)	—			—			(100		)
Balance at June 30, 2015	$	11,394		$	(12	)	$	(1	)	$	11,381
Balance at December 31, 2015	$	11,617		$	(11	)	$	—		$	11,606
Net income	532			—			—			532
Other comprehensive income	—			1			—			1
Distributions to parent	(1,200		)	—			—			(1,200		)
Balance at June 30, 2016	$	10,949		$	(10	)	$	—		$	10,939

See Notes to Condensed Consolidated Financial Statements

14

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended					Six Months Ended
	June 30,					June 30,
(in millions)	2016		2015			2016		2015
Operating Revenues	$	2,348	$	2,476		$	4,680	$	5,012
Operating Expenses
Fuel used in electric generation and purchased power	852		1,003			1,712		2,035
Operation, maintenance and other	525		568			1,117		1,133
Depreciation and amortization	296		283			586		570
Property and other taxes	120		124			239		235
Impairment charges	1		—			3		—
Total operating expenses	1,794		1,978			3,657		3,973
Gains on Sales of Other Assets and Other, net	6		6			12		14
Operating Income	560		504			1,035		1,053
Other Income and Expenses, net	28		19			48		46
Interest Expense	160		166			320		334
Income From Continuing Operations Before Income Taxes	428		357			763		765
Income Tax Expense From Continuing Operations	154		140			277		284
Income From Continuing Operations	274		217			486		481
Loss From Discontinued Operations, net of tax	—		—			—		(1		)
Net Income	274		217			486		480
Less: Net Income Attributable to Noncontrolling Interests	2		2			5		5
Net Income Attributable to Parent	$	272	$	215		$	481	$	475
Net Income	$	274	$	217		$	486	$	480
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	1		1			2		2
Reclassification into earnings from cash flow hedges	2		1			3		(1		)
Unrealized (losses) gains on available-for-sale securities	—		(1		)	1		(1		)
Other Comprehensive Income, net of tax	3		1			6		—
Comprehensive Income	277		218			492		480
Less: Comprehensive Income Attributable to Noncontrolling Interests	2		2			5		5
Comprehensive Income Attributable to Parent	$	275	$	216		$	487	$	475

See Notes to Condensed Consolidated Financial Statements

15

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	June 30, 2016			December 31, 2015
ASSETS
Current Assets
Cash and cash equivalents	$	34		$	44
Receivables (net of allowance for doubtful accounts of $6 at 2016 and 2015)	100			151
Receivables of VIEs (net of allowance for doubtful accounts of $8 at 2016 and 2015)	776			658
Receivables from affiliated companies	11			375
Inventory	1,725			1,751
Regulatory assets (includes $34 related to VIEs at 2016)	322			362
Other	168			156
Total current assets	3,136			3,497
Investments and Other Assets
Nuclear decommissioning trust funds	2,834			2,775
Goodwill	3,655			3,655
Other	852			834
Total investments and other assets	7,341			7,264
Property, Plant and Equipment
Cost	43,720			42,666
Accumulated depreciation and amortization	(15,087		)	(14,867		)
Generation facilities to be retired, net	506			548
Net property, plant and equipment	29,139			28,347
Regulatory Assets and Deferred Debits
Regulatory assets (includes $1,194 related to VIEs at 2016)	5,298			5,435
Other	4			5
Total regulatory assets and deferred debits	5,302			5,440
Total Assets	$	44,918		$	44,548
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	690		$	722
Accounts payable to affiliated companies	232			311
Notes payable to affiliated companies	916			1,308
Taxes accrued	162			53
Interest accrued	185			195
Current maturities of long-term debt (includes $35 related to VIEs at 2016)	300			315
Regulatory liabilities	166			286
Other	702			891
Total current liabilities	3,353			4,081
Long-Term Debt (includes $1,768 at 2016 and $479 at 2015 related to VIEs)	15,036			13,999
Long-Term Debt Payable to Affiliated Companies	150			150
Deferred Credits and Other Liabilities
Deferred income taxes	5,044			4,790
Accrued pension and other post-retirement benefit costs	519			536
Asset retirement obligations	5,386			5,369
Regulatory liabilities	2,409			2,387
Other	328			383
Total deferred credits and other liabilities	13,686			13,465
Commitments and Contingencies
Equity
Common stock, $0.01 par value, 100 shares authorized and outstanding at 2016 and 2015	—			—
Additional paid-in capital	8,092			8,092
Retained earnings	4,661			4,831
Accumulated other comprehensive loss	(42		)	(48		)
Total Progress Energy, Inc. stockholders' equity	12,711			12,875
Noncontrolling interests	(18		)	(22		)
Total equity	12,693			12,853
Total Liabilities and Equity	$	44,918		$	44,548

See Notes to Condensed Consolidated Financial Statements

16

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended
	June 30,
(in millions)	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	486		$	480
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	696			648
Equity component of AFUDC	(30		)	(26		)
Gains on sales of other assets	(15		)	(14		)
Impairment charges	3			—
Deferred income taxes	285			358
Accrued pension and other post-retirement benefit costs	(12		)	(3		)
Contributions to qualified pension plans	—			(42		)
Payments for asset retirement obligations	(126		)	(61		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	32			5
Receivables	(66		)	(103		)
Receivables from affiliated companies	306			(55		)
Inventory	25			62
Other current assets	45			215
Increase (decrease) in
Accounts payable	(26		)	(182		)
Accounts payable to affiliated companies	(79		)	68
Taxes accrued	90			94
Other current liabilities	(162		)	(9		)
Other assets	(72		)	(70		)
Other liabilities	15			(32		)
Net cash provided by operating activities	1,395			1,333
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,441		)	(1,170		)
Purchases of available-for-sale securities	(1,570		)	(562		)
Proceeds from sales and maturities of available-for-sale securities	1,594			624
Proceeds from insurance	58			—
Notes receivable from affiliated companies	—			220
Change in restricted cash	(6		)	—
Other	(14		)	4
Net cash used in investing activities	(1,379		)	(884		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,338			—
Payments for the redemption of long-term debt	(320		)	(549		)
Notes payable to affiliated companies	(392		)	110
Distributions to noncontrolling interests	(1		)	(4		)
Dividends to parent	(651		)	—
Other	—			(3		)
Net cash used in financing activities	(26		)	(446		)
Net (decrease) increase in cash and cash equivalents	(10		)	3
Cash and cash equivalents at beginning of period	44			42
Cash and cash equivalents at end of period	$	34		$	45
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	288		$	271

See Notes to Condensed Consolidated Financial Statements

17

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

								Accumulated Other Comprehensive Loss
								Net			Net Unrealized						Total Progress
			Additional					Losses on			Gains on			Pension and			Energy, Inc.
	Common		Paid-in		Retained			Cash Flow			Available-for-			OPEB			Stockholders'			Noncontrolling			Total
(in millions)	Stock		Capital		Earnings			Hedges			Sale Securities			Adjustments			Equity			Interests			Equity
Balance at December 31, 2014	$	—	$	7,467	$	3,782		$	(35	)	$	1		$	(7	)	$	11,208		$	(32	)	$	11,176
Net income	—		—		475			—			—			—			475			5			480
Other comprehensive (loss) income	—		—		—			(1		)	(1		)	2			—			—			—
Distributions to noncontrolling interests	—		—		—			—			—			—			—			(4		)	(4		)
Other	—		—		(2		)	—			—			—			(2		)	4			2
Balance at June 30, 2015	$	—	$	7,467	$	4,255		$	(36	)	$	—		$	(5	)	$	11,681		$	(27	)	$	11,654
Balance at December 31, 2015	$	—	$	8,092	$	4,831		$	(31	)	$	—		$	(17	)	$	12,875		$	(22	)	$	12,853
Net income	—		—		481			—			—			—			481			5			486
Other comprehensive income	—		—		—			3			1			2			6			—			6
Distributions to noncontrolling interests	—		—		—			—			—			—			—			(1		)	(1		)
Dividends to parent	—		—		(651		)	—			—			—			(651		)	—			(651		)
Balance at June 30, 2016	$	—	$	8,092	$	4,661		$	(28	)	$	1		$	(15	)	$	12,711		$	(18	)	$	12,693

See Notes to Condensed Consolidated Financial Statements

18

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Operating Revenues	$	1,213	$	1,193	$	2,520	$	2,642
Operating Expenses
Fuel used in electric generation and purchased power	424		449		872		1,024
Operation, maintenance and other	321		362		707		737
Depreciation and amortization	175		163		350		315
Property and other taxes	38		35		79		67
Total operating expenses	958		1,009		2,008		2,143
Gains on Sales of Other Assets and Other, net	—		—		1		1
Operating Income	255		184		513		500
Other Income and Expenses, net	12		15		29		35
Interest Expense	64		56		127		116
Income Before Income Taxes	203		143		415		419
Income Tax Expense	72		58		147		151
Net Income and Comprehensive Income	$	131	$	85	$	268	$	268

See Notes to Condensed Consolidated Financial Statements

19

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	June 30, 2016			December 31, 2015
ASSETS
Current Assets
Cash and cash equivalents	$	8		$	15
Receivables (net of allowance for doubtful accounts of $4 at 2016 and 2015)	35			87
Receivables of VIEs (net of allowance for doubtful accounts of $5 at 2016 and 2015)	421			349
Receivables from affiliated companies	9			16
Inventory	1,068			1,088
Regulatory assets	187			264
Other	35			121
Total current assets	1,763			1,940
Investments and Other Assets
Nuclear decommissioning trust funds	2,110			2,035
Other	509			486
Total investments and other assets	2,619			2,521
Property, Plant and Equipment
Cost	27,771			27,313
Accumulated depreciation and amortization	(10,350		)	(10,141		)
Generation facilities to be retired, net	506			548
Net property, plant and equipment	17,927			17,720
Regulatory Assets and Deferred Debits
Regulatory assets	2,744			2,710
Other	2			3
Total regulatory assets and deferred debits	2,746			2,713
Total Assets	$	25,055		$	24,894
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	300		$	399
Accounts payable to affiliated companies	134			190
Notes payable to affiliated companies	78			209
Taxes accrued	71			15
Interest accrued	96			96
Current maturities of long-term debt	252			2
Regulatory liabilities	84			85
Other	314			412
Total current liabilities	1,329			1,408
Long-Term Debt	6,163			6,366
Long-Term Debt Payable to Affiliated Companies	150			150
Deferred Credits and Other Liabilities
Deferred income taxes	3,167			3,027
Investment tax credits	152			132
Accrued pension and other post-retirement benefit costs	249			262
Asset retirement obligations	4,594			4,567
Regulatory liabilities	1,901			1,878
Other	23			45
Total deferred credits and other liabilities	10,086			9,911
Commitments and Contingencies
Equity
Member's Equity	7,327			7,059
Total equity	7,327			7,059
Total Liabilities and Equity	$	25,055		$	24,894

See Notes to Condensed Consolidated Financial Statements

20

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended
	June 30,
(in millions)	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	268		$	268
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	451			389
Equity component of AFUDC	(20		)	(23		)
Gains on sales of other assets	(3		)	(1		)
Deferred income taxes	172			177
Accrued pension and other post-retirement benefit costs	(16		)	(7		)
Contributions to qualified pension plans	—			(21		)
Payments for asset retirement obligations	(100		)	(32		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(1		)	(3		)
Receivables	(19		)	(64		)
Receivables from affiliated companies	7			6
Inventory	20			53
Other current assets	131			156
Increase (decrease) in
Accounts payable	(28		)	(128		)
Accounts payable to affiliated companies	(56		)	62
Taxes accrued	56			66
Other current liabilities	(12		)	(15		)
Other assets	(26		)	(31		)
Other liabilities	(6		)	(21		)
Net cash provided by operating activities	818			831
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(704		)	(699		)
Purchases of available-for-sale securities	(1,299		)	(319		)
Proceeds from sales and maturities of available-for-sale securities	1,284			301
Notes receivable from affiliated companies	—			237
Other	(19		)	6
Net cash used in investing activities	(738		)	(474		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	59			—
Payments for the redemption of long-term debt	(15		)	(544		)
Notes payable to affiliated companies	(131		)	192
Other	—			(1		)
Net cash used in financing activities	(87		)	(353		)
Net (decrease) increase in cash and cash equivalents	(7		)	4
Cash and cash equivalents at beginning of period	15			9
Cash and cash equivalents at end of period	$	8		$	13
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	73		$	135

See Notes to Condensed Consolidated Financial Statements

21

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Common		Retained		Member's		Total
(in millions)	Stock		Earnings		Equity		Equity
Balance at December 31, 2014	$	2,159	$	3,708	$	—	$	5,867
Net income	—		268		—		268
Balance at June 30, 2015	$	2,159	$	3,976	$	—	$	6,135
Balance at December 31, 2015	$	—	$	—	$	7,059	$	7,059
Net income	—		—		268		268
Balance at June 30, 2016	$	—	$	—	$	7,327	$	7,327

See Notes to Condensed Consolidated Financial Statements

22

PART I

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Operating Revenues	$	1,133	$	1,281	$	2,157	$	2,367
Operating Expenses
Fuel used in electric generation and purchased power	429		554		841		1,011
Operation, maintenance and other	199		202		404		390
Depreciation and amortization	122		122		236		256
Property and other taxes	82		88		160		168
Impairment charges	1		—		3		—
Total operating expenses	833		966		1,644		1,825
Operating Income	300		315		513		542
Other Income and Expenses, net	14		4		19		10
Interest Expense	40		50		81		99
Income Before Income Taxes	274		269		451		453
Income Tax Expense	103		104		170		175
Net Income	$	171	$	165	$	281	$	278
Other Comprehensive Income, net of tax
Unrealized gains on investments in available-for-sale securities	—		$	—	1		—
Comprehensive Income	$	171	$	165	$	282	$	278

See Notes to Condensed Consolidated Financial Statements

23

PART I

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	June 30, 2016			December 31, 2015
ASSETS
Current Assets
Cash and cash equivalents	$	8		$	8
Receivables (net of allowance for doubtful accounts of $2 at 2016 and 2015)	64			60
Receivables of VIEs (net of allowance for doubtful accounts of $3 at 2016 and 2015)	355			308
Receivables from affiliated companies	3			84
Inventory	657			663
Regulatory assets (includes $34 related to VIEs at 2016)	135			98
Other	43			21
Total current assets	1,265			1,242
Investments and Other Assets
Nuclear decommissioning trust funds	724			740
Other	288			292
Total investments and other assets	1,012			1,032
Property, Plant and Equipment
Cost	15,938			15,343
Accumulated depreciation and amortization	(4,730		)	(4,720		)
Net property, plant and equipment	11,208			10,623
Regulatory Assets and Deferred Debits
Regulatory assets (includes $1,194 related to VIEs at 2016)	2,553			2,725
Other	3			2
Total regulatory assets and deferred debits	2,556			2,727
Total Assets	$	16,041		$	15,624
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	390		$	322
Accounts payable to affiliated companies	100			116
Notes payable to affiliated companies	406			813
Taxes accrued	156			132
Interest accrued	40			43
Current maturities of long-term debt (includes $35 related to VIEs at 2016)	48			13
Regulatory liabilities	82			200
Other	361			452
Total current liabilities	1,583			2,091
Long-Term Debt (includes $1,468 at 2016 and $225 at 2015 related to VIEs)	5,492			4,253
Deferred Credits and Other Liabilities
Deferred income taxes	2,571			2,460
Accrued pension and other post-retirement benefit costs	238			242
Asset retirement obligations	792			802
Regulatory liabilities	508			509
Other	103			146
Total deferred credits and other liabilities	4,212			4,159
Commitments and Contingencies
Equity
Member's equity	4,753			5,121
Accumulated other comprehensive income	1			—
Total equity	4,754			5,121
Total Liabilities and Equity	$	16,041		$	15,624

See Notes to Condensed Consolidated Financial Statements

24

PART I

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended
	June 30,
(in millions)	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	281		$	278
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	239			258
Equity component of AFUDC	(9		)	(2		)
Impairment charges	3			—
Deferred income taxes	113			237
Accrued pension and other post-retirement benefit costs	1			3
Contributions to qualified pension plans	—			(21		)
Payments for asset retirement obligations	(25		)	(28		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	34			5
Receivables	(49		)	(40		)
Receivables from affiliated companies	23			(53		)
Inventory	5			10
Other current assets	(13		)	10
Increase (decrease) in
Accounts payable	3			(53		)
Accounts payable to affiliated companies	(16		)	3
Taxes accrued	5			65
Other current liabilities	(142		)	5
Other assets	(47		)	(44		)
Other liabilities	20			(19		)
Net cash provided by operating activities	426			614
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(737		)	(471		)
Purchases of available-for-sale securities	(271		)	(243		)
Proceeds from sales and maturities of available-for-sale securities	310			323
Proceeds from insurance	58			—
Change in restricted cash	(6		)	—
Other	5			1
Net cash used in investing activities	(641		)	(390		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,278			—
Payments for the redemption of long-term debt	(5		)	(5		)
Notes payable to affiliated companies	(407		)	137
Dividends to parent	—			(350		)
Distributions to parent	(649		)	—
Other	(2		)	(1		)
Net cash provided by (used in) financing activities	215			(219		)
Net increase in cash and cash equivalents	—			5
Cash and cash equivalents at beginning of period	8			8
Cash and cash equivalents at end of period	$	8		$	13
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	215		$	136

See Notes to Condensed Consolidated Financial Statements

25

PART I

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

									Accumulated
									Other
									Comprehensive
									Income
									Net Unrealized
									Gains on
	Common		Retained			Member's			Available-for-Sale		Total
(in millions)	Stock		Earnings			Equity			Securities		Equity
Balance at December 31, 2014	$	1,762	$	3,460		$	—		$	—	$	5,222
Net income	—		278			—			—		278
Dividends to parent	—		(350		)	—			—		(350		)
Balance at June 30, 2015	$	1,762	$	3,388		$	—		$	—	$	5,150
Balance at December 31, 2015	$	—	$	—		$	5,121		$	—	$	5,121
Net income	—		—			281			—		281
Other comprehensive income	—		—			—			1		1
Distributions to parent	—		—			(649		)	—		(649		)
Balance at June 30, 2016	$	—	$	—		$	4,753		$	1	$	4,754

See Notes to Condensed Consolidated Financial Statements

26

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended					Six Months Ended
	June 30,					June 30,
(in millions)	2016		2015			2016		2015
Operating Revenues
Regulated electric	$	323	$	299		$	663	$	638
Nonregulated electric and other	6		9			12		23
Regulated natural gas	99		97			269		330
Total operating revenues	428		405			944		991
Operating Expenses
Fuel used in electric generation and purchased power – regulated	100		107			211		222
Fuel used in electric generation and purchased power – nonregulated	13		12			23		26
Cost of natural gas	9		12			58		109
Operation, maintenance and other	122		118			241		246
Depreciation and amortization	64		58			125		115
Property and other taxes	65		57			136		127
Total operating expenses	373		364			794		845
Gains on Sales of Other Assets and Other, net	—		2			1		8
Operating Income	55		43			151		154
Other Income and Expenses, net	1		(5		)	3		(2		)
Interest Expense	21		18			41		38
Income From Continuing Operations Before Income Taxes	35		20			113		114
Income Tax Expense From Continuing Operations	12		7			33		42
Income From Continuing Operations	23		13			80		72
Income (Loss) From Discontinued Operations, net of tax	—		(65		)	2		25
Net Income (Loss) and Comprehensive Income (Loss)	$	23	$	(52	)	$	82	$	97

See Notes to Condensed Consolidated Financial Statements

27

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	June 30, 2016			December 31, 2015
ASSETS
Current Assets
Cash and cash equivalents	$	10		$	14
Receivables (net of allowance for doubtful accounts of $2 at 2016 and 2015)	63			66
Receivables from affiliated companies	35			84
Notes receivable from affiliated companies	186			—
Inventory	110			105
Regulatory assets	54			36
Other	65			110
Total current assets	523			415
Investments and Other Assets
Goodwill	920			920
Other	16			20
Total investments and other assets	936			940
Property, Plant and Equipment
Cost	7,906			7,750
Accumulated depreciation and amortization	(2,536		)	(2,507		)
Net property, plant and equipment	5,370			5,243
Regulatory Assets and Deferred Debits
Regulatory assets	472			497
Other	2			2
Total regulatory assets and deferred debits	474			499
Total Assets	$	7,303		$	7,097
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	218		$	207
Accounts payable to affiliated companies	76			53
Notes payable to affiliated companies	—			103
Taxes accrued	108			171
Interest accrued	19			18
Current maturities of long-term debt	54			106
Regulatory liabilities	18			12
Other	82			153
Total current liabilities	575			823
Long-Term Debt	1,808			1,467
Long-Term Debt Payable to Affiliated Companies	25			25
Deferred Credits and Other Liabilities
Deferred income taxes	1,476			1,407
Accrued pension and other post-retirement benefit costs	52			56
Asset retirement obligations	125			125
Regulatory liabilities	241			245
Other	160			165
Total deferred credits and other liabilities	2,054			1,998
Commitments and Contingencies
Equity
Common stock, $8.50 par value, 120,000,000 shares authorized; 89,663,086 shares outstanding at 2016 and 2015	762			762
Additional paid-in capital	2,695			2,720
Accumulated deficit	(616		)	(698		)
Total equity	2,841			2,784
Total Liabilities and Equity	$	7,303		$	7,097

See Notes to Condensed Consolidated Financial Statements

28

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended
	June 30,
(in millions)	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	82		$	97
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	127			117
Equity component of AFUDC	(2		)	(2		)
Gains on sales of other assets and other, net	(1		)	(8		)
Impairment charges	—			40
Deferred income taxes	68			62
Accrued pension and other post-retirement benefit costs	3			4
Contributions to qualified pension plans	—			(1		)
Payments for asset retirement obligations	(3		)	(1		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(2		)	(12		)
Receivables	3			6
Receivables from affiliated companies	49			46
Inventory	(5		)	3
Other current assets	49			32
Increase (decrease) in
Accounts payable	8			(12		)
Accounts payable to affiliated companies	23			19
Taxes accrued	(68		)	(68		)
Other current liabilities	(66		)	99
Other assets	(8		)	19
Other liabilities	(9		)	(52		)
Net cash provided by operating activities	248			388
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(214		)	(166		)
Notes receivable from affiliated companies	(186		)	130
Other	(13		)	(4		)
Net cash used in investing activities	(413		)	(40		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	341			—
Payments for the redemption of long-term debt	(52		)	(152		)
Notes payable to affiliated companies	(103		)	(193		)
Dividends to parent	(25		)	—
Other	—			(1		)
Net cash provided by (used in) financing activities	161			(346		)
Net (decrease) increase in cash and cash equivalents	(4		)	2
Cash and cash equivalents at beginning of period	14			20
Cash and cash equivalents at end of period	$	10		$	22
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	30		$	19
Distribution of membership interest of Duke Energy SAM, LLC to parent	—			1,912

See Notes to Condensed Consolidated Financial Statements

29

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

			Additional
	Common		Paid-in			Accumulated			Total
(in millions)	Stock		Capital			Deficit			Equity
Balance at December 31, 2014	$	762	$	4,782		$	(870	)	$	4,674
Net Income	—		—			97			97
Distribution of membership interest of Duke Energy SAM, LLC to parent	—		(1,912		)	—			(1,912		)
Balance at June 30, 2015	$	762	$	2,870		$	(773	)	$	2,859
Balance at December 31, 2015	$	762	$	2,720		$	(698	)	$	2,784
Net income	—		—			82			82
Dividends to parent	—		(25		)	—			(25		)
Balance at June 30, 2016	$	762	$	2,695		$	(616	)	$	2,841

See Notes to Condensed Consolidated Financial Statements

30

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016			2015
Operating Revenues	$	702	$	686	$	1,416		$	1,474
Operating Expenses
Fuel used in electric generation and purchased power	220		235		448			529
Operation, maintenance and other	189		180		351			361
Depreciation and amortization	97		107		222			211
Property and other taxes	22		19		45			18
Total operating expenses	528		541		1,066			1,119
Gain on Sale of Other Assets and Other, net	—		1		—			1
Operating Income	174		146		350			356
Other Income and Expenses, net	6		4		10			9
Interest Expense	47		43		91			88
Income Before Income Taxes	133		107		269			277
Income Tax Expense	48		39		89			101
Net Income	$	85	$	68	$	180		$	176
Other Comprehensive Loss, net of tax
Reclassification into earnings from cash flow hedges	—		—		(1		)	(1		)
Comprehensive Income	$	85	$	68	$	179		$	175

See Notes to Condensed Consolidated Financial Statements

31

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	June 30, 2016			December 31, 2015
ASSETS
Current Assets
Cash and cash equivalents	$	12		$	9
Receivables (net of allowance for doubtful accounts of $1 at 2016 and 2015)	87			96
Receivables from affiliated companies	60			71
Notes receivable from affiliated companies	147			83
Inventory	508			570
Regulatory assets	115			102
Other	45			15
Total current assets	974			946
Investments and Other Assets	221			212
Property, Plant and Equipment
Cost	13,677			14,007
Accumulated depreciation and amortization	(4,219		)	(4,484		)
Generation facilities to be retired, net	93			—
Net property, plant and equipment	9,551			9,523
Regulatory Assets and Deferred Debits
Regulatory assets	825			716
Other	2			2
Total regulatory assets and deferred debits	827			718
Total Assets	$	11,573		$	11,399
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	146		$	189
Accounts payable to affiliated companies	87			83
Taxes accrued	40			89
Interest accrued	59			56
Current maturities of long-term debt	221			547
Regulatory liabilities	57			62
Other	101			97
Total current liabilities	711			1,123
Long-Term Debt	3,566			3,071
Long-Term Debt Payable to Affiliated Companies	150			150
Deferred Credits and Other Liabilities
Deferred income taxes	1,732			1,657
Investment tax credits	137			138
Accrued pension and other post-retirement benefit costs	74			80
Asset retirement obligations	520			525
Regulatory liabilities	745			754
Other	72			65
Total deferred credits and other liabilities	3,280			3,219
Commitments and Contingencies
Equity
Member's equity	3,866			—
Common stock, no par; $0.01 stated value, 60,000,000 shares authorized; 53,913,701 shares outstanding at 2015	—			1
Additional paid-in capital	—			1,384
Retained earnings	—			2,450
Accumulated other comprehensive income	—			1
Total equity	3,866			3,836
Total Liabilities and Equity	$	11,573		$	11,399

See Notes to Condensed Consolidated Financial Statements

32

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended
	June 30,
(in millions)	2016			2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	180		$	176
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	223			214
Equity component of AFUDC	(7		)	(6		)
Gain on sale of other assets and other, net	—			(1		)
Deferred income taxes	36			232
Accrued pension and other post-retirement benefit costs	4			6
Contributions to qualified pension plans	—			(9		)
Payments for asset retirement obligations	(16		)	(3		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	—			(2		)
Receivables	12			(1		)
Receivables from affiliated companies	11			6
Inventory	62			(42		)
Other current assets	(19		)	87
Increase (decrease) in
Accounts payable	(22		)	26
Accounts payable to affiliated companies	4			2
Taxes accrued	(42		)	(21		)
Other current liabilities	(60		)	5
Other assets	(29		)	(31		)
Other liabilities	44			(43		)
Net cash provided by operating activities	381			595
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(325		)	(380		)
Purchases of available-for-sale securities	(7		)	(4		)
Proceeds from sales and maturities of available-for-sale securities	5			3
Proceeds from the sales of other assets	—			14
Notes receivable from affiliated companies	(64		)	(25		)
Other	(6		)	25
Net cash used in investing activities	(397		)	(367		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	495			—
Payments for the redemption of long-term debt	(326		)	—
Notes payable to affiliated companies	—			(71		)
Dividends to parent	—			(150		)
Distributions to parent	(149		)	—
Other	(1		)	(1		)
Net cash provided by (used in) financing activities	19			(222		)
Net increase in cash and cash equivalents	3			6
Cash and cash equivalents at beginning of period	9			6
Cash and cash equivalents at end of period	$	12		$	12
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	43		$	46

See Notes to Condensed Consolidated Financial Statements

33

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

													Accumulated
													Other
													Comprehensive
													Income
				Additional									Net Gains on
	Common			Paid-in			Retained			Member's			Cash Flow			Total
(in millions)	Stock			Capital			Earnings			Equity			Hedges			Equity
Balance at December 31, 2014	$	1		$	1,384		$	2,460		$	—		$	3		$	3,848
Net income	—			—			176			—			—			176
Other comprehensive loss	—			—			—			—			(1		)	(1		)
Dividends to parent	—			—			(150		)	—			—			(150		)
Balance at June 30, 2015	$	1		$	1,384		$	2,486		$	—		$	2		$	3,873
Balance at December 31, 2015	$	1		$	1,384		$	2,450		$	—		$	1		$	3,836
Net income	—			—			—			180			—			180
Other comprehensive loss	—			—			—			—			(1		)	(1		)
Distributions to parent	—			—			—			(149		)	—			(149		)
Transfer to Member's Equity	(1		)	(1,384		)	(2,450		)	3,835			—			—
Balance at June 30, 2016	$	—		$	—		$	—		$	3,866		$	—		$	3,866

See Notes to Condensed Consolidated Financial Statements

34

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

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. Tables within the notes may not sum across due to Progress Energy's consolidation of Duke Energy Progress, Duke Energy Florida and other subsidiaries that are not registrants. In addition, the Duke Energy amounts include balances from subsidiaries that are not registrants.

Applicable Notes

Registrant

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

17

Duke Energy Corporation

•

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Duke Energy Carolinas, LLC

•

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Progress Energy, Inc.

•

•

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•

•

Duke Energy Progress, LLC

•

•

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•

•

Duke Energy Florida, LLC

•

•

•

•

•

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•

•

•

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Duke Energy Ohio, Inc.

•

•

•

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Duke Energy Indiana, LLC

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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, LLC (Duke Energy Progress); Duke Energy Florida, LLC (Duke Energy Florida); Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, LLC (Duke Energy Indiana, formerly Duke Energy Indiana, Inc.). 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 (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 primarily engaged in the transmission and distribution of electricity in portions of Ohio and Kentucky, the generation and sale of electricity in portions of Kentucky, and the transportation and sale of natural gas in portions of Ohio and Kentucky. Duke Energy Ohio conducts competitive auctions for retail electricity supply in Ohio whereby the energy price is recovered from retail customers and recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Operations in Kentucky are conducted through its wholly owned subsidiary, Duke Energy Kentucky, Inc. (Duke Energy Kentucky). References herein to Duke Energy Ohio collectively 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. On April 2, 2015, Duke Energy completed the sale of its nonregulated Midwest generation business, which sold power into wholesale energy markets, to a subsidiary of Dynegy Inc. (Dynegy). See Note 2 for additional information. Substantially all of Duke Energy Ohio’s operations that remain after the sale qualify for regulatory accounting.

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 FERC. Substantially all of Duke Energy Indiana’s operations qualify for regulatory accounting. On January 1, 2016, Duke Energy Indiana, an Indiana corporation, converted into an Indiana limited liability company.

35

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

BASIS OF PRESENTATION

Duke Energy completed the sale of Duke Energy Ohio's nonregulated Midwest generation business and Duke Energy Retail Sales (collectively, the Disposal Group), a retail sales business owned by Duke Energy, to Dynegy on April 2, 2015. The results of operations of these businesses prior to the date of sale have been classified as Discontinued Operations on the Condensed Consolidated Statements of Operations. Duke Energy has elected to present cash flows of discontinued operations combined with cash flows of continuing operations. Unless otherwise noted, the notes to these Condensed Consolidated Financial Statements exclude amounts related to discontinued operations. See Note 2 for additional information.

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. Since 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, 2015.

The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to Combined Notes to Condensed Consolidated Financial Statements. However, none of the registrants make any representations as to information related solely to Duke Energy or the subsidiaries of Duke Energy other than itself.

These Condensed Consolidated Financial Statements, in the opinion of the respective companies’ management, reflect all normal recurring adjustments 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 natural gas are recognized when service is provided or the product is delivered. 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, customer mix, average price in effect for customer classes, timing of rendering customer bills and meter reading schedules.

Unbilled revenues, which are included within Receivables and Receivables of variable interest entities (VIEs) on the Condensed Consolidated Balance Sheets, are presented in the following table.

(in millions)	June 30, 2016		December 31, 2015
Duke Energy	$	840	$	748
Duke Energy Carolinas	330		283
Progress Energy	209		172
Duke Energy Progress	104		102
Duke Energy Florida	105		70
Duke Energy Ohio	2		3
Duke Energy Indiana	38		31

Additionally, Duke Energy Ohio and Duke Energy Indiana sell nearly all of their retail accounts receivable to an affiliate, Cinergy Receivables Company, LLC (CRC), on a revolving basis. These transfers of receivables are accounted for as sales and include receivables for unbilled revenues. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 12 for further information. These receivables for unbilled revenues are shown in the table below.

(in millions)	June 30, 2016		December 31, 2015
Duke Energy Ohio	$	70	$	71
Duke Energy Indiana	109		97

36

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

AMOUNTS ATTRIBUTABLE TO CONTROLLING INTERESTS

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

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, excise taxes are accounted for net.

Excise taxes accounted for on a gross basis as both operating revenues and property and other taxes on the Condensed Consolidated Statements of Operations were as follows.

	Three Months Ended June 30,				Six Months Ended June 30,
(in millions)	2016		2015		2016		2015
Duke Energy	$	87	$	97	$	178	$	197
Duke Energy Carolinas	7		9		15		18
Progress Energy	50		57		96		106
Duke Energy Progress	4		4		9		8
Duke Energy Florida	46		53		87		98
Duke Energy Ohio	22		23		51		55
Duke Energy Indiana	8		8		16		18

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2016 and 2015 had no material impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. The following accounting standard was adopted by the Duke Energy Registrants during 2015.

Balance Sheet Presentation of Debt Issuance Costs. In April and August of 2015, the Financial Accounting Standards Board (FASB) issued revised accounting guidance for the presentation of debt issuance costs. The core principle of this revised accounting guidance is that debt issuance costs are not assets, but adjustments to the carrying cost of debt. For Duke Energy, this revised accounting guidance was adopted retrospectively.

The implementation of this accounting standard resulted in a reduction of Other within Regulatory Assets and Deferred Debits and in Long-Term Debt of $192 million and $170 million on the Condensed Consolidated Balance Sheets as of June 30, 2016, and December 31, 2015, respectively.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of June 30, 2016.

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. The amendments in this update also require disclosure of sufficient information to allow users to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.

For Duke Energy, the revised accounting guidance is effective for interim and annual periods beginning January 1, 2018. The guidance can be applied retrospectively to all prior reporting periods presented or retrospectively with a cumulative effect as of the initial date of application. Duke Energy is currently evaluating the requirements. The ultimate impact of the new standard has not yet been determined.

Leases. In February 2016, the FASB issued revised accounting guidance for leases. The core principle of this guidance is that a lessee should recognize the assets and liabilities that arise from leases on the balance sheet.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2019, although it can be early adopted. The guidance is applied using a modified retrospective approach. Duke Energy is currently evaluating the requirements. Other than an expected increase in assets and liabilities, the ultimate impact of the new standard has not yet been determined.

Stock-Based Compensation and Income Taxes. In March 2016, the FASB issued revised accounting guidance for stock-based compensation and the associated income taxes. This standard changes certain aspects of accounting for stock-based payment awards to employees including the accounting for income taxes, statutory tax withholding requirements, as well as the classification on the Condensed Consolidated Statements of Cash Flows. This guidance will be applied prospectively, retrospectively, or using a modified retrospective transition method depending on the item changed.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2017, although it can be early adopted. Duke Energy is currently evaluating the requirements. The primary change expected is an increase in the volatility of income tax expense.

37

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

2. ACQUISITIONS AND DISPOSITIONS

ACQUISITIONS

The Duke Energy Registrants consolidate assets and liabilities from acquisitions as of the purchase date, and include earnings from acquisitions in consolidated earnings after the purchase date.

Acquisition of Piedmont Natural Gas

On October 24, 2015, Duke Energy entered into an Agreement and Plan of Merger (Merger Agreement) with Piedmont Natural Gas Company, Inc. (Piedmont), a North Carolina corporation. Under the terms of the Merger Agreement, Duke Energy will acquire Piedmont for approximately $4.9 billion in cash and Piedmont will become a wholly owned subsidiary of Duke Energy. In addition, Duke Energy will assume Piedmont's existing debt, which was approximately $2.0 billion at April 30, 2016, the end of Piedmont's most recent filed quarter. The excess of the purchase price over the fair value of Piedmont's assets and liabilities on the acquisition date will be recorded as goodwill. Duke Energy estimates the transaction would result in incremental goodwill of approximately $3.5 billion. Duke Energy expects to finance the transaction with a combination of debt, equity issuances and other cash sources. As of June 30, 2016, Duke Energy had entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. For additional information on the forward-starting swaps, see Note 9.

In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into equity forward sale agreements (the Equity Forwards) with Barclays Capital, Inc. (Barclays). Duke Energy expects to settle the Equity Forwards on or around the closing date of the Piedmont acquisition. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont. For additional information regarding the Equity Forwards, see Note 13.

In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion senior unsecured bridge financing facility (Bridge Facility) with Barclays. The Bridge Facility, if drawn upon, may be used to (i) fund the cash consideration for the transaction and (ii) pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to approximately $3.2 billion as a result of the Equity Forwards and $1 billion of the commitments under a term loan amended and restated as of August 1, 2016. See Note 6, Term Loan Facility, for more information.

Piedmont's shareholders have approved the company's acquisition by Duke Energy and the Federal Trade Commission (FTC) has granted early termination of the 30-day waiting period under the federal Hart-Scott-Rodino Antitrust Improvements Act of 1976. On January 15, 2016, Duke Energy and Piedmont filed an application with the NCUC for approval of the proposed business combination and associated financing transactions. On January 29, 2016, the NCUC approved Duke Energy's proposed financing transactions. On March 7, 2016, the KPSC granted Duke Energy's declaratory request that the transaction does not constitute a change in control and does not require KPSC approval. The Tennessee Regulatory Authority approved Duke Energy's and Piedmont's request of the change in control resulting from the transaction at its March 14, 2016, meeting. On June 10, 2016 the North Carolina Public Staff reached an agreement with Duke Energy and Piedmont on certain stipulations and conditions for approval of the transaction. Duke Energy and Piedmont have also entered into settlement agreements with the Environmental Defense Fund (EDF) and the Carolina Utility Customers Association, Inc. (CUCA) resolving EDF's and CUCA's issues in the case.

On July 19, 2016, the NCUC concluded an evidentiary hearing for the proposed business combination. Proposed orders are due from all parties by August 25, 2016, after which the NCUC will rule on the application. Subject to receipt of NCUC approval and meeting closing conditions, Duke Energy and Piedmont expect to close the transaction by the end of 2016.

The Merger Agreement contains certain termination rights for both Duke Energy and Piedmont, and provides that, upon termination of the Merger Agreement under specified circumstances, Duke Energy would be required to pay a termination fee of $250 million to Piedmont and Piedmont would be required to pay Duke Energy a termination fee of $125 million.

See Note 4 for additional information regarding Duke Energy and Piedmont's joint investment in Atlantic Coast Pipeline, LLC (ACP).

Purchase of NCEMPA's Generation

On July 31, 2015, Duke Energy Progress completed the purchase of North Carolina Eastern Municipal Power Agency’s (NCEMPA) ownership interests in certain generating assets, fuel and spare parts inventory jointly owned with and operated by Duke Energy Progress for approximately $1.25 billion. This purchase was accounted for as an asset acquisition. The purchase resulted in the acquisition of a total of approximately 700 megawatts (MW) of generating capacity at Brunswick Nuclear Plant, Shearon Harris Nuclear Plant, Mayo Steam Plant and Roxboro Steam Plant. In connection with this transaction, Duke Energy Progress and NCEMPA entered into a 30-year wholesale power agreement, whereby Duke Energy Progress will sell power to NCEMPA to continue to meet the needs of NCEMPA customers.

The purchase price exceeded the historical carrying value of the acquired assets by $350 million, which was recognized as an acquisition adjustment and recorded in property, plant and equipment. Duke Energy Progress established a rider in North Carolina to recover the costs to acquire, operate and maintain interests in the assets purchased as allocated to its North Carolina retail operations, including the purchase acquisition adjustment, and included the purchase acquisition adjustment in wholesale power formula rates. Duke Energy Progress received an order from the PSCSC to defer the recovery of the South Carolina retail allocated costs of the asset purchased until the Duke Energy Progress' next general rate case, which was filed in July 2016. See Note 4, for additional information on the South Carolina Rate Case.

38

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DISPOSITIONS

Potential Sale of International Energy

In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the equity method investment in National Methanol Company (NMC). Duke Energy is actively marketing the business. Non-binding offers have been received and are being evaluated. There is no assurance that this process will result in a transaction and the timing for execution of a potential transaction is uncertain. Proceeds from a successful sale would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. If the potential of a sale were to progress, it could result in classification of International Energy as assets held for sale and as a discontinued operation.

Based upon the advancement of the marketing efforts, Duke Energy performed recoverability tests of the long-lived asset groups of International Energy as of June 30, 2016. As a result, Duke Energy determined the carrying value of certain assets in Central America is not fully recoverable and recorded a pretax impairment charge of $194 million, which is included within Impairment Charges on the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2016. The impairment charge represents the excess of carrying value over the estimated fair value of the assets. The fair value of the assets was primarily determined from the income approach using discounted cash flows but also considered market information obtained in 2016.

As of June 30, 2016, the International Energy segment had a carrying value of approximately $2.4 billion, adjusted for approximately $589 million of cumulative foreign currency translation losses currently classified as accumulated other comprehensive loss.

Midwest Generation Exit

Duke Energy, through indirect subsidiaries, completed the sale of the Disposal Group to a subsidiary of Dynegy on April 2, 2015, for approximately $2.8 billion in cash. The nonregulated Midwest generation business included generation facilities with approximately 5,900 MW of owned capacity located in Ohio, Pennsylvania and Illinois. On April 1, 2015, prior to the sale, Duke Energy Ohio distributed its indirect ownership interest in the nonregulated Midwest generation business to a subsidiary of Duke Energy Corporation.

The Disposal Group's results of operations are classified as discontinued operations in the accompanying Condensed Consolidated Statements of Operations and Comprehensive Income. The following table presents the results of discontinued operations for the three and six months ended June 30, 2015.

	Three Months Ended						Six Months Ended
	June 30, 2015						June 30, 2015
				Duke						Duke
	Duke			Energy			Duke			Energy
(in millions)	Energy			Ohio			Energy			Ohio
Operating Revenues	$	—		$	—		$	543		$	412
Gain (Loss) on disposition	6			—			(37		)	(44		)
(Loss) Income before income taxes(a)	$	(80	)	$	(88	)	$	67		$	52
Income tax (benefit) expense	(21		)	(23		)	30			27
(Loss) Income from discontinued operations of the Disposal Group	(59		)	(65		)	37			25
Other, net of tax(b)	2			—			(3		)	—
(Loss) Income from Discontinued Operations, net of tax	$	(57	)	$	(65	)	$	34		$	25

(a) The (Loss) Income before income taxes includes the pretax impact of a $71 million and $81 million charge for the agreement in principle reached in a lawsuit related to the Disposal Group for the three and six months ended June 30, 2015, respectively. Refer to Note 5 for further information related to the lawsuit.

(b) Relates to discontinued operations of businesses not related to the Disposal Group and includes indemnifications provided for certain legal, tax and environmental matters, and foreign currency translation adjustments.

Commercial Portfolio utilized a revolving credit agreement (RCA) to support the operations of the nonregulated Midwest generation business. Interest expense associated with the RCA was allocated to discontinued operations. No other interest expense related to corporate level debt was allocated to discontinued operations. Duke Energy Ohio had a power purchase agreement with the Disposal Group for a portion of its standard service offer (SSO) supply requirement. The agreement and the SSO expired in May 2015.

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.

39

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

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 of the business. During the first quarter of 2016, the Duke Energy chief operating decision-maker began to evaluate interim period segment performance based on financial information that includes the impact of income tax levelization within segment income. This represents a change from the previous measure, where the interim period impacts of income tax levelization were included within Other, and therefore excluded from segment income. As a result, prior period segment results presented have been recast to conform to this change.

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 Portfolio.

RegulatedUtilities conducts electric and natural gas operations that are substantially all regulated and, accordingly, qualify for regulatory accounting treatment. These operations are primarily conducted through the Subsidiary Registrants and are subject to the rules and regulations of the FERC, NRC, NCUC, PSCSC, FPSC, PUCO, IURC and KPSC.

International Energy 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 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. In February 2016, Duke Energy announced it had initiated a process to potentially divest its International Energy business segment, excluding the investment in NMC. See Note 2 for further information.

Commercial Portfolio builds, develops and operates wind and solar renewable generation and storage and energy transmission projects throughout the U.S. For periods subsequent to the sale of the Disposal Group, beginning in the second quarter of 2015, certain immaterial results of operations and related assets previously presented in the Commercial Portfolio segment are presented in Regulated Utilities and Other.

Theremainder of Duke Energy’s operations is presented as Other, which is primarily comprised of unallocated corporate interest expense, unallocated corporate costs, contributions to the Duke Energy Foundation and the operations of Duke Energy’s wholly owned captive insurance subsidiary, Bison Insurance Company Limited (Bison).

	Three Months Ended June 30, 2016
								Total
	Regulated		International			Commercial		Reportable
(in millions)	Utilities		Energy			Portfolio		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,090	$	270		$	112	$	5,472	$	12		$	—		$	5,484
Intersegment revenues	9		—			—		9		17			(26		)	—
Total revenues	$	5,099	$	270		$	112	$	5,481	$	29		$	(26	)	$	5,484
Segment income (loss)(a)(b)	$	718	$	(102	)	$	14	$	630	$	(120	)	$	—		$	510
Add back noncontrolling interests																3
Loss from discontinued operations, net of tax																(1		)
Net income																$	512
Segment assets	$	112,754	$	3,131		$	4,329	$	120,214	$	2,260		$	180		$	122,654

(a) Other includes after-tax charges for costs to achieve mergers of $69 million, primarily due to unrealized losses on forward-starting interest rate swaps related to the Piedmont acquisition, and cost savings initiatives of $15 million primarily due to severance costs. See Notes 2 and 9 for additional information related to the forward-starting interest rate swaps.

(b) International Energy includes an after-tax impairment charge of $145 million. See Note 2 for additional information.

	Three Months Ended June 30, 2015
								Total
	Regulated		International		Commercial			Reportable
(in millions)	Utilities		Energy		Portfolio			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,211	$	287	$	75		$	5,573	$	16		$	—		$	5,589
Intersegment revenues	9		—		—			9		18			(27		)	—
Total revenues	$	5,220	$	287	$	75		$	5,582	$	34		$	(27	)	$	5,589
Segment income (loss)(a)(b)	$	632	$	52	$	(30	)	$	654	$	(51	)	$	(3	)	$	600
Add back noncontrolling interests																4
Loss from discontinued operations, net of tax(c)																(57		)
Net income																$	547

(a)    Other includes after-tax costs to achieve the Progress Energy merger of $14 million.

40

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

(b) Commercial Portfolio includes state tax expense of $41 million, resulting from changes to state apportionment factors due to the sale of the Disposal Group, that does not qualify for discontinued operations. Refer to Note 2 for further information related to the sale.

(c) Includes the after-tax impact of $46 million for the agreement in principle reached in a lawsuit related to the Disposal Group. Refer to Note 5 for further information related to the lawsuit.

	Six Months Ended June 30, 2016
							Total
	Regulated		International		Commercial		Reportable
(in millions)	Utilities		Energy		Portfolio		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	10,340	$	516	$	227	$	11,083	$	23		$	—		$	11,106
Intersegment revenues	18		—		—		9		35			(53		)	—
Total revenues	$	10,358	$	516	$	227	$	11,092	$	58		$	(53	)	$	11,106
Segment income (loss)(a)(b)	$	1,413	$	21	$	41	$	1,475	$	(274	)	$	—		$	1,201
Add back noncontrolling interests															8
Income from discontinued operations, net of tax															2
Net income															$	1,211

(a) Other includes after-tax charges for costs to achieve mergers of $143 million, primarily due to unrealized losses on forward-starting interest rate swaps related to the Piedmont acquisition, and cost savings initiatives of $27 million primarily due to severance costs. See Notes 2 and 9 for additional information related to the forward-starting interest rate swaps.

(b) International Energy includes an after-tax impairment charge of $145 million. See Note 2 for additional information.

	Six Months Ended June 30, 2015
								Total
	Regulated		International		Commercial			Reportable
(in millions)	Utilities		Energy		Portfolio			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	10,924	$	560	$	148		$	11,632	$	22		$	—		$	11,654
Intersegment revenues	19		—		—			19		39			(58		)	—
Total revenues	$	10,943	$	560	$	148		$	11,651	$	61		$	(58	)	$	11,654
Segment income (loss)(a)(b)	$	1,406	$	88	$	(23	)	$	1,471	$	(94	)	$	(4	)	$	1,373
Add back noncontrolling interests																7
Income from discontinued operations, net of tax(c)																34
Net income																$	1,414

(a)    Other includes after-tax costs to achieve the Progress Energy merger of $27 million.

(b) Commercial Portfolio includes state tax expense of $41 million, resulting from changes to state apportionment factors due to the sale of the Disposal Group, that does not qualify for discontinued operations. Refer to Note 2 for further information related to the sale.

(c) Includes after-tax impact of $53 million for the agreement in principle reached in a lawsuit related to the Disposal Group. Refer to Note 5 for further information related to the lawsuit.

SUBSIDIARY REGISTRANTS

The Subsidiary Registrants each have one reportable operating segment, Regulated Utilities, which generates, transmits, distributes and sells electricity, and for Duke Energy Ohio, also transports and sells natural gas. The remainder of operations is primarily comprised of unallocated corporate costs and classified as Other. The following table provides the amount of Other net expense.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
(in millions)	2016			2015			2016			2015
Duke Energy Carolinas	$	(17	)	$	(10	)	$	(34	)	$	(18	)
Progress Energy(a)	(45		)	(42		)	(94		)	(84		)
Duke Energy Progress	(8		)	(4		)	(16		)	(8		)
Duke Energy Florida	(5		)	(3		)	(9		)	(6		)
Duke Energy Ohio	(10		)	(6		)	(19		)	(8		)
Duke Energy Indiana	(5		)	(2		)	(7		)	(4		)

(a) Other for Progress Energy also includes interest expense on corporate debt instruments of $55 million and $111 million for the three and six months endedJune 30, 2016, respectively, and $59 million and $119 million for the three and six months endedJune 30, 2015, respectively.

41

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

The assets of the Subsidiary Registrants are substantially all included within the Regulated Utilities segment at June 30, 2016.

Duke Energy Ohio

Duke Energy Ohio had two reportable operating segments, Regulated Utilities and Commercial Portfolio, during 2015 prior to the sale of the nonregulated Midwest generation business. Duke Energy Ohio's Commercial Portfolio segment had total revenues of $14 million and segment loss of $9 million for the six months ended June 30, 2015. As a result of the sale discussed in Note 2, Commercial Portfolio no longer qualifies as a Duke Energy Ohio reportable operating segment. Therefore, beginning in the second quarter of 2015, all of the remaining assets and related results of operations previously presented in Commercial Portfolio are presented in Regulated Utilities and Other.

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, Kentucky and Indiana), as well as sales of transmission service.

Duke Energy Carolinas and Duke Energy Progress

Ash Basin Closure Costs Deferral

On July 13, 2016, in response to a joint petition of Duke Energy Carolinas and Duke Energy Progress the PSCSC issued an accounting order for the deferment into a regulatory account of certain costs incurred in connection with federal and state environmental remediation requirements related to the permanent closure of ash basins and other ash storage units at coal-fired generating facilities that have provided or are providing generation to customers located in South Carolina. The decision allows for ash basin closure expenses to be partially offset with excess regulatory liability amounts from the deferral of nuclear decommissioning costs that are collected from South Carolina retail customers and for Duke Energy Progress to offset incurred ash basin closure costs with costs of removal amounts collected from customers. The PSCSC's ruling does not change retail rates or the tariff amounts and in no way limits the PSCSC's ability to challenge the reasonableness of expenditures in subsequent proceedings.

FERC Transmission Return on Equity Complaints

On January 7, 2016, a group of transmission service customers filed a complaint with the FERC that the rate of return on equity of 10.2 percent in Duke Energy Carolinas' transmission formula rates is excessive and should be reduced to no higher than 8.49 percent, effective upon the complaint date. On the same date a similar complaint was filed with the FERC claiming that the rate of return on equity of 10.8 percent in Duke Energy Progress' transmission formula rates is excessive and should be reduced to no higher than 8.49 percent, effective upon the complaint date. On April 21, 2016, the FERC issued an order which consolidated the cases, set a refund effective date of January 7, 2016, and set the consolidated case for settlement and hearing. Duke Energy Carolinas and Duke Energy Progress do not expect the potential impact on results of operations, cash flows or financial position to be material.

Duke Energy Carolinas

Advanced Metering Infrastructure Deferral

On July 12, 2016, the PSCSC issued an accounting order for Duke Energy Carolinas to defer the financial effects of depreciation expense incurred for the installation of advanced metering infrastructure (AMI) meters, the carrying costs on the investment at its weighted average cost of capital and the carrying costs on the deferred costs at its weighted average cost of capital not to exceed $45 million. The decision also allows Duke Energy Carolinas to continue to depreciate the non-AMI meters to be replaced. Current retail rates will not change as a result of the decision and the PSCSC's ability to challenge the reasonableness of expenditures in subsequent proceedings is not limited.

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 Duke Energy Carolinas' existing William States Lee Generating Station in Anderson, South Carolina. Duke Energy Carolinas began construction in July 2015 and estimates a cost to build of $600 million for its share of the facility, including 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 (SCCL) and Southern Alliance for Clean Energy (SACE) jointly filed a Notice of Appeal with the Court of Appeals of South Carolina (S.C. Court of Appeals) seeking the court's review of the PSCSC's decision, claiming the PSCSC did not properly consider a request related to a proposed solar facility prior to granting approval of the CECPCN. The S.C. Court of Appeals affirmed the PSCSC's decision on February 10, 2016, and on March 24, 2016, denied a request for rehearing filed by SCCL and SACE. On April 21, 2016, SCCL and SACE petitioned the South Carolina Supreme Court for review of the S.C. Court of Appeals decision. Duke Energy Carolinas filed its response on June 13, 2016, and SCCL and SACE filed a reply on June 23, 2016. Duke Energy Carolinas cannot predict the outcome of this matter.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Duke Energy Progress

South Carolina Rate Case

On July 1, 2016, Duke Energy Progress filed an application with the PSCSC requesting an average 14.5 percent increase in retail revenues. The requested rate change would increase annual revenues by approximately $79 million, with a rate of return on equity of 10.75 percent. The increase is designed to recover the cost of investment in new generation infrastructure, environmental expenditures including allocated historical ash basin closure costs and increased nuclear operating costs. Duke Energy Progress has requested new rates to be effective January 1, 2017. A hearing has been scheduled to begin on October 31, 2016. Duke Energy Progress cannot predict the outcome of this matter.

Western Carolinas Modernization Plan

On November 4, 2015, in response to community feedback, Duke Energy Progress announced a revised Western Carolinas Modernization Plan with an estimated cost of $1.1 billion. The revised plan includes retirement of the existing Asheville coal-fired plant, the construction of two 280 MW combined-cycle natural gas plants having dual fuel capability, with the option to build a third natural gas simple cycle unit in 2023 based upon the outcome of initiatives to reduce the region's power demand. The revised plan includes upgrades to existing transmission lines and substations, but eliminates the need for a new transmission line and a new substation associated with the project in South Carolina. The revised plan has the same overall project cost as the original plan and the plans to install solar generation remain unchanged. Duke Energy Progress has also proposed to add a pilot battery storage project. These investments will be made within the next seven years. Duke Energy Progress is also working with the local natural gas distribution company to upgrade an existing natural gas pipeline to serve the natural gas plant. The plan requires various approvals including regulatory approvals in North Carolina.

Duke Energy Progress filed for a Certificate of Public Convenience and Necessity (CPCN) with the NCUC for the new natural gas units on January 15, 2016. On March 28, 2016, the NCUC issued an order approving the CPCN for the new combined-cycle natural gas plants, but denying the CPCN for the contingent simple cycle unit without prejudice to Duke Energy Progress to refile for approval in the future. Construction of these plants is scheduled to begin in 2016 and the plants are expected to be in service by late 2019. Duke Energy Progress plans to file for future approvals related to the proposed solar generation and pilot battery storage project.

On May 27, 2016, NC WARN and The Climate Times filed a notice of appeal from the CPCN order to the N.C. Court of Appeals. On May 31, 2016, Duke Energy Progress filed a motion to dismiss the notice of appeal with the NCUC due to NC WARN's and The Climate Times' failure to post a required appeal bond. After a series of filings, an NCUC order, petitions to the N.C. Court of Appeals and an evidentiary hearing, on July 8, 2016, the NCUC issued an order setting NC WARN's and The Climate Times' appeal bond at $98 million. On July 28, 2016, NC WARN and The Climate Times filed a notice of appeal and exceptions from the NCUC's July 8, 2016, appeal bond order. On August 2, 2016, the NCUC granted Duke Energy Progress' motion to dismiss NC WARN's and The Climate Times' notice of appeal from the CPCN order due to failure to post the requisite bond. Duke Energy Progress cannot predict the outcome of this matter.

The carrying value of the 376 MW Asheville coal-fired plant, including associated ash basin closure costs, of $506 million and $548 million are included in Generation facilities to be retired, net on Duke Energy Progress' Condensed Consolidated Balance Sheet as of June 30, 2016 and December 31, 2015, respectively.

Duke Energy Florida

Hines Chiller Uprate Project

On May 20, 2016, Duke Energy Florida filed a petition seeking approval to include in base rates the revenue requirement for a Chiller Uprate Project (Uprate Project) at the Hines station. Duke Energy Florida proposes to complete the Uprate Project in two phases: phase one work on Hines Units 1-3 and the common equipment to be completed and placed into service in October 2016; and phase two work on Hines Unit 4 to be completed and placed into service in January 2017. The final construction cost estimate for both phases of approximately $150 million is below the cost estimate provided during the need determination proceeding. Duke Energy Florida estimates the annual retail revenue requirements for phases one and two to be approximately $16 million and $3 million, respectively. Duke Energy Florida’s petition seeks approval of both revenue requirements, but only seeks to include the phase one revenue requirement in base rates and customer bills beginning November 2016, and will separately petition to include the phase two revenue requirement in base rates and customer bills beginning February 2017. Duke Energy Florida cannot predict the outcome of this matter.

Purchase of Osprey Energy Center

In December 2014, Duke Energy Florida and Osprey Energy Center, LLC, a wholly owned subsidiary of Calpine Corporation (Calpine), entered into an Asset Purchase and Sale Agreement for the purchase of a 599 MW combined-cycle natural gas plant in Auburndale, Florida (Osprey Plant acquisition) for approximately $166 million. In July 2015, the FERC and the FPSC issued separate orders of approval for the Osprey Plant acquisition. The Hart-Scott-Rodino waiting period expired on May 2, 2016. Closing of the acquisition is expected to occur by the first quarter of 2017, upon the expiration of an existing Power Purchase Agreement between Calpine and Duke Energy Florida. In anticipation of closing, in August 2016, Duke Energy Florida filed a petition seeking approval to include in base rates the revenue requirements for the Osprey Plant acquisition to be included in customer bills beginning in February 2017. Duke Energy Florida estimates the retail revenue requirements to be approximately $48 million.

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Crystal River Unit 3 Regulatory Asset

In June 2015, the governor of Florida signed legislation to allow utilities to issue nuclear asset-recovery bonds to finance the recovery of certain retired nuclear generation assets, with approval of the FPSC. In November 2015, the FPSC issued a financing order approving Duke Energy Florida’s request to issue nuclear asset-recovery bonds to finance its unrecovered regulatory asset related to Crystal River Unit 3 (Crystal River 3) through a wholly owned special purpose entity. Nuclear asset-recovery bonds replace the base rate recovery methodology authorized by the 2013 Revised and Restated Stipulation and Settlement Agreement (2013 Agreement) and result in a lower rate impact to customers with a recovery period of approximately 20 years.

Pursuant to provisions in Florida Statutes and the FPSC financing order, in 2016, Duke Energy Florida formed Duke Energy Florida Project Finance, LLC (DEFPF), a wholly owned, bankruptcy remote special purpose subsidiary for the purpose of issuing nuclear asset-recovery bonds. In June 2016, DEFPF issued $1,294 million aggregate principal amount of senior secured bonds (nuclear asset-recovery bonds) to finance the recovery of Duke Energy Florida's Crystal River 3 regulatory asset.

In connection with this financing, net proceeds to DEFPF of approximately $1,287 million, after underwriting costs, were used to acquire nuclear asset-recovery property from Duke Energy Florida and to pay transaction related expenses. The nuclear asset-recovery property includes the right to impose, bill, collect and adjust a non-bypassable nuclear asset-recovery charge, to be collected on a per kilowatt-hour basis from all Duke Energy Florida retail customers until the bonds are paid in full. Duke Energy Florida began collecting the nuclear asset-recovery charge on behalf of DEFPF in customer rates in July 2016.

See Notes 6 and 12 for additional information.

Duke Energy Ohio

Natural Gas Pipeline Extension

Duke Energy Ohio is proposing to install a new natural gas pipeline in its Ohio service territory to increase system reliability and enable the retirement of older infrastructure. The proposed project involves the installation of a natural gas line and is estimated to cost between $100 million and $150 million. Duke Energy Ohio is currently evaluating potential routes and has conducted public informational meetings. Duke Energy Ohio will narrow the route options to two and then make a filing with the Ohio Power Siting Board for approval of one of the two proposed routes.

Advanced Metering Infrastructure

On April 25, 2016, Duke Energy Kentucky filed with the KPSC an application for approval of a certificate of public convenience and necessity for the construction of advanced metering infrastructure. Duke Energy Kentucky anticipates that the estimated $49 million project, if approved, will take about two years to complete. Duke Energy Kentucky also requested approval to establish a regulatory asset of approximately $10 million for the remaining book value of existing meter equipment and inventory that will be replaced. On July 20, 2016, the Kentucky Attorney General, the only intervenor in the proceeding, moved to dismiss the application. Duke Energy Kentucky filed its opposition to the Kentucky Attorney General's motion to dismiss on July 27, 2016. Duke Energy Kentucky cannot predict the outcome of this matter.

Accelerated Natural Gas Service Line Replacement Rider

On January 20, 2015, Duke Energy Ohio filed an application for approval of an accelerated natural gas service line replacement program (ASRP). Under the ASRP, Duke Energy Ohio proposes to replace certain natural gas service lines on an accelerated basis. The program is proposed to last 10 years. Through the ASRP, Duke Energy Ohio also proposes to complete preliminary survey and investigation work related to natural gas service lines that are customer owned and for which it does not have valid records and, further, to relocate interior natural gas meters to suitable exterior locations where such relocation can be accomplished. Duke Energy Ohio projects total capital and operations and maintenance expenditures under the ASRP to approximate $320 million. The filing also seeks approval of Rider ASRP to recover related expenditures. Duke Energy Ohio proposes to update Rider ASRP on an annual basis. Duke Energy Ohio’s application is pending before the PUCO and it is uncertain when an order will be issued. Intervenors oppose the ASRP, primarily because they believe the program is neither required nor necessary under federal pipeline regulation. The hearing concluded on November 19, 2015, and initial and reply briefs were filed, with briefing complete on December 23, 2015. Duke Energy Ohio cannot predict the outcome of this matter.

Energy Efficiency Cost Recovery

On March 28, 2014, Duke Energy Ohio filed an application for recovery of program costs, lost distribution revenue and performance incentives related to its energy efficiency and peak demand reduction programs. These programs are undertaken to comply with environmental mandates set forth in Ohio law. After a comment period, the PUCO approved Duke Energy Ohio’s application, but found that Duke Energy Ohio was not permitted to use banked energy savings from previous years in order to calculate the amount of allowed incentive. This conclusion represented a change to the cost recovery mechanism that had been agreed to by intervenors and approved by the PUCO in previous cases. The PUCO granted the applications for rehearing filed by Duke Energy Ohio and an intervenor on July 8, 2015. Substantive ruling on the application for rehearing is pending. On January 6, 2016, Duke Energy Ohio and PUCO Staff entered into a stipulation pending PUCO approval, resolving the issues related to, among other things, performance incentives and the PUCO Staff audit of 2013 costs. Based on the stipulation, in December 2015, Duke Energy Ohio re-established approximately $20 million of revenues that had been reversed in the second quarter of 2015. A hearing on the stipulation commenced on March 10, 2016, and the post-hearing briefing has concluded. Duke Energy Ohio cannot predict the outcome of this matter.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

2012 Natural Gas Rate Case/Manufactured Gas Plant Cost Recovery

On November 13, 2013, the PUCO issued an order approving a settlement of Duke Energy Ohio’s natural gas base rate case and authorizing the recovery of costs incurred between 2008 and 2012 for environmental investigation and remediation of two former manufactured gas plant (MGP) sites. The order contained deadlines for the recovery of such costs. Specifically, for the property known as the East End site, PUCO established a deadline of December 31, 2016, and for the West End site, a deadline of December 31, 2019. The PUCO authorized Duke Energy Ohio to seek to extend these deadlines due to certain circumstances. On May 16, 2016, Duke Energy Ohio filed an application to extend the deadline for cost recovery applicable to the East End site. The order also authorized Duke Energy Ohio to continue deferring environmental investigation and remediation costs incurred subsequent to 2012 and to submit annual filings to adjust the MGP rider for future costs. Duke Energy Ohio submitted MGP rider update filings in 2014, 2015, and 2016 for recovery of costs incurred in 2013, 2014, and 2015, which are pending approval. Duke Energy Ohio cannot predict the outcome of this matter.

Regional Transmission Organization 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. The PUCO approved a settlement related to Duke Energy Ohio’s recovery of certain costs of the Regional Transmission Organization (RTO) realignment via a non-bypassable rider. Duke Energy Ohio is allowed to recover all MISO Transmission Expansion 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. The KPSC also approved a 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.

Duke Energy Ohio had a recorded liability for its exit obligation and share of MTEP costs, excluding MVP, of $91 million and $92 million, respectively, at June 30, 2016 and December 31, 2015, within Other in Current liabilities and Other in Deferred credits and other liabilities on Duke Energy Ohio’s Condensed Consolidated Balance Sheets. The retail portion of MTEP costs billed by MISO are recovered by Duke Energy Ohio through a non-bypassable rider. As of June 30, 2016 and December 31, 2015, Duke Energy Ohio had $72 million recorded in Regulatory assets on the Condensed Consolidated Balance Sheets.

MVP. MISO approved 17 MVP proposals prior to Duke Energy Ohio’s exit from MISO on December 31, 2011. Construction of these projects is expected to continue through 2020. Costs of these projects, including operating and maintenance costs, property and income taxes, depreciation and an allowed return, are allocated and billed to MISO transmission owners.

On December 29, 2011, MISO filed a tariff with the FERC providing for the allocation of MVP costs to a withdrawing owner based on monthly energy usage. The FERC set for hearing (i) whether MISO’s proposed cost allocation methodology to transmission owners who withdrew from MISO prior to January 1, 2012, is consistent with the tariff at the time of their withdrawal from MISO and, (ii) if not, what the amount of and methodology for calculating any MVP cost responsibility should be. 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. 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 FERC to overturn the ALJ’s decision.

On October 29, 2015, the FERC issued an order reversing the ALJ's decision. The FERC ruled the cost allocation methodology is not consistent with the MISO tariff and that Duke Energy Ohio has no liability for MVP costs after its withdrawal from MISO. On May 19, 2016, the FERC denied the request for rehearing filed by MISO and the MISO Transmission Owners. On July 15, 2016, the MISO Transmission Owners filed a petition for review with the U.S. Court of Appeals for the Sixth Circuit. Duke Energy Ohio cannot predict the outcome of this matter.

Duke Energy Indiana

Coal Combustion Residual Plan

On March 17, 2016, Duke Energy Indiana filed with the IURC a request for approval of its first group of federally mandated Coal Combustion Residual (CCR) rule compliance projects (Phase I CCR Compliance Projects) to comply with the U.S. Environmental Protection Agency's (EPA) CCR rule. The projects in this Phase I filing are CCR compliance projects, including the conversion of Cayuga and Gibson Stations to dry bottom ash handling and related water treatment. Duke Energy Indiana has requested timely recovery of approximately $380 million in retail capital costs and incremental operating and maintenance costs under a federal mandate tracker which provides for timely recovery of 80 percent of such costs and deferral with carrying costs of 20 percent of such costs for recovery in a subsequent retail base rate case. An evidentiary hearing is scheduled for November 2016. Duke Energy Indiana cannot predict the outcome of this matter.

Edwardsport Integrated Gasification Combined Cycle Plant

On November 20, 2007, the IURC granted Duke Energy Indiana a CPCN for the construction of the Edwardsport Integrated Gasification Combined Cycle (IGCC) Plant. 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. The Edwardsport IGCC Plant 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.

The ninth semi-annual IGCC rider order was appealed by the Joint Intervenors. The proceeding has been remanded to the IURC for further proceedings and additional findings on the tax in-service issue. An evidentiary hearing has been set for September 13, 2016.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

The 11th through 15th semi-annual IGCC riders and a subdocket to Duke Energy Indiana's fuel adjustment clause remain pending at the IURC. Issues in these filings include the determination whether the IGCC plant was properly declared in-service for ratemaking purposes in June 2013 and a review of the operational performance of the plant. On September 17, 2015, Duke Energy Indiana, the Office of Utility Consumer Counselor, the Industrial Group and Nucor Steel Indiana reached a settlement agreement to resolve these pending issues. On January 15, 2016, The Citizens Action Coalition of Indiana, Inc., Sierra Club, Save the Valley and Valley Watch joined a revised settlement (IGCC settlement). The IGCC settlement will result in customers not being billed for previously incurred operating costs of $87.5 million, and for additional Duke Energy Indiana payments and commitments of $5.5 million for attorneys’ fees and amounts to fund consumer programs. Attorneys’ fees and expenses for the new settling parties will be addressed in a separate proceeding. Duke Energy Indiana recognized pretax impairment and related charges of $93 million in 2015. Additionally, under the IGCC settlement, the operating and maintenance expenses and ongoing maintenance capital at the plant are subject to certain caps during the years of 2016 and 2017. The IGCC settlement also includes a commitment to either retire or stop burning coal by December 31, 2022, at the Gallagher Station. Pursuant to the IGCC settlement, the in-service date used for accounting and ratemaking will remain as June 2013. Remaining deferred costs will be recovered over eight years and not earn a carrying cost. The IGCC settlement, which is opposed by an intervenor, is subject to IURC approval. An evidentiary hearing on the IGCC settlement was held on April 18, 2016, and a decision is expected in the third quarter of 2016. As of June 30, 2016, deferred costs related to the project are approximately $175 million. Under the IGCC settlement, future IGCC riders will be filed annually, rather than every six months, with the next filing scheduled for first quarter 2017.

Duke Energy Indiana cannot predict the outcome of these matters or future IGCC rider proceedings.

FERC Transmission Return on Equity Complaint

Customer groups have filed with the FERC complaints against MISO and its transmission-owning members, including Duke Energy Indiana, alleging, among other things, that the current base rate of return on equity earned by MISO transmission owners of 12.38 percent is unjust and unreasonable. The latest complaint, filed on February 12, 2015, claims the base rate of return on equity should be reduced to 8.67 percent and requests a consolidation of complaints. The motion to consolidate complaints was denied. On January 5, 2015, the FERC issued an order accepting the MISO transmission owners 0.50 percent adder to the base rate of return on equity based on participation in an RTO subject to it being applied to a return on equity that is shown to be just and reasonable in the pending return on equity complaints. A hearing in the base return on equity proceeding was held in August 2015. On December 22, 2015, the presiding FERC ALJ in the first complaint issued an Initial Decision in which he set the base rate of return on equity at 10.32 percent. On June 30, 2016, the presiding FERC ALJ in the second complaint issued an Initial Decision setting the base rate of return on equity at 9.70 percent. The Initial Decisions will be reviewed by the FERC. Duke Energy Indiana currently believes these matters will have an immaterial impact on its results of operations, cash flows and financial position.

Grid Infrastructure Improvement Plan

On August 29, 2014, pursuant to a new statute, 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. The plan also provided for cost recovery through a transmission and distribution rider (T&D Rider). In May 2015, the IURC denied the original proposal due to an insufficient level of detailed projects and cost estimates in the plan. On December 7, 2015, Duke Energy Indiana filed a revised infrastructure improvement plan with an estimated cost of $1.8 billion in response to guidance from IURC orders and the Indiana Court of Appeals decisions related to this new statute. The revised plan uses a combination of advanced technology and infrastructure upgrades to improve service to customers and provide them with better information about their energy use. It also provides for cost recovery through a T&D rider. In March 2016, Duke Energy Indiana entered into a settlement with all parties to the proceeding except the Citizens Action Coalition of Indiana, Inc. The settlement agreement decreased the capital expenditures eligible for timely recovery of costs in the seven-year plan to approximately $1.4 billion, including the removal of an AMI project. The settlement provided for deferral accounting for depreciation and post-in-service carrying costs for AMI projects outside the seven-year plan. Duke Energy Indiana withdrew its request for a regulatory asset for current meters and will retain any savings associated with future AMI installation until the next retail base rate case, which is required to be filed prior to the end of the seven-year plan. Under the settlement, the return on equity to be used in the T&D Rider is 10 percent. The IURC approved the settlement and issued a final order on June 29, 2016.

OTHER REGULATORY MATTERS

Atlantic Coast Pipeline

On September 2, 2014, Duke Energy, Dominion Resources (Dominion), Piedmont and AGL Resources announced the formation of a company, ACP, to build and own the proposed Atlantic Coast Pipeline (the pipeline), a 564-mile interstate natural gas pipeline. The pipeline is designed to meet the needs identified in requests for proposals by Duke Energy Carolinas, Duke Energy Progress and Piedmont. Dominion will build and operate the pipeline and has a 45 percent ownership percentage in ACP. Duke Energy has a 40 percent ownership interest in ACP through its Commercial Portfolio segment. Piedmont owns 10 percent and the remaining share is owned by 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. On September 18, 2015, ACP filed an application with the FERC requesting a CPCN authorizing ACP to construct the pipeline. FERC approval of the application is expected in early 2017 and construction is projected to begin in summer of 2017, with a targeted in-service date of late 2018. ACP is working with various agencies to develop the final pipeline route. ACP also requested approval of an open access tariff and the precedent agreements it entered into with future pipeline customers, including Duke Energy Carolinas and Duke Energy Progress.

On October 24, 2015, Duke Energy entered into a Merger Agreement with Piedmont. The ACP partnership agreement includes provisions to allow Dominion an option to purchase additional ownership interest in ACP to maintain a leading ownership percentage. Any change in ownership interests is not expected to be material to Duke Energy. Refer to Note 2 for further information related to Duke Energy's proposed acquisition of Piedmont.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Sabal Trail Transmission, LLC Pipeline

On May 4, 2015, Duke Energy acquired a 7.5 percent ownership interest from Spectra Energy in the proposed 500-mile Sabal Trail natural gas pipeline. Spectra Energy will continue to own 59.5 percent of the Sabal Trail pipeline and NextEra Energy will own the remaining 33 percent. The Sabal Trail pipeline will traverse Alabama, Georgia and Florida to meet rapidly growing demand for natural gas in those states. The primary customers of the Sabal Trail pipeline, Duke Energy Florida and Florida Power & Light Company (FP&L), have each contracted to buy pipeline capacity for 25-year initial terms. On February 3, 2016, the FERC issued an order granting the request for a CPCN to construct and operate the Sabal Trail pipeline. The Sabal Trail pipeline requires additional regulatory approvals and is scheduled to begin service in mid-2017.

Progress Energy Merger FERC Mitigation

In June 2012, the FERC approved the merger with Progress Energy, including Duke Energy and Progress Energy’s revised market power mitigation plan, the Joint Dispatch Agreement (JDA) and the joint Open Access Transmission Tariff. The revised market power mitigation plan provided for the acceleration of one transmission project and the completion of seven other transmission projects (Long-Term FERC Mitigation) and interim firm power sale agreements during the completion of the transmission projects (Interim FERC Mitigation). The Long-Term FERC Mitigation 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.

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. The city of New Bern filed a protest and requested that FERC order additional mitigation. On October 29, 2014, the FERC ordered that the amount of the stub mitigation be increased from 25 MW to 129 MW. The stub mitigation is Duke Energy’s commitment to set aside for third parties a certain quantity of firm transmission capacity from Duke Energy Carolinas to Duke Energy Progress during summer off-peak hours. The 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. The costs to comply with this order are not material. The FERC also referred Duke Energy’s failure to expressly designate the phase shifter reactivation as a mitigation project in the original mitigation plan filing in March 2012 to the FERC Office of Enforcement for further inquiry. In response, and since December 2014, the FERC Office of Enforcement has conducted a nonpublic investigation of Duke Energy's market power analyses included in the Progress merger filings submitted to FERC. Duke Energy cannot predict the outcome of this investigation.

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 long term (10 to 20 years), 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 Florida and Indiana earlier than their current estimated useful lives. These facilities do not have the requisite emission control equipment, primarily to meet EPA regulations recently approved or proposed.

The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement due to a lack of requisite environmental control equipment. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of June 30, 2016.

		Remaining Net
	Capacity	Book Value(a)
	(in MW)	(in millions)
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2	873	126
Duke Energy Indiana
Wabash River Unit 6(b)	318	34
Gallagher Units 2 and 4(c)	280	135
Total Duke Energy	1,471	295

(a) Remaining net book value amounts exclude any capitalized asset retirement costs.

(b) In April 2016, Wabash River 6 terminated coal burning operations and is targeted for retirement by the end of 2016. The total net book value of $93 million for the retail portion of Wabash River Unit 6 and the retail portion of capitalized asset retirement costs for Wabash River Units 2 through 6 is classified as Generation facilities to be retired, net on Duke Energy Indiana's Condensed Consolidated Balance Sheet at June 30, 2016.

(c) Duke Energy Indiana committed to either retire or stop burning coal at Gallagher Units 2 and 4 by December 31, 2022, as part of the proposed settlement of Edwardsport IGCC matters.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

On October 23, 2015, the EPA published in the Federal Register the Clean Power Plan (CPP) rule for regulating carbon dioxide (CO2) emissions from existing fossil fuel-fired electric generating units (EGUs). The CPP establishes CO2 emission rates and mass cap goals that apply to fossil fuel-fired generation. Under the CPP, states are required to develop and submit a final compliance plan, or an initial plan with an extension request, to the EPA by September 6, 2016, or no later than September 6, 2018, with an approved extension. These state plans are subject to EPA approval, with a federal plan applied to states that fail to submit a plan to the EPA or if a state plan is not approved. Legal challenges to the CPP have been filed by stakeholders and motions to stay the requirements of the rule pending the outcome of the litigation were granted by the U.S. Supreme Court in February 2016. Final resolution of these legal challenges could take several years. Compliance with CPP could cause the industry to replace coal generation with natural gas and renewables, especially in states that have significant CO2 reduction targets under the rule. Costs to operate coal-fired generation plants continue to grow due to increasing environmental compliance requirements, including ash management costs unrelated to CPP, and this may result in the retirement of coal-fired generation plants earlier than the current end of useful lives. Duke Energy continues to evaluate the need to retire generating facilities and plans to seek regulatory recovery, where appropriate, for amounts that have not been recovered upon asset retirements. However, recovery is subject to future regulatory approval, including the recovery of carrying costs on remaining book values, and therefore cannot be assured.

Refer to the "Western Carolinas Modernization Plan" discussion above for details of Duke Energy Progress' planned retirements.

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.

Remediation Activities

In addition to Asset Retirement Obligations recorded as a result of various environmental regulations, the Duke Energy Registrants are responsible for environmental remediation at various sites. These include certain 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, remediation activities vary based upon site conditions and location, 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 environmental impacts 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 tables contain 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, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Balance at beginning of period	$	97		$	10		$	17		$	3		$	14		$	54		$	12
Provisions/adjustments	28			3			4			1			3			1			21
Cash reductions	(7		)	(2		)	(4		)	(1		)	(3		)	(1		)	(1		)
Balance at end of period	$	118		$	11		$	17		$	3		$	14		$	54		$	32

	Six Months Ended June 30, 2015
				Duke					Duke			Duke			Duke			Duke
	Duke			Energy		Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas		Energy			Progress			Florida			Ohio			Indiana
Balance at beginning of period	$	97		$	10	$	17		$	5		$	12		$	54		$	10
Provisions/adjustments	5			—		2			—			2			1			3
Cash reductions	(4		)	—		(2		)	(1		)	(1		)	(1		)	(1		)
Balance at end of period	$	98		$	10	$	17		$	4		$	13		$	54		$	12

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 not material except as presented in the table below.

(in millions)
Duke Energy	$	75
Duke Energy Carolinas	22
Duke Energy Ohio	42
Duke Energy Indiana	7

North Carolina and South Carolina Ash Basins

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy Carolinas’ retired Dan River Steam Station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy Carolinas estimates 30,000 to 39,000 tons of ash and 24 million to 27 million gallons of basin water were released into the river. In July 2014, Duke Energy completed remediation work identified by the EPA and continues to cooperate with the EPA's civil enforcement process. Future costs related to the Dan River release, including pending or future state or federal civil enforcement proceedings, future regulatory directives, natural resources damages, additional pending litigation, future claims or litigation and long-term environmental impact costs, cannot be reasonably estimated at this time.

North Carolina Department of Environmental Quality (NCDEQ), formerly the North Carolina Department of Environment and Natural Resources, has historically assessed Duke Energy Carolinas and Duke Energy Progress with Notice of Violations (NOV) for violations that were most often resolved through satisfactory corrective actions and minor, if any, fines or penalties. Subsequent to the Dan River matter discussed above, Duke Energy Carolinas and Duke Energy Progress have been served with a higher level of Notices of Violation (NOVs), including for violations at L.V. Sutton Plant and Dan River Steam Station. In August 2014, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' L.V. Sutton Plant. On March 10, 2015, NCDEQ issued a civil penalty of approximately $25 million to Duke Energy Progress for environmental damages related to groundwater contamination at the L.V. Sutton Plant. On February 8, 2016, NCDEQ assessed a penalty of approximately $6.8 million, including enforcement costs, against Duke Energy Carolinas related to stormwater pipes and associated discharges at the Dan River Steam Station. Duke Energy Carolinas recorded a charge in December 2015 for this penalty. See "Litigation" section below for additional discussion of matters related to these penalties. These fines and penalties are unprecedented and were not consistent with historic enforcement practices of NCDEQ. Based on historic practices the expected liability of any existing notice of violations would not be material. Duke Energy Carolinas and Duke Energy Progress cannot predict whether the NCDEQ will assess future penalties related to existing NOVs and if such penalties would be material.

Asset retirement obligations recorded on the Duke Energy Carolinas and Duke Energy Progress Condensed Consolidated Balance Sheets at June 30, 2016 and December 31, 2015, include the legal obligation for closure of coal ash basins and the disposal of related ash as a result of the North Carolina Coal Ash Management Act of 2014, as amended (Coal Ash Act), and other agreements. In January 2016, NCDEQ published draft proposed risk classifications for sites not specifically delineated by the Coal Ash Act as high priority. These risk rankings were generally determined based on three primary criteria: structural integrity of the impoundments and impact to both surface and groundwater. NCDEQ categorized 12 basins at four sites as intermediate risk and four basins at 3 plants as low risk. Basins at high priority sites (Dan River, Riverbend, Asheville and Sutton) require closure through excavation including a combination of transferring the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of high priority basins is required to be completed no later than August 1, 2019, except for Asheville which is required to be completed no later than August 1, 2022. Intermediate risk basins require closure through excavation including a combination of converting the basin to a lined industrial landfill, transferring of the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of intermediate risk basins is required to be completed no later than December 31, 2024. Low risk basins require closure through either the combination of the installation and maintenance of a cap system and groundwater monitoring system designed to minimize infiltration and erosion or other closure options available to intermediate-risk basins. Closure of low risk basins is required to be completed no later than December 31, 2029. NCDEQ also categorized nine basins at six plants as “low-to-intermediate” risk, thereby not assigning a definitive risk ranking at that time. On May 18, 2016, NCDEQ issued new proposed risk classifications, ranking all originally proposed low risk and "low-intermediate" risk sites as intermediate.

On July 14, 2016, the Governor of North Carolina signed legislation which amends the Coal Ash Act and requires Duke Energy to undertake dam improvement projects and to provide access to a permanent alternative drinking water source to certain residents within a half mile of coal ash basin compliance boundaries and to certain other potentially impacted residents. The new legislation also ranks basins at the H.F. Lee, Cape Fear and Weatherspoon stations as intermediate risk consistent with Duke Energy's previously announced plans to excavate those basins. These specific intermediate basins require closure through excavation including a combination of transferring ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of these specific intermediate basins is required to be completed no later than August 1, 2028. Additionally, the new legislation requires the installation and operation of three large-scale coal ash beneficiation projects which are expected to produce reprocessed ash for use in the concrete industry. Closure of basins at sites with these beneficiation projects are required to be completed no later than December 31, 2029. Upon satisfactory completion of the dam improvement projects and installation of alternate drinking water sources by October 15, 2018, the legislation requires NCDEQ to reclassify intermediate risk sites, excluding H.F. Lee, Cape Fear and Weatherspoon, as low risk.

Per the Coal Ash Act, final proposed classifications were to be subject to Coal Ash Management Commission (Coal Ash Commission) approval. In March 2016, the Coal Ash Commission created by the Coal Ash Act was disbanded by the Governor of North Carolina based on a North Carolina Supreme Court ruling regarding the constitutionality of the body. The new legislation eliminates the Coal Ash Commission and transfers responsibility for ash basin closure oversight to the NCDEQ.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Estimated asset retirement obligations, including impacts from the legislation signed by the Governor of North Carolina on July 14, 2016, have been recognized based on the assigned risk categories or a probability weighting of potential closure methods. Actual closure costs incurred could be materially different from current estimates that form the basis of the recorded asset retirement obligations. Costs incurred have been deferred as regulatory assets and recovery will be pursued through the normal ratemaking process with federal and state utility commissions, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations.

Coal Combustion Residuals

On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. The federal regulation, which became effective in October 2015, classifies CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act and allows for beneficial use of CCR with some restrictions. The regulation applies to all new and existing landfills, new and existing surface impoundments receiving CCR and existing surface impoundments that are no longer receiving CCR but contain liquid located at stations currently generating electricity (regardless of fuel source). The rule establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. Various industry and environmental parties have appealed the EPA's CCR rule in the D.C. Circuit Court of Appeals. On April 18, 2016, the EPA filed an unopposed motion with the federal court to settle five issues raised in litigation. On June 14, 2016, the court approved the motion with respect to all of those issues. Duke Energy does not expect a material impact from the settlement or that it will result in additional asset retirement obligation adjustments.

In addition to the requirements of the federal CCR regulation, CCR landfills and surface impoundments will continue to be independently regulated by most states. As a result of the EPA rule, the Subsidiary Registrants recorded asset retirement obligation amounts during 2015.

LITIGATION

Duke Energy

Ash Basin Shareholder Derivative Litigation

Five shareholder derivative lawsuits were filed in Delaware Chancery Court relating to the release at Dan River and to the management of Duke Energy’s ash basins. On October 31, 2014, the five lawsuits were consolidated in a single proceeding titled In Re Duke Energy Corporation Coal Ash Derivative Litigation. On December 2, 2014, plaintiffs filed a Corrected Verified Consolidated Shareholder Derivative Complaint (Consolidated Complaint). The Consolidated Complaint names as defendants several current and former Duke Energy officers and directors (Duke Energy Defendants). Duke Energy is named as a nominal defendant.

The Consolidated Complaint alleges the Duke Energy Defendants breached their fiduciary duties by failing to adequately oversee Duke Energy’s ash basins and that these breaches of fiduciary duty may have contributed to the incident at Dan River and continued thereafter. The lawsuit also asserts 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 lawsuit seeks both injunctive relief against Duke Energy and restitution from the Duke Energy Defendants. On January 21, 2015, the Duke Energy Defendants filed a Motion to Stay and an alternative Motion to Dismiss. On August 31, 2015, the court issued an order staying the case which was lifted on March 24, 2016. On April 22, 2016, plaintiffs filed an Amended Verified Consolidated Shareholder Derivative Complaint (Amended Complaint) making the same allegations as in the Consolidated Complaint. The Duke Energy Defendants filed a motion to dismiss the Amended Complaint on June 21, 2016.

On March 5, 2015, shareholder Judy Mesirov filed a shareholder derivative complaint (Mesirov Complaint) in North Carolina state court. The lawsuit, styled Mesirov v. Good, is similar to the consolidated derivative action pending in Delaware Chancery Court and was filed against the same current directors and former directors and officers as the Delaware litigation. Duke Energy Corporation, Duke Energy Progress and Duke Energy Carolinas are named as nominal defendants. The Mesirov Complaint alleges that the Duke Energy Board of Directors was aware of Clean Water Act (CWA) compliance issues and failures to maintain structures in ash basins, but that the Board of Directors did not require Duke Energy Carolinas and Duke Energy Progress to take action to remedy deficiencies. The Mesirov Complaint further alleges that the Board of Directors sanctioned activities to avoid compliance with the law by allowing improper influence of NCDEQ to minimize regulation and by opposing previously anticipated citizen suit litigation. The Mesirov Complaint seeks corporate governance reforms and damages relating to costs associated with the Dan River release, remediation of ash basins that are out of compliance with the CWA and defending and payment of fines, penalties and settlements relating to criminal and civil investigations and lawsuits. The case was stayed until July 1, 2016. On July 5, 2016, the plaintiff filed a Notice of Voluntary Dismissal Without Prejudice, closing this matter.

In addition to the above derivative complaints, in 2014, Duke Energy also received two shareholder litigation demand letters. The letters alleged that the members of the Board of Directors and certain officers breached their fiduciary duties by allowing the company to illegally dispose of and store coal ash pollutants. One of the letters also alleged a breach of fiduciary duty in the decision-making relating to the leadership changes following the close of the Progress Energy merger in July 2012.

By letter dated September 4, 2015, attorneys for the shareholders were informed that, on the recommendation of the Demand Review Committee formed to consider such matters, the Board of Directors concluded not to pursue potential claims against individuals. One of the shareholders, Mitchell Pinsly, sent a formal demand for records and Duke Energy responded to this request.

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

On October 30, 2015, shareholder Saul Bresalier filed a shareholder derivative complaint (Bresalier Complaint) in the U.S. District Court for the District of Delaware. The lawsuit alleges that several current and former Duke Energy officers and directors (Bresalier Defendants) breached their fiduciary duties in connection with coal ash environmental issues, the post-merger change in Chief Executive Officer (CEO) and oversight of political contributions. Duke Energy is named as a nominal defendant. The Bresalier Complaint contends that the Demand Review Committee failed to appropriately consider the shareholder’s earlier demand for litigation and improperly decided not to pursue claims against the Bresalier Defendants. The Bresalier Defendants filed a Motion to Dismiss the Bresalier litigation on January 15, 2016. In lieu of a response to the Motion to Dismiss, the plaintiff filed a Motion to Convert the Bresalier Defendants' Motion to Dismiss into a Motion for Summary Judgment and also for limited discovery. Following a hearing on June 15, 2016, the court denied the plaintiff's Motion to Convert and is requiring the parties to complete briefing on the Bresalier Defendants' Motion to Dismiss. On July 29, 2016, the Bresalier Defendants filed an Amended Motion to Dismiss.

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

Progress Energy Merger Shareholder Litigation

On May 31, 2013, the Delaware Chancery Court consolidated four shareholder derivative lawsuits filed in 2012. The Court also appointed a lead plaintiff and counsel for plaintiffs and designated the case as In Re Duke Energy Corporation Derivative Litigation. The lawsuit names as defendants the 11 members of the Board of Directors who were also members of the pre-merger Board of Directors (Legacy Duke Energy Directors). Duke Energy is named as a nominal defendant. The case alleges claims for breach of fiduciary duties of loyalty and care in connection with the post-merger change in CEO. On December 10, 2015, the Legacy Duke Energy Directors filed a Motion to Dismiss the litigation. The court heard oral argument on the motion on May 9, 2016.

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 against the Legacy Duke Energy Directors 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 December 21, 2015, Plaintiff filed a Consolidated Amended Complaint asserting the same claims contained in the original complaints. The Legacy Duke Energy Directors filed a Motion to Dismiss on February 19, 2016. On March 18, 2016, the Chancery Court Plaintiffs moved to intervene in the Tansey proceeding, asking the federal district court to stay the federal litigation in favor of the Delaware Chancery litigation, which was denied on June 27, 2016. Oral argument on the Legacy Duke Energy Directors' Motion to Dismiss is scheduled for August 24, 2016.

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 litigation.

Price Reporting Cases

Duke Energy Trading and Marketing, LLC (DETM), a non-operating Duke Energy affiliate, was a defendant, along with numerous other energy companies, in four class action lawsuits and a fifth single-plaintiff lawsuit pending in a consolidated federal court proceeding in Nevada. Each of these lawsuits contains 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.

In February 2016, DETM reached agreements in principle to settle all of the pending lawsuits. Settlement of the single-plaintiff settlement was finalized and paid in March 2016. Settlement of the class action lawsuits are currently being finalized and will be subject to court approval. The settlement amounts are not material to Duke Energy.

Brazil Expansion Lawsuit

On August 9, 2011, the State of São Paulo sued Duke Energy International Geracao Paranapenema S.A. (DEIGP) in Brazilian state court. The lawsuit claims DEIGP is under a continuing obligation to expand installed generation capacity in the State of São Paulo by 15 percent pursuant to a stock purchase agreement under which DEIGP purchased generation assets from the state. On August 10, 2011, a judge granted an injunction ordering DEIGP to present a detailed expansion plan in satisfaction of the 15 percent obligation. DEIGP has previously taken a position that 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. In January 2013, DEIGP filed appeals in the federal courts, which are still pending, regarding various procedural issues. A decision on the merits in the first instance court is also pending. It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with this matter.

Brazil Generation

Record drought conditions in Brazil during 2014 and 2015 negatively impacted DEIGP. A number of electric generators have filed lawsuits seeking relief in the Brazilian courts to mitigate hydrological exposure and diminishing dispatch levels. Some courts have granted injunction orders to limit the financial exposure of certain generators. The implication of these orders is that other electricity market participants not covered by the injunctions may be required to compensate for the financial impact of the liability limitations. The Independent Power Producer Association (APINE) filed one such lawsuit on behalf of DEIGP and other hydroelectric generators against the Brazilian electric regulatory agency (ANEEL). On July 2, 2015, an injunction was granted in favor of APINE limiting the financial exposure of DEIGP and the other plaintiff generators, until the merits of the lawsuit are determined. ANEEL's appeal of the injunction was denied on December 18, 2015. The outcome of these lawsuits is uncertain. It is not possible to predict the impact to Duke Energy from the outcome of these matters.

51

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Duke Energy Carolinas and Duke Energy Progress

NCDEQ Notices of Violation

In August 2014, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' L.V. Sutton Plant. On March 10, 2015, NCDEQ issued a civil penalty of approximately $25 million to Duke Energy Progress for environmental damages related to the groundwater contamination at the L.V. Sutton Plant. On April 9, 2015, Duke Energy Progress filed a Petition for Contested Case hearing in the Office of Administrative Hearings. In February 2015, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' Asheville Plant. Duke Energy Progress responded to NCDEQ regarding this NOV.

On September 29, 2015, Duke Energy Progress and Duke Energy Carolinas entered into a settlement agreement with NCDEQ resolving all former, current and future groundwater penalties at all Duke Energy Carolinas and Duke Energy Progress coal facilities in North Carolina. Under the agreement, Duke Energy Progress paid approximately $6 million and Duke Energy Carolinas paid approximately $1 million. In addition to these payments, Duke Energy Progress and Duke Energy Carolinas will accelerate remediation actions at the Sutton, Asheville, Belews Creek and H.F. Lee plants. The ALJ entered a consent order resolving the contested case relating to the Sutton Plant and NCDEQ rescinded the NOVs relating to alleged groundwater violations at both the Sutton and Asheville plants.

On October 13, 2015, the Southern Environmental Law Center (SELC), representing multiple conservation groups, filed a lawsuit in North Carolina Superior Court seeking judicial review of the order approving the settlement agreement with NCDEQ. The conservation groups contend that the ALJ exceeded his statutory authority in approving a settlement that provided for past, present, and future resolution of groundwater issues at facilities which were not at issue in the penalty appeal. On December 18, 2015, Duke Energy Carolinas and Duke Energy Progress filed a Motion to Dismiss the complaint. On February 12, 2016, the ALJ entered a new order clarifying that the dismissal of the contested case only applied to the specific issues before the ALJ in the Petition for Contested Case. On March 10, 2016, the court dismissed the SELC lawsuit based on the ALJ's entry of the new order.

On February 8, 2016, NCDEQ assessed a penalty of approximately $6.8 million, including enforcement costs, against Duke Energy Carolinas related to storm water pipes and associated discharges at the Dan River Steam Station. Duke Energy Carolinas recorded a charge in December 2015 for this penalty. In March 2016, Duke Energy Carolinas filed an appeal of this penalty. A summary judgment hearing is set for August 22, 2016, for this proceeding. Duke Energy Carolinas cannot predict the outcome of this matter.

NCDEQ State Enforcement Actions

In the first quarter of 2013, SELC sent notices of intent to sue Duke Energy Carolinas and Duke Energy Progress related to alleged CWA violations from coal ash basins at two of their coal-fired power plants in North Carolina. NCDEQ filed enforcement actions against Duke Energy Carolinas and Duke Energy Progress alleging violations of water discharge permits and North Carolina groundwater standards. The cases have been consolidated and are being heard before a single judge.

On August 16, 2013, NCDEQ filed an enforcement action against Duke Energy Carolinas and Duke Energy Progress related to their remaining plants in North Carolina, alleging violations of the CWA and violations of the North Carolina groundwater standards. Both of these cases have been assigned to the judge handling the enforcement actions discussed above. SELC is representing several environmental groups who have been permitted to intervene in these cases.

On July 10, 2015, Duke Energy Carolinas and Duke Energy Progress filed two Motions for Partial Summary Judgment in the case on the basis that there is no longer either a genuine controversy or disputed material facts about the relief for seven of the 14 North Carolina plants with coal ash basins. On September 14, 2015, the court granted the Motions for Partial Summary Judgment pending court approval of the terms through an order. On April 4, 2016, the court issued an order granting Duke Energy Progress' Motion for Partial Summary Judgment for cases involving the H.F. Lee, Cape Fear and Weatherspoon plants. On June 1, 2016, the court issued an order granting Duke Energy Carolinas' and Duke Energy Progress' Motion for Partial Summary Judgment for cases involving the Asheville, Dan River, Riverbend and Sutton plants. The litigation is concluded for these seven plants. Litigation continues for the remaining seven plants.

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.

Federal Citizens Suits

There are currently three cases filed in various North Carolina federal courts related to the Sutton, Buck and Mayo plants. Three other previously filed cases involving the Riverbend, Cape Fear and H.F. Lee plants were dismissed on June 7, 2016.

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 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. In response to a motion filed by the SELC on August 1, 2014, the court modified the original 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 permits are back in the case. On August 26, 2015, the court suspended the proceedings until further order from the court.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

On September 3, 2014, three citizen suits 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 surface water and groundwater violations at the Cape Fear Plant; (ii) in the United States Court for the Eastern District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the H.F. Lee Plant; and (iii) in the United States Court for the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Buck Steam Station. Motions to Stay or Dismiss the proceedings were filed in each of the three cases. The proceedings related to Cape Fear and H.F. Lee were dismissed on June 8, 2016, closing these matters. On October 20, 2015, the court issued an order denying the motions to stay or dismiss in the Buck proceedings. Duke Energy Carolinas' motion seeking appellate review of the District Court's decision relating to Buck was denied on January 29, 2016. The court has set an April 2017 trial date in the Buck proceeding.

On June 13, 2016, the Roanoke River Basin Association filed a federal citizen suit in the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Mayo Plant. Duke Energy Progress expects to file a response to the complaint in third quarter of 2016.

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.

Potential Groundwater Contamination Claims

Beginning in May 2015, a number of residents living in the vicinity of the North Carolina facilities with ash basins received letters from NCDEQ advising them not to drink water from the private wells on their land tested by NCDEQ as the samples were found to have certain substances at levels higher than the criteria set by the North Carolina Department of Health and Human Services (DHHS). The criteria, in some cases, are considerably more stringent than federal drinking water standards established to protect human health and welfare. The Coal Ash Act requires additional groundwater monitoring and assessments for each of the 14 coal-fired plants in North Carolina, including sampling of private water supply wells. The data gathered through these Comprehensive Site Assessments (CSAs) will be used by NCDEQ to determine whether the water quality of these private water supply wells has been adversely impacted by the ash basins. Duke Energy has submitted CSAs documenting the results of extensive groundwater monitoring around coal ash basins at all 14 of the plants with coal ash basins. Generally, the data gathered through the installation of new monitoring wells and soil and water samples across the state have been consistent with historical data provided to state regulators over many years. The DHHS and NCDEQ sent follow-up letters on October 15, 2015, to residents near coal ash basins who have had their wells tested, stating that private well samplings at a considerable distance from coal ash impoundments, as well as some municipal water supplies, contain similar levels of vanadium and hexavalent chromium which leads investigators to believe these constituents are naturally occurring. In March 2016, DHHS rescinded the advisories. It is not possible to estimate the maximum exposure of loss, if any, that may occur in connection with claims which might be made by these residents.

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 30, 2016, there were 89 asserted claims for non-malignant cases with the cumulative relief sought of up to $24 million, and 83 asserted claims for malignant cases with the cumulative relief sought of up to $15 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 $515 million at June 30, 2016 and $536 million at December 31, 2015. 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. 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 $847 million in excess of the self-insured retention. Receivables for insurance recoveries were $600 million at June 30, 2016 and $599 million at December 31, 2015. 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.

Duke Energy Florida

Class Action Lawsuit

On February 22, 2016, a lawsuit was filed in the U.S. District Court for the Southern District of Florida on behalf of a putative class of Duke Energy Florida and FP&L’s customers in Florida. The suit alleges the State of Florida’s nuclear power plant cost recovery statutes (NCRS) are unconstitutional and pre-empted by federal law. Plaintiffs claim they are entitled to repayment of all money paid by customers of Duke Energy Florida and FP&L as a result of the NCRS, as well as an injunction against any future charges under those statutes. The constitutionality of the NCRS has been challenged unsuccessfully in a number of prior cases on alternative grounds. Duke Energy Florida and FP&L filed motions to dismiss the complaint on May 5, 2016. Duke Energy Florida cannot predict the outcome of this matter.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Westinghouse Contract Litigation

On March 28, 2014, Duke Energy Florida filed a lawsuit against 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 Engineering, Procurement and Construction agreement (EPC) 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. Duke Energy Florida recognized an exit obligation as a result of the termination of the EPC contract.

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 alleged damages under the EPC 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. In November 2014, Westinghouse filed a Motion for Partial Judgment on the pleadings, which was denied on March 30, 2015. The trial date is set for October 17, 2016. On July 11, 2016, Duke Energy Florida and Westinghouse filed separate Motions for Summary Judgment. It is not possible to predict the outcome of the litigation, whether Duke Energy Florida will ultimately have any liability for terminating the EPC contract 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 nonpublic option agreements in exchange for their withdrawal of challenges to Duke Energy Ohio’s Rate Stabilization Plan implemented in early 2005. In March 2014, a federal judge certified this matter as a class action. Plaintiffs alleged claims of antitrust violations under the federal Robinson Patman Act as well as fraud and conspiracy allegations under the federal Racketeer Influenced and Corrupt Organizations statute and the Ohio Corrupt Practices Act.

During 2015, the parties received preliminary court approval of a settlement agreement. Duke Energy Ohio included a litigation reserve of $81 million in Other within Current Liabilities on the Consolidated Balance Sheet at December 31, 2015. Duke Energy Ohio recognized pretax charges of $71 million and $81 million in (Loss) Income from Discontinued Operations, net of tax in the Condensed Consolidated Statements of Operations and Comprehensive Income for the three and six months ended June 30, 2015, respectively. The settlement agreement was approved at a federal court hearing on April 19, 2016.

W.C. Beckjord Fuel Release

On August 18, 2014, approximately 9,000 gallons of fuel oil were inadvertently discharged into the Ohio River during a fuel oil transfer at the W.C. Beckjord generating station. The Ohio Environmental Protection Agency (Ohio EPA) issued a NOV related to the discharge. Duke Energy Ohio is cooperating with the Ohio EPA, the EPA and the U.S. Attorney for the Southern District of Ohio. No NOV has been issued by the EPA and no penalty has been assessed. Total repair and remediation costs related to the release were not material. Other costs related to the release, including state or federal civil or criminal enforcement proceedings, cannot be reasonably estimated at this time.

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, excluding asbestos related reserves and the exit obligation discussed above related to the termination of an EPC contract. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Accounts payable and Other within Current Liabilities. The reasonably possible range of loss in excess of recorded reserves is not material, other than as described above.

(in millions)	June 30, 2016		December 31, 2015
Reserves for Legal Matters
Duke Energy	$	110	$	166
Duke Energy Carolinas	14		11
Progress Energy	52		54
Duke Energy Progress	6		6
Duke Energy Florida	30		31
Duke Energy Ohio	4		80

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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, noncancelable 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.

6. DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

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

				Six Months Ended
				June 30, 2016
						Duke		Duke		Duke		Duke		Duke
	Maturity	Interest		Duke		Energy		Energy		Energy		Energy		Energy
Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Florida		Ohio		Indiana
Unsecured
April 2016(a)	April 2023	2.875	%	$	350	$	350	$	—	$	—	$	—	$	—
First Mortgage Bonds
March 2016(b)	March 2023	2.500	%	500		—		500		—		—		—
March 2016(b)	March 2046	3.875	%	500		—		500		—		—		—
May 2016(c)	May 2046	3.750	%	500		—		—		—		—		500
June 2016(b)	June 2046	3.700	%	250		—		—		—		250		—
Secured Debt
June 2016(d)	March 2020	1.196	%	183		—		—		183		—		—
June 2016(d)	September 2022	1.731	%	150		—		—		150		—		—
June 2016(d)	September 2029	2.538	%	436		—		—		436		—		—
June 2016(d)	March 2033	2.858	%	250		—		—		250		—		—
June 2016(d)	September 2036	3.112	%	275		—		—		275		—		—
Total issuances				$	3,394	$	350	$	1,000	$	1,294	$	250	$	500

(a) Proceeds were used to pay down outstanding commercial paper and for general corporate purposes.

(b) Proceeds were used to fund capital expenditures for ongoing construction, capital maintenance and for general corporate purposes.

(c) Proceeds were used to repay $325 million of unsecured debt due June 2016, $150 million of first mortgage bonds due July 2016 and for general corporate purposes.

(d) Proceeds from the nuclear asset recovery bonds issued by DEFPF, a bankruptcy remote subsidiary of Duke Energy Florida, were used to acquire nuclear asset-recovery property from its parent, Duke Energy Florida. The nuclear asset-recovery bonds are payable only from and secured by the nuclear asset-recovery property. DEFPF is consolidated for financial reporting purposes; however, the nuclear asset-recovery bonds do not constitute a debt, liability or other legal obligation of, or interest in, Duke Energy Florida or any of its affiliates other than DEFPF. The assets of DEFPF, including the nuclear asset-recovery property, are not available to pay creditors of Duke Energy Florida or any of its affiliates. Duke Energy Florida used the proceeds from the sale to repay short-term borrowings under the intercompany money pool borrowing arrangement and make an equity distribution of $649 million to the ultimate parent, Duke Energy (Parent), which repaid short-term borrowings. The nuclear asset-recovery bonds are sequential pay amortizing bonds. The maturity date above represents the scheduled final maturity date for the bonds. See Notes 4 and 12 for additional information.

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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		June 30, 2016
Unsecured Debt
Duke Energy (Parent)	November 2016	2.150	%	$	500
Duke Energy (Parent)	April 2017	1.009	%	400
Duke Energy	May 2017	15.530	%	56
Secured Debt
Duke Energy	June 2017	2.075	%	45
First Mortgage Bonds
Duke Energy Indiana	July 2016	0.979	%	150
Duke Energy Carolinas	December 2016	1.750	%	350
Duke Energy Progress	March 2017	0.880	%	250
Tax-exempt Bonds
Duke Energy Carolinas	February 2017	3.600	%	77
Duke Energy Ohio(a)	August 2027	1.280	%	50
Duke Energy Indiana(b)	May 2035	1.092	%	44
Other(c)				420
Current maturities of long-term debt				$	2,342

(a) Represents Duke Energy Kentucky's bonds with a mandatory put in December 2016.

(b) The bonds have a mandatory put in December 2016.

(c) Includes capital lease obligations, amortizing debt and small bullet maturities.

AVAILABLE CREDIT FACILITIES

Master Credit Facility

Duke Energy has a Master Credit Facility with a capacity of $7.5 billion through January 2020. The Duke Energy Registrants, excluding Progress Energy (Parent), have borrowing capacity under the Master Credit Facility up to a specified sublimit 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. Duke Energy Carolinas and Duke Energy Progress are also required to each maintain $250 million of available capacity under the Master Credit Facility as security to meet obligations under plea agreements reached with the U.S. Department of Justice in 2015 related to violations at North Carolina facilities with ash basins. The table below includes the current borrowing sublimits and available capacity under the Master Credit Facility.

	June 30, 2016
				Duke			Duke			Duke			Duke			Duke			Duke
	Duke			Energy			Energy			Energy			Energy			Energy			Energy
(in millions)	Energy			(Parent)			Carolinas			Progress			Florida			Ohio			Indiana
Facility size(a)	$	7,500		$	3,475		$	800		$	1,000		$	1,200		$	425		$	600
Reduction to backstop issuances
Commercial paper(b)	(1,673		)	(992		)	(300		)	(159		)	(47		)	(25		)	(150		)
Outstanding letters of credit	(77		)	(70		)	(4		)	(2		)	(1		)	—			—
Tax-exempt bonds	(116		)	—			(35		)	—			—			—			(81		)
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—
Available capacity	$	5,134		$	2,413		$	211		$	589		$	1,152		$	400		$	369

(a) Represents the sublimit of each borrower.

(b) Duke Energy issued $625 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana. The balances are classified as Long-Term Debt Payable to Affiliated Companies in the Condensed Consolidated Balance Sheets.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Piedmont Bridge Facility

In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion Bridge Facility with Barclays. The Bridge Facility, if drawn upon, may be used (i) to fund the cash consideration for the transaction and (ii) to pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to approximately $3.2 billion as a result of the Equity Forwards described in Note 13 and $1 billion of commitments under a term loan amended and restated as of August 1, 2016, described below. Refer to Note 2 for additional information on the Piedmont acquisition.

Term Loan Facility

On February 22, 2016, Duke Energy entered into a six-month term loan facility with commitments totaling $1.0 billion (the February 2016 Term Loan). As of June 30, 2016, $100 million was outstanding under the February 2016 Term Loan. On August 1, 2016, Duke Energy and each of the lenders under the February 2016 Term Loan amended and restated certain terms of this facility, resulting in aggregate commitments of $1.5 billion and extending the maturity date to July 31, 2017. 

As of August 1, 2016, $100 million has been drawn under the amended and restated term loan (the August 2016 Term Loan). The remaining $1.4 billion of commitments under the August 2016 Term Loan can be drawn in up to two separate borrowings, which must occur no later than 90 calendar days following August 1, 2016. Any borrowings under the August 2016 Term Loan will be used to manage short-term liquidity, including funding a portion of the Piedmont acquisition, and for general corporate purposes. The terms and conditions of the August 2016 Term Loan are generally consistent with those governing Duke Energy’s Master Credit Facility.

Solar Facilities Financing

In August 2016, Emerald State Solar, LLC, an indirect wholly owned subsidiary of Duke Energy, entered into a portfolio financing of approximately 22 North Carolina Solar facilities. The $333 million term loan facility consists of Tranche A of $228 million due in June 2034 secured by substantially all the assets of the solar facilities and Tranche B of $105 million due in June 2020 secured by an Equity Contribution Agreement with Duke Energy. The initial interest rate on the loans is six months London Interbank Offered Rate (LIBOR) plus an applicable margin. The initial applicable margin is 1.75 percent with 0.125 percent increases every three years thereafter. In connection with this debt issuance, Emerald State Solar, LLC entered into two interest rate swaps to convert the substantial majority of the loan interest payments from variable rates to fixed rates of approximately 1.81 percent for Tranche A and 1.38 percent for Tranche B, plus the applicable margin.

7. GOODWILL AND INTANGIBLE ASSETS

GOODWILL

The following table presents goodwill by reportable operating segment for Duke Energy.

Duke Energy

	Regulated		International		Commercial
(in millions)	Utilities		Energy		Portfolio		Total
Goodwill at December 31, 2015	$	15,950	$	271	$	122	$	16,343
Foreign exchange changes	—		14		—		14
Goodwill at June 30, 2016	$	15,950	$	285	$	122	$	16,357

Duke Energy Ohio

Duke Energy Ohio's Goodwill balance of $920 million is included in the Regulated Utilities operating segment and presented net of accumulated impairment charges of $216 million on the Condensed Consolidated Balance Sheets at June 30, 2016 and December 31, 2015.

Progress Energy

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

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

8. RELATED PARTY TRANSACTIONS

The Subsidiary Registrants engage in related party transactions in accordance with 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,
(in millions)	2016		2015		2016		2015
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	202	$	416	$	421
Indemnification coverages(b)	5		6		11		12
JDA revenue(c)	2		14		11		40
JDA expense(c)	50		38		91		95
Progress Energy
Corporate governance and shared service expenses(a)	$	160	$	172	$	334	$	339
Indemnification coverages(b)	9		9		17		19
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	89	$	93	$	189	$	194
Indemnification coverages(b)	4		4		7		8
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	79	$	145	$	145
Indemnification coverages(b)	5		5		10		11
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	87	$	103	$	172	$	188
Indemnification coverages(b)	1		1		2		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	89	$	83	$	183	$	172
Indemnification coverages(b)	2		2		4		4

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, 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) Duke Energy Carolinas and Duke Energy Progress participate in a JDA which 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.

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 months ended June 30, 2016 and 2015 for the Subsidiary Registrants.

As discussed in Note 12, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to CRC, an affiliate formed by a subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but also include a subordinated note from the affiliate for a portion of the purchase price.

Duke Energy Ohio's nonregulated indirect subsidiary, Duke Energy Commercial Asset Management (DECAM), owned generating plants included in the Disposal Group sold to Dynegy on April 2, 2015. On April 1, 2015, Duke Energy Ohio distributed its indirect ownership interest in DECAM to a Duke Energy subsidiary and non-cash settled DECAM's intercompany loan payable of $294 million. Refer to Note 2 for further information on the sale of the Disposal Group.

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Intercompany Income Taxes

Duke Energy and the Subsidiary Registrants file a consolidated federal income tax return and other state and jurisdictional returns. The Subsidiary Registrants have a tax sharing agreement with Duke Energy for the allocation of consolidated tax liabilities and benefits. Income taxes recorded represent amounts the Subsidiary Registrants would incur as separate C-Corporations. The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana
June 30, 2016
Intercompany income tax receivable	$	10	$	90	$	—	$	—	$	15	$	6
Intercompany income tax payable	—		—		11		48		—		—
December 31, 2015
Intercompany income tax receivable	$	122	$	120	$	104	$	—	$	54	$	—
Intercompany income tax payable	—		—		—		96		—		47

9. DERIVATIVES AND HEDGING

The Duke Energy Registrants use commodity and interest rate contracts to manage commodity price risk and interest rate risk. The primary use of 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 arrangements is offset against the collateralized derivatives on the Condensed Consolidated Balance Sheets. The cash impacts of settled derivatives are recorded as operating activities on the Condensed Consolidated Statements of Cash Flows.

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.

Cash Flow Hedges

For a derivative designated as hedging the exposure to variable cash flows of a future transaction, referred to as a cash flow hedge, the effective portion of the derivative's gain or loss is initially reported as a component of other comprehensive income and subsequently reclassified into earnings once the future transaction affects earnings. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt. Gains and losses reclassified out of Accumulated other comprehensive income (AOCI) for the three and six months ended June 30, 2016, were not material. Duke Energy's interest rate derivatives designated as hedges include interest rate swaps used to hedge existing debt within the International Energy and Renewables' businesses.

Undesignated Contracts

Undesignated contracts include contracts not designated as a hedge because they are accounted for under regulatory accounting and contracts that do not qualify for hedge accounting.

Duke Energy’s interest rate swaps for its Regulated Utilities operations employ regulatory accounting. With regulatory accounting, the mark-to-market gains or losses on the swaps are deferred as regulatory liabilities or regulatory assets, respectively. Regulatory assets and liabilities are amortized consistent with the treatment of the related costs in the ratemaking process. The accrual of interest on the swaps is recorded as Interest Expense.

As of June 30, 2016, Duke Energy has entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. The swaps do not qualify for hedge accounting and are marked-to-market, with any gains or losses included within earnings. Unrealized losses on the swaps of $75 million and $168 million were included within Interest Expense on the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2016. The swaps will be terminated in conjunction with the acquisition financing. See Note 2 for additional information related to the Piedmont acquisition.

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

The following table shows notional amounts of outstanding derivatives related to interest rate risk.

	June 30, 2016
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	663	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	2,327		400		500		250		250		27
Total notional amount	$	2,990	$	400	$	500	$	250	$	250	$	27

	December 31, 2015
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	700	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,827		400		500		250		250		27
Total notional amount	$	2,527	$	400	$	500	$	250	$	250	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $463 million at June 30, 2016 and $497 million at December 31, 2015.

COMMODITY PRICE RISK

The Duke Energy Registrants are exposed to the impact of changes in the 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.

Regulated public utilities may have cost-based rate regulations and various other cost recovery mechanisms that result in a limited exposure to market volatility of commodity fuel prices. Financial derivative contracts, where approved by the respective state regulatory commissions, can be used to manage the risk of price volatility. At June 30, 2016, substantially all of Duke Energy's open commodity derivative instruments were undesignated because they are accounted for under regulatory accounting. Mark-to-market gains or losses on contracts that use regulatory accounting are deferred as regulatory liabilities or regulatory assets, respectively. Undesignated contracts expire as late as 2020.

The Subsidiary Registrants utilize cost-tracking mechanisms, commonly referred to as fuel adjustment clauses. These clauses allow for the recovery of fuel and fuel-related costs, including settlements of undesignated derivatives for fuel commodities, and portions of purchased power costs through surcharges on customer rates. The difference between the costs incurred and the surcharge revenues is recorded as an adjustment to Fuel used in electric generation and purchased power – regulated or as Operating Revenues: Regulated electric on the Condensed Consolidated Statements of Operations, with an offsetting impact on regulatory assets or liabilities. Therefore, due to the regulatory accounting followed by the Subsidiary Registrants for undesignated derivatives, realized and unrealized gains and losses on undesignated commodity derivatives do not have an immediate impact on reported net income.

Volumes

The tables below show volumes of outstanding commodity derivatives. Amounts disclosed represent the absolute value of notional volumes of commodity contracts excluding NPNS. 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, 2016
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana
Electricity (gigawatt-hours)	7	—	—	—	—	—	7
Natural gas (millions of decatherms)	418	80	338	124	214	—	—

	December 31, 2015
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana
Electricity (gigawatt-hours)	70	—	—	—	—	34	36
Natural gas (millions of decatherms)	398	66	332	117	215	—	—

60

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

LOCATION AND FAIR VALUE OF DERIVATIVE ASSETS AND LIABILITIES RECOGNIZED IN THE CONDENSED CONSOLIDATED BALANCE SHEETS

The following tables show the fair value and balance sheet location of derivative instruments. 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.

Derivative Assets	June 30, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	64	$	8	$	20	$	8	$	12	$	5	$	31
Noncurrent	28		10		18		10		8		—		—
Total Derivative Assets – Commodity Contracts	$	92	$	18	$	38	$	18	$	20	$	5	$	31
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	$	3	$	—	$	3	$	1	$	2	$	—	$	—
Noncurrent	13		—		13		6		7		—		—
Total Derivative Assets – Interest Rate Contracts	$	16	$	—	$	16	$	7	$	9	$	—	$	—
Total Derivative Assets	$	108	$	18	$	54	$	25	$	29	$	5	$	31

Derivative Liabilities	June 30, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	84	$	7	$	77	$	18	$	59	$	—	$	1
Noncurrent	23		—		23		—		17		—		—
Total Derivative Liabilities – Commodity Contracts	$	107	$	7	$	100	$	18	$	76	$	—	$	1
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	9	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	52		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current(a)	170		—		—		—		—		1		—
Noncurrent	90		82		—		—		—		7		—
Total Derivative Liabilities – Interest Rate Contracts	$	321	$	82	$	—	$	—	$	—	$	8	$	—
Total Derivative Liabilities	$	428	$	89	$	100	$	18	$	76	$	8	$	1

(a) Duke Energy amount includes $168 million related to forward-starting interest rate swaps associated with the Piedmont acquisition.

61

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Derivative Assets	December 31, 2015
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	12	$	—	$	1	$	—	$	1	$	3	$	7
Noncurrent	4		—		4		—		4		—		—
Total Derivative Assets – Commodity Contracts	$	16	$	—	$	5	$	—	$	5	$	3	$	7
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	4	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	6		—		6		2		2		—		—
Total Derivative Assets – Interest Rate Contracts	$	10	$	—	$	6	$	2	$	2	$	—	$	—
Total Derivative Assets	$	26	$	—	$	11	$	2	$	7	$	3	$	7

Derivative Liabilities	December 31, 2015
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	256	$	32	$	222	$	77	$	145	$	—	$	—
Noncurrent	100		8		92		16		71		—		—
Total Derivative Liabilities – Commodity Contracts	$	356	$	40	$	314	$	93	$	216	$	—	$	—
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	11	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	33		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	4		—		3		—		—		1		—
Noncurrent	15		5		5		5		—		6		—
Total Derivative Liabilities – Interest Rate Contracts	$	63	$	5	$	8	$	5	$	—	$	7	$	—
Total Derivative Liabilities	$	419	$	45	$	322	$	98	$	216	$	7	$	—

OFFSETTING ASSETS AND LIABILITIES

The following tables present the line items on the Condensed Consolidated Balance Sheets where derivatives are reported. Substantially all of Duke Energy's outstanding derivative contracts are subject to enforceable master netting arrangements. The Gross amounts offset in the tables below show the effect of these netting arrangements on financial position, and include collateral posted to offset the net position. The amounts shown are 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.

62

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Derivative Assets	June 30, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	67		$	8		$	23		$	9		$	14		$	5	$	31
Gross amounts offset	(15		)	(3		)	(13		)	(6		)	(7		)	—		—
Net amounts presented in Current Assets: Other	$	52		$	5		$	10		$	3		$	7		$	5	$	31
Noncurrent
Gross amounts recognized	$	41		$	10		$	31		$	16		$	15		$	—	$	—
Gross amounts offset	(5		)	—			(5		)	—			(4		)	—		—
Net amounts presented in Investments and Other Assets: Other	$	36		$	10		$	26		$	16		$	11		$	—	$	—

Derivative Liabilities	June 30, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	263		$	7		$	77		$	18		$	59		$	1	$	1
Gross amounts offset	(15		)	(3		)	(13		)	(6		)	(7		)	—		—
Net amounts presented in Current Liabilities: Other	$	248		$	4		$	64		$	12		$	52		$	1	$	1
Noncurrent
Gross amounts recognized	$	165		$	82		$	23		$	—		$	17		$	7	$	—
Gross amounts offset	(5		)	—			(5		)	—			(4		)	—		—
Net amounts presented in Deferred Credits and Other Liabilities: Other	$	160		$	82		$	18		$	—		$	13		$	7	$	—

Derivative Assets	December 31, 2015
				Duke					Duke		Duke			Duke		Duke
	Duke			Energy		Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas		Energy			Progress		Florida			Ohio		Indiana
Current
Gross amounts recognized	$	18		$	—	$	7		$	2	$	3		$	3	$	7
Gross amounts offset	(3		)	—		(2		)	—		(2		)	—		—
Net amounts presented in Current Assets: Other	$	15		$	—	$	5		$	2	$	1		$	3	$	7
Noncurrent
Gross amounts recognized	$	8		$	—	$	4		$	—	$	4		$	—	$	—
Gross amounts offset	(4		)	—		(4		)	—		(4		)	—		—
Net amounts presented in Investments and Other Assets: Other	$	4		$	—	$	—		$	—	$	—		$	—	$	—

Derivative Liabilities	December 31, 2015
				Duke					Duke			Duke			Duke		Duke
	Duke			Energy		Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas		Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	271		$	32	$	225		$	77		$	145		$	1	$	—
Gross amounts offset	(22		)	—		(21		)	(1		)	(20		)	—		—
Net amounts presented in Current Liabilities: Other	$	249		$	32	$	204		$	76		$	125		$	1	$	—
Noncurrent
Gross amounts recognized	$	148		$	13	$	97		$	21		$	71		$	6	$	—
Gross amounts offset	(16		)	—		(15		)	—			(15		)	—		—
Net amounts presented in Deferred Credits and Other Liabilities: Other	$	132		$	13	$	82		$	21		$	56		$	6	$	—

63

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

OBJECTIVE CREDIT CONTINGENT FEATURES

Certain derivative contracts contain objective credit contingent features. These features include the requirement to post cash collateral or letters of credit 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 Ohio and Duke Energy Indiana were not material.

	June 30, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Aggregate fair value of derivatives in a net liability position	$	348	$	89	$	90	$	18	$	72
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	348		89		90		18		72

	December 31, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Aggregate fair value of derivatives in a net liability position	$	334	$	45	$	290	$	93	$	194
Fair value of collateral already posted	30		—		30		—		30
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	304		45		260		93		164

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 arrangement. Amounts disclosed below represent the receivables related to the right to reclaim cash collateral under master netting arrangements. All receivables presented below were offset against net derivative positions on the Condensed Consolidated Balance Sheets.

	June 30, 2016		December 31, 2015
(in millions)	Receivables		Receivables
Duke Energy	$	—	$	30
Progress Energy	—		30
Duke Energy Florida	—		30

10.INVESTMENTS IN DEBT AND EQUITY SECURITIES

The Duke Energy Registrants classify their investments in debt and equity securities as available-for-sale.

Duke Energy’s available-for-sale securities are primarily comprised of investments held in (i) the nuclear decommissioning 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 Other Post-Retirement Benefit Obligations (OPEB) plans and (iii) Bison.

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

Investment Trusts

The investments within the NDTF investments 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 losses associated with debt and equity securities within the Investment Trusts are considered other-than-temporary impairments and are recognized immediately.

Investments within the Investment Trusts generally qualify for regulatory accounting, and accordingly realized and unrealized gains and losses are deferred as a regulatory asset or liability. However, certain investments held in Duke Energy Florida's NDTF, which were acquired in a settlement with Florida Municipal Joint Owners (FMJO), do not qualify for regulatory accounting. Except for other than temporary impairments of unrealized losses, unrealized gains and losses on these assets are included in other comprehensive income until realized. The other than temporary impairments of realized amounts and unrealized losses are included within Other income and expense, net on the Condensed Consolidated Statements of Operations. The value of these assets has not materially changed since the assets were acquired from FMJO. As a result, there is no material impact on earnings of the Duke Energy Registrants.

64

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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. 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. If an other than temporary impairment exists, the unrealized loss is included in earnings. There were no material credit losses as of June 30, 2016 and December 31, 2015.

DUKE ENERGY

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	189	$	—	$	—	$	179
Equity securities	1,869		78		3,834		1,823		58		3,590
Corporate debt securities	22		1		480		7		8		432
Municipal bonds	12		1		307		5		1		185
U.S. government bonds	38		—		1,038		11		5		1,254
Other debt securities	1		3		144		—		4		177
Total NDTF	$	1,942	$	83	$	5,992	$	1,846	$	76	$	5,817
Other Investments
Cash and cash equivalents	$	—	$	—	$	27	$	—	$	—	$	29
Equity securities	34		1		98		32		1		95
Corporate debt securities	2		1		97		1		3		92
Municipal bonds	6		1		80		3		1		74
U.S. government bonds	2		—		47		—		—		45
Other debt securities	—		1		57		—		2		62
Total Other Investments(a)	$	44	$	4	$	406	$	36	$	7	$	397
Total Investments	$	1,986	$	87	$	6,398	$	1,882	$	83	$	6,214

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

(b) Substantially all these amounts are considered other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	88
Due after one through five years	660
Due after five through 10 years	511
Due after 10 years	991
Total	$	2,250

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	64	$	28	$	118	$	130
Realized losses	42		17		92		31

65

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY CAROLINAS

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	66	$	—	$	—	$	34
Equity securities	1,045		44		2,128		1,021		27		2,094
Corporate debt securities	13		1		309		3		5		292
Municipal bonds	2		—		42		1		—		33
U.S. government bonds	16		—		482		3		3		438
Other debt securities	1		3		136		—		4		147
Total NDTF	$	1,077	$	48	$	3,163	$	1,028	$	39	$	3,038
Other Investments
Other debt securities	$	—	$	1	$	3	$	—	$	1	$	3
Total Other Investments(a)	$	—	$	1	$	3	$	—	$	1	$	3
Total Investments	$	1,077	$	49	$	3,166	$	1,028	$	40	$	3,041

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	6
Due after one through five years	198
Due after five through 10 years	235
Due after 10 years	533
Total	$	972

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	33	$	17	$	67	$	107
Realized losses	19		11		56		23

66

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

PROGRESS ENERGY

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	123	$	—	$	—	$	145
Equity securities	824		34		1,706		802		31		1,496
Corporate debt securities	9		—		171		4		3		140
Municipal bonds	10		1		265		4		1		152
U.S. government bonds	22		—		556		8		2		816
Other debt securities	—		—		8		—		—		30
Total NDTF	$	865	$	35	$	2,829	$	818	$	37	$	2,779
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	18
Municipal bonds	4		—		47		3		—		45
Total Other Investments(a)	$	4	$	—	$	68	$	3	$	—	$	63
Total Investments	$	869	$	35	$	2,897	$	821	$	37	$	2,842

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	65
Due after one through five years	375
Due after five through 10 years	200
Due after 10 years	407
Total	$	1,047

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	31	$	9	$	50	$	21
Realized losses	23		5		36		6

67

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

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, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	58	$	—	$	—	$	110
Equity securities	614		28		1,379		596		25		1,178
Corporate debt securities	7		—		118		3		2		96
Municipal bonds	10		1		265		4		1		150
U.S. government bonds	14		—		281		6		2		486
Other debt securities	—		—		5		—		—		18
Total NDTF	$	645	$	29	$	2,106	$	609	$	30	$	2,038
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	1
Total Other Investments(a)	$	—	$	—	$	1	$	—	$	—	$	1
Total Investments	$	645	$	29	$	2,107	$	609	$	30	$	2,039

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	14
Due after one through five years	191
Due after five through 10 years	154
Due after 10 years	310
Total	$	669

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	27	$	8	$	42	$	17
Realized losses	20		4		31		5

68

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

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, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	65	$	—	$	—	$	35
Equity securities	210		6		327		206		6		318
Corporate debt securities	2		—		53		1		1		44
Municipal bonds	—		—		—		—		—		2
U.S. government bonds	8		—		275		2		—		330
Other debt securities	—		—		3		—		—		12
Total NDTF	$	220	$	6	$	723	$	209	$	7	$	741
Other Investments
Cash and cash equivalents	$	—	$	—	$	4	$	—	$	—	$	6
Municipal bonds	4		—		47		3		—		45
Total Other Investments(a)	$	4	$	—	$	51	$	3	$	—	$	51
Total Investments	$	224	$	6	$	774	$	212	$	7	$	792

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	51
Due after one through five years	184
Due after five through 10 years	46
Due after 10 years	97
Total	$	378

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	4	$	1	$	8	$	4
Realized losses	3		1		5		1

69

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

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, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	2
Equity securities	28		—		73		27		—		71
Corporate debt securities	—		—		2		—		—		2
Municipal bonds	1		1		29		—		1		26
Total Other Investments(a)	$	29	$	1	$	104	$	27	$	1	$	101
Total Investments	$	29	$	1	$	104	$	27	$	1	$	101

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	2
Due after one through five years	16
Due after five through 10 years	8
Due after 10 years	5
Total	$	31

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 months ended June 30, 2016 and 2015.

11. 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.

Not Categorized – Certain investments are not categorized within the Fair Value hierarchy. These investments are measured based on the fair value of the underlying investments but may not be readily redeemable at that fair value.

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.

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 during the three and six months endedJune 30, 2016 and 2015.

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 Composite (NASDAQ) and New York Stock Exchange (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 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 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 natural 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 the fair value of natural 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.

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. See Note 10 for additional information related to investments by major security type.

	June 30, 2016
(in millions)	Total Fair Value			Level 1			Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	3,834		$	3,666		$	1		$	—	$	167
Nuclear decommissioning trust fund debt securities	2,158			744			1,414			—		—
Other available-for-sale equity securities	98			98			—			—		—
Other available-for-sale debt securities	308			74			230			4		—
Derivative assets	108			2			72			34		—
Total assets	6,506			4,584			1,717			38		167
Derivative liabilities	(428		)	(1		)	(427		)	—		—
Net assets	$	6,078		$	4,583		$	1,290		$	38	$	167

71

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	3,590		$	3,418	$	—		$	—	$	172
Nuclear decommissioning trust fund debt securities	2,227			672		1,555			—		—
Other available-for-sale equity securities	95			95		—			—		—
Other available-for-sale debt securities	302			75		222			5		—
Derivative assets	26			—		16			10		—
Total assets	6,240			4,260		1,793			15		172
Derivative liabilities	(419		)	—		(419		)	—		—
Net assets	$	5,821		$	4,260	$	1,374		$	15	$	172

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. There was no change to the Level 3 balance during the three months endedJune 30, 2015.

	Three Months Ended June 30, 2016
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	4	$	2		$	6
Purchases, sales, issuances and settlements:
Purchases	—		34			34
Settlements	—		(6		)	(6		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		4			4
Balance at end of period	$	4	$	34		$	38

	Six Months Ended June 30, 2016
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	5		$	10		$	15
Purchases, sales, issuances and settlements:
Purchases	—			34			34
Sales	(1		)	—			(1		)
Settlements	—			(13		)	(13		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—			3			3
Balance at end of period	$	4		$	34		$	38

	Six Months Ended June 30, 2015
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	5	$	(1	)	$	4
Total pretax realized or unrealized gains included in earnings	—		18			18
Purchases, sales, issuances and settlements:
Purchases	—		24			24
Settlements	—		(22		)	(22		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		4			4
Balance at end of period	$	5	$	23		$	28

72

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY CAROLINAS

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,128		$	1,960	$	1		$	—	$	167
Nuclear decommissioning trust fund debt securities	1,035			245		790			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	18			—		18			—		—
Total assets	3,184			2,205		809			3		167
Derivative liabilities	(89		)	—		(89		)	—		—
Net assets	$	3,095		$	2,205	$	720		$	3	$	167

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,094		$	1,922	$	—		$	—	$	172
Nuclear decommissioning trust fund debt securities	944			246		698			—		—
Other available-for-sale debt securities	3			—		—			3		—
Total assets	3,041			2,168		698			3		172
Derivative liabilities	(45		)	—		(45		)	—		—
Net assets	$	2,996		$	2,168	$	653		$	3	$	172

There was no change to the Level 3 balance during the three and six months ended June 30, 2016 and June 30, 2015.

PROGRESS 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. See Note 10 for additional information related to investments by major security type.

	June 30, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,706		$	1,706	$	—
Nuclear decommissioning trust fund debt securities	1,123			499		624
Other available-for-sale debt securities	68			21		47
Derivative assets	54			—		54
Total assets	2,951			2,226		725
Derivative liabilities	(100		)	—		(100		)
Net assets	$	2,851		$	2,226	$	625

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,496		$	1,496	$	—
Nuclear decommissioning trust fund debt securities	1,283			426		857
Other available-for-sale debt securities	63			18		45
Derivative assets	11			—		11
Total assets	2,853			1,940		913
Derivative liabilities	(322		)	—		(322		)
Net assets	$	2,531		$	1,940	$	591

73

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY PROGRESS

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,379		$	1,379	$	—
Nuclear decommissioning trust fund debt securities and other	727			228		499
Other available-for-sale debt securities and other	1			1		—
Derivative assets	25			—		25
Total assets	2,132			1,608		524
Derivative liabilities	(18		)	—		(18		)
Net assets	$	2,114		$	1,608	$	506

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,178		$	1,178	$	—
Nuclear decommissioning trust fund debt securities and other	860			141		719
Other available-for-sale debt securities and other	1			1		—
Derivative assets	2			—		2
Total assets	2,041			1,320		721
Derivative liabilities	(98		)	—		(98		)
Net assets	$	1,943		$	1,320	$	623

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	327		$	327	$	—
Nuclear decommissioning trust fund debt securities and other	396			271		125
Other available-for-sale debt securities and other	51			4		47
Derivative assets	29			—		29
Total assets	803			602		201
Derivative liabilities	(76		)	—		(76		)
Net assets	$	727		$	602	$	125

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	318		$	318	$	—
Nuclear decommissioning trust fund debt securities and other	423			285		138
Other available-for-sale debt securities and other	51			6		45
Derivative assets	7			—		7
Total assets	799			609		190
Derivative liabilities	(216		)	—		(216		)
Net assets (liabilities)	$	583		$	609	$	(26	)

74

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY OHIO

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 are disclosed in Note 9.

	June 30, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	5		$	—	$	—		$	5
Derivative liabilities	(8		)	—		(8		)	—
Net (liabilities) assets	$	(3	)	$	—	$	(8	)	$	5

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	3		$	—	$	—		$	3
Derivative liabilities	(7		)	—		(7		)	—
Net (liabilities) assets	$	(4	)	$	—	$	(7	)	$	3

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

	Derivatives (net)
	Three Months Ended June 30,
(in millions)	2016		2015
Balance at beginning of period	$	—	$	7
Total pretax realized or unrealized gains included in earnings	—		(4		)
Purchases, sales, issuances and settlements:
Purchases	5		—
Sales	—		5
Settlements	—		(3		)
Balance at end of period	$	5	$	5

	Derivatives (net)
	Six Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	3		$	(18	)
Total pretax realized or unrealized gains included in earnings	—			21
Purchases, sales, issuances and settlements:
Purchases	5			—
Sales	—			5
Settlements	(2		)	(3		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(1		)	—
Balance at end of period	$	5		$	5

75

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 9. See Note 10 for additional information related to investments by major security type.

	June 30, 2016
(in millions)	Total Fair Value			Level 1			Level 2		Level 3
Other available-for-sale equity securities	$	73		$	73		$	—	$	—
Other available-for-sale debt securities and other	31			—			31		—
Derivative assets	31			2			—		29
Total assets	135			75			31		29
Derivative liabilities	(1		)	(1		)	—		—
Net assets	$	134		$	74		$	31	$	29

	December 31, 2015
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Other available-for-sale equity securities	$	71	$	71	$	—	$	—
Other available-for-sale debt securities and other	30		2		28		—
Derivative assets	7		—		—		7
Net assets	$	108	$	73	$	28	$	7

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

	Derivatives (net)
	Three Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	2		$	3
Purchases, sales, issuances and settlements:
Purchases	29			18
Settlements	(6		)	(10		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4			6
Balance at end of period	$	29		$	17

	Derivatives (net)
	Six Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	7		$	14
Purchases, sales, issuances and settlements:
Purchases	29			18
Settlements	(11		)	(19		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4			4
Balance at end of period	$	29		$	17

76

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

The following table includes quantitative information about the Duke Energy Registrants' derivatives classified as Level 3. As of June 30, 2016 and December 31, 2015, all Level 3 derivatives were financial transmission rights (FTRs).

	June 30, 2016
	Fair Value of FTRs
	(in millions)		Valuation Technique	Unobservable Input	Range
Duke Energy	$	34	RTO auction pricing	FTR price – per Megawatt-Hour (MWh)	$	(1.64	)	-	$	8.64
Duke Energy Ohio	5		RTO auction pricing	FTR price – per MWh	0.36			-	2.47
Duke Energy Indiana	29		RTO auction pricing	FTR price – per MWh	(1.64		)	-	8.64

	December 31, 2015
	Fair Value of FTRs
	(in millions)		Valuation Technique	Unobservable Input	Range
Duke Energy	$	10	RTO auction pricing	FTR price – per MWh	$	(0.74	)	-	$	7.29
Duke Energy Ohio	3		RTO auction pricing	FTR price – per MWh	0.67			-	2.53
Duke Energy Indiana	7		RTO auction pricing	FTR price – per MWh	(0.74		)	-	7.29

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, 2016				December 31, 2015
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy	$	42,273	$	47,953	$	39,569	$	42,537
Duke Energy Carolinas	9,360		10,874		8,367		9,156
Progress Energy	15,486		16,715		14,464		15,856
Duke Energy Progress	6,565		7,344		6,518		6,757
Duke Energy Florida	5,540		5,226		4,266		4,908
Duke Energy Ohio	1,887		2,134		1,598		1,724
Duke Energy Indiana	3,937		4,717		3,768		4,219

At both June 30, 2016 and December 31, 2015, fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper, and non-recourse notes payable of VIEs 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. 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 activities of the VIE that most significantly impact its economic performance and (ii) what party has rights to receive benefits or is obligated to absorb losses that could potentially be significant to the VIE. The analysis of the party that consolidates a VIE is a continual reassessment.

CONSOLIDATED VIEs

The obligations of the consolidated VIEs discussed in the following paragraphs are nonrecourse to the Duke Energy registrants. The registrants have no requirement to provide liquidity to, purchase assets of or guarantee performance of these VIEs unless noted in the following paragraphs.

No financial support was provided to any of the consolidated VIEs during the six months ended June 30, 2016 and the year ended December 31, 2015, or is expected to be provided in the future, that was not previously contractually required.

Receivables Financing – DERF / DEPR / DEFR

Duke Energy Receivables Finance Company, LLC (DERF), Duke Energy Progress Receivables, LLC (DEPR) and Duke Energy Florida Receivables, LLC (DEFR) are bankruptcy remote, special purpose subsidiaries of Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively. DERF, DEPR and DEFR are wholly owned limited liability companies with separate legal existence from their parent companies, and their assets are not generally available to creditors of their parent companies. On a revolving basis, DERF, DEPR and DEFR buy certain accounts receivable arising from the sale of electricity and related services from their parent companies.

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DERF, DEPR and DEFR borrow amounts under credit facilities to buy these receivables. Borrowing availability from the credit facilities is limited to the amount of qualified receivables purchased. The sole source of funds to satisfy the related debt obligations is cash collections from the receivables. Amounts borrowed under the credit facilities are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt.

The most significant activity that impacts the economic performance of DERF, DEPR and DEFR are the decisions made to manage delinquent receivables. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida consolidate DERF, DEPR and DEFR, respectively, as they make those decisions.

Receivables Financing – CRC

CRC is a bankruptcy remote, special purpose entity indirectly owned by Duke Energy. On a revolving basis, CRC buys certain accounts receivable arising from the sale of electricity and related services from Duke Energy Ohio and Duke Energy Indiana. CRC borrows amounts under a credit facility to buy the receivables from Duke Energy Ohio and Duke Energy Indiana. Borrowing availability from the credit facility is limited to the amount of qualified receivables sold to CRC. The sole source of funds to satisfy the related debt obligation is cash collections from the receivables. Amounts borrowed under the credit facility are reflected on Duke Energy's Condensed Consolidated Balance Sheets as Long-Term Debt.

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. Depending on collection experience, additional equity infusions to CRC may be required by Duke Energy to maintain a minimum equity balance of $3 million.

CRC is considered a VIE because (i) equity capitalization is insufficient to support its operations, (ii) power to direct the activities that most significantly impact the economic performance of the entity are not performed by the equity holder, and (iii) deficiencies in net worth of CRC are funded by Duke Energy. The most significant activities that impact the economic performance of CRC are decisions made to manage delinquent receivables. Duke Energy consolidates CRC as it makes these decisions. Neither Duke Energy Ohio nor Duke Energy Indiana consolidate CRC.

Receivables Financing – Credit Facilities

The following table summarizes the amounts and expiration dates of the credit facilities described above. Amounts borrowed under the credit facilities are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
	CRC		DERF		DEPR		DEFR
Expiration date	December 2018		December 2018		February 2019		April 2019
Credit facility amount (in millions)	$	325	$	425	$	300	$	225
Amounts borrowed at June 30, 2016	325		425		300		225
Amounts borrowed at December 31, 2015	325		425		254		225

Nuclear Asset-Recovery Bonds – DEFPF

DEFPF is a bankruptcy remote, wholly owned special purpose subsidiary of Duke Energy Florida. DEFPF was formed in 2016 for the sole purpose of issuing nuclear asset-recovery bonds to finance Duke Energy Florida's unrecovered regulatory asset related to Crystal River Unit 3.

In June 2016, DEFPF issued $1,294 million of senior secured bonds and used the proceeds to acquire nuclear asset-recovery property from Duke Energy Florida. The nuclear asset-recovery property acquired includes the right to impose, bill, collect and adjust a non-bypassable nuclear asset-recovery charge from all Duke Energy Florida retail customers until the bonds are paid in full and all financing costs have been recovered. The nuclear asset-recovery bonds are secured by the nuclear asset-recovery property, and cash collections from the nuclear asset-recovery charges are the sole source of funds to satisfy the debt obligation. The bondholders have no recourse to Duke Energy Florida. For additional information see Notes 4 and 6.

DEFPF is considered a VIE primarily because the equity capitalization is insufficient to support its operations. Duke Energy Florida has the power to direct the significant activities of the VIE as described above, and therefore Duke Energy Florida is considered the primary beneficiary and consolidates DEFPF.

The following table summarizes the impact of DEFPF on Duke Energy Florida's Condensed Consolidated Balance Sheets.

(in millions)	June 30, 2016
Regulatory Assets: Current	$	34
Current Assets: Other	7
Regulatory Assets and Deferred Debits: Regulatory assets	1,194
Current maturities of long-term debt	35
Long-Term Debt	1,243

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Renewables

Certain Duke Energy renewable energy facilities are VIEs due to long-term fixed-price power purchase agreements. These fixed-price agreements effectively transfer commodity price risk to the buyer of the power. Certain other Duke Energy renewable energy facilities are VIEs due to Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. For certain VIEs, assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders. The activities that most significantly 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 is responsible for all of these decisions.

The table below presents material balances reported on Duke Energy's Condensed Consolidated Balance Sheets related to renewables VIEs.

(in millions)	June 30, 2016			December 31, 2015
Current Assets: Other	$	223		$	138
Property, plant and equipment, cost	2,578			2,015
Accumulated depreciation and amortization	(376		)	(321		)
Current maturities of long-term debt	154			108
Long-Term Debt	866			968
Deferred Credits and Other Liabilities: Deferred income taxes	31			289
Deferred Credits and Other Liabilities: Other	277			33

NON-CONSOLIDATED VIEs

The following tables summarize the impact of non-consolidated VIEs on the Condensed Consolidated Balance Sheets.

	June 30, 2016
	Duke Energy						Duke		Duke
							Energy		Energy
(in millions)	Renewables		Other		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	39	$	58
Investments in equity method unconsolidated affiliates	222		252		474		—		—
Total assets	$	222	$	252	$	474	$	39	$	58
Other current liabilities	—		3		3		—		—
Deferred credits and other liabilities	—		13		13		—		—
Total liabilities	$	—	$	16	$	16	$	—	$	—
Net assets	$	222	$	236	$	458	$	39	$	58

	December 31, 2015
	Duke Energy						Duke		Duke
							Energy		Energy
(in millions)	Renewables		Other		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	47	$	60
Investments in equity method unconsolidated affiliates	235		152		387		—		—
Total assets	$	235	$	152	$	387	$	47	$	60
Other current liabilities	—		3		3		—		—
Deferred credits and other liabilities	—		14		14		—		—
Total liabilities	$	—	$	17	$	17	$	—	$	—
Net assets	$	235	$	135	$	370	$	47	$	60

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 Ohio Valley Electric Corporation (OVEC), which is discussed below, and various guarantees, reflected in the table above as Deferred credits and other liabilities. For more information on various guarantees, refer to Note 5.

Renewables

Duke Energy has investments in various renewable energy project entities. Some of these entities are VIEs due to long-term fixed-price power purchase agreements. 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.

79

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Other

Duke Energy holds a 50 percent equity interest in Duke-American Transmission Company, LLC (DATC). DATC is considered a VIE due to insufficient equity at risk to permit DATC to finance its own activities without additional subordinated financial support. The activities that most significantly impact DATC’s economic performance are the decisions related to investing in existing and development of new transmission facilities. The power to direct these activities is jointly and equally shared by Duke Energy and the other joint venture partner, and therefore Duke Energy does not consolidate DATC.

Duke Energy has a 40 percent equity interest and a 7.5 percent equity interest in ACP and Sabal Trail Transmission, LLC (Sabal Trail), respectively. These entities are considered VIEs as their equity is not sufficient to permit the entities to finance their activities without additional subordinated financial support. The activity that most significantly impacts the economic performance of both ACP and Sabal Trail is construction. Duke Energy does not control these activities and therefore does not consolidate ACP or Sabal Trail.

OVEC

Duke Energy Ohio’s 9 percent ownership interest in OVEC is considered a non-consolidated VIE. 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. Proposed environmental rulemaking could increase the costs of OVEC, which would be passed through to Duke Energy Ohio.

CRC

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

Amounts included in Receivables from affiliated companies 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. 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 turn over 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
	2016		2015		2016		2015
Anticipated credit loss ratio	0.5	%	0.6	%	0.3	%	0.3	%
Discount rate	1.4	%	1.2	%	1.4	%	1.2	%
Receivable turnover rate	13.2	%	12.9	%	10.6	%	10.6	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Receivables sold	$	208	$	233	$	279	$	260
Less: Retained interests	39		47		58		60
Net receivables sold	$	169	$	186	$	221	$	200

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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

	Duke Energy Ohio								Duke Energy Indiana
	Three Months Ended				Six Months Ended				Three Months Ended				Six Months Ended
	June 30,				June 30,				June 30,				June 30,
(in millions)	2016		2015		2016		2015		2016		2015		2016		2015
Sales
Receivables sold	$	429	$	425	$	961	$	1,069	$	623	$	637	$	1,258	$	1,353
Loss recognized on sale	2		2		5		5		2		2		5		5
Cash flows
Cash proceeds from receivables sold	427		467		964		1,107		612		660		1,255		1,382
Collection fees received	—		1		—		1		1		1		1		1
Return received on retained interests	—		1		1		2		1		1		2		3

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 the prior month-end LIBOR plus a fixed rate of 1.00 percent.

13. COMMON STOCK

Basic Earnings Per Share (EPS) is computed by dividing net income attributable to Duke Energy common stockholders, adjusted for distributed and undistributed earnings allocated to participating securities, by the weighted average number of common stock outstanding during the period. Diluted EPS is computed by dividing net income attributable to Duke Energy common stockholders, as adjusted for distributed and undistributed earnings allocated to participating securities, by the diluted weighted average number of common stock 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 and the Equity Forwards, were exercised or settled. Duke Energy’s participating securities are restricted stock units that are entitled to dividends declared on Duke Energy common stock 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 stock outstanding to the diluted weighted average number of common shares outstanding.

	Three Months Ended June 30,				Six Months Ended June 30,
(in millions, except per-share amounts)	2016		2015		2016		2015
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	508	$	600	$	1,199	$	1,372
Weighted average shares outstanding – basic	689		692		689		700
Equity Forwards	1		—		—		—
Weighted average shares outstanding – diluted	690		692		689		700
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	0.74	$	0.87	$	1.74	$	1.96
Diluted	$	0.74	$	0.87	$	1.74	$	1.96
Potentially dilutive items excluded from the calculation(a)	2		2		2		2
Dividends declared per common share	$	0.825	$	0.795	$	1.65	$	1.59

(a) Performance stock awards were not included in the dilutive securities calculation because the performance measures related to the awards had not been met.

Equity Forwards

In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into Equity Forwards with Barclays. No amounts have or will be recorded in Duke Energy’s Condensed Consolidated Financial Statements with respect to the equity offering until settlements of the Equity Forwards occur. The Equity Forwards require Duke Energy to, at its election prior to June 30, 2017, either physically settle the transactions by issuing the total of 10.6 million of its common stock to Barclays in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $69.84 per share) or Duke Energy can net settle the transactions in whole or in part through the delivery or receipt of cash or shares. If Duke Energy had elected to net share settle the contract as of June 30, 2016, Duke Energy would have been required to deliver 2.1 million shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreements. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont.

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DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Until settlement of the Equity Forwards, earnings per share dilution resulting from the agreements will be determined under the treasury stock method.

Accelerated Stock Repurchase Program

On April 6, 2015, Duke Energy entered into agreements with each of Goldman, Sachs & Co. and JPMorgan Chase Bank, National Association (the Dealers) to repurchase a total of $1.5 billion of Duke Energy common stock under an accelerated stock repurchase program (the ASR). Duke Energy made payments of $750 million to each of the Dealers and was delivered 16.6 million shares, with a total fair value of $1.275 billion, which represented approximately 85 percent of the total number of shares of Duke Energy common stock expected to be repurchased under the ASR. The company recorded the $1.5 billion payment as a reduction to common stock as of April 6, 2015. In June 2015, the Dealers delivered 3.2 million additional shares to Duke Energy to complete the ASR. Approximately 19.8 million shares, in total, were delivered to Duke Energy and retired under the ASR at an average price of $75.75 per share. The final number of shares repurchased was based upon the average of the daily volume weighted average stock prices of Duke Energy’s common stock during the term of the program, less a discount.

14. 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.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Restricted stock unit awards	$	10	$	11	$	17	$	20
Performance awards	5		8		10		13
Pretax stock-based compensation cost	$	15	$	19	$	27	$	33
Tax benefit associated with stock-based compensation expense	$	5	$	7	$	9	$	12
Stock-based compensation costs capitalized	1		1		2		2

15. 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 equal to a percentage of current eligible earnings based on age or the combination of age and 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 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. The qualified and non-qualified, non-contributory defined benefit plans are closed to new and rehired non-union and certain unionized employees.

Duke Energy’s policy is to fund amounts on an actuarial basis to provide assets sufficient to meet benefit payments to be paid to plan participants. The following table includes information related to the Duke Energy Registrants’ contributions to its U.S. qualified defined benefit pension plans. Duke Energy did not make any contributions to its U.S. qualified defined benefit pension plans during the six months ended June 30, 2016.

Six Months Ended June 30, 2015

Duke

Duke

Duke

Duke

Duke

Duke

Energy

Progress

Energy

Energy

Energy

Energy

(in millions)

Energy

Carolinas

Energy

Progress

Florida

Ohio

Indiana

Contributions

$

132

$

42

$

42

$

21

$

21

$

1

$

9

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 costs 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 costs for employees of Duke Energy’s shared services affiliate that provides support to the Subsidiary Registrants. These allocated amounts are included in the governance and shared service costs discussed in Note 8. Duke Energy uses a December 31 measurement date for its defined benefit retirement plan assets and obligations.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

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, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	37		$	12		$	10		$	6		$	5		$	1		$	2
Interest cost on projected benefit obligation	83			22			27			13			14			5			7
Expected return on plan assets	(129		)	(36		)	(42		)	(20		)	(21		)	(7		)	(11		)
Amortization of actuarial loss	33			8			13			5			7			1			3
Amortization of prior service credit	(4		)	(2		)	(1		)	(1		)	—			—			—
Other	1			—			—			1			—			—			—
Net periodic pension costs	$	21		$	4		$	7		$	4		$	5		$	—		$	1

	Three Months Ended June 30, 2015
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	39		$	12		$	11		$	6		$	5		$	1		$	2
Interest cost on projected benefit obligation	81			20			26			12			13			4			7
Expected return on plan assets	(129		)	(33		)	(41		)	(21		)	(22		)	(7		)	(11		)
Amortization of actuarial loss	44			10			17			9			8			3			4
Amortization of prior service credit	(3		)	(2		)	(1		)	(1		)	(1		)	—			—
Other	2			—			—			1			1			—			—
Net periodic pension costs	$	34		$	7		$	12		$	6		$	4		$	1		$	2

	Six Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	73		$	24		$	21		$	12		$	10		$	2		$	4
Interest cost on projected benefit obligation	166			43			53			25			28			10			14
Expected return on plan assets	(258		)	(71		)	(84		)	(41		)	(42		)	(14		)	(21		)
Amortization of actuarial loss	66			16			27			11			14			2			6
Amortization of prior service credit	(8		)	(4		)	(2		)	(1		)	—			—			—
Other	4			1			1			1			—			—			—
Net periodic pension costs	$	43		$	9		$	16		$	7		$	10		$	—		$	3

	Six Months Ended June 30, 2015
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	79		$	25		$	22		$	12		$	10		$	2		$	5
Interest cost on projected benefit obligation	163			41			52			24			27			9			14
Expected return on plan assets	(258		)	(69		)	(84		)	(41		)	(44		)	(13		)	(21		)
Amortization of actuarial loss	87			20			34			17			16			5			7
Amortization of prior service credit	(7		)	(4		)	(2		)	(1		)	(1		)	—			—
Other	4			1			1			1			1			—			—
Net periodic pension costs	$	68		$	14		$	23		$	12		$	9		$	3		$	5

83

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	3		1		1		1		1
Amortization of actuarial loss	2		—		—		—		—
Net periodic pension costs	$	6	$	1	$	1	$	1	$	1

	Three Months Ended June 30, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	3		—		1		1		1
Amortization of actuarial loss	1		—		1		—		—
Net periodic pension costs	$	5	$	—	$	2	$	1	$	1

	Six Months Ended June 30, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	7		1		2		1		1
Amortization of actuarial loss	4		—		1		—		—
Net periodic pension costs	$	12	$	1	$	3	$	1	$	1

	Six Months Ended June 30, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	1	$	—	$	—
Interest cost on projected benefit obligation	7		1		2		1		1
Amortization of actuarial loss	3		—		1		—		1
Net periodic pension costs	$	11	$	1	$	4	$	1	$	2

OTHER POST-RETIREMENT BENEFIT PLANS

Duke Energy provides, and the Subsidiary Registrants participate in, some health care and life insurance benefits for retired employees on a contributory and non-contributory basis. Employees are eligible for these benefits if they have met age and service requirements at retirement, as set forth in the plans. The health care benefits include medical, dental, vision, and prescription drug coverage and are subject to certain limitations, such as deductibles and co-payments.

84

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

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, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	1		$	—		$	—		$	—		$	—		$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			3			2			1			1			1
Expected return on plan assets	(4		)	(2		)	—			—			—			—			(1		)
Amortization of actuarial loss (gain)	2			(1		)	6			3			3			(1		)	—
Amortization of prior service credit	(36		)	(3		)	(25		)	(17		)	(9		)	—			—
Net periodic other post-retirement benefit costs	$	(28	)	$	(4	)	$	(16	)	$	(12	)	$	(5	)	$	—		$	—

	Three Months Ended June 30, 2015
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Service cost	$	1		$	1		$	1		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			3			2			1			1		2
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—
Amortization of actuarial loss (gain)	7			(1		)	7			4			2			—		(1		)
Amortization of prior service credit	(35		)	(3		)	(25		)	(16		)	(7		)	—		—
Net periodic other post-retirement benefit costs	$	(21	)	$	(3	)	$	(14	)	$	(10	)	$	(4	)	$	1	$	1

	Six Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	2		$	—		$	—		$	—		$	—		$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	17			4			7			4			3			1			2
Expected return on plan assets	(7		)	(4		)	—			—			—			—			(1		)
Amortization of actuarial loss (gain)	3			(2		)	11			6			5			(1		)	(1		)
Amortization of prior service credit	(71		)	(6		)	(51		)	(34		)	(18		)	—			—
Net periodic other post-retirement benefit costs	$	(56	)	$	(8	)	$	(33	)	$	(24	)	$	(10	)	$	—		$	—

	Six Months Ended June 30, 2015
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Service cost	$	3		$	1		$	1		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	18			4			7			4			3			1		2
Expected return on plan assets	(6		)	(4		)	—			—			—			—		—
Amortization of actuarial loss (gain)	13			(1		)	14			9			5			—		(1		)
Amortization of prior service credit	(70		)	(7		)	(51		)	(33		)	(16		)	—		—
Net periodic other post-retirement benefit costs	$	(42	)	$	(7	)	$	(29	)	$	(20	)	$	(8	)	$	1	$	1

85

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

EMPLOYEE SAVINGS PLAN

Duke Energy sponsors, and the Subsidiary Registrants participate in, an employee savings plan that covers 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 of up to 6 percent of eligible pay per pay period. Dividends on Duke Energy shares held by the savings plan are charged to retained earnings when declared and shares held in the plan are considered outstanding in the calculation of basic and diluted earnings per share.

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, subject to a three-year vesting requirement, is provided to the employee’s savings plan account.

The following table presents employer contributions made by Duke Energy and expensed by the Subsidiary Registrants.

			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Three Months Ended June 30,
2016	$	39	$	13	$	12	$	8	$	4	$	1	$	2
2015	37		13		12		8		3		1		2
Six Months Ended June 30,
2016	$	91	$	31	$	27	$	19	$	8	$	2	$	4
2015	86		29		26		19		7		2		4

16. INCOME TAXES

TAXES ON FOREIGN EARNINGS

As of December 31, 2015, Duke Energy's intention was to indefinitely reinvest foreign earnings of International Energy earned after December 31, 2014. In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the investment in NMC. Accordingly, Duke Energy no longer intends to indefinitely reinvest the undistributed earnings of International Energy. The Company recorded U.S. income taxes of approximately $4 million and $16 million for the three and six months ended June 30, 2016, respectively, related to such earnings and will prospectively provide U.S. income taxes on future foreign earnings.

This change in the Company's intent, combined with the extension of bonus depreciation by Congress in late 2015, allows Duke Energy to more efficiently utilize foreign tax credits and reduce U.S. deferred tax liabilities associated with historic unremitted foreign earnings by approximately $95 million for the six months ended June 30, 2016.

EFFECTIVE TAX RATES

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
Duke Energy	31.8	%	35.6	%	27.2	%	33.6	%
Duke Energy Carolinas	35.1	%	36.6	%	34.6	%	36.2	%
Progress Energy	36.0	%	39.2	%	36.3	%	37.1	%
Duke Energy Progress	35.5	%	40.6	%	35.4	%	36.0	%
Duke Energy Florida	37.6	%	38.7	%	37.7	%	38.6	%
Duke Energy Ohio	34.3	%	35.0	%	29.2	%	36.8	%
Duke Energy Indiana	36.1	%	36.4	%	33.1	%	36.5	%

The decrease in the effective tax rate for Duke Energy for the three and six months ended June 30, 2016, is driven by lower income taxes on foreign earnings due to a more efficient utilization of foreign tax credits, as described above, and favorable impacts of finalizing federal tax audits. Refer to "Taxes on Foreign Earnings" above for additional information.

The decrease in the effective tax rate for Duke Energy Carolinas for the three and six months ended June 30, 2016, is primarily due to a favorable state resolution related to prior-year tax returns and favorable impacts of finalizing tax audits.

The decrease in the effective tax rate for Progress Energy for the three months ended June 30, 2016, is primarily due to a change in tax levelization.

The decrease in the effective tax rate for Duke Energy Progress for the three months ended June 30, 2016, is primarily due to a change in tax levelization.

86

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

The decrease in the effective tax rate for Duke Energy Florida for the three months ended June 30, 2016, is primarily due to an increase in AFUDC equity.

The decrease in the effective tax rate for Duke Energy Ohio for the six months ended June 30, 2016, is primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.

The decrease in the effective tax rate for Duke Energy Indiana for the six months ended June 30, 2016, is primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.

87

PART I

DUKE ENERGY CORPORATION – DUKE ENERGY CAROLINAS, LLC – PROGRESS ENERGY, INC. –

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

17. SUBSEQUENT EVENTS

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

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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, LLC (Duke Energy Progress), Duke Energy Florida, LLC (Duke Energy Florida), Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, LLC (Duke Energy Indiana) (collectively referred to as the Subsidiary Registrants). However, none of the registrants make 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.) primarily 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.

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 months ended June 30, 2016, and with Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.

Acquisition of Piedmont Natural Gas

On October 24, 2015, Duke Energy entered into an Agreement and Plan of Merger (Merger Agreement) with Piedmont Natural Gas Company, Inc., (Piedmont) a North Carolina corporation. Under the terms of the Merger Agreement, Duke Energy will acquire Piedmont for approximately $4.9 billion in cash and Piedmont will become a wholly owned subsidiary of Duke Energy. In addition, Duke Energy will assume Piedmont's existing debt, which was approximately $2.0 billion at April 30, 2016, the end of Piedmont's most recent filed quarter. The excess of the purchase price over the fair value of Piedmont's assets and liabilities on the acquisition date will be recorded as goodwill. Duke Energy estimates the transaction would result in incremental goodwill of approximately $3.5 billion. Duke Energy expects to finance the transaction with a combination of debt, equity issuances and other cash sources. As of June 30, 2016, Duke Energy entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. For additional information on the forward-starting swaps, see Note 9 to the Condensed Consolidated Financial Statements, "Derivatives and Hedging."

In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of Duke Energy common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into equity forward sale agreements (the Equity Forwards) with Barclays Capital, Inc. (Barclays). Duke Energy expects to settle the Equity Forwards on or around the closing date of the Piedmont acquisition. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont. For additional information regarding the Equity Forwards, see Note 13 to the Condensed Consolidated Financial Statements, "Common Stock."

In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion senior unsecured bridge financing facility (Bridge Facility) with Barclays. The Bridge Facility, if drawn upon, may be used to (i) fund the cash consideration for the transaction and (ii) pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to $3.2 billion as a result of the Equity Forwards and $1 billion of the commitments under a term loan amended and restated as of August 1, 2016. See Note 6 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities," for additional information.

Piedmont's shareholders have approved the company's acquisition by Duke Energy and the Federal Trade Commission (FTC) has granted early termination of the 30-day waiting period under the federal Hart-Scott-Rodino Antitrust Improvements Act of 1976. On January 15, 2016, Duke Energy and Piedmont filed an application with the North Carolina Utilities Commission (NCUC) for approval of the proposed business combination and associated financing transactions. On January 29, 2016, the NCUC approved Duke Energy's proposed financing transactions. On March 7, 2016, the Kentucky Public Service Commission (KPSC) granted Duke Energy's declaratory request that the transaction does not constitute a change in control and does not require KPSC approval. The Tennessee Regulatory Authority approved Duke Energy's and Piedmont's request of the change in control resulting from the transaction at its March 14, 2016, meeting. On June 10, 2016 the North Carolina Public Staff reached an agreement with Duke Energy and Piedmont on certain stipulations and conditions for approval of the transaction. Duke Energy and Piedmont have also entered into settlement agreements with the Environmental Defense Fund (EDF) and the Carolina Utility Customers Association, Inc. (CUCA) resolving EDF's and CUCA's issues in the case.

On July 19, 2016, the NCUC concluded an evidentiary hearing for the proposed business combination. Proposed orders are due from all parties by August 25, 2016, after which the NCUC will rule on the application. Subject to receipt of NCUC approval, and meeting closing conditions, Duke Energy and Piedmont expect to close the transaction by the end of 2016. Upon closing of the proposed acquisition, Duke Energy expects to record expenses of $175 million to $200 million, representing accruals for commitments made in conjunction with the transaction, such as funding charitable and community support contributions, professional fees and severance.

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PART I

The Merger Agreement contains certain termination rights for both Duke Energy and Piedmont, and provides that, upon termination of the Merger Agreement under specified circumstances, Duke Energy would be required to pay a termination fee of $250 million to Piedmont and Piedmont would be required to pay Duke Energy a termination fee of $125 million.

Upon closing of the proposed acquisition of Piedmont, the chief operating decision-maker may determine that changes to business segments are necessary. The final outcome has not been determined.

See Note 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information regarding Duke Energy and Piedmont's joint investment in Atlantic Coast Pipeline, LLC (ACP).

Change In Segment Income

During the first quarter of 2016, the Duke Energy chief operating decision-maker began to evaluate interim period segment performance based on financial information that includes the impact of income tax levelization within segment income. This represents a change from the previous measure, where the interim period impacts of income tax levelization were included within Other, and therefore excluded from segment income. As a result, prior period segment results presented have been recast to conform to this change.

Potential Sale of International Energy

In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the equity method investment in National Methanol Company (NMC). Duke Energy is actively marketing the business. Non-binding offers have been received and are being evaluated. There is no assurance that this process will result in a transaction and the timing for execution of a potential transaction is uncertain. Proceeds from a successful sale would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. If the potential of a sale were to progress, it could result in classification of International Energy as assets held for sale and as a discontinued operation.

Based upon the advancement of the marketing efforts Duke Energy performed recoverability tests of the long-lived asset groups of International Energy as of June 30, 2016. As a result, Duke Energy determined the carrying value of certain assets in Central America is not fully recoverable and recorded a pretax impairment charge of $194 million, which is included within Impairment Charges on the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2016. The impairment charge represents the excess of carrying value over the estimated fair value of the assets. The fair value of the assets was primarily determined from the income approach using discounted cash flows but also considered market information obtained in 2016.

As of June 30, 2016, the International Energy segment had a carrying value of approximately $2.4 billion, adjusted for approximately $589 million of cumulative foreign currency translation losses currently classified as accumulated other comprehensive loss.

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 non-GAAP financial measures, adjusted earnings and adjusted diluted EPS. These items represent income from continuing operations net of income (loss) attributable to noncontrolling interests, adjusted for the dollar and per-share impact of special items. Special items represent certain charges and credits, which management believes are not indicative of Duke Energy's ongoing performance, as discussed below. 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 Duke Energy Board of Directors, employees, stockholders, 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 stockholders.

Special items included in the periods presented include the following:

• Costs to achieve mergers and International impairment represent charges that result from potential or completed strategic acquisitions and divestitures that do not reflect ongoing costs of the business.

• Costs savings initiatives represent restructuring charges incurred to reduce future expenses and do not represent ongoing costs.

• Midwest generation operations represents the operating results of the nonregulated Midwest generation business and Duke Energy Retail Sales (collectively, the Disposal Group), which have been classified as discontinued operations. Management believes inclusion of the Disposal Group's operating results within adjusted earnings and adjusted diluted EPS results in a better reflection of Duke Energy's financial performance during the period.

Management 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 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, which are discussed above. 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.

Duke Energy’s adjusted earnings, adjusted diluted EPS, 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.

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PART I

Executive Overview

Reported EPS attributable to Duke Energy Corporation common stockholders (Reported EPS) was $0.74 for the second quarter of 2016 compared to $0.78 for the second quarter of 2015. Reported EPS was lower due to an impairment of certain assets in Central America, unrealized losses on interest rate swaps related to the proposed Piedmont acquisition, and lower revenues due to less favorable weather; partially offset by higher retail revenues from pricing and rider recoveries, and charges in the prior year related to the Disposal Group.

As discussed above, management also evaluates financial performance based on adjusted diluted EPS. Duke Energy’s second quarter 2016 adjusted diluted EPS was $1.07 compared to $0.95 for the second quarter of 2015.

The following table reconciles non-GAAP measures, including adjusted diluted EPS, to their most directly comparable GAAP measures.

	Three Months Ended June 30, 2016
(in millions, except per-share amounts)	Regulated Utilities		International Energy			Commercial Portfolio		Total Reportable Segments		Other			Eliminations/ Discontinued Operations			Duke Energy		Per Diluted Share
Reported Net Income Attributable to Duke Energy Corporation/Reported EPS	$	718	$	(102	)	$	14	$	630	$	(120	)	$	(1	)	$	509	$	0.74
Costs to achieve, mergers(a)	—		—			—		—		69			—			69		0.10
International impairment(b)	—		145			—		145		—			—			145		0.21
Cost savings initiatives(c)	—		—			—		—		15			—			15		0.02
Discontinued operations	—		—			—		—		—			1			1		—
Adjusted earnings/Adjusted EPS	$	718	$	43		$	14	$	775	$	(36	)	$	—		$	739	$	1.07

(a) Net of $42 million tax benefit. Primarily consists of unrealized losses on forward-starting interest rate swaps utilized to manage interest rate exposure for the expected financing of the Piedmont acquisition.

(b) Net of $49 million tax benefit. Impairment of certain assets in Central America.

(c) Net of $9 million tax benefit. Primarily consists of severance costs.

	Three Months Ended June 30, 2015
(in millions, except per-share amounts)	Regulated Utilities		International Energy		Commercial Portfolio			Total Reportable Segments		Other			Eliminations/ Discontinued Operations			Duke Energy		Per Diluted Share
Reported Net Income Attributable to Duke Energy Corporation/Reported EPS	$	632	$	52	$	(30	)	$	654	$	(51	)	$	(60	)	$	543	$	0.78
Costs to achieve Progress Energy merger(a)	—		—		—			—		14			—			14		0.02
Discontinued operations	—		—		41			41		—			60			101		0.15
Adjusted earnings/Adjusted EPS	$	632	$	52	$	11		$	695	$	(37	)	$	—		$	658	$	0.95

(a) Net of $8 million tax benefit.

The increase in adjusted earnings for the three months endedJune 30, 2016, compared to the same period in 2015, was primarily due to:

• Higher regulated results due to increased retail pricing and riders, including energy efficiency programs, partially offset by less favorable weather;

• Lower operations and maintenance expense primarily due to lower outage costs and cost savings initiatives;

• Improved results in Brazil primarily due to favorable hydrology, partially offset by weaker foreign currency exchange rates; and

• Incremental earnings from the additional ownership interest in generating assets acquired from North Carolina Eastern Municipal Power Agency (NCEMPA).

Partially offset by:

• Lower earnings from International Energy's equity method investment in NMC, primarily due to lower methyl tertiary butyl ether (MTBE) and methanol prices.

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Duke Energy's Reported EPS was $1.74 for the six months ended June 30, 2016 compared to $2.01 for the six months ended June 30, 2015. Reported EPS was lower due to an impairment of certain assets in Central America, unrealized losses on interest rate swaps related to the proposed Piedmont acquisition, and lower revenues due to less favorable weather; partially offset by higher retail revenues from pricing and rider recoveries, and a favorable tax adjustment at International Energy.

As discussed above, management also evaluates financial performance based on adjusted diluted EPS. Duke Energy’s adjusted diluted EPS was $2.20 for the six months ended June 30, 2016, which is consistent with adjusted diluted EPS for the six months ended June 30, 2015.

The following table reconciles non-GAAP measures, including adjusted diluted EPS, to their most directly comparable GAAP measures.

	Six Months Ended June 30, 2016
(in millions, except per-share amounts)	Regulated Utilities		International Energy		Commercial Portfolio		Total Reportable Segments		Other			Eliminations/ Discontinued Operations			Duke Energy			Per Diluted Share
Net Income Attributable to Duke Energy Corporation/Reported EPS	$	1,413	$	21	$	41	$	1,475	$	(274	)	$	2		$	1,203		$	1.74
Costs to achieve, mergers(a)	—		—		—		—		143			—			143			0.21
International impairment(b)	—		145		—		145		—			—			145			0.21
Cost savings initiatives(c)	—		—		—		—		27			—			27			0.04
Discontinued operations	—		—		—		—		—			(2		)	(2		)	—
Adjusted earnings/Adjusted EPS	$	1,413	$	166	$	41	$	1,620	$	(104	)	$	—		$	1,516		$	2.20

(a) Net of $88 million tax benefit. Primarily consists of unrealized losses on forward-starting interest rate swaps utilized to manage interest rate exposure for the expected financing of the Piedmont acquisition.

(b) Net of $49 million tax benefit. Impairment of certain assets in Central America.

(c) Net of $17 million tax benefit. Primarily consists of severance costs.

	Six Months Ended June 30, 2015
(in millions, except per-share amounts)	Regulated Utilities		International Energy		Commercial Portfolio			Total Reportable Segments		Other			Eliminations/ Discontinued Operations			Duke Energy		Per Diluted Share
Net Income Attributable to Duke Energy Corporation/Reported EPS	$	1,406	$	88	$	(23	)	$	1,471	$	(94	)	$	30		$	1,407	$	2.01
Midwest generation operations	—		—		94			94		—			(94		)	—		—
Costs to achieve Progress Energy merger(a)	—		—		—			—		27			—			27		0.04
Discontinued operations	—		—		41			41		—			64			105		0.15
Adjusted earnings/Adjusted EPS	$	1,406	$	88	$	112		$	1,606	$	(67	)	$	—		$	1,539	$	2.20

(a) Net of $16 million tax benefit.

The decrease in adjusted earnings for the six months endedJune 30, 2016, compared to the same period in 2015, was primarily due to:

• Lower results due to the absence of earnings from the Disposal Group sold in April 2015;

• Increased depreciation and amortization expense primarily due to a higher amount of property, plant and equipment in service; and

• Lower earnings from International Energy's equity method investment in NMC, primarily due to lower MTBE and methanol prices.

Partially offset by:

• Lower income tax expense as a result of the Company's intent to no longer indefinitely reinvest the foreign earnings of the International Energy segment combined with more efficient utilization of foreign tax credits, net of additional tax expense recognized in 2016 on International Energy's unremitted earnings. See Note 16 to the Condensed Consolidated Financial Statements, "Income Taxes," for additional information;

• Higher regulated results due to increased retail pricing and riders, including energy efficiency programs, partially offset by less favorable weather;

• Higher results in Latin America primarily due to favorable hydrology in Brazil, partially offset by weaker foreign currency exchange rates;

• Lower operations and maintenance expense primarily due to lower outage costs and cost efficiency initiatives, partially offset by an increase in storm restoration costs due to more severe winter storms in the Carolinas;

• Incremental earnings from the additional ownership interest in generating assets acquired from NCEMPA; and

• Reduction in weighted average shares outstanding primarily due to the prior-year accelerated stock repurchase.

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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,
(in millions)	2016		2015		Variance			2016		2015		Variance
Operating Revenues	$	5,099	$	5,220	$	(121	)	$	10,358	$	10,943	$	(585	)
Operating Expenses	3,772		4,003		(231		)	7,739		8,308		(569		)
Gains on Sales of Other Assets and Other, net	1		2		(1		)	2		9		(7		)
Operating Income	1,328		1,219		109			2,621		2,644		(23		)
Other Income and Expenses, net	74		59		15			138		131		7
Interest Expense	278		274		4			555		549		6
Income Before Income Taxes	1,124		1,004		120			2,204		2,226		(22		)
Income Tax Expense	406		372		34			791		820		(29		)
Segment Income	$	718	$	632	$	86		$	1,413	$	1,406	$	7
Duke Energy Carolinas Gigawatt-hours (GWh) sales	20,757		21,306		(549		)	42,382		43,774		(1,392		)
Duke Energy Progress GWh sales	16,829		14,952		1,877			33,978		31,717		2,261
Duke Energy Florida GWh sales	10,646		10,802		(156		)	19,102		19,275		(173		)
Duke Energy Ohio GWh sales	5,796		6,233		(437		)	11,903		13,000		(1,097		)
Duke Energy Indiana GWh sales	8,157		7,705		452			17,551		16,433		1,118
Total Regulated Utilities GWh sales	62,185		60,998		1,187			124,916		124,199		717
Net proportional Megawatt (MW) capacity in operation								49,620		49,528		92

Three Months Ended June 30, 2016 as Compared to June 30, 2015

Regulated Utilities’ results were impacted by increased rate riders and retail pricing, lower operations and maintenance expenses, and an increase in wholesale power margins. These impacts were partially offset by less favorable weather in the Carolinas and Florida. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• a $223 million decrease in fuel revenues driven by lower fuel prices included in electric rates and overall lower retail volumes; and

• a $43 million decrease in electric retail sales, net of fuel revenue, due to less favorable weather in the Carolinas and Florida compared to the prior year.

Partially offset by:

• a $112 million increase in rate riders, including increased revenues related to energy efficiency programs and the additional ownership interest in certain generating assets acquired from NCEMPA in the third quarter of 2015, and retail electric pricing primarily due to lower sales volumes which resulted in higher average customer rates; and

• a $38 million increase in wholesale power revenues, primarily due to additional volumes and capacity charges for customers served under long-term contracts, including the NCEMPA wholesale contract that became effective August 1, 2015.

Operating Expenses. The variance was driven primarily by:

• a $215 million decrease in fuel expense (including purchased power and natural gas purchases for resale) primarily due to lower natural gas and coal prices, and decreased generation due to lower sales volumes; and

• a $42 million decrease in operations and maintenance expense primarily due to lower outage costs and costs savings initiatives.

Other Income and Expenses, net. The variance was driven primarily by higher allowance for funds used during construction (AFUDC) equity.

Income Tax Expense. The variance was primarily due to an increase in pretax income, partially offset by a lower effective tax rate. The effective tax rates for the three months ended June 30, 2016 and 2015 were 36.1 percent and 37.1 percent, respectively. The decrease in the effective tax rate is primarily due to favorable impacts of finalizing tax audits.

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Regulated Utilities’ results were impacted by increased rate riders and retail pricing, an increase in wholesale power margins and lower operations and maintenance expense. These impacts were partially offset by less favorable weather, increased depreciation and amortization expense, and higher property and other tax expense. The following is a detailed discussion of the variance drivers by line item.

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Operating Revenues. The variance was driven primarily by:

• a $635 million decrease in fuel revenues driven by lower fuel prices included in electric rates and overall lower volumes; and

• a $157 million decrease in electric retail sales, net of fuel revenue, due to less favorable weather across all the jurisdictions compared to the prior year.

Partially offset by:

• a $169 million increase in rate riders including increased revenues related to energy efficiency programs and the additional ownership interest in certain generating assets acquired from NCEMPA in the third quarter of 2015, and retail electric pricing primarily due to lower sales volumes, which resulted in higher average customer rates; and

• a $52 million increase in wholesale power revenues, primarily due to additional volumes and capacity charges for customers served under long-term contracts, including the NCEMPA wholesale contract that became effective August 1, 2015.

Operating Expenses. The variance was driven primarily by:

• a $627 million decrease in fuel expense (including purchased power and natural gas purchases for resale) primarily due to lower natural gas and coal prices, decreased generation due to lower sales volumes, and lower natural gas volumes and prices to full-service retail natural gas customers; and

• a $29 million decrease in operations and maintenance expense primarily due to lower outage costs and cost savings initiatives, partially offset by higher storm restoration costs.

Partially offset by:

• a $44 million increase in depreciation and amortization expense primarily due to additional plant in service, including the additional ownership interest in generating assets acquired from NCEMPA in the third quarter of 2015; and

• a $40 million increase in property and other taxes primarily due to higher sales and use tax at Duke Energy Indiana and higher property taxes across multiple jurisdictions.

Income Tax Expense. The variance is due to a decrease in the effective tax rate and lower pretax income. The effective tax rates for the six months ended June 30, 2016 and 2015 were 35.9 percent and 36.8 percent, respectively.

Matters Impacting Future Regulated Utilities Results

On May 18, 2016, the North Carolina Department of Environmental Quality (NCDEQ) issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the North Carolina Coal Ash Management Act of 2014 (Coal Ash Act) were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation signed by the North Carolina governor on July 14, 2016. Regulated Utilities' estimated asset retirement obligations related to the closure of North Carolina ash impoundments are based upon the mandated closure method or a probability weighting of potential closure methods for the impoundments that may be reassessed to low risk. As the final risk ranking classifications in North Carolina are delineated, final closure plans are developed and approved for each site and the closure work progresses, and the closure method scope is determined, the complexity of work and the amount of coal combustion material could be different than estimated and, therefore, could materially impact 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.

Duke Energy is a party to multiple lawsuits and could be subject to fines and other penalties related to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. The outcome of these lawsuits and potential fines and penalties could have an adverse impact on 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.

An order from regulatory authorities disallowing recovery of costs related to closure of ash impoundments could have an adverse impact on Regulated Utilities' financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.

Duke Energy Indiana entered into a revised settlement agreement with multiple parties that will resolve all disputes, claims and issues from the IURC proceedings related to post-commercial operating performance and recovery of ongoing operating and capital costs at the Edwardsport Integrated Gasification Combined Cycle (IGCC) generating facility. The agreement is subject to Indiana Utility Regulatory Commission (IURC) approval. Pursuant to the terms of this agreement, Duke Energy Indiana recognized an impairment and related charges of $93 million for the year ended December 31, 2015. The agreement stipulates that recovery of the remaining regulatory asset will be over an eight-year period and confirms an in-service date for accounting and ratemaking purposes of June 7, 2013. The agreement, if approved, will also impose a cost cap for recoverable operations and maintenance retail costs in the second half of 2016, and 2017, as well as a cost cap for ongoing capital expenditures through 2017. As part of the settlement, Duke Energy Indiana committed to either retire or cease burning coal at Gallagher Station by December 31, 2022. If the settlement agreement is not approved, outstanding issues before the IURC related to Edwardsport would resume and the resolution of such could have an adverse impact on Regulated Utilities' financial position, results of operations and cash flows. In addition, an inability to manage operating and capital costs in accordance with caps imposed pursuant to the agreement could have an adverse impact on Regulated Utilities' financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

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International Energy

	Three Months Ended June 30,									Six Months Ended June 30,
(in millions)	2016			2015			Variance			2016			2015			Variance
Operating Revenues	$	270		$	287		$	(17	)	$	516		$	560		$	(44	)
Operating Expenses	382			232			150			536			439			97
Loss on Sales of Other Assets and Other, net	(1		)	(1		)	—			(1		)	(1		)	—
Operating (Loss) Income	(113		)	54			(167		)	(21		)	120			(141		)
Other Income and Expense, net	23			31			(8		)	39			45			(6		)
Interest Expense	22			22			—			44			45			(1		)
(Loss) Income Before Income Taxes	(112		)	63			(175		)	(26		)	120			(146		)
Income Tax (Benefit) Expense	(13		)	10			(23		)	(52		)	30			(82		)
Less: Income Attributable to Noncontrolling Interests	3			1			2			5			2			3
Segment (Loss) Income	$	(102	)	$	52		$	(154	)	$	21		$	88		$	(67	)
Sales, GWh	5,625			4,520			1,105			11,505			8,990			2,515
Net proportional MW capacity in operation										4,315			4,333			(18		)

Three Months Ended June 30, 2016 as Compared to June 30, 2015

International Energy’s results were impacted by an impairment of certain assets in Central America, lower earnings from the equity method investment in NMC and weaker exchange rates; partially offset by improved hydrology in Brazil. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues.The variance was driven primarily by a $14 million decrease in Central America due to lower average prices partially offset by higher volumes. Higher revenues at Brazil due to improved hydrology were offset by weaker exchange rates.

Operating Expenses.The variance was driven primarily by:

• a $181 million increase in Central America due to the asset impairment, partially offset by lower purchased power costs.

Partially offset by:

• a $28 million decrease in Brazil due to lower purchased power costs due to improved hydrology and weaker foreign currency exchange rates, partially offset by higher variable costs.

Other Income and Expense, net. The variance was primarily due to lower earnings from the equity method investment in NMC, as a result of lower average MTBE and methanol prices.

Income Tax (Benefit) Expense. The variance was primarily due to a tax benefit associated with the impairment of certain assets in Central America. The effective tax rates for the three months ended June 30, 2016 and 2015 were 11.6 percent and 15.9 percent, respectively.

Six Months Ended June 30, 2016 as Compared to June 30, 2015

International Energy’s results were impacted by an impairment of certain assets in Central America, lower earnings from the equity method investment in NMC and weaker exchange rates in Latin America; partially offset by lower income taxes as a result of the Company's intent to no longer indefinitely reinvest foreign earnings and improved hydrology in Brazil. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues.The variance was driven primarily by:

• a $26 million decrease in Central America due to lower average prices partially offset by higher volumes; and

• a $17 million decrease in Brazil due to weaker foreign currency exchange rates partially offset by higher volumes.

Operating Expenses.The variance was driven primarily by:

• a $164 million increase in Central America due to the asset impairment, partially offset by lower purchased power costs.

Partially offset by:

• a $66 million decrease in Brazil due to lower purchased power costs due to improved hydrology and weaker foreign currency exchange rates, partially offset by higher variable costs.

Other Income and Expense, net. The variance was primarily due to lower earnings from the equity method investment in NMC, primarily due to lower average MTBE and methanol prices, as well as lower MTBE sales volumes driven by planned maintenance; partially offset by lower butane costs.

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Income Tax (Benefit) Expense. The variance was due to an increase in the effective tax rate and a decrease in pretax income. The increase in the effective tax rate was primarily a result of Duke Energy's ability to more efficiently utilize foreign tax credits. See Note 16 to the Condensed Consolidated Financial Statements, "Income Taxes," for additional information.

Matters Impacting Future International Energy Results

International Energy's operations include conventional hydroelectric power generation facilities located in Brazil. The weather and recessionary economic conditions in Brazil during recent years have resulted in higher energy prices, lower electricity demand and unfavorable impacts to the exchange rate of Brazil's currency. These weather and economic conditions have also resulted in lawsuits brought to the Brazilian courts by certain hydroelectric generators to limit the financial exposure to the generators. International Energy's earnings and future cash flows could be adversely impacted if reservoir levels return to the recent low levels, from a further decline of the economic and political conditions within Brazil, or as a result of the outcome of legal matters in the Brazilian courts.

International Energy's earnings from an equity method investment in NMC reflect sales of methanol and MTBE, which generate margins that are directionally correlated with Brent crude oil prices. The recent decline in crude oil prices have reduced the earnings realized from NMC. Further weakness in the market price of Brent crude oil and related commodities may result in a further decline in earnings.

In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the equity method investment in NMC. Duke Energy is actively marketing the business. Non-binding offers have been received and are being evaluated. There is no assurance that this process will result in a transaction and the timing for execution of a potential transaction is uncertain. Proceeds from a successful sale would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. If the potential of a sale were to progress, it could result in classification of International Energy as assets held for sale and as a discontinued operation. As of June 30, 2016, the International Energy segment had a carrying value of approximately $2.4 billion, adjusted for $589 million of cumulative foreign currency translation losses currently classified as accumulated other comprehensive loss.

Commercial Portfolio

	Three Months Ended June 30,									Six Months Ended June 30,
(in millions)	2016			2015			Variance			2016			2015			Variance
Operating Revenues	$	112		$	75		$	37		$	226		$	148		$	78
Operating Expenses	121			84			37			232			173			59
Gains on Sales of Other Assets and Other, net	1			6			(5		)	2			6			(4		)
Operating Loss	(8		)	(3		)	(5		)	(4		)	(19		)	15
Other Income and Expense, net	4			(2		)	6			6			—			6
Interest Expense	11			10			1			23			22			1
Loss Before Income Taxes	(15		)	(15		)	—			(21		)	(41		)	20
Income Tax (Benefit) Expense	(28		)	15			(43		)	(61		)	(18		)	(43		)
Less: Income Attributable to Noncontrolling Interests	(1		)	—			(1		)	(1		)	—			(1		)
Segment Income (Loss)	$	14		$	(30	)	$	44		$	41		$	(23	)	$	64
Renewable plant production, GWh	1,758			1,373			385			3,818			2,683			1,135
Net proportional MW capacity in operation										1,978			1,634			344

Three Months Ended June 30, 2016 as Compared to June 30, 2015

Commercial Portfolio’s higher earnings are primarily due to a state tax charge recorded in the prior year related to the Disposal Group. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• a $26 million increase in electric revenues due to growth in the REC Solar business; and

• a $9 million increase in electric revenues from new wind and solar generation placed in service.

Operating Expenses. The variance was driven primarily by:

• a $24 million increase in operating expenses due to growth in the REC Solar business; and

• a $9 million increase in operating expenses from new wind and solar generation placed in service.

Income Tax (Benefit) Expense.The variance was primarily due to a $41 million charge in the prior year related to changes in state tax apportionment factors on deferred taxes resulting from the sale of the Disposal Group in the second quarter of 2015.

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Commercial Portfolio’s higher earnings are primarily due to a state tax charge recorded in the prior year related to the Midwest generation business, operating expenses recorded in the prior year related to residual Midwest Generation operations that were shifted out of Commercial Portfolio and new wind and solar generation placed in service. The following is a detailed discussion of the variance drivers by line item.

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Operating Revenues. The variance was driven primarily by:

• a $56 million increase in electric revenues due to acquisition and growth of REC Solar; and

• a $31 million increase in electric revenues from new wind and solar generation placed in service and improved wind production.

Operating Expenses. The variance was driven primarily by:

• a $55 million increase in operating expenses due to acquisition and growth of REC Solar; and

• a $24 million increase in operating expenses from new wind and solar generation placed in service.

Partially offset by:

• a $28 million decrease due to the shift of the residual Midwest generation business out of Commercial Portfolio following the sale of the Disposal Group. See Note 3 to the Condensed Consolidated Financial Statements, “Business Segments” for additional information.

Income Tax (Benefit) Expense.The variance was primarily due to a $41 million charge in the prior year related to changes in state tax apportionment factors on deferred taxes resulting from the sale of the Disposal Group in the second quarter of 2015.

Other

	Three Months Ended June 30,									Six Months Ended June 30,
(in millions)	2016			2015			Variance			2016			2015			Variance
Operating Revenues	$	30		$	34		$	(4	)	$	59		$	61		$	(2	)
Operating Expenses	96			63			33			188			113			75
Gains on Sales of Other Assets and Other, net	4			6			(2		)	11			13			(2		)
Operating Loss	(62		)	(23		)	(39		)	(118		)	(39		)	(79		)
Other Income and Expense, net	8			9			(1		)	18			10			8
Interest Expense	191			97			94			396			194			202
Loss Before Income Taxes	(245		)	(111		)	(134		)	(496		)	(223		)	(273		)
Income Tax Benefit	(126		)	(63		)	(63		)	(226		)	(134		)	(92		)
Less: Income Attributable to Noncontrolling Interests	1			3			(2		)	4			5			(1		)
Net Expense	$	(120	)	$	(51	)	$	(69	)	$	(274	)	$	(94	)	$	(180	)

Three Months Ended June 30, 2016 as Compared to June 30, 2015

Other's higher net expense was driven by unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition, as well as severance accruals. The following is a detailed discussion of the variance drivers by line item.

Operating Expenses. The increase was primarily due to an increase in severance accruals.

Interest Expense. The increase was primarily due to unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition. For additional information see Notes 2 and 9 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions" and "Derivatives and Hedging," respectively.

Income Tax Benefit. The variance was primarily due to an increase in pretax losses, partially offset by a decrease in the effective tax rate. The effective tax rates for the three months ended June 31, 2016 and 2015 were 51.4 percent and 56.8 percent, respectively. The decrease in the effective tax rate was primarily due to an increase in pretax losses, partially offset by favorable impacts of finalizing federal tax audits.

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Other's higher net expense was due to unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition, as well as severance accruals. The following is a detailed discussion of the variance drivers by line item.

Operating Expenses. The increase was primarily due to severance accruals and higher charges in the current year due to the shift of the residual Midwest Generation business from the Commercial Portfolio segment to Other in the second quarter of 2015. See Note 3 to the Condensed Consolidated Financial Statements, “Business Segments” for additional information.

Interest Expense. The increase was primarily due to unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition. For additional information see Notes 2 and 9 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions" and "Derivatives and Hedging," respectively.

Income Tax Benefit. The variance was primarily due to an increase in pretax losses, partially offset by a decrease in the effective tax rate. The effective tax rates for the six months ended June 30, 2016 and 2015 were 45.6 percent and 60.1 percent, respectively. The decrease in the effective tax rate was primarily due to an increase in pretax losses, partially offset by favorable impacts of finalizing federal tax audits.

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Matters Impacting Future Other Results

Duke Energy Ohio’s retired Beckjord generating station (Beckjord), previously an asset of Commercial Portfolio, became an asset of Other after the sale of the Disposal Group. Beckjord, a nonregulated facility retired during 2014, is not subject to the U.S. Environmental Protection Agency (EPA) rule related to the disposal of Coal Combustion Residuals (CCR) from electric utilities. However, if costs are incurred as a result of environmental regulations or to mitigate risk associated with on-site storage of coal ash, the costs could have an adverse impact on Other's financial position, results of operations and cash flows.

INCOME (LOSS) FROM DISCONTINUED OPERATIONS, NET OF TAX

Three Months Ended June 30, 2016 as Compared to June 30, 2015

Discontinued Operations, Net of Tax. The variance was primarily driven by a litigation reserve recorded in 2015, as discussed in Note 5, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements.

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Discontinued Operations, Net of Tax. The variance was primarily driven by the Disposal Group's operating results in 2015, partially offset by a litigation reserve recorded in 2015, as discussed in Note 5, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements.

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 months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.

Results of Operations

	Six Months Ended June 30,
(in millions)	2016		2015		Variance
Operating Revenues	$	3,415	$	3,608	$	(193	)
Operating Expenses	2,470		2,610		(140		)
Operating Income	945		998		(53		)
Other Income and Expenses, net	82		83		(1		)
Interest Expense	214		208		6
Income Before Income Taxes	813		873		(60		)
Income Tax Expense	281		316		(35		)
Net Income	$	532	$	557	$	(25	)

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

(Decrease) increase over prior year	2016
Residential sales	(6.9	)%
General service sales	(1.5	)%
Industrial sales	(0.6	)%
Wholesale power sales	2.7	%
Joint dispatch sales	(59.7	)%
Total sales	(3.2	)%
Average number of customers	1.4	%

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Operating Revenues.The variance was driven primarily by:

• a $215 million decrease in fuel revenues driven by lower fuel prices included in electric retail and wholesale rates and overall lower volumes; and

• a $59 million decrease in electric sales, net of fuel revenues, to retail customers due to less favorable weather compared to the prior year.

Partially offset by:

• a $65 million increase in retail pricing and rate riders, which primarily reflects increased revenues related to energy efficiency programs and the expiration of the North Carolina cost of removal decrement rider.

Operating Expenses. The variance was driven primarily by:

• a $195 million decrease in fuel used in electric generation and purchased power primarily related to lower natural gas and coal prices, and decreased generation due to lower sales volumes.

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Partially offset by:

• a $30 million increase in operating and maintenance expense primarily due to higher storm restoration costs and severance expenses related to cost savings initiatives; and

• a $24 million increase in depreciation and amortization expense primarily due to higher amount of property, plant and equipment in service.

Income Tax Expense. The variance was primarily due to a decrease in pretax income and a reduction in the effective tax rate. The effective tax rates for the six months ended June 30, 2016 and 2015 were 34.6 percent and 36.2 percent, respectively. The decrease in the effective tax rate was primarily due to a favorable state resolution related to prior-year tax returns and favorable impacts of finalizing tax audits.

Matters Impacting Future Results

On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation signed by the North Carolina governor on July 14, 2016. Duke Energy Carolinas' estimated asset retirement obligations related to the closure of North Carolina ash impoundments are based upon the mandated closure method or a probability weighting of potential closure methods for the impoundments that may be reassessed to low risk. As the final risk ranking classifications in North Carolina are delineated, final closure plans are developed and approved for each site and the closure work progresses, and the closure method scope is determined, the complexity of work and the amount of coal combustion material could be different than estimated and, therefore, could materially impact 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.

Duke Energy Carolinas is a party to multiple lawsuits and subject to fines and other penalties related to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. The outcome of these lawsuits, fines and penalties could have an adverse impact on 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 impoundments could have an adverse impact on Duke Energy Carolinas' financial position, results of operations and cash flows. See Notes 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.

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PROGRESS ENERGY

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.

Results of Operations

	Six Months Ended June 30,
(in millions)	2016		2015			Variance
Operating Revenues	$	4,680	$	5,012		$	(332	)
Operating Expenses	3,657		3,973			(316		)
Gains on Sales of Other Assets and Other, net	12		14			(2		)
Operating Income	1,035		1,053			(18		)
Other Income and Expenses, net	48		46			2
Interest Expense	320		334			(14		)
Income From Continuing Operations Before Taxes	763		765			(2		)
Income Tax Expense From Continuing Operations	277		284			(7		)
Income From Continuing Operations	486		481			5
Loss From Discontinued Operations, net of tax	—		(1		)	1
Net Income	486		480			6
Less: Net Income Attributable to Noncontrolling Interest	5		5			—
Net Income Attributable to Parent	$	481	$	475		$	6

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Operating Revenues. The variance was driven primarily by:

• a $336 million decrease in fuel and capacity revenues from retail customers primarily due to lower natural gas prices, changes in generation mix, and decreased demand from retail customers; partially offset by increased capacity rates to retail customers at Duke Energy Florida; and

• a $67 million decrease in retail sales, net of fuel revenue, to retail customers due to less favorable weather compared to the prior year.

Partially offset by:

• a $46 million increase in rate riders, including increased revenues related to energy efficiency programs and the additional ownership interest in certain generating assets acquired from NCEMPA in the third quarter of 2015, partially offset by lower nuclear cost recovery clause rider revenues due to suspending recovery for the Levy nuclear project; and

• a $32 million increase in wholesale power revenues primarily due to a new NCEMPA contract effective August 1, 2015, partially offset by lower peak demand at Duke Energy Progress.

Operating Expenses. The variance was driven primarily by:

• a $323 million decrease in fuel used in electric generation and purchased power primarily due to lower fuel prices, decreased demand from retail customers and changes in generation mix; and

• a $16 million decrease in operations and maintenance expense primarily due to lower outage costs and cost savings initiatives, partially offset by higher storm costs, an increase in costs recoverable through the energy conservation cost recovery clause and an increase in employee benefit costs.

Partially offset by:

• a $16 million increase in depreciation and amortization expense primarily due to additional plant in service, including the additional ownership interest in generating assets acquired from NCEMPA, partially offset reductions in the amounts recorded through the nuclear cost recovery clause at Duke Energy Florida.

Interest Expense. The variance was driven by accelerated Crystal River Unit 3 regulatory asset cost recovery in 2015, which resulted in a lower debt return in 2015, as well as lower outstanding debt.

Income Tax Expense. The effective tax rates for the six months ended June 30, 2016 and 2015 were 36.3 percent and 37.1 percent, respectively.

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Matters Impacting Future Results

On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation signed by the North Carolina governor on July 14, 2016. Progress Energy's estimated asset retirement obligations related to the closure of North Carolina ash impoundments are based upon the mandated closure method or a probability weighting of potential closure methods for the impoundments that may be reassessed to low risk. As the final risk ranking classifications in North Carolina are delineated, final closure plans are developed and approved for each site and the closure work progresses, and the closure method scope is determined, the complexity of work and the amount of coal combustion material could be different than estimated and, therefore, could materially impact Progress 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.

Progress Energy is a party to multiple lawsuits and subject to fines and other penalties related to operations at certain North Carolina facilities with ash basins. The outcome of these lawsuits, fines and penalties could have an adverse impact on Progress 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 impoundments could have an adverse impact on Progress Energy’s financial position, results of operations and cash flows. See Notes 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.

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DUKE ENERGY PROGRESS

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.

Results of Operations

	Six Months Ended June 30,
(in millions)	2016		2015		Variance
Operating Revenues	$	2,520	$	2,642	$	(122	)
Operating Expenses	2,008		2,143		(135		)
Gains on Sales of Other Assets and Other, net	1		1		—
Operating Income	513		500		13
Other Income and Expenses, net	29		35		(6		)
Interest Expense	127		116		11
Income Before Income Taxes	415		419		(4		)
Income Tax Expense	147		151		(4		)
Net Income and Comprehensive Income	$	268	$	268	$	—

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

(Decrease) Increase over prior period	2016
Residential sales	(8.9	)%
General service sales	(1.3	)%
Industrial sales	(0.3	)%
Wholesale power sales	23.4	%
Joint dispatch sales	59.9	%
Total sales	7.1	%
Average number of customers	1.3	%

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Operating Revenues. The variance was driven primarily by:

• a $151 million decrease in fuel revenues driven by lower natural gas prices, changes in generation mix and decreased demand from retail customers; and

• a $50 million decrease in electric sales, net of fuel revenue, to retail customers due to less favorable weather compared to the prior year.

Partially offset by:

• a $68 million increase in rate rider revenues due to the purchase of NCEMPA’s ownership interest in certain generating assets and energy efficiency programs; and

• a $32 million increase in wholesale power revenues primarily due to a new NCEMPA contract effective August 1, 2015, partially offset by lower peak demand.

Operating Expenses. The variance was driven primarily by:

• a $152 million decrease in fuel used in electric generation and purchased power primarily due to decreased demand from retail customers, lower natural gas prices, and changes in generation mix; and

• a $30 million decrease in operations and maintenance expense mostly due to lower nuclear outage costs, net of nuclear levelization impacts, driven by fewer outages in 2016, partially offset by higher storm costs.

Partially offset by:

• a $35 million increase in depreciation and amortization expenses primarily due to additional plant in service, including the additional ownership interest in generating assets acquired from NCEMPA in the third quarter of 2015; and

• a $12 million increase in property and other taxes due to a 2015 North Carolina Franchise Tax refund and increases in current year property taxes in North Carolina and South Carolina.

Interest Expense. The variance was primarily driven by interest related to new debt issuances in 2015.

Income Tax Expense. The effective tax rates for the six months ended June 30, 2016 and 2015 were 35.4 percent and 36.0 percent, respectively.

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Matters Impacting Future Results

On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation signed by the North Carolina governor on July 14, 2016. Duke Energy Progress' estimated asset retirement obligations related to the closure of North Carolina ash impoundments are based upon the mandated closure method or a probability weighting of potential closure methods for the impoundments that may be reassessed to low risk. As the final risk ranking classifications in North Carolina are delineated, final closure plans are developed and approved for each site and the closure work progresses, and the closure method scope is determined, the complexity of work and the amount of coal combustion material could be different than estimated and, therefore, could materially impact 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.

Duke Energy Progress is a party to multiple lawsuits and subject to fines and other penalties related to operations at certain North Carolina facilities with ash basins. The outcome of these lawsuits, fines and penalties could have an adverse impact on 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 impoundments could have an adverse impact on Duke Energy Progress’ financial position, results of operations and cash flows. See Notes 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.

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DUKE ENERGY FLORIDA

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.

Results of Operations

	Six Months Ended June 30,
(in millions)	2016		2015		Variance
Operating Revenues	$	2,157	$	2,367	$	(210	)
Operating Expenses	1,644		1,825		(181		)
Operating Income	513		542		(29		)
Other Income and Expenses, net	19		10		9
Interest Expense	81		99		(18		)
Income Before Income Taxes	451		453		(2		)
Income Tax Expense	170		175		(5		)
Net Income	$	281	$	278	$	3

The following table shows the percent changes in GWh sales and average number of customers. The 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, public and private utilities and power marketers. Amounts are not weather-normalized.

Increase (decrease) over prior period	2016
Residential sales	—	%
General service sales	(0.4	)%
Industrial sales	(1.1	)%
Wholesale and other	1.7	%
Total sales	(0.9	)%
Average number of customers	1.6	%

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Operating Revenues. The variance was driven primarily by:

• a $185 million decrease in fuel and capacity revenues primarily due to decreased fuel prices to retail customers, partially offset by increased capacity rates to retail customers;

• a $22 million decrease in rider revenues primarily due to a decrease in nuclear cost recovery clause revenues as a result of suspending Levy recovery in 2015, partially offset by an increase in energy conservation cost recovery clause and environmental cost recovery clause revenues due to higher recovery rates in 2016; and

• a $17 million decrease in revenues primarily due to less favorable weather compared to the prior year.

Partially offset by:

• a $17 million increase in other revenue primarily due to a transmission customer settlement charge taken in the prior year and an increase in nonregulated customer products and services in the current year.

Operating Expenses. The variance was driven primarily by:

• a $170 million decrease in fuel used in electric generation and purchased power primarily due to lower fuel prices and lower usage; and

• a $20 million decrease in depreciation and amortization expense primarily due to reductions in the amounts recorded through the nuclear cost recovery clause, partially offset by increased depreciation due to additional plant in service.

Partially offset by:

• a $14 million increase in operations and maintenance expense primarily due to an increase in costs recoverable through the energy conservation cost recovery clause, an increase in expenses associated with fleet outages and an increase in employee benefit costs; partially offset by a decrease in expenses due to routine fleet maintenance work.

Interest Expense. The variance was driven by accelerated Crystal River Unit 3 regulatory asset cost recovery in 2015, which resulted in a lower debt return in 2015, as well as lower outstanding debt.

Income Tax Expense. The effective tax rates for the six months ended June 30, 2016 and 2015 were 37.7 percent and 38.6 percent, respectively.

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DUKE ENERGY OHIO

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.

Results of Operations

	Six Months Ended June 30,
(in millions)	2016		2015			Variance
Operating Revenues	$	944	$	991		$	(47	)
Operating Expenses	794		845			(51		)
Gains on Sales of Other Assets and Other, net	1		8			(7		)
Operating Income	151		154			(3		)
Other Income and Expenses, net	3		(2		)	5
Interest Expense	41		38			3
Income from Continuing Operations Before Income Taxes	113		114			(1		)
Income Tax Expense from Continuing Operations	33		42			(9		)
Income from Continuing Operations	80		72			8
Income from Discontinued Operations, net of tax	2		25			(23		)
Net Income	$	82	$	97		$	(15	)

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

(Decrease) increase over prior year	2016
Residential sales	(9.5	)%
General service sales	(2.2	)%
Industrial sales	(0.9	)%
Wholesale power sales	(76.9	)%
Total sales	(8.4	)%
Average number of customers	0.7	%

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Operating Revenues.The variance was driven primarily by:

• a $45 million decrease in fuel revenues driven by lower electric fuel and natural gas prices and decreased sales volumes; and

• a $15 million decrease due to less favorable weather compared to the prior year.

Partially offset by:

• a $23 million increase in the energy efficiency rider due to a prior year unfavorable regulatory order limiting the ability to utilize energy efficiency banked savings.

Operating Expenses. The variance was driven by a $51 million decrease in cost of natural gas, primarily due to decreased sales volumes and lower natural gas prices.

Income Tax Expense. The variance was primarily due to a decrease in the effective tax rate. The effective tax rates for the six months ended June 30, 2016 and 2015 were 29.2 percent and 36.8 percent, respectively. The decrease in the effective tax rate was primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.

Discontinued Operations, Net of Tax. The variance was primarily driven by the Disposal Group's operating results in 2015.

Matters Impacting Future Results

An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact on Duke Energy Ohio's financial position, results of operations and cash flows. See Notes 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015, "Asset Retirement Obligations," for additional information.

Beckjord, a facility retired during 2014, is not subject to the EPA rule related to the disposal of CCR from electric utilities. However, if costs are incurred as a result of environmental regulations or to mitigate risk associated with on-site storage of coal ash at the facility, the costs could have an adverse impact on Duke Energy Ohio's financial position, results of operations and cash flows.

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DUKE ENERGY INDIANA

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the six months ended June 30, 2016 and 2015 and the Annual Report on Form 10-K for the year ended December 31, 2015.

Results of Operations

	Six Months Ended June 30,
(in millions)	2016		2015		Variance
Operating Revenues	$	1,416	$	1,474	$	(58	)
Operating Expenses	1,066		1,119		(53		)
Gains of Sales of Other Assets and Other, net	—		1		(1		)
Operating Income	350		356		(6		)
Other Income and Expenses, net	10		9		1
Interest Expense	91		88		3
Income Before Income Taxes	269		277		(8		)
Income Tax Expense	89		101		(12		)
Net Income	$	180	$	176	$	4

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

(Decrease) increase over prior year	2016
Residential sales	(8.7	)%
General service sales	(2.9	)%
Industrial sales	0.9	%
Wholesale power sales	64.3	%
Total sales	6.8	%
Average number of customers	1.0	%

Six Months Ended June 30, 2016 as Compared to June 30, 2015

Operating Revenues.The variance was driven primarily by:

• a $67 million decrease in fuel revenues, including emission allowances, primarily due to a decrease in fuel prices and lower sales volumes; and

• a $15 million decrease in electric sales, net of fuel revenue, to retail customers due to less favorable weather compared to the prior year.

Partially offset by:

• a $20 million increase in retail pricing and rate rider revenues due to increased revenues related to clean coal equipment.

Operating Expenses.The variance was driven primarily by:

• an $81 million decrease in fuel used in electric generation and purchased power primarily due to lower fuel prices; and

• a $10 million decrease in operations and maintenance expense due to a decrease in outage work at generation plants.

Partially offset by:

• a $27 million increase in property and other taxes, primarily driven by higher sales and use tax due to the partial reversal in 2015 of a tax reserve upon settlement of the matter; and

• an $11 million increase in depreciation and amortization expenses primarily due to a higher amount of property, plant and equipment in service.

Income Tax Expense. The variance was primarily due to a decrease in the effective tax rate. The effective tax rates for the six months ended June 30, 2016 and 2015 were 33.1 percent and 36.5 percent, respectively. The decrease in the effective tax rate was primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.

Matters Impacting Future Results

On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. Duke Energy Indiana has interpreted the rule to identify the coal ash basin sites impacted and has assessed the amounts of coal ash subject to the rule and a method of compliance. Duke Energy Indiana's interpretation of the requirements of the CCR rule is subject to potential legal challenges and further regulatory approvals, which could result in additional ash basin closure requirements, higher costs of compliance and greater asset retirement obligations. An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact on Duke Energy Indiana's financial position, results of operations and cash flows.

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Duke Energy Indiana entered into a revised settlement agreement with multiple parties that will resolve all disputes, claims and issues from the IURC proceedings related to post-commercial operating performance and recovery of ongoing operating and capital costs at the Edwardsport IGCC generating facility. The agreement is subject to IURC approval. Pursuant to the terms of this agreement, Duke Energy Indiana recognized an impairment and related charges of $93 million for the year ended December 31, 2015. The agreement stipulates that recovery of the remaining regulatory asset will be over an eight-year period and confirms an in-service date for accounting and ratemaking purposes of June 7, 2013. The agreement, if approved, will also impose a cost cap for recoverable operations and maintenance retail costs in the second half of 2016, and 2017, as well as a cost cap for ongoing capital expenditures through 2017. As part of the settlement, Duke Energy Indiana committed to either retire or cease burning coal at Gallagher Station by December 31, 2022. If the settlement agreement is not approved, outstanding issues before the IURC related to Edwardsport would resume and the resolution of such could have an adverse impact on Duke Energy Indiana's financial position, results of operations and cash flows. In addition, an inability to manage operating and capital costs in accordance with caps imposed pursuant to the agreement could have an adverse impact on Duke Energy Indiana's financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

Duke Energy Indiana agreed as part of the grid infrastructure improvement plan to defer depreciation and other post-in-service carrying costs related to a planned automated metering infrastructure (AMI) project until the next retail base rate case. Duke Energy Indiana also agreed to withdraw its request for the creation of a regulatory asset for the remaining book value of existing meters that would be replaced as part of the AMI project. If Duke Energy Indiana proceeds with the AMI project, an impairment charge could be incurred for some or all of the remaining book value of the existing meters. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

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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, 2015, for a summary and detailed discussion of primary sources and uses of cash for 2016 to 2018.

On October 24, 2015, Duke Energy entered into a Merger Agreement with Piedmont, a North Carolina corporation. Under the terms of the Merger Agreement, Duke Energy will acquire Piedmont for $4.9 billion in cash. In addition, Duke Energy will assume Piedmont's existing debt, which was approximately $2.0 billion at April 30, 2016, the end of Piedmont's most recent filed fiscal quarter. Duke Energy expects to finance the transaction with a combination of debt, equity issuances and other cash sources. As of June 30, 2016, Duke Energy had entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. For additional information on the Piedmont acquisition, refer to Note 2 to the Condensed Consolidated Financial Statements, “Acquisitions and Dispositions."

In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into the Equity Forwards with Barclays. Duke Energy expects to settle the Equity Forwards on or around the closing date of the Piedmont acquisition. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont. For additional information regarding the Equity Forwards, see Note 13 to the Condensed Consolidated Financial Statements, "Common Stock."

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 (Parent), 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 (Parent), 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. From time to time, Duke Energy’s current liabilities 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 FACILITIES AND REGISTRATION STATEMENTS

Master Credit Facility Summary

Duke Energy has a Master Credit Facility with a capacity of $7.5 billion through January 2020. The Duke Energy Registrants, excluding Progress Energy (Parent), have borrowing capacity under the Master Credit Facility up to a specified sublimit 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. Duke Energy Carolinas and Duke Energy Progress are also required to each maintain $250 million of available capacity under the Master Credit Facility as security to meet obligations under plea agreements reached with the U.S. Department of Justice in 2015 related to violations at North Carolina facilities with ash basins. The table below includes the current borrowing sublimits and available capacity under the Master Credit Facility.

	June 30, 2016
				Duke			Duke			Duke			Duke			Duke			Duke
	Duke			Energy			Energy			Energy			Energy			Energy			Energy
(in millions)	Energy			(Parent)			Carolinas			Progress			Florida			Ohio			Indiana
Facility size(a)	$	7,500		$	3,475		$	800		$	1,000		$	1,200		$	425		$	600
Reduction to backstop issuances
Commercial paper(b)	(1,673		)	(992		)	(300		)	(159		)	(47		)	(25		)	(150		)
Outstanding letters of credit	(77		)	(70		)	(4		)	(2		)	(1		)	—			—
Tax-exempt bonds	(116		)	—			(35		)	—			—			—			(81		)
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—
Available capacity	$	5,134		$	2,413		$	211		$	589		$	1,152		$	400		$	369

(a) Represents the sublimit of each borrower.

(b) Duke Energy issued $625 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana. The balances are classified as Long-Term Debt Payable to Affiliated Companies in the Condensed Consolidated Balance Sheets.

Piedmont Bridge Facility

In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion Bridge Facility with Barclays. The Bridge Facility, if drawn upon, may be used (i) to fund the cash consideration for the transaction and (ii) to pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to approximately $3.2 billion as a result of the Equity Forwards described above and $1 billion of commitments under a term loan amended and restated as of August 1, 2016, described below.

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Term Loan Facility

On February 22, 2016, Duke Energy entered into a six-month term loan facility with commitments totaling $1.0 billion (the February 2016 Term Loan). As of June 30, 2016, $100 million was outstanding under the February 2016 Term Loan. On August 1, 2016, Duke Energy and each of the lenders under the February 2016 Term Loan amended and restated certain terms of this facility, resulting in aggregate commitments of $1.5 billion and extending the maturity date to July 31, 2017. 

As of August 1, 2016, $100 million has been drawn under the amended and restated term loan (the August 2016 Term Loan). The remaining $1.4 billion of commitments under the August 2016 Term Loan can be drawn in up to two separate borrowings, which must occur no later than 90 calendar days following August 1, 2016. Any borrowings under the August 2016 Term Loan will be used to manage short-term liquidity, including funding a portion of the Piedmont acquisition, and for general corporate purposes. The terms and conditions of the August 2016 Term Loan are generally consistent with those governing Duke Energy’s Master Credit Facility.

Solar Facilities Financing

In August 2016, Emerald State Solar, LLC, an indirect wholly owned subsidiary of Duke Energy, entered into a portfolio financing of approximately 22 North Carolina Solar facilities. The $333 million term loan facility consists of Tranche A of $228 million due in June 2034 secured by substantially all the assets of the solar facilities and Tranche B of $105 million due in June 2020 secured by an Equity Contribution Agreement with Duke Energy. The initial interest rate on the loans is six months LIBOR plus an applicable margin. The initial applicable margin is 1.75 percent with 0.125 percent increases every three years thereafter. In connection with this debt issuance, Emerald State Solar, LLC entered into two interest rate swaps to convert the substantial majority of the loan interest payments from variable rates to fixed rates of approximately 1.81 percent for Tranche A and 1.38 percent for Tranche B, plus the applicable margin.

Shelf Registration

In September 2013, Duke Energy filed a Form S-3 with the Securities and Exchange Commission (SEC). Under this Form S-3, which is uncapped, the Duke Energy Registrants, excluding Progress Energy, may issue debt and other securities in the future at amounts, prices and with terms to be determined at the time of future offerings. The registration statement also allows for the issuance of common stock by Duke Energy. Duke Energy will file a new Form S-3 to be effective prior to the expiration of the current registration statement in September 2016.

DEBT MATURITIES

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		June 30, 2016
Unsecured Debt
Duke Energy (Parent)	November 2016	2.150	%	$	500
Duke Energy (Parent)	April 2017	1.009	%	400
Duke Energy	May 2017	15.530	%	56
Secured Debt
Duke Energy	June 2017	2.075	%	45
First Mortgage Bonds
Duke Energy Indiana	July 2016	0.979	%	150
Duke Energy Carolinas	December 2016	1.750	%	350
Duke Energy Progress	March 2017	0.880	%	250
Tax-exempt Bonds
Duke Energy Carolinas	February 2017	3.600	%	77
Duke Energy Ohio(a)	August 2027	1.280	%	50
Duke Energy Indiana(b)	May 2035	1.092	%	44
Other(c)				420
Current maturities of long-term debt				$	2,342

(a) Represents Duke Energy Kentucky, Inc.'s bonds with a mandatory put in December 2016.

(b) The bonds have a mandatory put in December 2016.

(c) Includes capital lease obligations, amortizing debt and small bullet maturities.

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, storms and legal costs and related settlements, can affect the timing and level of cash flows from operations.

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, 2015, for additional information).

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At June 30, 2016, Duke Energy had cash and cash equivalents of $676 million, of which $454 million is held by entities domiciled in foreign jurisdictions. In December 2014, Duke Energy declared a taxable dividend of historical foreign earnings in the form of notes payable to repatriate approximately $2.7 billion of cash held and expected to be generated by International Energy over a period of up to eight years. As of June 30, 2016, approximately $1.6 billion has been remitted.

Proceeds received from the notes described above or resulting from a sale of International Energy would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. For further information on the potential sale of International Energy, refer to Note 2 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions."

As of December 31, 2015, Duke Energy’s intention was to indefinitely reinvest foreign earnings of International Energy earned after December 31, 2014. In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the investment in NMC. Accordingly, Duke Energy no longer intends to indefinitely reinvest the undistributed earnings of International Energy. As of June 30, 2016, Duke Energy recorded U.S. income taxes of approximately $16 million related to such earnings and will prospectively provide U.S. income taxes on future foreign earnings.

This change in Duke Energy's intent, combined with the extension of bonus depreciation by Congress in late 2015, allows Duke Energy to more efficiently utilize foreign tax credits and reduce U.S. deferred tax liabilities associated with historic unremitted foreign earnings by approximately $95 million.

Restrictive Debt Covenants

The Duke Energy Registrants’ debt and credit agreements contain various financial and other covenants. The Master Credit Facility contains a covenant requiring the debt-to-total capitalization ratio 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 30, 2016, each of the Duke Energy Registrants were in compliance with all covenants related to their 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 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 deteriorate, credit ratings could be negatively impacted.

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 and outlooks from Fitch, Moody's and S&P have not changed since February 2016.

Cash Flow Information

The following table summarizes Duke Energy’s cash flows.

	Six Months Ended
	June 30,
(in millions)	2016			2015
Cash flows provided by (used in):
Operating activities	$	3,206		$	2,879
Investing activities	(3,608		)	(294		)
Financing activities	221			(3,661		)
Net decrease in cash and cash equivalents	(181		)	(1,076		)
Cash and cash equivalents at beginning of period	857			2,036
Cash and cash equivalents at end of period	$	676		$	960

OPERATING CASH FLOWS

The following table summarizes key components of Duke Energy’s operating cash flows.

	Six Months Ended
	June 30,
(in millions)	2016			2015
Net income	$	1,211		$	1,414
Non-cash adjustments to net income	2,231			2,409
Contributions to qualified pension plans	—			(132		)
Payments for asset retirement obligations	(263		)	(125		)
Working capital	27			(687		)
Net cash provided by operating activities	$	3,206		$	2,879

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The variance was driven primarily due to:

• a $714 million increase in working capital primarily due to unrealized losses on forward-starting interest rate swaps related to the expected financing of the Piedmont acquisition, higher property tax accruals due to timing of payments, and lower coal stock inventory due to management of high inventory levels and timing of shipments partially due to higher utilization as a result of warmer than normal weather;

Partially offset by:

• a $381 million decrease in net income after non-cash adjustments, primarily due to the absence of earnings from the Disposal Group sold in April 2015 and less favorable weather in 2016 compared to prior year, partially offset by increased retail pricing and riders.

INVESTING CASH FLOWS

The following table summarizes key components of Duke Energy’s investing cash flows.

	Six Months Ended
	June 30,
(in millions)	2016			2015
Capital, investment and acquisition expenditures	$	(3,529	)	$	(3,189	)
Available for sale securities, net	26			13
Proceeds from sales of the Disposal Group	—			2,792
Other investing items	(105		)	90
Net cash used in investing activities	$	(3,608	)	$	(294	)

The variance was primarily due to:

• a $2,832 million decrease in proceeds mainly due to prior year sale of the Disposal Group to Dynegy; and

• a $340 million increase in capital, investment and acquisition expenditures primarily due to growth in regulated generation investments, natural gas infrastructure and renewable energy projects.

FINANCING CASH FLOWS

The following table summarizes key components of Duke Energy’s financing cash flows.

	Six Months Ended
	June 30,
(in millions)	2016			2015
Issuance of common stock related to employee benefit plans	$	7		$	16
Issuances (Redemptions) of long-term debt, net	2,719			(672		)
Notes payable and commercial paper	(1,341		)	(365		)
Dividends paid	(1,140		)	(1,115		)
Repurchase of common shares	—			(1,500		)
Other financing items	(24		)	(25		)
Net cash provided by (used in) financing activities	$	221		$	(3,661	)

The variance was due primarily to:

• a $3,391 million increase in proceeds from net issuances of long-term debt, driven by the issuance of $1,294 million of senior secured bonds used to finance the recovery of certain retired nuclear generation assets and other issuances primarily used to fund capital expenditures, repay debt maturities and pay down outstanding commercial paper; and

• a $1,500 million decrease in cash outflows due to the prior year repurchase of 19.8 million common shares under the accelerated stock repurchase program.

Partially offset by:

• a $976 million increase in net payments of notes payable and commercial paper, primarily due to repayment of commercial paper. These cash outflows were primarily made with proceeds from long-term debt issuances.

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Summary of Significant Debt Issuances

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

				Six Months Ended
				June 30, 2016
						Duke		Duke		Duke		Duke		Duke
	Maturity	Interest		Duke		Energy		Energy		Energy		Energy		Energy
Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Florida		Ohio		Indiana
Unsecured
April 2016(a)	April 2023	2.875	%	$	350	$	350	$	—	$	—	$	—	$	—
First Mortgage Bonds
March 2016(b)	March 2023	2.500	%	500		—		500		—		—		—
March 2016(b)	March 2046	3.875	%	500		—		500		—		—		—
May 2016(c)	May 2046	3.750	%	500		—		—		—		—		500
June 2016(b)	June 2046	3.700	%	250		—		—		—		250		—
Secured Debt
June 2016(d)	March 2020	1.196	%	183		—		—		183		—		—
June 2016(d)	September 2022	1.731	%	150		—		—		150		—		—
June 2016(d)	September 2029	2.538	%	436		—		—		436		—		—
June 2016(d)	March 2033	2.858	%	250		—		—		250		—		—
June 2016(d)	September 2036	3.112	%	275		—		—		275		—		—
Total issuances				$	3,394	$	350	$	1,000	$	1,294	$	250	$	500

(a) Proceeds were used to pay down outstanding commercial paper and for general corporate purposes.

(b) Proceeds were used to fund capital expenditures for ongoing construction, capital maintenance and for general corporate purposes.

(c) Proceeds were used to repay $325 million of unsecured debt due June 2016, $150 million of first mortgage bonds due July 2016 and for general corporate purposes.

(d) Proceeds from the nuclear asset recovery bonds issued by Duke Energy Florida Project Finance, LLC (DEFPF), a bankruptcy remote subsidiary of Duke Energy Florida, were used to acquire nuclear asset-recovery property from its parent, Duke Energy Florida. The nuclear asset-recovery bonds are payable only from and secured by the nuclear asset-recovery property. DEFPF is consolidated for financial reporting purposes; however, the nuclear asset-recovery bonds do not constitute a debt, liability or other legal obligation of, or interest in, Duke Energy Florida or any of its affiliates other than DEFPF. The assets of DEFPF, including the nuclear asset-recovery property, are not available to pay creditors of Duke Energy Florida or any of its affiliates. Duke Energy Florida used the proceeds from the sale to repay short-term borrowings under the intercompany money pool borrowing arrangement and make an equity distribution of $649 million to the ultimate parent, Duke Energy (Parent), which repaid short-term borrowings. The nuclear asset-recovery bonds are sequential pay amortizing bonds. The maturity date above represents the scheduled final maturity date for the bonds. See Notes 4 and 12 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and "Variable Interest Entities," respectively, for additional information.

OTHER MATTERS

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 and result in new obligations of the Duke Energy Registrants.

The following sections outline various proposed and recently enacted regulations that may impact the Duke Energy Registrants. 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.

Coal Combustion Residuals

On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. The federal regulation, which became effective in October 2015, classifies CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act and allows for beneficial use of CCR with some restrictions. The regulation applies to all new and existing landfills, new and existing surface impoundments receiving CCR and existing surface impoundments that are no longer receiving CCR but contain liquid located at stations currently generating electricity (regardless of fuel source). The rule establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. Various industry and environmental parties have appealed the EPA's CCR rule in the D.C. Circuit Court of Appeals. On April 18, 2016, the EPA filed a motion with the federal court to settle five issues raised in litigation. On June 14, 2016, the court approved the motion with respect to all of those issues. Duke Energy does not expect a material impact from the settlement or that it will result in additional asset retirement obligation adjustments.

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In addition to the requirements of the federal CCR regulation, CCR landfills and surface impoundments will continue to be independently regulated by most states. As a result of the EPA rule, the Subsidiary Registrants recorded asset retirement obligation amounts during 2015. Cost recovery for future expenditures will be pursued through the normal ratemaking process with federal and state utility commissions and via wholesale contracts, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations. For more information, see Note 9, "Asset Retirement Obligations," in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.

Beckjord, a facility retired during 2014, is not subject to the recently enacted EPA rule related to the disposal of CCR from electric utilities. However, if costs are incurred as a result of environmental regulations or to mitigate risk associated with on-site storage of coal ash at the facility, the costs could have an adverse impact on Duke Energy Ohio's financial position, results of operations and cash flows. Costs incurred by Ohio Valley Electric Corporation (OVEC) related to environmental regulations could also have an adverse impact on Duke Energy Ohio's financial position, results of operations and cash flows.

Coal Ash Management Act of 2014

On September 20, 2014, the Coal Ash Act became law and was amended on June 24, 2015, by the North Carolina Mountain Energy Act. The Coal Ash Act, as amended, established requirements regarding the use and closure of existing ash impoundments, the disposal of ash at active coal plants and the handling of surface and groundwater impacts from ash basins in North Carolina. The Coal Ash Act, as amended, deemed eight ash impoundments at four facilities to be high priority and requires closure no later than August 1, 2019, with a potential extension for closure of the Asheville impoundment until 2022. The Coal Ash Act required state regulators to provide risk ranking classifications for the remaining 25 ash impoundments at 10 North Carolina facilities.

In January 2016, NCDEQ published draft proposed risk classifications for sites not specifically delineated by the Coal Ash Act as high priority. These risk rankings were generally determined based on three primary criteria: structural integrity of the impoundments and impact to both surface and groundwater. NCDEQ categorized 12 basins at four sites as intermediate risk and four basins at three plants as low risk. Basins at high priority sites (Dan River, Riverbend, Asheville and Sutton) require closure through excavation including a combination of transferring the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of high priority basins is required to be completed no later than August 1, 2019, except for Asheville which is required to be completed no later than August 1, 2022. Intermediate risk basins require closure through excavation including a combination of converting the basin to a lined industrial landfill, transferring of the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of intermediate risk basins is required to be completed no later than December 31, 2024. Low risk basins require closure through either the combination of the installation and maintenance of a cap system and groundwater monitoring system designed to minimize infiltration and erosion or other closure options available to intermediate-risk basins. Closure of low risk basins is required to be completed no later than December 31, 2029. NCDEQ also categorized nine basins at six plants as “low-to-intermediate” risk, thereby not assigning a definitive risk ranking at that time. On May 18, 2016, the NCDEQ issued new proposed risk classifications, ranking all originally proposed low risk and "low-intermediate" risk sites as intermediate.

On July 14, 2016, the Governor of North Carolina signed legislation which amends the Coal Ash Act and requires Duke Energy to undertake dam improvement projects and to provide access to a permanent alternative drinking water source to certain residents within a half mile of coal ash basin compliance boundaries and to certain other potentially impacted residents. The new legislation also ranks basins at the H.F. Lee, Cape Fear and Weatherspoon stations as intermediate risk consistent with Duke Energy's previously announced plans to excavate those basins. These specific intermediate basins require closure through excavation including a combination of transferring ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of these specific intermediate basins is required to be completed no later than August 1, 2028. Additionally, the new legislation requires the installation and operation of three large-scale coal ash beneficiation projects which are expected to produce reprocessed ash for use in the concrete industry. Closure of basins at sites with these beneficiation projects are required to be completed no later than December 31, 2029. Upon satisfactory completion of the dam improvement projects and installation of alternate drinking water sources by October 15, 2018, the legislation requires NCDEQ to reclassify intermediate risk sites, excluding H.F. Lee, Cape Fear and Weatherspoon, as low risk.

Per the Coal Ash Act, final proposed classifications were to be subject to Coal Ash Management Commission (Coal Ash Commission) approval. In March 2016, the Coal Ash Commission created by the Coal Ash Act was disbanded by the Governor of North Carolina based on a North Carolina Supreme Court ruling regarding the constitutionality of the body. The new legislation eliminates the Coal Ash Commission and transfers responsibility for ash basin closure oversight to the NCDEQ.

Estimated asset retirement obligations have been recognized based on the assigned risk categories based on a probability weighting of potential closure methods. Actual closure costs incurred could be materially different from current estimates that form the basis of the recorded asset retirement obligations. Costs incurred have been deferred as regulatory assets and recovery will be pursued through the normal ratemaking process with federal and state utility commissions, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations.

Mercury and Air Toxics Standards

The final Mercury and Air Toxics Standards (MATS) rule was issued on February 16, 2012. The rule established emission limits for hazardous air pollutants from new and existing coal-fired and oil-fired steam electric generating units. The rule required sources to comply with emission limits by April 16, 2015, or by April 16, 2016, with approved extension. Strategies to achieve compliance included installation of new air emission control equipment, development of monitoring processes, fuel switching and acceleration of retirement for some coal-fired electric-generation units. All of Duke Energy's coal-fired units are in compliance with the emission limits, work practices standards and other requirements of the MATS rule. For additional information, refer to Note 4 of the Condensed Consolidated Financial Statements, “Regulatory Matters,” regarding potential plant retirements.

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Clean Water Act 316(b)

The EPA published the final 316(b) cooling water intake structure rule on August 15, 2014, with an effective date of October 14, 2014. The rule applies to 26 of the electric generating facilities the Duke Energy Registrants own and operate. The rule allows for several options to demonstrate 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 time frame. Petitions challenging the rule have been filed by several groups. It is unknown at this time when the courts will rule on the petitions.

Steam Electric Effluent Limitations Guidelines

On January 4, 2016, the final Steam Electric Effluent Limitations Guidelines (ELG) rule became effective. The rule establishes new requirements for wastewater streams associated with steam electric power generation and includes more stringent controls for any new coal plants that may be built in the future. Affected facilities must comply between 2018 and 2023, depending on timing of new Clean Water Act (CWA) permits. Most, if not all, of the steam electric generating facilities the Duke Energy Registrants own are likely affected sources. The Duke Energy Registrants are well positioned to meet the majority of the requirements of the rule due to current efforts to convert to dry ash handling. Petitions challenging the rule have been filed by several groups. On March 16, 2015, Duke Energy Indiana filed its own legal challenge to the rule with the Seventh Circuit Court of Appeals specific to the ELG for wastewater associated rule focused on the limits imposed on integrated gas combined-cycle facilities. All challenges to the rule have been consolidated in the Fifth Circuit Court of Appeals. It is unknown at this time when the courts will rule on the petitions.

Estimated Cost and Impacts of Rulemakings

Duke Energy will incur capital expenditures to comply with the environmental regulations and rules discussed above. The following table provides five-year estimated costs, excluding AFUDC, of new control equipment that may need to be installed on existing power plants primarily to comply with the Coal Ash Act requirements for conversion to dry disposal of bottom ash and fly ash, MATS, CWA 316(b) and ELGs, through December 31, 2020. The table excludes ash basin closure costs recorded as Asset retirement obligations on the Condensed Consolidated Balance Sheets. For more information related to asset retirement obligations, see Note 9 in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2015.

(in millions)	Estimated Cost
Duke Energy	$	1,350
Duke Energy Carolinas	625
Progress Energy	350
Duke Energy Progress	300
Duke Energy Florida	50
Duke Energy Ohio	100
Duke Energy Indiana	275

The Duke Energy Registrants also expect to incur increased fuel, purchased power, operation and maintenance and other expenses, in addition to costs for replacement generation for potential coal-fired power plant retirements, as a result of these regulations. Actual compliance costs incurred may be materially different from these estimates due to reasons such as the timing and requirements of EPA regulations and the resolution of legal challenges to the rules. The Duke Energy Registrants intend to seek rate recovery of necessary and prudently incurred costs associated with regulated operations to comply with these regulations.

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 sulfur dioxide (SO2) budgets and annual and seasonal nitrogen oxide (NOx) budgets that were to take effect on January 1, 2012.

On August 21, 2012, the D.C. Circuit Court vacated the CSAPR. The court also directed the EPA to continue administering the Clean Air Interstate Rule (CAIR), which required additional reductions in SO2 and NOX emissions beginning in 2015. On April 29, 2014, the Supreme Court reversed the D.C. Circuit Court’s decision, finding that with CSAPR the EPA reasonably interpreted the good neighbor provision of the CAA. The case was remanded to the D.C. Circuit Court for further proceedings consistent with the Supreme Court’s opinion. On October 23, 2014, the D.C. Circuit Court lifted the CSAPR stay, which allowed Phase 1 of the rule to take effect on January 1, 2015, terminating the CAIR. Where the CSAPR requirements are constraining, actions to meet the requirements may include purchasing emission allowances, power purchases, curtailing generation and utilizing low sulfur fuel. The CSAPR did not result in Duke Energy Registrants adding new emission controls.

On December 3, 2015, the EPA proposed a rule to lower the current CSAPR Phase 2 state ozone season NOX emission budgets for 23 Eastern states, including North Carolina, Ohio, Kentucky and Indiana. The EPA also proposed to eliminate the CSAPR Phase 2 ozone season state NOX budgets for Florida and South Carolina. The EPA proposed that these changes to state budgets take effect on May 1, 2017. The EPA has indicated that it plans to finalize a rule during the summer of 2016. The EPA's proposed changes would impose requirements to achieve emission reduction targets within short timelines and could result in an impact on the emission allowance trading market, increase costs for customers, and hamper the ability to demonstrate compliance. Duke Energy Registrants cannot predict the outcome of these proceedings.

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Carbon Pollution Standards for New, Modified and Reconstructed Power Plants

On October 23, 2015, the EPA published a final rule in the Federal Register establishing carbon dioxide (CO2) emissions limits for new, modified and reconstructed power plants. The requirements for new plants do not apply to any facility that Duke Energy currently has in operation, but would apply to plants that commenced construction after January 8, 2014. The EPA set an emissions standard for coal units of 1,400 pounds which would require the application of partial carbon capture and storage (CCS) technology for a coal unit to be able to meet the limit. Utility-scale CCS is not currently a demonstrated and commercially available technology for coal-fired electric generating units, and therefore the final standard effectively prevents the development of new coal-fired generation. The EPA set a final standard of 1,000 pounds of CO2 per gross MWh for new natural gas combined-cycle units. Petitions challenging the rule have been filed by several groups. Briefing in the case was scheduled to conclude on October 21, 2016, but on June 24, 2016, the D.C. Circuit suspended the briefing schedule and set a deadline of August 4, 2016, for parties to submit motions to amend the briefing schedule. It is unknown at this time when briefing or oral argument will occur, or when the court will rule on the petitions. The Duke Energy Registrants do not expect the impacts of the final standards will be material to Duke Energy's financial position, results of operations or cash flows.

Clean Power Plan (CPP)

On October 23, 2015, the EPA published in the Federal Register the final CPP rule that regulates CO2 emissions from existing fossil fuel-fired electric generating units. The CPP establishes CO2 emission rates and mass cap goals that apply to existing fossil fuel-fired electric generation units. Under the CPP, states are required to develop and submit a final compliance plan, or an initial plan with an extension request, to the EPA by September 6, 2016. States that receive an extension must submit a final completed plan to the EPA by September 6, 2018. The EPA intends to review and approve or disapprove state plans within 12 months of receipt. The CPP does not directly impose regulatory requirements on the Duke Energy Registrants. State implementation plans will include the regulatory requirements that will apply to the Duke Energy Registrants. The EPA also published a proposed federal plan for public comment. A federal plan would be applied to states that fail to submit a plan to EPA or where a state plan is not approved by the EPA. Comments on the proposed federal plan were due by January 21, 2016.

Legal challenges to the final CPP have been filed by stakeholders. On January 21, 2016, the U.S. Court of Appeals for the District of Columbia denied motions from petitioners to stay the CPP pending court review. On February 9, 2016, the Supreme Court granted a stay in the matter, halting implementation of the CPP until legal challenges are resolved. The states in which Duke Energy's regulated operations are located have suspended work on the CPP in response to the stay. Oral arguments before the full D.C. Circuit court are scheduled for September 27, 2016.

Compliance with CPP could cause the industry to replace coal generation with natural gas and renewables. Costs to operate coal-fired generation plants continue to grow due to increasing environmental compliance requirements, including ash management costs unrelated to CPP, which may result in the retirement of coal-fired generation plants earlier than the current end of useful lives. If the CPP is ultimately upheld by the courts and implementation goes forward, the Duke Energy Registrants could incur increased fuel, purchased power, operation and maintenance and other costs for replacement generation as a result of this rule. Due to the uncertainties related to the implementation of the CPP, the Duke Energy Registrants cannot predict the outcome of these matters.

Global Climate Change

For other information on global climate change and the potential impacts on Duke Energy, see “Other Matters” 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, 2015.

Nuclear Matters

For other information on nuclear matters and the potential impacts on Duke Energy, see “Other Matters” 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, 2015.

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 months ended June 30, 2016, 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, 2015.

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 months ended June 30, 2016, 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, 2015.

Subsequent Events

See Note 17 to the Condensed Consolidated Financial Statements, “Subsequent Events,” for a discussion of subsequent events.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

During the three and six months ended June 30, 2016, 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, 2015.

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 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 30, 2016, 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 30, 2016, and have concluded no change has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

116

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

For information regarding legal proceedings, including regulatory and environmental matters, that became reportable events or in which there were material developments in the second quarter of 2016, see Note 4, "Regulatory Matters," and Note 5, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements.

MTBE Litigation

On June 29, 2007, the New Jersey Department of Environmental Protection (NJDEP) filed suit against, among others, Duke Energy Merchants (DEM), alleging contamination of “waters of the state” by MTBE from leaking gasoline storage tanks. MTBE is a gasoline additive intended to increase the oxygen level in gasoline and make it burn cleaner. The case was moved to federal court and consolidated in an existing multidistrict litigation docket of pending MTBE cases. DEM and NJDEP have reached an agreement in principle to settle the case for a payment by DEM of $1.7 million. On February 19, 2016, the court approved a Consent Decree executed by the parties which settles the case. Payment was made in February 2016. The case was dismissed by the court on April 29, 2016. DEM is also a defendant in a similar case filed by the Commonwealth of Pennsylvania on June 19, 2014. That case has been moved to the consolidated multidistrict proceeding. Discovery in this case continues.

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, 2015, which could materially affect the Duke Energy Registrants’ financial condition or future results.

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

ISSUERPURCHASES OF EQUITY SECURITIES

There were no issuer purchases of equity securities during the second quarter of 2016.

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PART II

ITEM 6. EXHIBITS

Exhibits filed herein are 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 (***).

			Duke		Duke	Duke	Duke	Duke
Exhibit		Duke	Energy	Progress	Energy	Energy	Energy	Energy
Number		Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana
4.1	Sixty-Eighth Supplemental Indenture, dated as of May 12, 2016 (incorporated by reference to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on May 12, 2016, File No. 1-3543).							X
4.2	Forty-Fourth Supplemental Indenture, dated as of June 23, 2016 (incorporated by reference to Exhibit 4.1 registrant's Current Report on Form 8-K filed on June 23, 2016, File No. 1-1232).						X
*10.1	$1,500,000,000 Amended and Restated Term Loan Agreement among Duke Energy Corporation, as Borrower, the Lenders listed therein, The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Administrative Agent, and The Bank of Tokyo-Mitsubishi UFJ, Ltd., Santander Bank, N.A. and TD Bank, N.A., as Joint Lead Arrangers and Bookrunners, dated as of August 1, 2016.	X
*12	Computation of Ratio of Earnings to Fixed Charges – DUKE ENERGY CORPORATION.	X
*31.1.1	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.	X
*31.1.2	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.		X
*31.1.3	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.			X
*31.1.4	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.				X
*31.1.5	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.					X
*31.1.6	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.						X
*31.1.7	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.							X
*31.2.1	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.	X
*31.2.2	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.		X
*31.2.3	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.			X
*31.2.4	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.				X
*31.2.5	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.					X
*31.2.6	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.						X
*31.2.7	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.							X

118

PART II

*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.	X
*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.		X
*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.			X
*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.				X
*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.					X
*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.						X
*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.							X
*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.	X
*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.		X
*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.			X
*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.				X
*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.					X
*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.						X
*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.							X
*101.INS	XBRL Instance Document.	X	X	X	X	X	X	X
*101.SCH	XBRL Taxonomy Extension Schema Document.	X	X	X	X	X	X	X
*101.CAL	XBRL Taxonomy Calculation Linkbase Document.	X	X	X	X	X	X	X
*101.LAB	XBRL Taxonomy Label Linkbase Document.	X	X	X	X	X	X	X
*101.PRE	XBRL Taxonomy Presentation Linkbase Document.	X	X	X	X	X	X	X
*101.DEF	XBRL Taxonomy Definition Linkbase Document.	X	X	X	X	X	X	X

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 SEC, to furnish copies of any or all of such instruments to it.

119

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 DUKE ENERGY PROGRESS, LLC DUKE ENERGY FLORIDA, LLC DUKE ENERGY OHIO, INC. DUKE ENERGY INDIANA, LLC
Date:	August 4, 2016	/s/ STEVEN K. YOUNG
		Steven K. Young Executive Vice President and Chief Financial Officer (Principal Financial Officer)
Date:	August 4, 2016	/s/ WILLIAM E. CURRENS JR.
		William E. Currens Jr. Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)
		PROGRESS ENERGY, INC.
Date:	August 4, 2016	/s/ STEVEN K. YOUNG
		Steven K. Young Executive Vice President and Chief Financial Officer (Principal Financial Officer)
Date:	August 4, 2016	/s/ WILLIAM E. CURRENS JR.
		William E. Currens Jr. Chief Accounting Officer and Controller (Principal Accounting Officer)

120

EX-10.1

Exhibit 10.1

$1,500,000,000

AMENDED AND RESTATED TERM LOAN CREDIT AGREEMENT

dated as of

August 1, 2016

among

Duke Energy Corporation,

as Borrower,

The Lenders Listed Herein,

The Bank of Tokyo-Mitsubishi UFJ, Ltd.

as Administrative Agent,

and

The Bank of Tokyo-Mitsubishi UFJ, Ltd.,

Santander Bank, N.A. and

TD Bank, N.A.,

as Joint Lead Arrangers and Bookrunners

TABLE OF CONTENTS

PAGE

ARTICLE 1DEFINITIONS

Section 1.01.Definitions1

Section 1.02.Accounting Terms and Determinations14

Section 1.03.Types of Borrowings15

ARTICLE 2
THE CREDIT

Section 2.01.Commitments to Lend;Treatment of Existing Loans15

Section 2.02.Notice of Borrowings16

Section 2.03.Notice to Lenders; Funding of Loans16

Section 2.04.Registry; Notes17

Section 2.05.Maturity of Loans18

Section 2.06.Interest Rates18

Section 2.07.Ticking Fee.19

Section 2.08.[Reserved].19

Section 2.09.Method of Electing Interest Rates19

Section 2.10.[Reserved]21

Section 2.11.Optional Prepayments21

Section 2.12.General Provisions as to Payments21

Section 2.13.Funding Losses22

Section 2.14.Computation of Interest and Fees22

Section 2.15.[Reserved]22

Section 2.16.Regulation D Compensation22

Section 2.17.[Reserved]23

Section 2.18.[Reserved]23

Section 2.19.Defaulting Lenders23

ARTICLE 3
CONDITIONS

Section 3.01.Effective Date25

Section 3.02.[Reserved].25

Section 3.03.Borrowings26

ARTICLE 4
REPRESENTATIONS AND WARRANTIES

Section 4.01.Organization and Power26

Section 4.02.Corporate and Governmental Authorization; No Contravention26

Section 4.03.Binding Effect27

Section 4.04.Financial Information27

Section 4.05.Regulation U27

i

Section 4.06.Litigation27

Section 4.07.Compliance with Laws28

Section 4.08.Taxes28

Section 4.09.Anti-corruption Law and Sanctions28

ARTICLE 5
COVENANTS

Section 5.01.Information29

Section 5.02.Payment of Taxes30

Section 5.03.Maintenance of Property; Insurance31

Section 5.04.Maintenance of Existence31

Section 5.05.Compliance with Laws31

Section 5.06.Books and Records31

Section 5.07.Negative Pledge32

Section 5.08.Consolidations, Mergers and Sales of Assets34

Section 5.09.Use of Proceeds34

Section 5.10.Indebtedness/Capitalization Ratio34

ARTICLE 6
DEFAULTS

Section 6.01.Events of Default34

Section 6.02.Notice of Default36

ARTICLE 7
THE ADMINISTRATIVE AGENT

Section 7.01.Appointment and Authorization36

Section 7.02.Administrative Agent and Affiliates37

Section 7.03.Action by Administrative Agent37

Section 7.04.Consultation with Experts37

Section 7.05.Liability of Administrative Agent37

Section 7.06.Indemnification38

Section 7.07.Credit Decision38

Section 7.08.Successor Administrative Agent38

Section 7.09.Administrative Agent’s Fee39

ARTICLE 8
CHANGE IN CIRCUMSTANCES

Section 8.01.Basis for Determining Interest Rate Inadequate or Unfair39

Section 8.02.Illegality39

Section 8.03.Increased Cost and Reduced Return40

Section 8.04.Taxes41

Section 8.05.Base Rate Loans Substituted for Affected Euro-Dollar Loans45

Section 8.06.Substitution of Lender; Termination Option45

ARTICLE 9
MISCELLANEOUS

ii

Section 9.01.Notices46

Section 9.02.No Waivers47

Section 9.03.Expenses; Indemnification47

Section 9.04.Sharing of Set-offs48

Section 9.05.Amendments and Waivers48

Section 9.06.Successors and Assigns49

Section 9.07.Collateral51

Section 9.08.Confidentiality51

Section 9.09.Governing Law; Submission to Jurisdiction52

Section 9.10.Counterparts; Integration52

Section 9.11.WAIVER OF JURY TRIAL53

Section 9.12.USA Patriot Act53

Section 9.13.[Reserved]53

Section 9.14.No Fiduciary Duty53

Section 9.15.Survival53

Section 9.16.Acknowledgment and Consent to Bail-In of EEA Financial Institutions53

COMMITMENT SCHEDULE

EXHIBIT A -    Note

EXHIBIT B -    Opinion of Internal Counsel of the Borrower

EXHIBIT C -    Opinion of Special Counsel for the Borrower

EXHIBIT D - Assignment and Assumption Agreement

iii

AMENDED AND RESTATED TERM LOAN CREDIT AGREEMENT

AMENDED AND RESTATED TERM LOAN CREDIT AGREEMENT dated as of August 1, 2016 among DUKE ENERGY CORPORATION, as Borrower, the Lenders from time to time party hereto and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Administrative Agent.

WHEREAS, the Borrower, the Lenders (in such capacity, the “Existing Lenders”) and the Administrative Agent (in such capacity, the “Existing Agent”) are parties to that certain Credit Agreement dated as of February 22, 2016 (the “Existing Credit Agreement”);

WHEREAS, on the terms and conditions set forth in the Existing Credit Agreement the Existing Lenders made loans (the “Existing Loans”) to the Borrower;

WHEREAS, the Borrower has requested and the Existing Lenders and Existing Agent have agreed to the amendment and restatement of the Existing Credit Agreement upon the terms and subject to the conditions set forth herein; and

WHEREAS, as of the Effective Date, the principal amount of the Existing Loans then outstanding under the Existing Credit Agreement will be deemed to (i) be Loans made and outstanding under this Agreement and (ii) have utilized the Commitment of each Lender under this Agreement by the amount of such Lender’s pro rata share (based on its Percentage) of the aggregate principal amount of the Existing Loans;

NOW, THEREFORE, the parties hereto agree as follows:

ARTICLE 1DEFINITIONS

Section 1.01.Definitions. The following terms, as used herein, have the following meanings:

“Administrative Agent” means The Bank of Tokyo-Mitsubishi UFJ, Ltd. in its capacity as administrative agent for the Lenders hereunder, and its successors in such capacity.

“Administrative Questionnaire” means, with respect to each Lender, the administrative questionnaire in the form submitted to such Lender by the Administrative Agent and submitted to the Administrative Agent (with a copy to the Borrower) duly completed by such Lender.

“Affiliate” means, as to any Person (the “specified Person”) (i) any Person that directly, or indirectly through one or more intermediaries, controls the specified Person (a “Controlling Person”) or (ii) any Person (other than the specified Person or a Subsidiary of the specified Person) which is controlled by or is under common control with a Controlling Person. As used herein, the term “control” means possession, directly or

indirectly, of the power to direct or cause the direction of the management or policies of a Person, whether through the ownership of voting securities, by contract or otherwise.

“Agreement”means this Amended and Restated Term Loan Credit Agreement as the same may be amended from time to time.

“Anti-Corruption Laws” means the United States Foreign Corrupt Practices Act of 1977 and all other laws, rules, and regulations of any jurisdiction concerning or relating to bribery, corruption or money laundering.

“Applicable Lending Office” means, with respect to any Lender, (i) in the case of its Base Rate Loans, its Domestic Lending Office and (ii) in the case of its Euro-Dollar Loans, its Euro‑Dollar Lending Office.

“Applicable Margin” means, with respect to Euro-Dollar Loans to the Borrower, the applicable rate per annum for the Borrower determined in accordance with the Pricing Schedule.

“Approved Fund” means any Fund that is administered or managed by (i) a Lender, (ii) an Affiliate of a Lender or (iii) an entity or an Affiliate of an entity that administers or manages a Lender.

“Approved Officer” means the president, the chief financial officer, a vice president, the treasurer, an assistant treasurer or the controller of the Borrower or such other representative of the Borrower as may be designated by any one of the foregoing with the consent of the Administrative Agent.

“Assignee” has the meaning set forth in Section 9.06(c).

“Bail-In Action” means the exercise of any Write-Down and Conversion Powers by the applicable EEA Resolution Authority in respect of any liability of an EEA Financial Institution.

“Bail-In Legislation” means, with respect to any EEA Member Country implementing Article 55 of Directive 2014/59/EU of the European Parliament and of the Council of the European Union, the implementing law for such EEA Member Country from time to time which is described in the EU Bail-In Legislation Schedule.

“Bankruptcy Event” means, with respect to any Person, such Person becomes the subject of a bankruptcy or insolvency proceeding (or any similar proceeding), or generally fails to pay its debts as such debts become due, or admits in writing its inability to pay its debts generally, or has had a receiver, conservator, trustee, administrator, custodian, assignee for the benefit of creditors or similar Person charged with the reorganization or liquidation of its business or assets appointed for it, or, in the good faith determination of the Administrative Agent (or, if the Administrative Agent is the subject of the Bankruptcy Event, the Required Lenders), has taken any action in furtherance of,

2

or indicating its consent to, approval of, or acquiescence in, any such proceeding or appointment, provided that a Bankruptcy Event shall not result solely by virtue of any ownership interest, or the acquisition of any ownership interest, in such Person by a Governmental Authority or instrumentality thereof so long as such ownership interest does not result in or provide such Person with immunity from the jurisdiction of courts within the United States or from the enforcement of judgments or writs of attachment on its assets or permit such Person (or such Governmental Authority or instrumentality) to reject, repudiate, disavow or disaffirm any contracts or agreements made by such Person.

“Base Rate” means, for any day for which the same is to be calculated, the highest of (a) the Prime Rate, (b) the Federal Funds Rate plus 1/2 of 1% and (c) the LIBOR Market Index Rate plus 1%; provided, that, if the Base Rate shall be less than zero, such rate shall be deemed to be zero for purposes of this Agreement. Each change in the Base Rate shall take effect simultaneously with the corresponding change in the rates described in clauses (a), (b) or (c) above, as the case may be.

“Base Rate Loan” means (i) a Loan which bears interest at the Base Rate pursuant to the applicable Notice of Borrowing or Notice of Interest Rate Election or the provisions of Article 8 or (ii) an overdue amount which was a Base Rate Loan immediately before it became overdue.

“Borrower” means Duke Energy Corporation, a Delaware corporation..

“Borrowing” means a borrowing made on a single date and for a single Interest Period.

“Change” has the meaning set forth in Section 9.05(b).

“Change in Law” means the occurrence of any of the following after the date of this Agreement: (a) the adoption or taking effect of any law, rule, regulation or treaty, (b) any change in any law, rule, regulation or treaty or in the administration, interpretation or application thereof by any Governmental Authority, or (c) the making or issuance of any request, rules, guideline, requirement or directive (whether or not having the force of law) by any Governmental Authority; provided however, that notwithstanding anything herein to the contrary, (i) the Dodd-Frank Wall Street Reform and Consumer Protection Act and all requests, rules, guidelines, requirements and directives thereunder, issued in connection therewith or in implementation thereof, and (ii) all requests, rules, guidelines, requirements and directives promulgated by the Bank for International Settlements, the Basel Committee on Banking Supervision (or any successor or similar authority) or the United States or foreign regulatory authorities, in each case pursuant to Basel III, shall in each case be deemed to be a “Change in Law” after the date hereof regardless of the date enacted, adopted, issued or implemented.

“Commitment” means (i) with respect to any Lender listed on the signature pages hereof, the amount set forth opposite its name on the Commitment Schedule, and (ii) with respect to each Assignee which becomes a Lender pursuant to Sections 8.06 or

3

9.06(c), the amount of the Commitment thereby assumed by it, in each case as such amount may from time to time be reduced pursuant to Sections 8.06 or 9.06(c) or increased pursuant to Sections 8.06 or 9.06(c).

“Commitment Schedule” means the Commitment Schedule attached hereto.

“Commitment Termination Date” means the date that is 90 days after the Effective Date.

“Connection Income Taxes” means, with respect to any Lender or Agent, taxes that are imposed on or measured by net income (however denominated), franchise taxes or branch profits taxes, in each case, imposed as a result of a connection (including any former connection) between such Lender or Agent and the jurisdiction imposing such tax (other than connections arising from such Lender or Agent having executed, delivered, become a party to, performed its obligations under, received payments under, received or perfected a security interest under, engaged in any other transaction pursuant to or enforced this Agreement or any Note, or sold or assigned an interest in any Loan, this Agreement or any Note).

“Consolidated Capitalization” means, with respect to the Borrower, the sum, without duplication, of (i) Consolidated Indebtedness of the Borrower, (ii) consolidated common equityholders’ equity as would appear on a consolidated balance sheet of the Borrower and its Consolidated Subsidiaries prepared in accordance with generally accepted accounting principles, (iii) the aggregate liquidation preference of preferred or priority equity interests (other than preferred or priority equity interests subject to mandatory redemption or repurchase) of the Borrower and its Consolidated Subsidiaries upon involuntary liquidation, (iv) the aggregate outstanding amount of all Equity Preferred Securities of the Borrower and (v) minority interests as would appear on a consolidated balance sheet of the Borrower and its Consolidated Subsidiaries prepared in accordance with generally accepted accounting principles.

“Consolidated Indebtedness” means, at any date, with respect to the Borrower, all Indebtedness of the Borrower and its Consolidated Subsidiaries determined on a consolidated basis in accordance with generally accepted accounting principles; provided that Consolidated Indebtedness shall exclude, to the extent otherwise reflected therein, Equity Preferred Securities of the Borrower and its Consolidated Subsidiaries up to a maximum excluded amount equal to 15% of Consolidated Capitalization of the Borrower.

“Consolidated Net Assets” means, at any date with respect to the Borrower, (a) total assets of the Borrower and its Subsidiaries (minus applicable reserves) determined on a consolidated basis in accordance with GAAP minus (b) total liabilities of the Borrower and its Subsidiaries, in each case determined on a consolidated basis in accordance with GAAP, all as reflected in the consolidated financial statements of the Borrower most recently delivered to the Administrative Agent and the Lenders pursuant to Section 5.01(a) or 5.01(b).

4

“Consolidated Subsidiary” means, for any Person, at any date any Subsidiary or other entity the accounts of which would be consolidated with those of such Person in its consolidated financial statements if such statements were prepared as of such date.

“Default” means any condition or event which constitutes an Event of Default or which with the giving of notice or lapse of time or both would, unless cured or waived, become an Event of Default.

“Defaulting Lender” means any Lender that (a) has failed to (i) fund any portion of its Loans within two Domestic Business Days of the date required to be funded or (ii) pay over to any Lender Party any other amount required to be paid by it hereunder within two Domestic Business Days of the date required to be paid, unless, in the case of clause (i) or (ii) above, such Lender notifies the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) in writing that such failure is the result of such Lender’s good faith determination that a condition precedent to funding (specifically identified and including the particular default, if any) has not been satisfied, (b) has notified the Borrower or the Administrative Agent in writing, or has made a public statement to the effect, that it does not intend or expect to comply with any of its funding obligations under this Agreement (unless such writing or public statement indicates that such position is based on such Lender’s good faith determination that a condition precedent (specifically identified and including the particular default, if any) to funding under this Agreement cannot be satisfied) or generally under other agreements in which it commits to extend credit, (c) has failed, within three Domestic Business Days after written request by the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) or the Borrower, acting in good faith, to provide a certification in writing from an authorized officer of such Lender that it will comply with its obligations to fund prospective Loans under this Agreement unless such Lender notifies the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) in writing that such failure is the result of such Lender’s good faith determination that one or more conditions precedent to funding (specifically identified and including the particular default, if any) has not been satisfied, provided that such Lender shall cease to be a Defaulting Lender pursuant to this clause (c) upon receipt by the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) and the Borrower of such certification in form and substance satisfactory to the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) and the Borrower, or (d) has become (or has a direct or indirect Parent that has become) the subject of a Bankruptcy Event or a Bail-In Action. Any determination by the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) that a Lender is a Defaulting Lender shall be conclusive and binding absent manifest error, and such Lender shall be deemed to be a Defaulting Lender upon delivery of written notice of such determination to the Borrower and each Lender.

5

“Domestic Business Day” means any day except a Saturday, Sunday or other day on which commercial banks in New York City or in the State of North Carolina are authorized by law to close.

“Domestic Lending Office” means, as to each Lender, its office located at its address set forth in its Administrative Questionnaire (or identified in its Administrative Questionnaire as its Domestic Lending Office) or such other office as such Lender may hereafter designate as its Domestic Lending Office by notice to the Borrower and the Administrative Agent.

“EEA Financial Institution” means (a) any credit institution or investment firm established in any EEA Member Country which is subject to the supervision of an EEA Resolution Authority, (b) any entity established in an EEA Member Country which is a parent of an institution described in clause (a) of this definition, or (c) any financial institution established in an EEA Member Country which is a subsidiary of an institution described in clauses (a) or (b) of this definition and is subject to consolidated supervision with its parent;

“EEA Member Country” means any of the member states of the European Union, Iceland, Liechtenstein, and Norway.

“EEA Resolution Authority” means any public administrative authority or any person entrusted with public administrative authority of any EEA Member Country (including any delegee) having responsibility for the resolution of any EEA Financial Institution.

“Effective Date” means the date on which all the conditions precedent in Section 3.01 are satisfied or waived in accordance Section 9.05.

“Endowment” means the Duke Endowment, a charitable common law trust established by James B. Duke by Indenture dated December 11, 1924.

“Environmental Laws” means any and all federal, state, local and foreign statutes, laws, regulations, ordinances, rules, judgments, orders, decrees, permits, concessions, grants, franchises, licenses, agreements or other governmental restrictions relating to the environment or to emissions, discharges, releases of pollutants, contaminants, chemicals, or industrial, toxic or hazardous substances or wastes into the environment including, without limitation, ambient air, surface water, ground water, or land, or otherwise relating to the manufacture, processing, distribution, use, treatment, storage, disposal, transport, or handling of pollutants, contaminants, chemicals, or industrial, toxic or hazardous substances or wastes.

“Equity Preferred Securities” means, with respect to the Borrower, any trust preferred securities or deferrable interest subordinated debt securities issued by the Borrower or any Subsidiary or other financing vehicle of the Borrower that (i) have an original maturity of at least twenty years and (ii) require no repayments or prepayments

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and no mandatory redemptions or repurchases, in each case, prior to the first anniversary of the Maturity Date.

“ERISA” means the Employee Retirement Income Security Act of 1974, as amended.

“ERISA Group” means, with respect to the Borrower, the Borrower and all other members of a controlled group of corporations and all trades or businesses (whether or not incorporated) under common control which, together with the Borrower, are treated as a single employer under Section 414 of the Internal Revenue Code.

“EU Bail-In Legislation Schedule” means the EU Bail-In Legislation Schedule published by the Loan Market Association (or any successor person), as in effect from time to time.

“Euro-Dollar Business Day” means any Domestic Business Day on which commercial banks are open for international business (including dealings in dollar deposits) in London.

“Euro‑Dollar Lending Office” means, as to each Lender, its office, branch or affiliate located at its address set forth in its Administrative Questionnaire (or identified in its Administrative Questionnaire as its Euro‑Dollar Lending Office) or such other office, branch or affiliate of such Lender as it may hereafter designate as its Euro‑Dollar Lending Office by notice to the Borrower and the Administrative Agent.

“Euro‑Dollar Loan” means (i) a Loan which bears interest at a Euro-Dollar Rate pursuant to the applicable Notice of Borrowing or Notice of Interest Rate Election or (ii) an overdue amount which was a Euro-Dollar Loan immediately before it became overdue.

“Euro-Dollar Rate” means a rate of interest determined pursuant to Section 2.06(b) on the basis of a London Interbank Offered Rateand if the Euro-Dollar Rate shall be less than zero, such rate shall be deemed zero for purposes of this Agreement.

“Euro‑Dollar Reserve Percentage” has the meaning set forth in Section 2.16.

“Event of Default” has the meaning set forth in Section 6.01.

“Existing Agent” has the meaning set forth in the recitals hereto.

“Existing Credit Agreement” has the meaning set forth in the recitals hereto.

“Existing Lenders” has the meaning set forth in the recitals hereto.

“Existing Loans” has the meaning set forth in the recitals hereto.

“FATCA” has the meaning set forth in Section 8.04(a).

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“Federal Funds Rate” means, for any day, the rate per annum (rounded upwards, if necessary, to the nearest 1/100th of 1%) equal to the weighted average of the rates on overnight Federal funds transactions with members of the Federal Reserve System, as published by the Federal Reserve Bank of New York on the Domestic Business Day next succeeding such day; provided that (i) if such day is not a Domestic Business Day, the Federal Funds Rate for such day shall be such rate on such transactions on the next preceding Domestic Business Day as so published on the next succeeding Domestic Business Day and (ii) if no such rate is so published on such next succeeding Domestic Business Day, the Federal Funds Rate for such day shall be the average rate quoted to The Bank of Tokyo-Mitsubishi UFJ, Ltd. on such day on such transactions as determined by the Administrative Agent.

“First Funding Date” means the first date after the Effective Date on which all the conditions precedent in Section 3.03 are satisfied or waived in accordance with Section 9.05 and the Loans (other than the Existing Loans deemed made as Loans hereunder on the Effective Date) are made to the Borrower pursuant to Section 2.01.

“Fund” means any Person (other than a natural Person) that is (or will be) engaged in making, purchasing, holding or otherwise investing in commercial loans and similar extensions of credit in the ordinary course of its business.

“Funding Date” means each of (a) the First Funding Date and (b) the Second Funding Date.

“Governmental Authority” means any international, foreign, federal, state, regional, county, local or other governmental or quasi-governmental authority.

“Group of Loans” means at any time a group of Loans consisting of (i) all Loans to the Borrower which are Base Rate Loans at such time or (ii) all Euro-Dollar Loans to the Borrower having the same Interest Period at such time; provided that, if a Loan of any particular Lender is converted to or made as a Base Rate Loan pursuant to Article 8, such Loan shall be included in the same Group or Groups of Loans from time to time as it would have been if it had not been so converted or made.

“Hedging Agreement” means for any Person, any and all agreements, devices or arrangements designed to protect such Person or any of its Subsidiaries from the fluctuations of interest rates, exchange rates applicable to such party’s assets, liabilities or exchange transactions, including, but not limited to, dollar-denominated or cross-currency interest rate exchange agreements, forward currency exchange agreements, interest rate cap or collar protection agreements, commodity swap agreements, forward rate currency or interest rate options, puts and warrants. Notwithstanding anything herein to the contrary, “Hedging Agreements” shall also include fixed-for-floating interest rate swap agreements and similar instruments.

“Indebtedness” of any Person means at any date, without duplication, (i) all obligations of such Person for borrowed money, (ii) all indebtedness of such Person for

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the deferred purchase price of property or services purchased (excluding current accounts payable incurred in the ordinary course of business), (iii) all indebtedness created or arising under any conditional sale or other title retention agreement with respect to property acquired, (iv) all indebtedness under leases which shall have been or should be, in accordance with generally accepted accounting principles, recorded as capital leases in respect of which such Person is liable as lessee, (v) the face amount of all outstanding letters of credit issued for the account of such Person (other than letters of credit relating to indebtedness included in Indebtedness of such Person pursuant to another clause of this definition) and, without duplication, the unreimbursed amount of all drafts drawn thereunder, (vi) indebtedness secured by any Lien on property or assets of such Person, whether or not assumed (but in any event not exceeding the fair market value of the property or asset), (vii) all direct guarantees of Indebtedness referred to above of another Person, (viii) all amounts payable in connection with mandatory redemptions or repurchases of preferred stock or member interests or other preferred or priority equity interests and (ix) any obligations of such Person (in the nature of principal or interest) in respect of acceptances or similar obligations issued or created for the account of such Person.

“Indemnitee” has the meaning set forth in Section 9.03.

“Interest Period” means, with respect to each Euro-Dollar Loan, the period commencing on the date of borrowing specified in the applicable Notice of Borrowing or on the date specified in an applicable Notice of Interest Rate Election and ending one, two, three or six months thereafter, as the Borrower may elect in such notice; provided that:

(a)    any Interest Period which would otherwise end on a day which is not a Euro‑Dollar Business Day shall be extended to the next succeeding Euro‑Dollar Business Day unless such Euro‑Dollar Business Day falls in another calendar month, in which case such Interest Period shall end on the next preceding Euro‑Dollar Business Day; and

(b)    any Interest Period which begins on the last Euro‑Dollar Business Day of a calendar month (or on a day for which there is no numerically corresponding day in the calendar month at the end of such Interest Period) shall end on the last Euro‑Dollar Business Day of a calendar month;

providedfurther that no Interest Period applicable to any Loan of any Lender may end after the Maturity Date.

“Internal Revenue Code” means the Internal Revenue Code of 1986, as amended, or any successor statute.

“Investment Grade Status” exists as to any Person at any date if all senior long-term unsecured debt securities of such Person outstanding at such date which had been rated by S&P or Moody’s are rated BBB‑ or higher by S&P or Baa3 or higher by

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Moody’s, as the case may be, or if such Person does not have a rating of its long-term unsecured debt securities, then if the corporate credit rating of such Person, if any exists, from S&P is BBB- or higher or the issuer rating of such Person, if any exists, from Moody’s is Baa3 or higher.

“Irregular Interest Period” means any Interest Period with a duration other than one, two, three or six months.

“Lender” means each bank or other financial institution listed on the signature pages hereof, each Assignee which becomes a Lender pursuant to Section 8.06 or Section 9.06(c), and their respective successors.

“Lender Party” means any of the Lenders and the Administrative Agent.

“LIBOR Market Index Rate” means, for any day, the rate for one month U.S. dollar deposits as appears on the display designated as Reuters Screen LIBOR01 Page (or on any successor or substitute page of such service or any successor to or, if such service is not available, substitute for such service providing rate quotations comparable to those currently provided on such page of such service, as reasonably determined by the Administrative Agent from time to time for purposes of providing quotations of interest rates applicable to U.S. dollar deposits are offered to leading banks in the London interbank deposit market), approximately 11:00 a.m. London time, for such day; or if such day is not a Euro-Dollar Business Day, for the immediately preceding Euro-Dollar Business Day (or if not so reported, then as determined by the Administrative Agent from another recognized source or interbank quotation.)

“Lien” means, with respect to any asset, any mortgage, lien, pledge, charge, security interest or encumbrance of any kind in respect of such asset. For the purposes of this Agreement, the Borrower or any of its Subsidiaries shall be deemed to own subject to a Lien any asset which it has acquired or holds subject to the interest of a vendor or lessor under any conditional sale agreement, capital lease or other title retention agreement relating to such asset.

“Loan” means a loan made or to be made by a Lender pursuant to Section 2.01; provided that, if any such loan or loans (or portions thereof) are combined or subdivided pursuant to a Notice of Interest Rate Election, the term “Loan” shall refer to the combined principal amount resulting from such combination or to each of the separate principal amounts resulting from such subdivision, as the case may be.

“London Interbank Offered Rate” has the meaning set forth in Section 2.06(b).

“Master Credit Facility” means the Credit Agreement dated as of November 18, 2011, as amended by Amendment No. 1 and Consent dated as of December 18, 2013 and Amendment No. 2 and Consent, dated as of January 30, 2015, among the Borrower, the other borrowers thereto, the lenders party thereto, Wells Fargo Bank, National Association, as administrative agent, and the other agents party thereto, as the same may

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be amended, amended and restated, modified, supplemented, refinanced or replaced from time to time after the date hereof.

“Material Debt” means, with respect to the Borrower, Indebtedness of the Borrower or any of its Material Subsidiaries (other than any Non-Recourse Indebtedness) in an aggregate principal amount exceeding $150,000,000.

“Material Plan” has the meaning set forth in Section 6.01(i).

“Material Subsidiary” means at any time, with respect to the Borrower, any Subsidiary of the Borrower whose total assets exceeds 15% of the total assets (after intercompany eliminations) of the Borrower and its Subsidiaries, determined on a consolidated basis in accordance with GAAP, all as reflected in the consolidated financial statements of the Borrower most recently delivered to the Administrative Agent and the Lenders pursuant to Section 5.01(a) or 5.01(b).

“Maturity Date” means the date that is 364 calendar days following the Effective Date or, if such day is not a Domestic Business Day, the immediately preceding Domestic Business Day.

“Moody’s” means Moody’s Investors Service, Inc.

“Non-Consenting Lender” means any Lender that does not approve any consent, waiver or amendment that (i) requires the approval of all affected Lenders in accordance with the terms of Section 9.05(a) and (ii) has been approved by the Required Lenders.

“Non-Recourse Indebtedness” means any Indebtedness incurred by a Subsidiary of the Borrower to develop, construct, own, improve or operate a defined facility or project  (a) as to which the Borrower (i) does not provide credit support of any kind (including any undertaking, agreement or instrument that would constitute Indebtedness but excluding tax sharing arrangements and similar arrangements to make contributions to such Subsidiary to account for tax benefits generated by such Subsidiary), (ii) is not directly or indirectly liable as a guarantor or otherwise, or (iii) does not constitute the lender; (b) no default with respect to which would permit upon notice, lapse of time or both any holder of any other Indebtedness (other than the Loans or the Notes) of the Borrower to declare a default on such other Indebtedness or cause the payment thereof to be accelerated or payable prior to its stated maturity; and (c) as to which the lenders will not have any recourse to the stock or assets of the Borrower or other Subsidiary (other than the stock of or intercompany loans to such Subsidiary); provided that in each case in clauses (a) and (c) above, the Borrower or other Subsidiary may provide credit support and recourse in an amount not exceeding 15% in the aggregate of any such Indebtedness.

“Notes” means promissory notes of the Borrower, in the form required by Section 2.04, evidencing the obligation of the Borrower to repay the Loans made to it, and “Note” means any one of such promissory notes issued hereunder.

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“Notice of Borrowing” has the meaning set forth in Section 2.02.

“Notice of Interest Rate Election” has the meaning set forth in Section 2.09(b).

“OFAC” means the Office of Foreign Assets Control of the United States Department of the Treasury.

“Other Taxes” has the meaning set forth in Section 8.04(a).

“Parent” means, with respect to any Lender, any Person controlling such Lender.

“Participant” has the meaning set forth in Section 9.06(b).

“Participant Register” has the meaning set forth in Section 9.06(b).

“PBGC” means the Pension Benefit Guaranty Corporation or any entity succeeding to any or all of its functions under ERISA.

“Percentage” means, with respect to any Lender at any time, the percentage which the amount of its Commitment at such time represents of the aggregate amount of all the Commitments at such time; provided that in the case of Section 2.19 when a Defaulting Lender shall exist, “Percentage” shall mean the percentage of the total Commitments (disregarding any Defaulting Lender’s Commitment) represented by such Lender’s Commitment.

“Person” means an individual, a corporation, a partnership, an association, a trust or any other entity or organization, including a government or political subdivision or an agency or instrumentality thereof.

“Plan” means at any time an employee pension benefit plan which is covered by Title IV of ERISA or Sections 412 or 430 of the Internal Revenue Code or Sections 302 and 303 of ERISA and is either (i) maintained by a member of the ERISA Group for employees of a member of the ERISA Group or (ii) maintained pursuant to a collective bargaining agreement or any other arrangement under which more than one employer makes contributions and to which a member of the ERISA Group is then making or accruing an obligation to make contributions or has within the preceding five plan years made contributions.

“Pricing Schedule” means the Pricing Schedule attached hereto.

“Prime Rate” means the per annum rate of interest established from time to time by the Administrative Agent at its principal office in New York, New York as its Prime Rate. Any change in the interest rate resulting from a change in the Prime Rate shall become effective as of 12:01 a.m. of the Domestic Business Day on which each change in the Prime Rate is announced by the Administrative Agent. The Prime Rate is a reference rate used by the Administrative Agent in determining interest rates on certain loans and is

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not intended to be the lowest rate of interest charged on any extension of credit to any debtor.

“Quarterly Payment Date” means the first Domestic Business Day of each January, April, July and October.

“Regulation U” means Regulation U of the Board of Governors of the Federal Reserve System, as in effect from time to time.

“Related Parties” means, with respect to any Person, such Person’s Subsidiaries and Affiliates and the partners, directors, officers, employees, agents, trustees, administrators and managers of such Person and of such Person’s Subsidiaries and Affiliates.

“Required Lenders” means, at any time, two or more Lenders having at least 51% in aggregate amount of (a) prior to the First Funding Date, the Commitments or (b) from and after the First Funding Date, the sum of the unfunded Commitments and the outstanding Loans (excluding the Commitment(s) and the Loan(s) of any Defaulting Lender(s)).

“Sanctioned Person” means, at any time (a) any Person listed in any Sanctions-related list of specially designated Persons maintained by OFAC, the U.S. Department of State, United Nations Security Council, the European Union or Her Majesty’s Treasury of the United Kingdom, (b) any Person that has a place of business, or is organized or resident, in a jurisdiction that is the subject of any comprehensive territorial Sanctions or (c) any Person owned or controlled by any such Person.

“Sanctions” means economic or financial sanctions or trade embargoes imposed, administered or enforced from time to time by (a) OFAC or the U.S. Department of State, or (b) the United Nations Security Council, the European Union or Her Majesty’s Treasury of the United Kingdom.

“Second Funding Date” means the second date (if any) after the Effective Date on which all the conditions precedent in Section 3.03 are satisfied or waived in accordance with Section 9.05 and the Loans are made to the Borrower pursuant to Section 2.01.

“S&P” means Standard & Poor’s Financial Services LLC, a subsidiary of S&P Global Inc., and any successor thereto.

“Subsidiary” means, as to any Person, any corporation or other entity of which securities or other ownership interests having ordinary voting power to elect a majority of the board of directors or other persons performing similar functions are at the time directly or indirectly owned by such Person; unless otherwise specified, “Subsidiary” means a Subsidiary of the Borrower.

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“Substantial Assets” means, with respect to the Borrower, assets sold or otherwise disposed of in a single transaction or a series of related transactions representing 25% or more of the consolidated assets of the Borrower and its Consolidated Subsidiaries, taken as a whole.

“Taxes” has the meaning set forth in Section 8.04(a).

“Ticking Fee” has the meaning set forth in Section 2.07.

“Ticking Fee End Date” has the meaning set forth in Section 2.07.

“Trust” means The Doris Duke Trust, a trust established by James B. Duke by Indenture dated December 11, 1924 for the benefit of certain relatives.

“Unfunded Vested Liabilities” means, with respect to any Plan at any time, the amount (if any) by which (i) the present value of all benefits under such Plan, determined on a plan termination basis using the assumptions under 4001(a)(18) of ERISA, exceeds (ii) the fair market value of all Plan assets allocable to such benefits, all determined as of the then most recent valuation date for such Plan, but only to the extent that such excess represents a potential liability of a member of the ERISA Group to the PBGC or the Plan under Title IV of ERISA.

“United States” means the United States of America, including the States and the District of Columbia, but excluding its territories and possessions.

“U.S. Tax Compliance Certificate” has the meaning set forth in Section 8.04(d)(iii).

“U.S. Tax Law Change” has the meaning set forth in Section 8.04(a).

“Write-Down and Conversion Powers” means, with respect to any EEA Resolution Authority, the write-down and conversion powers of such EEA Resolution Authority from time to time under the Bail-In Legislation for the applicable EEA Member Country, which write-down and conversion powers are described in the EU Bail-In Legislation Schedule.

Section 1.02.Accounting Terms and Determinations. Unless otherwise specified herein, all accounting terms used herein shall be interpreted, all accounting determinations hereunder shall be made, and all financial statements required to be delivered hereunder shall be prepared in accordance with generally accepted accounting principles as in effect from time to time, applied on a basis consistent (except for changes concurred in by the Borrower’s independent public accountants) with the most recent audited consolidated financial statements of the Borrower and its Consolidated Subsidiaries delivered to the Lenders; provided, that if the Borrower notifies the Administrative Agent that it wishes to amend the financial covenant in Section 5.10 to eliminate the effect of any change in generally accepted accounting principles on the

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operation of such covenant (or if the Administrative Agent notifies the Borrower that the Required Lenders wish to amend Section 5.10 for such purpose), then the Borrower’s compliance with such covenant shall be determined on the basis of generally accepted accounting principles as in effect immediately before the relevant change in generally accepted accounting principles became effective, until either such notice is withdrawn or such covenant is amended in a manner satisfactory to the Borrower and the Required Lenders.

Section 1.03.Types of Borrowings. Borrowings are classified for purposes of this Agreement by reference to the pricing of Loans comprising such Borrowing (e.g., a “Euro-Dollar Borrowing” is a Borrowing comprised of Euro Dollar Loans).

ARTICLE 2
THE CREDIT

Section 2.01.Commitments to Lend; Treatment of Existing Loans. (a) Each Lender severally agrees, on the terms and conditions set forth in this Agreement, to make Loans to the Borrower pursuant to this subsection not to exceed in the aggregate such Lender’s Commitment in up to two drawings. Each Borrowing shall be made from the several Lenders ratably in proportion to their respective Commitments in effect on the date of such Borrowing. Amounts borrowed under this Section 2.01 and repaid or prepaid may not be reborrowed. Each Lender’s Commitment shall be permanently reduced by the amount of the Loans funded by such Lender on the date of such Borrowing. Each Lender’s Commitment shall terminate immediately and without further action upon the earlier of (x) the Second Funding Date after giving effect to the funding of such Lender’s Loans on such date and (y) the Commitment Termination Date.

(b)    On the Effective Date, without any further action by any party hereto and without any requirement for a Notice of Borrowing to be delivered pursuant to Section 2.02:

(i)     the Existing Loans will be deemed to (x) be Loans made under this Agreement on the Effective Date, (y) have utilized the Commitment of each Lender under this Agreement by the amount of such Lender’s pro rata share (based on its Percentage) of the aggregate principal amount of the Existing Loans and (z) be Loans comprising a Euro-Dollar Borrowing with an initial Interest Period of one month.

(ii)     (w) to the extent any Lender’s Loan deemed made pursuant Section 2.01(b)(i) exceeds its Existing Loan, such Lender shall pay an amount equal to the principal amount of such excess by wire transfer of immediately available funds to the Administrative Agent not later than 12:00 Noon (New York City time), (x) the Borrower shall pay all unpaid interest and fees and other amounts accrued under the Existing Credit Agreement to but excluding the Effective Date for the account of each Existing Lender in respect of such Existing Lender’s Existing Loans by wire transfer of immediately available funds to the Administrative Agent not later than 12:00 Noon (New York City time), (y) to the extent any Lender’s Loan deemed made pursuant Section 2.01(b)(i) is

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less than its Existing Loan, the Administrative Agent shall pay to such Lender, out of the amounts received by the Administrative Agent pursuant to clause (w) of this Section 2.01(b)(ii), an amount equal to the principal amount of such reduction by wire transfer of immediately available funds to the account designated by such Existing Lender to the Administrative Agent not later than 5:00 p.m. (New York City time) on the Effective Date, and (z) the Administrative Agent shall pay to each Existing Lender, out of the amounts received by the Administrative Agent pursuant to clause (x) of this Section 2.01(b)(ii), all unpaid interest and fees and other amounts accrued under the Existing Credit Agreement for the account of each Existing Lender in respect of such Existing Lender’s Existing Loans to but excluding the Effective Date by wire transfer of immediately available funds to the account designated by such Existing Lender to the Administrative Agent not later than 5:00 p.m. (New York City time) on the Effective Date. Notwithstanding the foregoing, each Lender hereby waives any right to reimbursement from the Borrower of any funding losses incurred by such Lender as a result of the Existing Loans being deemed made hereunder as Euro-Dollar Loans for new Interest Period on a day other than the last day of the Interest Period then in effect under the Existing Credit Agreement.

(c)     The Lenders that are parties to the Existing Credit Agreement hereby waive any requirement of prior notice of prepayment under the Existing Credit Agreement of Existing Loans.

Section 2.02.Notice of Borrowings. Except as provided in Section 2.01(b), the Borrower shall give the Administrative Agent notice (a “Notice of Borrowing”) not later than 11:00 A.M. (Eastern time) on (x) the date of each Base Rate Borrowing and (y) the third Euro‑Dollar Business Day before each Euro‑Dollar Borrowing, specifying:

(a)the date of the Borrowing, which shall be a Domestic Business Day in the case of a Base Rate Borrowing or a Euro‑Dollar Business Day in the case of a Euro‑Dollar Borrowing;

(b)the aggregate amount of the Borrowing which shall not exceed the aggregate amount of the Commitments on the date of the Borrowing specified ;

(c)whether the Loans comprising the Borrowing are to bear interest initially at the Base Rate or a Euro-Dollar Rate; and

(d)in the case of a Euro-Dollar Borrowing, the duration of the initial Interest Period applicable thereto, subject to the provisions of the definition of Interest Period.

Section 2.03.Notice to Lenders; Funding of Loans. (a)Upon receipt (or deemed receipt) of a Notice of Borrowing, the Administrative Agent shall promptly notify each Lender of the contents thereof and of such Lender’s share (if any) of a Borrowing and such Notice of Borrowing shall not thereafter be revocable by the Borrower.

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(b)Not later than 1:00 P.M. (Eastern time) on the date of a Borrowing, each Lender participating therein shall (except as provided in subsection (c) of this Section) make available its share of the Borrowing, in Federal or other immediately available funds, to the Administrative Agent at its address specified in or pursuant to Section 9.01. Unless the Administrative Agent determines that any applicable condition specified in Section 3.03 has not been satisfied, the Administrative Agent will disburse the funds so received from the Lenders to an account designated by an Approved Officer of the Borrower.

(c)Unless the Administrative Agent shall have received notice from a Lender prior to 1:00 P.M. (Eastern time) on the date of a Borrowing that such Lender will not make available to the Administrative Agent such Lender’s share of the Borrowing, the Administrative Agent may assume that such Lender has made such share available to the Administrative Agent on the date of such Borrowing in accordance with subsection (b) of this Section 2.03 and the Administrative Agent may, in reliance upon such assumption, make available to the Borrower on such date a corresponding amount. If and to the extent that such Lender shall not have so made such share available to the Administrative Agent, such Lender and, if such Lender shall not have made such payment within two Domestic Business Days of demand therefor, the Borrower agrees to repay to the Administrative Agent forthwith on demand such corresponding amount together with interest thereon, for each day from the date such amount is made available to the Borrower until the date such amount is repaid to the Administrative Agent, at (i) in the case of the Borrower, a rate per annum equal to the higher of the Federal Funds Rate and the interest rate applicable thereto pursuant to Section 2.06 and (ii) in the case of such Lender, the Federal Funds Rate. If such Lender shall repay to the Administrative Agent such corresponding amount, such amount so repaid shall constitute such Lender’s Loan included in the Borrowing for purposes of this Agreement.

(d)The failure of any Lender to make a Loan to be made by it as part of a Borrowing shall not relieve any other Lender of its obligation, if any, hereunder to make a Loan on the date of such Borrowing, but no Lender shall be responsible for the failure of any other Lender to make a Loan to be made by such other Lender.

Section 2.04.Registry; Notes. (a) The Administrative Agent shall maintain a register (the “Register”) on which it will record the Commitment of each Lender, each Loan made by such Lender and each repayment of any Loan made by such Lender. Any such recordation by the Administrative Agent on the Register shall be conclusive, absent manifest error. Failure to make any such recordation, or any error in such recordation, shall not affect the Borrower’s obligations hereunder.

(b)The Borrower hereby agrees that, promptly upon the request of any Lender at any time, the Borrower shall deliver to such Lender a duly executed Note, in substantially the form of Exhibit A hereto, payable to such Lender or its registered assigns as permitted pursuant to Section 9.06 and representing the obligation of the Borrower to pay the unpaid principal amount of the Loans made to the Borrower by such

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Lender, with interest as provided herein on the unpaid principal amount from time to time outstanding.

(c)Each Lender shall record the date, amount and maturity of each Loan made by it and the date and amount of each payment of principal made by the Borrower with respect thereto, and each Lender receiving a Note pursuant to this Section, if such Lender so elects in connection with any transfer or enforcement of its Note, may endorse on the schedule forming a part thereof appropriate notations to evidence the foregoing information with respect to each such Loan then outstanding; provided that the failure of such Lender to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Notes. Such Lender is hereby irrevocably authorized by the Borrower so to endorse its Note and to attach to and make a part of its Note a continuation of any such schedule as and when required.

Section 2.05.Maturity of Loans. Each Loan made by any Lender shall mature, and the principal amount thereof shall be due and payable together with accrued interest thereon, on the Maturity Date.

Section 2.06.Interest Rates. (a) Each Base Rate Loan shall bear interest on the outstanding principal amount thereof, for each day from the date such Loan is made until it becomes due, at a rate per annum equal to the Base Rate for such day. Such interest shall be payable quarterly in arrears on each Quarterly Payment Date and at maturity. Any overdue principal of or overdue interest on any Base Rate Loan shall bear interest, payable on demand, for each day until paid at a rate per annum equal to the sum of 1% plus the Base Rate for such day.

(b)Each Euro‑Dollar Loan shall bear interest on the outstanding principal amount thereof, for each day during each Interest Period applicable thereto, at a rate per annum equal to the sum of the Applicable Margin for such day plus the London Interbank Offered Rate applicable to such Interest Period. Such interest shall be payable for each Interest Period on the last day thereof and, if such Interest Period is longer than three months, at intervals of three months after the first day thereof.

The “London Interbank Offered Rate” applicable to any Interest Period means the rate appearing on Reuters Screen LIBOR01 Page (or on any successor or substitute page of such service, or any successor to or, if such service is not available, substitute for such service providing rate quotations comparable to those currently provided on such page of such service, as determined by the Administrative Agent from time to time for purposes of providing quotations of interest rates applicable to U.S. dollar deposits that are offered to leading banks in the London interbank deposit market) at approximately 11:00 A.M. (London time) two Euro-Dollar Business Days prior to the commencement of such Interest Period, as the rate for U.S. dollar deposits with a maturity comparable to such Interest Period. In the event that such rate is not so available at such time for any reason, then the “London Interbank Offered Rate” for such Interest Period shall be the average (rounded upward, if necessary, to the next higher 1/16 of 1%) of the respective rates per annum at which deposits in U.S. dollars are offered to leading banks in the

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London interbank market at approximately 11:00 A.M. (London time) two Euro-Dollar Business Days before the first day of such Interest Period in an amount approximately equal to the principal amount of the Loan of such leading banks to which such Interest Period is to apply and for a period of time comparable to such Interest Period.

(c)Any overdue principal of or overdue interest on any Euro‑Dollar Loan shall bear interest, payable on demand, for each day from and including the date payment thereof was due to but excluding the date of actual payment, at a rate per annum equal to the sum of 1% plus the higher of (i) the sum of the Applicable Margin for such day plus the London Interbank Offered Rate applicable to such Loan at the date such payment was due and (ii) the rate applicable to Base Rate Loans for such day.

(d)The Administrative Agent shall determine each interest rate applicable to the Loans hereunder. The Administrative Agent shall give prompt notice to the Borrower and the participating Lenders by facsimile of each rate of interest so determined, and its determination thereof shall be conclusive in the absence of manifest error unless the Borrower raises an objection thereto within five Domestic Business Days after receipt of such notice.

Section 2.07.Ticking Fee. The Borrower agrees to pay to the Administrative Agent for the account of each Lender a ticking fee (the “Ticking Fee”) in an amount equal to 0.15% per annum, accruing on the daily average of the unfunded Commitment of such Lender then outstanding, accruing from and including the Effective Date, to but excluding the earlier of (i) the termination of the Commitments with respect to this Agreement and (ii) the Second Funding Date (such earlier date, the “Ticking Fee End Date”); provided that (A) no Ticking Fee shall accrue on the Commitment of a Defaulting Lender so long as such Lender shall be a Defaulting Lender and (B) any Ticking Fee accrued with respect to the Commitment of a Defaulting Lender during the period prior to the time such Lender became a Defaulting Lender and unpaid at such time shall not be payable by the Borrower so long as such Lender shall be a Defaulting Lender.  The Ticking Fee shall be payable on the Ticking Fee End Date.

Section 2.08.[Reserved].

Section 2.09.Method of Electing Interest Rates. (a) The Loans included in each Borrowing shall bear interest initially at the type of rate specified by the Borrower in the Notice of Borrowing. Thereafter, the Borrower may from time to time elect to change or continue the type of interest rate borne by each Group of Loans (subject in each case to the provisions of Article 8 and the last sentence of this subsection (a)), as follows:

(i)if such Loans are Base Rate Loans, the Borrower may elect to convert such Loans to Euro‑Dollar Loans as of any Euro‑Dollar Business Day; and

(ii)if such Loans are Euro‑Dollar Loans, the Borrower may elect to convert such Loans to Base Rate Loans or elect to continue such Loans as

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Euro‑Dollar Loans for an additional Interest Period, subject to Section 2.13 in the case of any such conversion or continuation effective on any day other than the last day of the then current Interest Period applicable to such Loans.

Each such election shall be made by delivering a notice (a “Notice of Interest Rate Election”) to the Administrative Agent not later than 11:00 A.M. (Eastern time) on the third Euro‑Dollar Business Day before the conversion or continuation selected in such notice is to be effective. A Notice of Interest Rate Election may, if it so specifies, apply to only a portion of the aggregate principal amount of the relevant Group of Loans; provided that (i) such portion is allocated ratably among the Loans comprising such Group and (ii) the portion to which such notice applies, and the remaining portion to which it does not apply, are each $10,000,000 or any larger multiple of $1,000,000.

(b)Each Notice of Interest Rate Election shall specify:

(i)the Group of Loans (or portion thereof) to which such notice applies;

(ii)the date on which the conversion or continuation selected in such notice is to be effective, which shall comply with the applicable clause of subsection 2.09(a) above;

(iii)if the Loans comprising such Group are to be converted, the new type of Loans and, if the Loans being converted are to be Euro-Dollar Loans, the duration of the next succeeding Interest Period applicable thereto; and

(iv)if such Loans are to be continued as Euro‑Dollar Loans for an additional Interest Period, the duration of such additional Interest Period.

Each Interest Period specified in a Notice of Interest Rate Election shall comply with the provisions of the definition of the term “Interest Period”.

Notwithstanding anything to the contrary provided herein, the Borrower may request Irregular Interest Periods (without premium or penalty) in order to consolidate outstanding Interest Periods. Upon receipt of a Notice of Interest Rate Election from the Borrower requesting such Irregular Interest Period, and solely in the event that all Lenders agree to provide such Irregular Interest Period, the Administrative Agent and Lenders shall provide the Borrower with such Irregular Interest Period; provided that if the applicable Irregular Interest Period is not available in the London interbank market, in the reasonable judgment of the Administrative Agent, the Administrative Agent shall set the applicable Euro-Dollar Rate for such Irregular Interest Period through interpolating the available London Interbank Offered Rate for periods having terms ending immediately prior to and immediately following such Irregular Interest Period (e.g., for a 75 day Interest Period, the Administrative Agent shall use the midpoint of a two month and three month London Interbank Offered Rate).

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(c)Promptly after receiving a Notice of Interest Rate Election from the Borrower pursuant to subsection 2.09(a) above, the Administrative Agent shall notify each Lender of the contents thereof and such notice shall not thereafter be revocable by the Borrower. If no Notice of Interest Rate Election is timely received prior to the end of an Interest Period for any Group of Loans, the Borrower shall be deemed to have elected that such Group of Loans be converted to Base Rate Loans as of the last day of such Interest Period.

(d)An election by the Borrower to change or continue the rate of interest applicable to any Group of Loans pursuant to this Section shall not constitute a “Borrowing” subject to the provisions of Section 3.03.

Section 2.10.[Reserved].

Section 2.11.Optional Prepayments. (a) The Borrower may (i) upon notice to the Administrative Agent not later than 11:00 A.M. (Eastern time) on any Domestic Business Day prepay on such Domestic Business Day any Group of Base Rate Loans and (ii) upon at least three Euro‑Dollar Business Days’ notice to the Administrative Agent not later than 11:00 A.M. (Eastern time) prepay any Group of Euro‑Dollar Loans, in each case in whole at any time, or from time to time in part in amounts aggregating $5,000,000 or any larger multiple of $1,000,000, by paying the principal amount to be prepaid together with accrued interest thereon to the date of prepayment and together with any additional amounts payable pursuant to Section 2.13. Each such optional prepayment shall be applied to prepay ratably the Loans of the several Lenders included in such Group or Borrowing.

(b)Upon receipt of a notice of prepayment pursuant to this Section, the Administrative Agent shall promptly notify each Lender of the contents thereof and of such Lender’s share (if any) of such prepayment and such notice shall not thereafter be revocable by the Borrower.

Section 2.12.General Provisions as to Payments. (a)The Borrower shall make each payment of principal of, and interest on, the Loans and of fees hereunder, not later than 1:00 P.M. (Eastern time) on the date when due, in Federal or other funds immediately available in New York City, to the Administrative Agent at its address referred to in Section 9.01 and without reduction by reason of any set-off, counterclaim or deduction of any kind. The Administrative Agent will promptly distribute to each Lender in like funds its ratable share of each such payment received by the Administrative Agent for the account of the Lenders. Whenever any payment of principal of, or interest on, the Base Rate Loans or of fees shall be due on a day which is not a Domestic Business Day, the date for payment thereof shall be extended to the next succeeding Domestic Business Day. Whenever any payment of principal of, or interest on, the Euro‑Dollar Loans shall be due on a day which is not a Euro‑Dollar Business Day, the date for payment thereof shall be extended to the next succeeding Euro‑Dollar Business Day unless such Euro‑Dollar Business Day falls in another calendar month, in which case the date for payment thereof shall be the next preceding Euro‑Dollar

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Business Day. If the date for any payment of principal is extended by operation of law or otherwise, interest thereon shall be payable for such extended time.

(b)Unless the Administrative Agent shall have received notice from the Borrower prior to the date on which any payment is due to the Lenders hereunder that the Borrower will not make such payment in full, the Administrative Agent may assume that the Borrower has made such payment in full to the Administrative Agent on such date and the Administrative Agent may, in reliance upon such assumption, cause to be distributed to each Lender on such due date an amount equal to the amount then due such Lender. If and to the extent that the Borrower shall not have so made such payment, each Lender shall repay to the Administrative Agent forthwith on demand such amount distributed to such Lender together with interest thereon, for each day from the date such amount is distributed to such Lender until the date such Lender repays such amount to the Administrative Agent, at the Federal Funds Rate.

Section 2.13.Funding Losses. If the Borrower makes any payment of principal with respect to any Euro-Dollar Loan (other than payments made by an Assignee pursuant to Section 8.06(a) or by the Borrower pursuant to Section 8.06(b) in respect of a Defaulting Lender’s Euro-Dollar Loans) (whether voluntary, mandatory, automatic, by reason of acceleration, or otherwise) or any Euro-Dollar Loan is converted to a Base Rate Loan or continued as a Euro-Dollar Loan for a new Interest Period (pursuant to Article 2, 6 or 8 or otherwise) on any day other than the last day of an Interest Period applicable thereto, or if the Borrower fails to borrow, prepay, convert or continue any Euro-Dollar Loans after notice has been given to any Lender in accordance with Section 2.03(a), 2.09(c) or 2.11(b), the Borrower shall reimburse each Lender within 15 days after demand for any resulting loss or expense incurred by it (or by an existing or prospective Participant in the related Loan), including (without limitation) any loss incurred in obtaining, liquidating or employing deposits from third parties, but excluding loss of margin for the period after any such payment or conversion or failure to borrow, prepay, convert or continue; provided that such Lender shall have delivered to the Borrower a certificate setting forth in reasonable detail the calculation of the amount of such loss or expense, which certificate shall be conclusive in the absence of manifest error.

Section 2.14.Computation of Interest and Fees. Interest based on clause (a) of the definition of Base Rate shall be computed on the basis of a year of 365 days (or 366 days in a leap year) and paid for the actual number of days elapsed (including the first day but excluding the last day). All other interest and all fees shall be computed on the basis of a year of 360 days and paid for the actual number of days elapsed (including the first day but excluding the last day).

Section 2.15.[Reserved].

Section 2.16.Regulation D Compensation. In the event that a Lender is required to maintain reserves of the type contemplated by the definition of “Euro‑Dollar Reserve Percentage”, such Lender may require the Borrower to pay, contemporaneously with each payment of interest on the Euro‑Dollar Loans, additional interest on the related

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Euro‑Dollar Loan of such Lender at a rate per annum determined by such Lender up to but not exceeding the excess of (i) (A) the applicable London Interbank Offered Rate divided by (B) one minus the Euro‑Dollar Reserve Percentage over (ii) the applicable London Interbank Offered Rate. Any Lender wishing to require payment of such additional interest (x) shall so notify the Borrower and the Administrative Agent, in which case such additional interest on the Euro‑Dollar Loans of such Lender shall be payable to such Lender at the place indicated in such notice with respect to each Interest Period commencing at least three Euro‑Dollar Business Days after the giving of such notice and (y) shall notify the Borrower at least three Euro‑Dollar Business Days prior to each date on which interest is payable on the Euro‑Dollar Loans of the amount then due it under this Section. Each such notification shall be accompanied by such information as the Borrower may reasonably request.

“Euro‑Dollar Reserve Percentage” means for any day, that percentage (expressed as a decimal) which is in effect on such day, as prescribed by the Board of Governors of the Federal Reserve System (or any successor) for determining the maximum reserve requirement for a member bank of the Federal Reserve System in New York City with deposits exceeding five billion dollars in respect of “Eurocurrency liabilities” (or in respect of any other category of liabilities which includes deposits by reference to which the interest rate on Euro‑Dollar Loans is determined or any category of extensions of credit or other assets which includes loans by a non‑United States office of any Lender to United States residents).

Section 2.17.[Reserved].

Section 2.18. [Reserved].

Section 2.19.Defaulting Lenders. If any Lender becomes a Defaulting Lender, then the following provisions shall apply for so long as such Lender is a Defaulting Lender, to the extent permitted by applicable law:

(a)[Reserved];

(b)[Reserved];

(c)any payment of principal, interest, fees or other amounts received by the Administrative Agent for the account of a Defaulting Lender (whether voluntary or mandatory, at maturity, pursuant to Article 6 or otherwise) shall be applied at such time or times as may be determined by the Administrative Agent as follows:

(i)first, to the payment of any amounts owing by such Defaulting Lender to the Administrative Agent hereunder;

(ii)second, as the Borrower may request (so long as no Default exists), to the funding of any Loan in respect of which such Defaulting Lender has failed

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to fund its portion thereof as required by this Agreement, as determined by the Administrative Agent;

(iii)third, if so determined by the Administrative Agent and the Borrower, to be held in a deposit account and released pro rata in order to satisfy such Defaulting Lender’s potential future funding obligations with respect to Loans under this Agreement;

(iv)fourth, to the payment of any amounts owing to the Lenders as a result of any judgment of a court of competent jurisdiction obtained by any Lender against such Defaulting Lender as a result of such Defaulting Lender’s breach of its obligations under this Agreement;

(v)fifth, so long as no Default exists, to the payment of any amounts owing to the Borrower as a result of any judgment of a court of competent jurisdiction obtained by the Borrower against such Defaulting Lender as a result of such Defaulting Lender’s breach of its obligations under this Agreement; and

(vi)sixth, to such Defaulting Lender or as otherwise directed by a court of competent jurisdiction; provided that if (x) such payment is a payment of the principal amount of any Loans in respect of which such Defaulting Lender has not fully funded its appropriate share, and (y) such Loans were made at a time when the conditions set forth in Section 3.03 were satisfied or waived, such payment shall be applied solely to pay the Loans of all non-Defaulting Lenders on a pro rata basis prior to being applied to the payment of any Loans of such Defaulting Lender until such time as all Loans are held by the Lenders pro rata in accordance with the Commitments.

Any payments, prepayments or other amounts paid or payable to a Defaulting Lender that are applied (or held) to pay amounts owed by a Defaulting Lender pursuant to this Section 2.19(c) shall be deemed paid to and redirected by such Defaulting Lender, and each Lender irrevocably consents hereto; and

(d)in the event that the Administrative Agent and the Borrower agree that a Defaulting Lender has adequately remedied all matters that caused such Lender to be a Defaulting Lender, on such date such Lender shall purchase at par such of the Loans of the other Lenders as the Administrative Agent shall determine may be necessary in order for such Lender to hold such Loans in accordance with its Percentage; provided, that no adjustments will be made retroactively with respect to fees accrued or payments made by or on behalf of the Borrower while such Lender was a Defaulting Lender; and provided, further, that except to the extent otherwise expressly agreed by the affected parties, no change hereunder from Defaulting Lender to Lender will constitute a waiver or release of any claim of any party hereunder arising from that Lender’s having been a Defaulting Lender.

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ARTICLE 3
CONDITIONS

Section 3.01.Effective Date. This Agreement shall become effective and the Existing Credit Agreement shall be amended and restated in its entirety as set forth in this Agreement on the date that each of the following conditions shall have been satisfied (or waived in accordance with Section 9.05(a)):

(a)receipt by the Administrative Agent of counterparts hereof signed by each of the parties hereto (or, in the case of any party as to which an executed counterpart shall not have been received, receipt by the Administrative Agent in form satisfactory to it of facsimile or other written confirmation from such party of execution of a counterpart hereof by such party);

(b)receipt by the Administrative Agent of (i) an opinion of internal counsel of the Borrower, substantially in the form of Exhibit B hereto and (ii) an opinion of Robinson, Bradshaw & Hinson, P.A., special counsel for the Borrower, substantially in the form of Exhibit C hereto, and, in each case, covering such additional matters relating to the transactions contemplated hereby as the Required Lenders may reasonably request;

(c)receipt by the Administrative Agent of a certificate signed by a Vice President, the Treasurer, an Assistant Treasurer or the Controller of the Borrower, dated the Effective Date, to the effect set forth in clauses (c) and (d) of Section 3.03 (without giving effect to the parenthetical in such clause (d));

(d)receipt by the Administrative Agent of all documents it may have reasonably requested prior to the date hereof relating to the existence of the Borrower, the corporate authority for and the validity of this Agreement and the Notes, and any other matters relevant hereto, all in form and substance satisfactory to the Administrative Agent; and

(e)receipt by the Administrative Agent of evidence satisfactory to it that the upfront fees, arrangement fees, administrative agency fees and expenses (including, for the avoidance of doubt, the amounts required to be paid pursuant to Section 2.01(b)(ii)) payable by the Borrower on the Effective Date have been paid;

provided that the Commitments shall not become effective unless all of the foregoing conditions are satisfied not later than August 31, 2016. The Administrative Agent shall promptly notify the Borrower and the Lenders of the Effective Date, and such notice shall be conclusive and binding on all parties hereto.

Section 3.02.[Reserved].

Section 3.03.Borrowings. The obligation of any Lender to make a Loan on any Funding Date (other than Existing Loans deemed to be Loans pursuant to Section 2.01(b)) to the Borrower is subject to the satisfaction of the following conditions:

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(a)receipt by the Administrative Agent of a Notice of Borrowing as required by Section 2.02;

(b)[Reserved];

(c)the fact that, immediately after such Borrowing, no Default with respect to the Borrower shall have occurred and be continuing; and

(d)the fact that the representations and warranties of the Borrower contained in this Agreement (except the representations and warranties set forth in Sections 4.04(c) and 4.06) shall be true on and as of the date of such Borrowing.

The Borrowing hereunder shall be deemed to be a representation and warranty by the Borrower on the date of the Borrowing or issuance as to the facts specified in clauses (c) and (d) of this Section.

ARTICLE 4
REPRESENTATIONS AND WARRANTIES

The Borrower represents and warrants that:

Section 4.01.Organization and Power. The Borrower is duly organized, validly existing and in good standing under the laws of the jurisdiction of its organization and has all requisite powers and all material governmental licenses, authorizations, consents and approvals required to carry on its business as now conducted and is duly qualified to do business in each jurisdiction where such qualification is required, except where the failure so to qualify would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole.

Section 4.02.Corporate and Governmental Authorization; No Contravention. The execution, delivery and performance by the Borrower of this Agreement and the Notes are within the Borrower’s powers, have been duly authorized by all necessary company action, require no action by or in respect of, or filing with, any Governmental Authority (except for consents, authorizations or filings which have been obtained or made, as the case may be, and are in full force and effect) and do not contravene, or constitute a default under, any provision of applicable law or regulation or of the articles of incorporation, by‑laws, certificate of formation or the limited liability company agreement of the Borrower or of any material agreement, judgment, injunction, order, decree or other instrument binding upon the Borrower or result in the creation or imposition of any Lien on any asset of the Borrower or any of its Material Subsidiaries.

Section 4.03.Binding Effect. This Agreement constitutes a valid and binding agreement of the Borrower and each Note, if and when executed and delivered by it in accordance with this Agreement, will constitute a valid and binding obligation of the Borrower, in each case enforceable in accordance with its terms, except as the same may

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be limited by bankruptcy, insolvency or similar laws affecting creditors’ rights generally and by general principles of equity.

Section 4.04.Financial Information. (a)The consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of December 31, 2015 and the related consolidated statements of income, cash flows, capitalization and retained earnings for the fiscal year then ended, reported on by Deloitte & Touche, copies of which have been delivered to each of the Lenders by using the Borrower’s Syndtrak site or otherwise made available, fairly present in all material respects, in conformity with generally accepted accounting principles, the consolidated financial position of the Borrower and its Consolidated Subsidiaries as of such date and their consolidated results of operations and cash flows for such fiscal year.

(b)The unaudited consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of March 31, 2016 and the related unaudited consolidated statements of income and cash flows for the nine months then ended, copies of which have been delivered to each of the Lenders by using the Borrower’s Syndtrak site or otherwise made available, fairly present in all material respects, in conformity with generally accepted accounting principles applied on a basis consistent with the financial statements referred to in subsection (a) of this Section, the consolidated financial position of the Borrower and its Consolidated Subsidiaries as of such date and their consolidated results of operations and changes in financial position for such nine-month period (subject to normal year‑end adjustments and the absence of footnotes).

(c)Since December 31, 2015, there has been no material adverse change in the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, except as publicly disclosed prior to the Effective Date.

Section 4.05.Regulation U. The Borrower and its Material Subsidiaries are not engaged in the business of extending credit for the purpose of purchasing or carrying margin stock (within the meaning of Regulation U issued by the Board of Governors of the Federal Reserve System) and no proceeds of the Borrowing by the Borrower will be used to purchase or carry any margin stock or to extend credit to others for the purpose of purchasing or carrying any margin stock. Not more than 25% of the value of the assets of the Borrower and its Material Subsidiaries is represented by margin stock.

Section 4.06.Litigation. Except as publicly disclosed prior to the Effective Date, there is no action, suit or proceeding pending against, or to the knowledge of the Borrower threatened against or affecting, the Borrower or any of its Subsidiaries before any court or arbitrator or any Governmental Authority which would be likely to be decided adversely to the Borrower or such Subsidiary and, as a result, have a material adverse effect upon the business, consolidated financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or which in any manner draws into question the validity of this Agreement or any Note.

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Section 4.07.Compliance with Laws. The Borrower and each of its Material Subsidiaries is in compliance in all material respects with all applicable laws, ordinances, rules, regulations and requirements of Governmental Authorities (including, without limitation, ERISA and Environmental Laws) except where (i) non-compliance would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) the necessity of compliance therewith is contested in good faith by appropriate proceedings.

Section 4.08.Taxes. The Borrower and its Material Subsidiaries have filed all United States federal income tax returns and all other material tax returns which are required to be filed by them and have paid all taxes due pursuant to such returns or pursuant to any assessment received by the Borrower or any such Material Subsidiary except (i) where nonpayment would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) where the same are contested in good faith by appropriate proceedings. The charges, accruals and reserves on the books of the Borrower and its Material Subsidiaries in respect of taxes or other governmental charges are, in the opinion of the Borrower, adequate.

Section 4.09.Anti-corruption Law and Sanctions. The Borrower and its Material Subsidiaries have implemented and maintain in effect policies and procedures designed to prevent violations by the Borrower, its Subsidiaries and their respective directors, officers, employees and agents (acting in their capacity as such) of the applicable Anti-Corruption Laws and Sanctions, and the Borrower and its Material Subsidiaries are in compliance in all material respects with all applicable Anti-Corruption Laws and Sanctions, except where (i) noncompliance would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) the necessity of compliance therewith is contested in good faith by appropriate proceedings. None of (i) the Borrower or any Material Subsidiary or, (ii) to the knowledge of the Borrower, any director, officer or employee of the Borrower or any Material Subsidiary or (iii) to the knowledge of the Borrower, any agent of the Borrower or any Material Subsidiary acting in any capacity in connection with or benefitting from the credit facility established hereby, is a Sanctioned Person.

ARTICLE 5
COVENANTS

The Borrower agrees that, so long as any Lender has any Commitment hereunder with respect to the Borrower or any amount payable hereunder remains unpaid by the Borrower:

Section 5.01.Information. The Borrower will deliver to each of the Lenders:

(a)as soon as available and in any event within 120 days after the end of each fiscal year of the Borrower, a consolidated balance sheet of the Borrower and its

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Consolidated Subsidiaries as of the end of such fiscal year and the related consolidated statements of income, cash flows, capitalization and retained earnings for such fiscal year, setting forth in each case in comparative form the figures for the previous fiscal year, all reported on in a manner consistent with past practice and with applicable requirements of the Securities and Exchange Commission by Deloitte & Touche or other independent public accountants of nationally recognized standing;

(b)as soon as available and in any event within 60 days after the end of each of the first three quarters of each fiscal year of the Borrower, a consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of the end of such quarter and the related consolidated statements of income and cash flows for such quarter and for the portion of the Borrower’s fiscal year ended at the end of such quarter, setting forth in each case in comparative form the figures for the corresponding quarter and the corresponding portion of the Borrower’s previous fiscal year, all certified (subject to normal year-end adjustments) as to fairness of presentation in all material respects, generally accepted accounting principles and consistency (except as provided by Section 1.02) by an Approved Officer of the Borrower;

(c)within the maximum time period specified for the delivery of each set of financial statements referred to in clauses (a) and (b) above, a certificate of an Approved Officer of the Borrower (i) setting forth in reasonable detail the calculations required to establish whether the Borrower was in compliance with the requirements of Section 5.10 on the date of such financial statements and (ii) stating whether any Default exists on the date of such certificate and, if any Default then exists, setting forth the details thereof and the action which the Borrower is taking or proposes to take with respect thereto;

(d)within five days after any officer of the Borrower with responsibility relating thereto obtains knowledge of any Default, if such Default is then continuing, a certificate of an Approved Officer of the Borrower setting forth the details thereof and the action which the Borrower is taking or proposes to take with respect thereto;

(e)promptly upon the filing thereof, copies of all registration statements (other than the exhibits thereto and any registration statements on Form S-8 or its equivalent) and reports on Forms 10-K, 10-Q and 8-K (or their equivalents) which the Borrower shall have filed with the Securities and Exchange Commission;

(f)if and when any member of the Borrower’s ERISA Group (i) gives or is reasonably expected to give notice to the PBGC of any “reportable event” (as defined in Section 4043 of ERISA) with respect to any Material Plan which might constitute grounds for a termination of such Plan under Title IV of ERISA, or knows that the plan administrator of any Material Plan has given or is required to give notice of any such reportable event, a copy of the notice of such reportable event given or required to be given to the PBGC; (ii) receives notice of complete or partial withdrawal liability under Title IV of ERISA or notice that any Material Plan is in reorganization, is insolvent or has been terminated, a copy of such notice; (iii) receives notice from the PBGC under Title IV of ERISA of an intent to terminate, impose material liability (other than for premiums

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under Section 4007 of ERISA) in respect of, or appoint a trustee to administer any Plan, a copy of such notice; (iv) applies for a waiver of the minimum funding standard under Section 412 of the Internal Revenue Code, a copy of such application; (v) gives notice of intent to terminate any Material Plan under Section 4041(c) of ERISA, a copy of such notice and other information filed with the PBGC; (vi) gives notice of withdrawal from any Material Plan pursuant to Section 4063 of ERISA, a copy of such notice; (vii) receives notice of the cessation of operations at a facility of any member of the ERISA Group in the circumstances described in Section 4062(e) of ERISA; or (viii) fails to make any payment or contribution to any Material Plan or makes any amendment to any Material Plan which has resulted or could result in the imposition of a Lien or the posting of a bond or other security, a certificate of the chief financial officer or the chief accounting officer of the Borrower setting forth details as to such occurrence and action, if any, which the Borrower or applicable member of the ERISA Group is required or proposes to take;

(g)promptly, notice of any change in the ratings of the Borrower referred to in the Pricing Schedule; and

(h)from time to time such additional information regarding the financial position or business of the Borrower and its Subsidiaries as the Administrative Agent, at the request of any Lender, may reasonably request.

Information required to be delivered pursuant to these Sections 5.01(a), 5.01(b) and 5.01(e) shall be deemed to have been delivered on the date on which such information has been posted on the Securities and Exchange Commission website on the Internet at sec.gov/edaux/searches.htm, on the Borrower’s Syndtrak site or at another website identified in a notice from the Borrower to the Lenders and accessible by the Lenders without charge; provided that (i) a certificate delivered pursuant to Section 5.01(c) shall also be deemed to have been delivered upon being posted to the Borrower’s Syndtrak site and (ii) the Borrower shall deliver paper copies of the information referred to in Sections 5.01(a), 5.01(b) and 5.01(e) to any Lender which requests such delivery.

Section 5.02.Payment of Taxes. The Borrower will pay and discharge, and will cause each of its Material Subsidiaries to pay and discharge, at or before maturity, all their tax liabilities, except where (i) nonpayment would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) the same may be contested in good faith by appropriate proceedings, and will maintain, and will cause each of its Material Subsidiaries to maintain, in accordance with generally accepted accounting principles, appropriate reserves for the accrual of any of the same.

Section 5.03.Maintenance of Property; Insurance. (a)The Borrower will keep, and will cause each of its Material Subsidiaries to keep, all property necessary in its business in good working order and condition, ordinary wear and tear excepted, except where the failure to do so would not have a material adverse effect on the business,

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financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole.

(b)The Borrower will, and will cause each of its Material Subsidiaries to, maintain (either in the name of the Borrower or in such Subsidiary’s own name) with financially sound and responsible insurance companies, insurance on all their respective properties in at least such amounts and against at least such risks (and with such risk retention) as are usually insured against by companies of established repute engaged in the same or a similar business; provided that self‑insurance by the Borrower or any such Material Subsidiary, shall not be deemed a violation of this covenant to the extent that companies engaged in similar businesses and owning similar properties self‑insure; and will furnish to the Lenders, upon request from the Administrative Agent, information presented in reasonable detail as to the insurance so carried.

Section 5.04.Maintenance of Existence. The Borrower will preserve, renew and keep in full force and effect, and will cause each of its Material Subsidiaries to preserve, renew and keep in full force and effect their respective corporate or other legal existence and their respective rights, privileges and franchises material to the normal conduct of their respective businesses; provided that nothing in this Section 5.04 shall prohibit the termination of any right, privilege or franchise of the Borrower or any such Material Subsidiary or of the corporate or other legal existence of any such Material Subsidiary, or the change in form of organization of the Borrower or any such Material Subsidiary, if the Borrower in good faith determines that such termination or change is in the best interest of the Borrower, is not materially disadvantageous to the Lenders and, in the case of a change in the form of organization of the Borrower, the Administrative Agent has consented thereto.

Section 5.05.Compliance with Laws. The Borrower will comply, and cause each of its Material Subsidiaries to comply, in all material respects with all applicable laws, ordinances, rules, regulations, and requirements of Governmental Authorities (including, without limitation, ERISA, applicable Sanctions and Anti-Corruption Laws and Environmental Laws) except where (i) noncompliance would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) the necessity of compliance therewith is contested in good faith by appropriate proceedings.

Section 5.06.Books and Records. The Borrower will keep, and will cause each of its Material Subsidiaries to keep, proper books of record and account in which full, true and correct entries shall be made of all financial transactions in relation to its business and activities in accordance with its customary practices; and will permit, and will cause each such Material Subsidiary to permit, representatives of any Lender at such Lender’s expense (accompanied by a representative of the Borrower, if the Borrower so desires) to visit any of their respective properties, to examine any of their respective books and records and to discuss their respective affairs, finances and accounts with their

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respective officers, employees and independent public accountants, all upon such reasonable notice, at such reasonable times and as often as may reasonably be desired.

Section 5.07.Negative Pledge. The Borrower will not create, assume or suffer to exist any Lien on any asset now owned or hereafter acquired by it, except:

(a)Liens granted by the Borrower existing as of the Effective Date, securing Indebtedness outstanding on the date of this Agreement in an aggregate principal amount not exceeding $100,000,000;

(b)[Reserved];

(c)any Lien on any asset of any Person existing at the time such Person is merged or consolidated with or into the Borrower and not created in contemplation of such event;

(d)any Lien existing on any asset prior to the acquisition thereof by the Borrower and not created in contemplation of such acquisition;

(e)any Lien on any asset securing Indebtedness incurred or assumed for the purpose of financing all or any part of the cost of acquiring such asset; provided that such Lien attaches to such asset concurrently with or within 180 days after the acquisition thereof;

(f)any Lien arising out of the refinancing, extension, renewal or refunding of any Indebtedness secured by any Lien permitted by any of the foregoing clauses of this Section; provided that such Indebtedness is not increased (except by accrued interest, prepayment premiums and fees and expenses incurred in connection with such refinancing, extension, renewal or refunding) and is not secured by any additional assets;

(g)Liens for taxes, assessments or other governmental charges or levies not yet due or which are being contested in good faith by appropriate proceedings and with respect to which adequate reserves or other appropriate provisions are being maintained in accordance with generally accepted accounting principles;

(h)statutory Liens of landlords and Liens of carriers, warehousemen, mechanics, materialmen and other Liens imposed by law, created in the ordinary course of business and for amounts not past due for more than 60 days or which are being contested in good faith by appropriate proceedings which are sufficient to prevent imminent foreclosure of such Liens, are promptly instituted and diligently conducted and with respect to which adequate reserves or other appropriate provisions are being maintained in accordance with generally accepted accounting principles;

(i)Liens incurred or deposits made in the ordinary course of business (including, without limitation, surety bonds and appeal bonds) in connection with workers’ compensation, unemployment insurance and other types of social security

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benefits or to secure the performance of tenders, bids, leases, contracts (other than for the repayment of Indebtedness), statutory obligations and other similar obligations or arising as a result of progress payments under government contracts;

(j)easements (including, without limitation, reciprocal easement agreements and utility agreements), rights‑of‑way, covenants, consents, reservations, encroachments, variations and other restrictions, charges or encumbrances (whether or not recorded) affecting the use of real property;

(k)Liens with respect to judgments and attachments which do not result in an Event of Default;

(l)Liens, deposits or pledges to secure the performance of bids, tenders, contracts (other than contracts for the payment of money), leases (permitted under the terms of this Agreement), public or statutory obligations, surety, stay, appeal, indemnity, performance or other obligations arising in the ordinary course of business;

(m)other Liens including Liens imposed by Environmental Laws arising in the ordinary course of its business which (i) do not secure Indebtedness, (ii) do not secure any obligation in an amount exceeding $100,000,000 at any time at which Investment Grade Status does not exist as to the Borrower and (iii) do not in the aggregate materially detract from the value of its assets or materially impair the use thereof in the operation of its business;

(n)Liens securing obligations under Hedging Agreements entered into to protect against fluctuations in interest rates or exchange rates or commodity prices and not for speculative purposes, provided that such Liens run in favor of a Lender hereunder or under the Master Credit Facility or a Person who was, at the time of issuance, a Lender;

(o)Liens not otherwise permitted by the foregoing clauses of this Section on assets of the Borrower securing obligations in an aggregate principal or face amount at any date not to exceed 15% of the Consolidated Net Assets of the Borrower;

(p)[Reserved]; and

(q)Liens on regulatory assets up to the amount approved by state legislatures and/or regulatory orders.

Section 5.08.Consolidations, Mergers and Sales of Assets. The Borrower will not (i) consolidate or merge with or into any other Person or (ii) sell, lease or otherwise transfer, directly or indirectly, Substantial Assets to any Person (other than a Subsidiary of the Borrower); provided that the Borrower may merge with another Person if the Borrower is the Person surviving such merger and, after giving effect thereto, no Default shall have occurred and be continuing.

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Section 5.09.Use of Proceeds. The proceeds of the Loans made under this Agreement will be used by the Borrower for its general corporate purposes. None of such proceeds will be used, directly or indirectly, for the purpose, whether immediate, incidental or ultimate, of buying or carrying any “margin stock” within the meaning of Regulation U. None of such proceeds will be used (i) for the purpose of knowingly financing the activities of or any transactions with any Sanctioned Person or in any country or territory that is the subject of Sanctions applicable to the Borrower and its Subsidiaries and where the financed activity would be prohibited by such applicable Sanctions, at the time of such financing or (ii) in furtherance of an offer, payment, promise to pay, or authorization of the payment or giving of money, or anything else of value, to any Person in violation of any Anti-Corruption Laws.

Section 5.10.Indebtedness/Capitalization Ratio. The ratio of Consolidated Indebtedness of the Borrower to Consolidated Capitalization of the Borrower as at the end of any fiscal quarter of the Borrower will not exceed 65%.

ARTICLE 6
DEFAULTS

Section 6.01.Events of Default. If one or more of the following events (“Events of Default”) with respect to the Borrower shall have occurred and be continuing:

(a)the Borrower shall fail to pay when due any principal of any Loan to it or shall fail to pay, within five days of the due date thereof, any interest, fees or any other amount payable by it hereunder;

(b) the Borrower shall fail to observe or perform any covenant contained in Sections 5.04, 5.07, 5.08, 5.10 or the second or third sentence of 5.09, inclusive;

(c)the Borrower shall fail to observe or perform any covenant or agreement contained in this Agreement (other than those covered by clause (a) or (b) above) for 30 days after notice thereof has been given to the Borrower by the Administrative Agent at the request of any Lender;

(d)any representation, warranty, certification or statement made by the Borrower in this Agreement or in any certificate, financial statement or other document delivered pursuant to this Agreement shall prove to have been incorrect in any material respect when made (or deemed made);

(e)the Borrower or any of its Material Subsidiaries shall fail to make any payment in respect of Material Debt (other than Loans to the Borrower hereunder) when due or within any applicable grace period;

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(f)any event or condition shall occur and shall continue beyond the applicable grace or cure period, if any, provided with respect thereto so as to result in the acceleration of the maturity of Material Debt;

(g)the Borrower or any of its Material Subsidiaries shall commence a voluntary case or other proceeding seeking liquidation, reorganization or other relief with respect to itself or its debts under any bankruptcy, insolvency or other similar law now or hereafter in effect or seeking the appointment of a trustee, receiver, liquidator, custodian or other similar official of it or any substantial part of its property, or shall consent to any such relief or to the appointment of or taking possession by any such official in an involuntary case or other proceeding commenced against it, or shall make a general assignment for the benefit of creditors, or shall admit in writing its inability to, or shall fail generally to, pay its debts as they become due, or shall take any corporate action to authorize any of the foregoing;

(h)an involuntary case or other proceeding shall be commenced against the Borrower or any of its Material Subsidiaries seeking liquidation, reorganization or other relief with respect to it or its debts under any bankruptcy, insolvency or other similar law now or hereafter in effect or seeking the appointment of a trustee, receiver, liquidator, custodian or other similar official of it or any substantial part of its property, and such involuntary case or other proceeding shall remain undismissed and unstayed for a period of 90 days; or an order for relief shall be entered against the Borrower or any of its Material Subsidiaries under the federal bankruptcy laws as now or hereafter in effect;

(i)any member of the Borrower’s ERISA Group shall fail to pay when due an amount or amounts aggregating in excess of $150,000,000 which it shall have become liable to pay to the PBGC or to a Plan under Title IV of ERISA; or notice of intent to terminate a Plan or Plans of such ERISA Group having aggregate Unfunded Vested Liabilities in excess of $150,000,000 (collectively, a “Material Plan”) shall be filed under Title IV of ERISA by any member of such ERISA Group, any plan administrator or any combination of the foregoing; or the PBGC shall institute proceedings under Title IV of ERISA to terminate or to cause a trustee to be appointed to administer any such Material Plan or a proceeding shall be instituted by a fiduciary of any such Material Plan against any member of such ERISA Group to enforce Section 515 or 4219(c)(5) of ERISA and such proceeding shall not have been dismissed within 90 days thereafter; or a condition shall exist by reason of which the PBGC would be entitled to obtain a decree adjudicating that any such Material Plan must be terminated;

(j)a judgment or other court order for the payment of money in excess of $150,000,000 shall be rendered against the Borrower or any of its Material Subsidiaries and such judgment or order shall continue without being vacated, discharged, satisfied or stayed or bonded pending appeal for a period of 45 days;

(k)any person or group of persons (within the meaning of Section 13 or 14 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) other than trustees and participants in employee benefit plans of the Borrower and its Subsidiaries or

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the Endowment or Trust, shall have acquired beneficial ownership (within the meaning of Rule 13d-3 promulgated by the Securities and Exchange Commission under the Exchange Act) of 50% or more of the outstanding shares of common stock of the Borrower; during any period of twelve consecutive calendar months, individuals who were directors of the Borrower on the first day of such period (together with any successors nominated or appointed by then incumbent directors in the ordinary course) shall cease to constitute a majority of the board of directors of the Borrower; or

(l)any “Event of Default” (as defined in the Master Credit Facility) with respect to the Borrower under the Master Credit Facility;

then, and in every such event, the Administrative Agent shall (i) if requested by Lenders having more than 66-2/3% in aggregate amount of the Commitments, by notice to the Borrower terminate the Commitments as to the Borrower and they shall thereupon terminate, and the Borrower shall no longer be entitled to borrow hereunder, and (ii) if requested by Lenders holding more than 66-2/3% in aggregate principal amount of the Loans of the Borrower, by notice to the Borrower declare such Loans (together with accrued interest thereon) to be, and such Loans (together with accrued interest thereon) shall thereupon become, immediately due and payable without presentment, demand, protest or other notice of any kind, all of which are hereby waived by the Borrower; provided that in the case of any of the Events of Default specified in clause (g) or (h) above with respect to the Borrower, without any notice to the Borrower or any other act by the Administrative Agent or the Lenders, the Commitments shall thereupon terminate with respect to the Borrower and the Loans of the Borrower (together with accrued interest thereon) shall become immediately due and payable without presentment, demand, protest or other notice of any kind, all of which are hereby waived by the Borrower.

Section 6.02.Notice of Default. The Administrative Agent shall give notice to the Borrower under Section 6.01(c) promptly upon being requested to do so by any Lender and shall thereupon notify all the Lenders thereof.

ARTICLE 7
THE ADMINISTRATIVE AGENT

Section 7.01.Appointment and Authorization. Each Lender irrevocably appoints and authorizes the Administrative Agent to take such action as agent on its behalf and to exercise such powers under this Agreement and the Notes as are delegated to the Administrative Agent by the terms hereof or thereof, together with all such powers as are reasonably incidental thereto.

Section 7.02.Administrative Agent and Affiliates. The Bank of Tokyo-Mitsubishi UFJ, Ltd.shall have the same rights and powers under this Agreement as any other Lender and may exercise or refrain from exercising the same as though it were not the Administrative Agent, and The Bank of Tokyo-Mitsubishi UFJ, Ltd. and its affiliates may accept deposits from, lend money to, and generally engage in any kind of business

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with the Borrower or any Subsidiary or affiliate of the Borrower as if it were not the Administrative Agent hereunder.

Section 7.03.Action by Administrative Agent. The obligations of the Administrative Agent hereunder are only those expressly set forth herein. Without limiting the generality of the foregoing, the Administrative Agent shall not be required to take any action with respect to any Default, except as expressly provided in Article 6.

Section 7.04.Consultation with Experts. The Administrative Agent may consult with legal counsel (who may be counsel for the Borrower), independent public accountants and other experts selected by it and shall not be liable for any action taken or omitted to be taken by it in good faith in accordance with the advice of such counsel, accountants or experts.

Section 7.05.Liability of Administrative Agent. Neither the Administrative Agent nor any of its affiliates nor any of their respective directors, officers, agents or employees shall be liable to any Lender for any action taken or not taken by it in connection herewith (i) with the consent or at the request of the Required Lenders or (ii) in the absence of its own gross negligence or willful misconduct. Neither the Administrative Agent nor any of its affiliates nor any of their respective directors, officers, agents or employees shall be responsible for or have any duty to ascertain, inquire into or verify (i) any statement, warranty or representation made in connection with this Agreement or the borrowing hereunder; (ii) the performance or observance of any of the covenants or agreements of the Borrower; (iii) the satisfaction of any condition specified in Article 3, except receipt of items required to be delivered to the Administrative Agent; or (iv) the validity, effectiveness or genuineness of this Agreement, the Notes or any other instrument or writing furnished in connection herewith. The Administrative Agent shall not incur any liability by acting in reliance upon any notice, consent, certificate, statement, or other writing (which may be a bank wire, facsimile or similar writing) believed by it in good faith to be genuine or to be signed by the proper party or parties. Without limiting the generality of the foregoing, the use of the term “agent” in this Agreement with reference to the Administrative Agent is not intended to connote any fiduciary or other implied (or express) obligations arising under agency doctrine of any applicable law. Instead, such term is used merely as a matter of market custom and is intended to create or reflect only an administrative relationship between independent contracting parties.

Section 7.06.Indemnification. Each Lender shall, ratably in accordance with its portion of, prior to the First Funding Date, the Commitments or after the First Funding Date, the aggregate of the unfunded Commitments and the Loans outstanding, indemnify the Administrative Agent and its Related Parties (to the extent not reimbursed or indemnified by the Borrower) against any cost, expense (including counsel fees and disbursements), claim, demand, action, loss, penalties or liability (except such as result from such indemnitees’ gross negligence or willful misconduct) that such indemnitees may suffer or incur in connection with this Agreement or any action taken or omitted by

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the Administrative Agent in its capacity as such, or by any Related Party acting for the Administrative Agent in connection with such capacity.

Section 7.07.Credit Decision. Each Lender acknowledges that it has, independently and without reliance upon the Administrative Agent or any other Lender, and based on such documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Agreement. Each Lender also acknowledges that it will, independently and without reliance upon the Administrative Agent or any other Lender, and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking any action under this Agreement.

Section 7.08.Successor Administrative Agent.

(a)The Administrative Agent may resign at any time by giving notice thereof to the Lenders and the Borrower. Upon any such resignation, (i) the Borrower, with the consent of the Required Lenders (such consent not to be unreasonably withheld or delayed) or (ii) if an Event of Default has occurred and is continuing, then the Required Lenders, shall have the right to appoint a successor Administrative Agent. If no successor Administrative Agent shall have been so appointed, and shall have accepted such appointment, within 30 days after the retiring Administrative Agent gives notice of resignation, then the retiring Administrative Agent may, on behalf of the Lenders, appoint a successor Administrative Agent, which shall be a commercial bank organized or licensed under the laws of the United States of America or of any State thereof and having a combined capital and surplus of at least $250,000,000.

(b)If the Person serving as Administrative Agent is a Defaulting Lender, (i0 the Borrower, with the consent of the Required Lenders (such consent not to be unreasonably withheld or delayed) or (ii) if an Event of Default has occurred and is continuing, then the Required Lenders, shall have the right to appoint a successor Administrative Agent.

(c)Upon the acceptance of its appointment as Administrative Agent hereunder by a successor Administrative Agent, such successor Administrative Agent shall thereupon succeed to and become vested with all the rights, duties and obligations of the retiring Administrative Agent, and the retiring Administrative Agent shall be discharged from its duties and obligations hereunder; provided that if such successor Administrative Agent is appointed without the consent of the Borrower, such successor Administrative Agent may be replaced by the Borrower with the consent of the Required Lenders so long as no Event of Default has occurred and is continuing at the time. After any retiring Administrative Agent’s resignation or removal hereunder as Administrative Agent, the provisions of this Article shall inure to its benefit as to any actions taken or omitted to be taken by it while it was Administrative Agent.

(d)The fees payable by the Borrower to any successor Administrative Agent shall be the same as those payable to its predecessor unless otherwise agreed between the Borrower and such successor.

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Section 7.09.Administrative Agent’s Fee. The Borrower shall pay to the Administrative Agent for its own account fees in the amounts and at the times previously agreed upon between the Borrower and the Administrative Agent.

ARTICLE 8
CHANGE IN CIRCUMSTANCES

Section 8.01.Basis for Determining Interest Rate Inadequate or Unfair. If on or prior to the first day of any Interest Period for any Euro-Dollar Borrowing:

(a)the Administrative Agent determines (which determination shall be conclusive absent manifest error) that deposits in dollars (in the applicable amounts) are not being offered to financial institutions in general in the relevant market for such Interest Period, or

(b)Lenders having 66-2/3% or more of the aggregate amount of the affected Loans advise the Administrative Agent that the London Interbank Offered Rate as determined by the Administrative Agent will not adequately and fairly reflect the cost to such Lenders of funding their Euro‑Dollar Loans for such Interest Period,

the Administrative Agent shall forthwith give notice thereof to the Borrower and the Lenders, whereupon until the Administrative Agent notifies the Borrower that the circumstances giving rise to such suspension no longer exist, (i) the obligations of the Lenders to make Euro-Dollar Loans or to continue or convert outstanding Loans as or into Euro-Dollar Loans shall be suspended and (ii) each outstanding Euro-Dollar Loan shall be converted into a Base Rate Loan on the last day of the then current Interest Period applicable thereto. Unless the Borrower notifies the Administrative Agent at least one Domestic Business Day before the date of any Euro-Dollar Borrowing for which a Notice of Borrowing has previously been given that it elects not to borrow on such date, such Borrowing shall instead be made as a Base Rate Borrowing.

Section 8.02.Illegality. If any Change In Law shall make it unlawful or impossible for any Lender (or its Euro‑Dollar Lending Office) to make, maintain or fund any of its Euro‑Dollar Loans and such Lender shall so notify the Administrative Agent, the Administrative Agent shall forthwith give notice thereof to the other Lenders and the Borrower, whereupon until such Lender notifies the Borrower and the Administrative Agent that the circumstances giving rise to such suspension no longer exist, the obligation of such Lender to make Euro‑Dollar Loans, or to continue or convert outstanding Loans as or into Euro-Dollar Loans, shall be suspended. Before giving any notice to the Administrative Agent pursuant to this Section, such Lender shall designate a different Euro‑Dollar Lending Office if such designation will avoid the need for giving such notice and will not be otherwise disadvantageous to such Lender in the good faith exercise of its discretion. If such notice is given, each Euro-Dollar Loan of such Lender then outstanding shall be converted to a Base Rate Loan either (a) on the last day of the then current Interest Period applicable to such Euro-Dollar Loan if such Lender may lawfully continue to maintain and fund such Loan to such day or (b) immediately if such

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Lender shall determine that it may not lawfully continue to maintain and fund such Loan to such day.

Section 8.03.Increased Cost and Reduced Return. (a) If any Change In Law (i) shall impose, modify or deem applicable any reserve, special deposit, compulsory loan, insurance charge or similar requirement (including, without limitation, any such requirement imposed by the Board of Governors of the Federal Reserve System, but excluding with respect to any Euro‑Dollar Loan any such requirement included in an applicable Euro‑Dollar Reserve Percentage) against assets of, deposits with or for the account of, or credit extended by, any Lender (or its Applicable Lending Office); (ii) shall subject any Lender or Agent to any taxes (other than (A) Taxes, (B) taxes described in clauses (ii), (iii) or (iv) of the exclusions from the definition of Taxes and (C) Connection Income Taxes) on its loans, loan principal, letters of credit, commitments, or other obligations, or its deposits, reserves, other liabilities or capital attributable thereto; or (iii) shall impose on any Lender (or its Applicable Lending Office) or on the London interbank market any other condition, cost or expense affecting its Euro-Dollar Loans, its Note or its obligation to make Euro-Dollar Loans and the result of any of the foregoing is to increase the cost to such Lender (or its Applicable Lending Office) of making or maintaining any Euro-Dollar Loan (or, in the case of an adoption or change with respect to taxes, any Loan), or to reduce the amount of any sum received or receivable by such Lender (or its Applicable Lending Office) under this Agreement or under its Note with respect thereto, by an amount deemed by such Lender to be material, then, within 15 days after demand by such Lender (with a copy to the Administrative Agent), the Borrower shall pay to such Lender such additional amount or amounts as will compensate such Lender for such increased cost or reduction; provided that no such amount shall be payable with respect to any period commencing more than 90 days prior to the date such Lender first notifies the Borrower of its intention to demand compensation therefor under this Section 8.03(a).

(b)If any Lender shall have determined that any Change In Law has or would have the effect of reducing the rate of return on capital or liquidity of such Lender (or its Parent) as a consequence of such Lender’s obligations hereunder to a level below that which such Lender (or its Parent) could have achieved but for such Change In Law (taking into consideration its policies with respect to capital adequacy or liquidity) by an amount deemed by such Lender to be material, then from time to time, within 15 days after demand by such Lender (with a copy to the Administrative Agent), the Borrower shall pay to such Lender such additional amount or amounts as will compensate such Lender (or its Parent) for such reduction; provided that no such amount shall be payable with respect to any period commencing less than 30 days after the date such Lender first notifies the Borrower of its intention to demand compensation under this Section 8.03(b).

(c)Each Lender will promptly notify the Borrower and the Administrative Agent of any event of which it has knowledge, occurring after the date hereof, which will entitle such Lender to compensation pursuant to this Section and will designate a different Applicable Lending Office if such designation will avoid the need for, or reduce

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the amount of, such compensation and will not, in the judgment of such Lender, be otherwise disadvantageous to such Lender. A certificate of any Lender claiming compensation under this Section and setting forth the additional amount or amounts to be paid to it hereunder shall be conclusive in the absence of manifest error. In determining such amount, such Lender may use any reasonable averaging and attribution methods.

Section 8.04.Taxes. (a)For purposes of this Section 8.04 the following terms have the following meanings:

“FATCA” means Sections 1471 through 1474 of the Internal Revenue Code, as of the date of this Agreement (or any amended or successor version that is substantively comparable and not materially more onerous to comply with) any current or future regulations or official interpretations thereof and any agreement entered into pursuant to Section 1471(b)(1) of the Internal Revenue Code. For purposes of this Section 8.04, “applicable law” includes FATCA.

“Taxes” means any and all present or future taxes, duties, levies, imposts, deductions, charges or withholdings including any interest, additions to tax or penalties applicable thereto with respect to any payment by or on account of any obligation of the Borrower pursuant to this Agreement or any Note, excluding (i) in the case of each Lender and the Administrative Agent, taxes imposed on its income, net worth or gross receipts and franchise or similar taxes imposed on it by a jurisdiction under the laws of which such Lender or the Administrative Agent (as the case may be) is organized or in which its principal executive office is located or, in the case of each Lender, in which its Applicable Lending Office is located, (ii) in the case of each Lender, any United States withholding tax imposed on such payments except to the extent that (A) such Lender is subject to United States withholding tax by reason of a U.S. Tax Law Change or (B) in the case of a Lender not listed on the signature pages hereof or a Participant, amounts with respect to such Taxes were payable pursuant to Section 8.04 to such Lender’s assignor or to such Participant’s participating Lender immediately before such Lender or Participant acquired the applicable interest in a Loan or Commitment; (iii) Taxes attributable to such Lender’s or Administrative Agent’s failure to comply with Section 8.04(d) or (e) and (iv) any U.S. federal withholding Taxes imposed under FATCA.

“Other Taxes” means any present or future stamp or documentary taxes and any other excise or property taxes, or similar charges or levies, which arise from any payment made pursuant to this Agreement or under any Note or from the execution or delivery of, or otherwise with respect to, this Agreement or any Note.

“U.S. Tax Law Change” means with respect to any Lender or Participant the occurrence (x) in the case of each Lender listed on the signature pages hereof, after the date of its execution and delivery of this Agreement and (y) in the case of any other Lender, after the date such Lender shall have become a Lender hereunder, and (z) in the case of each Participant, after the date such Participant became a Participant hereunder, of the adoption of any applicable U.S. federal law, U.S. federal rule or U.S. federal

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regulation relating to taxation, or any change therein, or the entry into force, modification or revocation of any income tax convention or treaty to which the United States is a party.

(b)Any and all payments by or any account of the Borrower to or for the account of any Lender or the Administrative Agent hereunder or under any Note shall be made without deduction for any Taxes or Other Taxes, except as required by applicable law; provided that if the Borrower or the Administrative Agent shall be required by law to deduct any Taxes or Other Taxes from any such payments, (i) the sum payable by the Borrower shall be increased as necessary so that after all required deductions are made (including deductions applicable to additional sums payable under this Section 8.04) such Lender or the Administrative Agent (as the case may be) receives an amount equal to the sum it would have received had no such deductions been made, (ii) the Borrower or the Administrative Agent shall make such deductions, (iii) the Borrower or the Administrative Agent shall pay the full amount deducted to the relevant taxation authority or other authority in accordance with applicable law and (iv) if the withholding agent is the Borrower, the Borrower shall furnish to the Administrative Agent, at its address referred to in Section 9.01, the original or a certified copy of a receipt evidencing payment thereof.

(c)The Borrower agrees to indemnify each Lender and the Administrative Agent for the full amount of Taxes or Other Taxes (including, without limitation, any Taxes or Other Taxes imposed or asserted by any jurisdiction on amounts payable under this Section 8.04) paid by such Lender or the Administrative Agent (as the case may be) and any reasonable expenses arising therefrom or with respect thereto. This indemnification shall be paid within 15 days after such Lender or the Administrative Agent (as the case may be) makes demand therefor.

(d)Each Lender organized under the laws of a jurisdiction outside the United States, on or prior to the date of its execution and delivery of this Agreement in the case of each Lender listed on the signature pages hereof and on or prior to the date on which it becomes a Lender in the case of each other Lender, and from time to time thereafter as required by law or requested by the Borrower or the Administrative Agent (but only so long as such Lender remains lawfully able to do so), shall provide the Borrower and the Administrative Agent (in such number of copies as shall be requested by the recipient) with whichever of the following is applicable (including any successor forms prescribed by the Internal Revenue Service):

(i)in the case of a Lender claiming the benefits of an income tax treaty to which the United States is a party (x) with respect to payments of interest hereunder or under any Note, executed originals of IRS Form W-8BEN establishing an exemption from, or reduction of, U.S. federal withholding Tax pursuant to the “interest” article of such tax treaty and (y) with respect to any other applicable payments hereunder or under any Note, IRS Form W-8BEN establishing an exemption from, or reduction of, U.S. federal withholding Tax pursuant to the “business profits” or “other income” article of such tax treaty;

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(ii)executed originals of IRS Form W-8ECI;

(iii)in the case of a Lender claiming the benefits of the exemption for portfolio interest under Section 881(c) of the Internal Revenue Code, (x) a certificate reasonably acceptable to the Administrative Agent to the effect that such Lender is not a “bank” within the meaning of Section 881(c)(3)(A) of the Internal Revenue Code, a “10 percent shareholder” of the Borrower within the meaning of Section 881(c)(3)(B) of the Internal Revenue Code, or a “controlled foreign corporation” described in Section 881(c)(3)(C) of the Internal Revenue Code (a “U.S. Tax Compliance Certificate”) and (y) executed originals of IRS Form W-8BEN; or

(iv)to the extent a Lender is not the beneficial owner, executed originals of IRS Form W-8IMY, accompanied by IRS Form W-8ECI, IRS Form W-8BEN, a U.S. Tax Compliance Certificate, IRS Form W-9, and/or other certification documents from each beneficial owner, as applicable; provided that if the Lender is a partnership and one or more direct or indirect partners of such Lender are claiming the portfolio interest exemption, such Lender may provide a U.S. Tax Compliance Certificate on behalf of each such direct and indirect partner.

(e)Any Lender that is organized under the laws of a jurisdiction within the United States shall deliver to the Borrower and the Administrative Agent on or prior to the date on which such Lender becomes a Lender under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower or the Administrative Agent), executed originals of IRS Form W-9 certifying that such Lender is exempt from U.S. federal backup withholding tax.

(f)If a payment made to a Lender hereunder or under any Note would be subject to U.S. federal withholding Tax imposed by FATCA if such Lender were to fail to comply with the applicable reporting requirements of FATCA (including those contained in Section 1471(b) or 1472(b) of the Internal Revenue Code, as applicable), such Lender shall deliver to the Borrower and the Administrative Agent at the time or times prescribed by law and at such time or times reasonably requested by the Borrower or the Administrative Agent such documentation prescribed by applicable law (including as prescribed by Section 1471(b)(3)(C)(i) of the Internal Revenue Code) and such additional documentation reasonably requested by the Borrower or the Administrative Agent as may be necessary for the Borrower and the Administrative Agent to comply with their obligations under FATCA and to determine that such Lender has complied with such Lender’s obligations under FATCA or to determine the amount to deduct and withhold from such payment. Solely for purposes of this clause (f), “FATCA” shall include any amendments made to FATCA after the date of this Agreement.

(g)Each Lender agrees that if any form or certification it previously delivered expires or becomes obsolete or inaccurate in any respect, it shall update such form or

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certification or promptly notify the Borrower and the Administrative Agent in writing of its legal inability to do so.

(h)If a Lender, which is otherwise exempt from or subject to a reduced rate of withholding tax, becomes subject to Taxes because of its failure to deliver a form required hereunder, the Borrower shall take such steps as such Lender shall reasonably request to assist such Lender to recover such Taxes.

(i)If the Borrower is required to pay additional amounts to or for the account of any Lender pursuant to this Section 8.04, then such Lender will take such action (including changing the jurisdiction of its Applicable Lending Office) as in the good faith judgment of such Lender (i) will eliminate or reduce any such additional payment which may thereafter accrue and (ii) is not otherwise disadvantageous to such Lender.

(j)If any Lender or the Administrative Agent receives a refund of any Taxes or Other Taxes for which the Borrower has made a payment under Section 8.04(b) or (c) and such refund was received from the taxing authority which originally imposed such Taxes or Other Taxes, such Lender or the Administrative Agent agrees to reimburse the Borrower to the extent of such refund; provided that nothing contained in this paragraph (j) shall require any Lender or the Administrative Agent to seek any such refund or make available its tax returns (or any other information relating to its taxes which it deems to be confidential).

(k)Each Lender shall severally indemnify the Administrative Agent, within 10 days after demand therefor, for (i) any Taxes attributable to such Lender (but only to the extent that the Borrower has not already indemnified the Administrative Agent for such Taxes and without limiting the obligation of the Borrower to do so), (ii) any taxes attributable to such Lender’s failure to comply with the provisions of Section 9.06(b) relating to the maintenance of a Participant Register and (iii) any taxes excluded from the definition of Taxes attributable to such Lender, in each case, that are payable or paid by the Administrative Agent in connection with this Agreement or any Note, and any reasonable expenses arising therefrom or with respect thereto. A certificate as to the amount of such payment or liability delivered to any Lender by the Administrative Agent shall be conclusive absent manifest error. Each Lender hereby authorizes the Administrative Agent to set off and apply any and all amounts at any time owing to such Lender hereunder or under any Note or otherwise payable by the Administrative Agent to the Lender from any other source against any amount due to the Administrative Agent under this paragraph (k).

Section 8.05.Base Rate Loans Substituted for Affected Euro-Dollar Loans. If (i) the obligation of any Lender to make or to continue or convert outstanding Loans as or into Euro‑Dollar Loans has been suspended pursuant to Section 8.02 or (ii) any Lender has demanded compensation under Section 8.03(a) with respect to its Euro-Dollar Loans and the Borrower shall, by at least five Euro‑Dollar Business Days’ prior notice to such Lender through the Administrative Agent, have elected that the provisions of this Section shall apply to such Lender, then, unless and until such Lender notifies the Borrower that

44

the circumstances giving rise to such suspension or demand for compensation no longer apply:

(a)all Loans which would otherwise be made by such Lender as (or continued as or converted to) Euro‑Dollar Loans, as the case may be, shall instead be Base Rate Loans (on which interest and principal shall be payable contemporaneously with the related Euro-Dollar Loans of the other Lenders), and

(b)after each of its Euro‑Dollar Loans has been repaid, all payments of principal which would otherwise be applied to repay such Loans shall be applied to repay its Base Rate Loans instead.

If such Lender notifies the Borrower that the circumstances giving rise to such suspension or demand for compensation no longer exist, the principal amount of each such Base Rate Loan shall be converted into a Euro-Dollar Loan on the first day of the next succeeding Interest Period applicable to the related Euro-Dollar Loans of the other Lenders.

Section 8.06.Substitution of Lender; Termination Option. If (i) the obligation of any Lender to make or to convert or continue outstanding Loans as or into Euro-Dollar Loans has been suspended pursuant to Section 8.02, (ii) any Lender has demanded compensation under Section 8.03 or 8.04 (including any demand made by a Lender on behalf of a Participant), (iii) [reserved], (iv) any Lender becomes a Defaulting Lender, (v) Investment Grade Status ceases to exist as to any Lender or, (vi) for purposes of (a) below only, any Lender becomes a Non-Consenting Lender, then:

(a)the Borrower shall have the right, with the assistance of the Administrative Agent (or, if the Administrative Agent is a Defaulting Lender, the Required Lenders), to designate an Assignee (which may be one or more of the Lenders) mutually satisfactory to the Borrower and, so long as any such Persons are not Defaulting Lenders, the Administrative Agent (whose consent shall not be unreasonably withheld or delayed) to purchase for cash, pursuant to an Assignment and Assumption Agreement in substantially the form of Exhibit D hereto, the outstanding Loans of such Lender and assume the Commitment of such Lender (including any Commitments and Loans that have been participated), without recourse to or warranty by, or expense to, such Lender, for a purchase price equal to the principal amount of all of such Lender’s outstanding Loans plus any accrued but unpaid interest thereon and the accrued but unpaid fees in respect of such Lender’s Commitment hereunder and all other amounts payable by the Borrower to such Lender hereunder plus such amount, if any, as would be payable pursuant to Section 2.13 if the outstanding Loans of such Lender were prepaid in their entirety on the date of consummation of such assignment; and

(b)if at the time Investment Grade Status exists as to the Borrower, the Borrower may elect to terminate this Agreement as to such Lender (including any Commitments and Loans that have been participated); provided that (i) the Borrower notifies such Lender through the Administrative Agent (or, if the Administrative Agent is

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a Defaulting Lender, the Required Lenders) of such election at least three Euro‑Dollar Business Days before the effective date of such termination and (ii) the Borrower repay or prepay the principal amount of all outstanding Loans made by such Lender plus any accrued but unpaid interest thereon and the accrued but unpaid fees in respect of such Lender’s Commitment hereunder plus all other amounts payable by the Borrower to such Lender hereunder, not later than the effective date of such termination.

ARTICLE 9
MISCELLANEOUS

Section 9.01.Notices.

(a)All notices, requests and other communications to any party hereunder shall be in writing (including electronic transmission, bank wire, facsimile transmission or similar writing) and shall be given to such party: (x) in the case of the Borrower or the Administrative Agent, at its address or facsimile number set forth on the signature pages hereof, (y) in the case of any Lender, at its address or facsimile number set forth in its Administrative Questionnaire or (z) in the case of any party, such other address or facsimile number as such party may hereafter specify for the purpose by notice to the Administrative Agent and the Borrower. Each such notice, request or other communication shall be effective (i) if given by facsimile, when such facsimile is transmitted to the facsimile number specified in this Section and the appropriate answerback or confirmation slip, as the case may be, is received or (ii) if given by any other means, when delivered at the address specified in this Section; provided that notices to the Administrative Agent under Article 2 or Article 8 shall not be effective until delivered. Notices delivered through electronic communications shall be effective as and to the extent provided in subsection (b) below.

(b)Notices and other communications to the Lenders hereunder may be delivered or furnished by electronic communication (including e-mail and internet or intranet websites) pursuant to procedures approved by the Administrative Agent or as otherwise determined by the Administrative Agent, provided that the foregoing shall not apply to notices to any Lender pursuant to Article 2 if such Lender has notified the Administrative Agent that it is incapable of receiving notices under such Section by electronic communication. The Administrative Agent or the Borrower may, in its respective discretion, agree to accept notices and other communications to it hereunder by electronic communications pursuant to procedures approved by it or as it otherwise determines, provided that such determination or approval may be limited to particular notices or communications. Unless the Administrative Agent otherwise prescribes, (i) notices and other communications sent to an e-mail address shall be deemed received upon the sender’s receipt of an acknowledgement from the intended recipient (such as by the “return receipt requested” function, as available, return e-mail or other written acknowledgement), provided that if such notice or other communication is not given during the normal business hours of the recipient, such notice or communication shall be deemed to have been given at the opening of business on the next Domestic Business

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Day or Euro-Dollar Business Day, as applicable, for the recipient, and (ii) notices or communications posted to an internet or intranet website shall be deemed received upon the deemed receipt by the intended recipient at its e-mail address as described in the foregoing clause (i) of notification that such notice or communication is available and identifying the website address therefor.

Section 9.02.No Waivers. No failure or delay by the Administrative Agent or any Lender in exercising any right, power or privilege hereunder or under any Note shall operate as a waiver thereof nor shall any single or partial exercise thereof preclude any other or further exercise thereof or the exercise of any other right, power or privilege. The rights and remedies herein provided shall be cumulative and not exclusive of any rights or remedies provided by law.

Section 9.03.Expenses; Indemnification. (a) The Borrower shall pay (i) all reasonable out‑of‑pocket expenses of the Administrative Agent, including reasonable fees and disbursements of one special counsel for the Administrative Agent, in connection with the preparation of this Agreement, any waiver or consent hereunder or any amendment hereof or any Default or alleged Default with respect to the Borrower hereunder and (ii) if an Event of Default with respect to the Borrower occurs, all reasonable out‑of‑pocket expenses incurred by the Administrative Agent or any Lender, including reasonable fees and disbursements of counsel, in connection with such Event of Default and collection and other enforcement proceedings resulting therefrom.

(b)The Borrower agrees to indemnify the Administrative Agent and each Lender and the respective Related Parties of the foregoing (each an “Indemnitee”) and hold each Indemnitee harmless from and against any and all liabilities, losses, penalties, damages, costs and expenses of any kind, including, without limitation, the reasonable fees and disbursements of one counsel for all Indemnitees taken as a whole and, in the case of any actual or potential conflict of interest, one additional counsel to each group of affected Indemnitees similarly situated taken as a whole, which may be incurred by such Indemnitee in connection with any investigative, administrative or judicial proceeding (whether or not such Indemnitee shall be designated a party thereto) relating to or arising out of this Agreement or any actual or proposed use of proceeds of Loans hereunder; provided that no Indemnitee shall have the right to be indemnified hereunder for such Indemnitee’s own gross negligence or willful misconduct as determined by a court of competent jurisdiction. This Section shall not apply to Taxes other than any Taxes that represent losses, claims, damages, etc. arising from any non-Tax claim.

(c)To the fullest extent permitted by applicable law, the Borrower shall not assert, and hereby waives, any claim against any Indemnitee, on any theory of liability, for special, indirect, consequential or punitive damages (as opposed to direct or actual damages) arising out of, in connection with, or as a result of, this Agreement, or any agreement or instrument contemplated hereby, the transactions contemplated hereby or thereby, any Loan or the use of the proceeds thereof. No Indemnitee referred to in paragraph (b) above shall be liable for any damages arising from the use by unintended

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recipients of any information or other materials distributed by it through telecommunications, electronic or other information transmission systems in connection with this Agreement or the transactions contemplated hereby or thereby.

Section 9.04.Sharing of Set-offs. Each Lender agrees that if it shall, by exercising any right of set‑off or counterclaim or otherwise, receive payment of a proportion of the aggregate amount then due with respect to the Loans held by it which is greater than the proportion received by any other Lender in respect of the aggregate amount then due with respect to the Loans held by such other Lender, the Lender receiving such proportionately greater payment shall purchase such participations in the Loans held by the other Lenders, and such other adjustments shall be made, as may be required so that all such payments with respect to the Loans held by the Lenders shall be shared by the Lenders pro rata; provided that nothing in this Section shall impair the right of any Lender to exercise any right of set‑off or counterclaim it may have and to apply the amount subject to such exercise to the payment of indebtedness of the Borrower other than its indebtedness under this Agreement.

Section 9.05.Amendments and Waivers. (a) Any provision of this Agreement or the Notes may be amended or waived if, but only if, such amendment or waiver is in writing and is signed by the Borrower and the Required Lenders (and, if the rights or duties of the Administrative Agent is affected thereby, by the Administrative Agent); provided that no such amendment or waiver shall (x) unless signed by each adversely affected Lender, (i) increase the Commitment of any Lender or subject any Lender to any additional obligation, (ii) reduce the principal of or rate of interest on any Loan or any interest thereon or any fees hereunder, (iii) postpone the date fixed for any payment of principal of or interest on any Loan or interest thereon or any fees hereunder or for termination of any Commitment, or (iv) change the provisions of Section 9.04 or of any other provision of this Agreement providing for the ratable application of payments in respect of the Loans or (y) unless signed by all Lenders, change the definition of Required Lenders or the provisions of this Section 9.05.

(b)(i) If any representation or warranty in Article 4 of the Master Credit Facility, any covenant in Article 5 of the Master Credit Facility or any event of default in Article 6 of the Master Credit Facility and, in each case, any related definitions in the Master Credit Facility, is replaced, changed, amended, modified, supplemented or removed or (ii) any Default or Event of Default (as such terms are defined in the Master Credit Facility) is waived (any of the foregoing in clauses (i) and (ii), a “Change”), regardless of whether the Master Credit Facility is replaced, refinanced, amended and restated, amended, modified or supplemented and regardless of whether any such Change occurs in the corresponding article or definitions, such Change shall be incorporated automatically into this Agreement, or in the case of a waiver will be applied automatically to this Agreement for the corresponding Default or Event of Default occurring hereunder, upon the later of (i) the effectiveness of such Change in the Master Credit Facility and (ii) the 30th day after the Administrative Agent’s receipt of notice from the Borrower of such Change, provided that the Required Lenders hereunder do not

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notify the Borrower through the Administrative Agent within 30 days after the Administrative Agent’s receipt of such notice from the Borrower of their election (which may be made in their discretion) that such Change shall not be effective with respect to this Agreement; provided that no Change to the Master Credit Facility shall amend, waive, modify or impact the rights or remedies of the Lenders with respect to a Default or Event of Default under Section 6.01(a) of this Agreement.

Section 9.06.Successors and Assigns. (a) The provisions of this Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns and each Indemnitee, except that no Borrower may assign or otherwise transfer any of its rights under this Agreement without the prior written consent of all Lenders.

(b)Any Lender may, with the consent (unless an Event of Default then exists) of the Borrower (such consent not to be unreasonably withheld or delayed), at any time grant to one or more banks or other institutions (each a “Participant”) participating interests in its Commitment or any or all of its Loans; provided that any Lender may, without the consent of the Borrower, at any time grant participating interests in its Commitment or any or all of its Loans to another Lender, an Approved Fund or an Affiliate of such transferor Lender. In the event of any such grant by a Lender of a participating interest to a Participant, whether or not upon notice to the Administrative Agent, such Lender shall remain responsible for the performance of its obligations hereunder, and the Borrower and the Administrative Agent shall continue to deal solely and directly with such Lender in connection with such Lender’s rights and obligations under this Agreement. Any agreement pursuant to which any Lender may grant such a participating interest shall provide that (A) such Participant agrees to be subject to Section 8.06 as if it were an Assignee under paragraph (c) of this Section 9.06 or as if it were the Lender granting such participation and (B) such Lender shall retain the sole right and responsibility to enforce the obligations of the Borrower hereunder including, without limitation, the right to approve any amendment, modification or waiver of any provision of this Agreement; provided that such participation agreement may provide that such Lender will not agree to any modification, amendment or waiver of this Agreement described in clause (x)(i), (ii) or (iii)of Section 9.05(a) without the consent of the Participant. The Borrower agrees that each Participant shall, to the extent provided in its participation agreement, be entitled to the benefits of Article 8 with respect to its participating interest, subject to the performance by such Participant of the obligations of a Lender thereunder (it being understood that the documentation required under Section 8.04 shall be delivered by the Participant to the participating Lender and the Participant agrees to be subject to the provisions of Sections 8.04(i), 8.04(j) and 8.06 as if it were an Assignee). In addition, each Lender that sells a participation agrees, at the Borrower’s request, to use reasonable efforts to cooperate with the Borrower to effectuate the provisions of Section 8.06 with respect to any Participant. An assignment or other transfer which is not permitted by subsection (c) or (d) below shall be given effect for purposes of this Agreement only to the extent of a participating interest granted in accordance with this subsection (b). Each Lender that sells a participation shall, acting

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solely for this purpose as a non-fiduciary agent of the Borrower, maintain a register on which it enters the name and address of each Participant and the principal amounts (and stated interest) of each Participant’s interest in the Loans or other obligations hereunder or under any Note (the “Participant Register”); provided that no Lender shall have any obligation to disclose all or any portion of the Participant Register (including the identity of any Participant (other than for the consent requirements set forth in the first sentence of this Section 9.06(b)) or any information relating to a Participant’s interest in any Commitments, Loans or its other obligations hereunder or under any Note) to any Person except to the extent that such disclosure is necessary to establish that such Commitment, Loan or other obligation is in registered form under Section 5f.103-1(c) of the United States Treasury Regulations. The entries in the Participant Register shall be conclusive absent manifest error, and such Lender shall treat each Person whose name is recorded in the Participant Register as the owner of such participation for all purposes of this Agreement notwithstanding any notice to the contrary. For the avoidance of doubt, the Administrative Agent (in its capacity as Administrative Agent) shall have no responsibility for maintaining a Participant Register.

(c)Any Lender may at any time assign to one or more banks or other financial institutions (each an “Assignee”) other than (w) the Borrower, (x) a Subsidiary or Affiliate of the Borrower, (y) a Defaulting Lender or any Person who, upon becoming a Lender hereunder, would constitute a Defaulting Lender, or (z) a natural person (or a holding company, investment vehicle or trust for, or owned and operated for the primary benefit of, a natural person), all, or a proportionate part (equivalent to a Commitment of not less than $10,000,000 (unless the Borrower and the Administrative Agent shall otherwise agree)) of all, of its rights and obligations under this Agreement and its Note (if any), and such Assignee shall assume such rights and obligations, pursuant to an Assignment and Assumption Agreement in substantially the form of Exhibit D hereto executed by such Assignee and such transferor Lender, with (and only with and subject to) the prior written consent of the Administrative Agent (which shall not be unreasonably withheld or delayed) and, so long as no Event of Default has occurred and is continuing, the Borrower (which shall not be unreasonably withheld or delayed); provided that unless such assignment is of the entire right, title and interest of the transferor Lender hereunder, after making any such assignment such transferor Lender shall have a Commitment of at least $10,000,000 (unless the Borrower and the Administrative Agent shall otherwise agree). Upon execution and delivery of such instrument of assumption and payment by such Assignee to such transferor Lender of an amount equal to the purchase price agreed between such transferor Lender and such Assignee, such Assignee shall be a Lender party to this Agreement and shall have all the rights and obligations of a Lender with a Commitment as set forth in such instrument of assumption, and the transferor Lender shall be released from its obligations hereunder to a corresponding extent, and no further consent or action by any party shall be required. Upon the consummation of any assignment pursuant to this subsection (c), the transferor Lender, the Administrative Agent and the Borrower shall make appropriate arrangements so that, if required by the Assignee, a Note(s) is issued to the Assignee. The Assignee shall, prior to the first date on which interest or fees are payable hereunder for its account,

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deliver to the Borrower and the Administrative Agent any certifications, forms or other documentation in accordance with Section 8.04. All assignments (other than assignments to Affiliates) shall be subject to a transaction fee established by, and payable by the transferor Lender to, the Administrative Agent for its own account (which shall not exceed $3,500).

(d)Any Lender may at any time assign all or any portion of its rights under this Agreement and its Note (if any) to a Federal Reserve Bank. No such assignment shall release the transferor Lender from its obligations hereunder or modify any such obligations.

(e)No Assignee, Participant or other transferee of any Lender’s rights (including any Applicable Lending Office other than such Lender’s initial Applicable Lending Office) shall be entitled to receive any greater payment under Section 8.03 or 8.04 than such Lender would have been entitled to receive with respect to the rights transferred, unless such transfer is made by reason of the provisions of Section 8.02, 8.03 or 8.04 requiring such Lender to designate a different Applicable Lending Office under certain circumstances or at a time when the circumstances giving rise to such greater payment did not exist.

Section 9.07.Collateral. Each of the Lenders represents to the Administrative Agent and each of the other Lenders that it in good faith is not relying upon any “margin stock” (as defined in Regulation U) as collateral in the extension or maintenance of the credit provided for in this Agreement.

Section 9.08.Confidentiality. The Administrative Agent and each Lender (i) agrees to keep any information delivered or made available by the Borrower pursuant to this Agreement confidential from anyone other than persons employed or retained by such Lender and its Affiliates who are engaged in evaluating, approving, structuring or administering the credit facility contemplated hereby and (ii) further agrees on behalf of itself and, to the extent it has the power to do so, its Affiliates and agents, to keep all other information delivered or made available to it by the Borrower or Affiliate of the Borrower for other purposes which, (x) is marked confidential and is expressly made available subject to the terms of this section, and (y) is not otherwise subject to a confidentiality agreement, confidential from anyone other than persons employed or retained by such Lender and its Affiliates and agents who need to receive such information in furtherance of the engagement or matter pursuant to which the information is provided; provided that nothing herein shall prevent any Lender or, solely with respect to information disclosed in a manner set forth in clauses (b) through (g) and (k) in this Section 9.08, any Affiliate of such Lender from disclosing such information, to the extent necessary under the circumstances under which such disclosure is required, (a) to any other Lender or the Administrative Agent, (b) upon the order of any court or administrative agency, (c) upon the request or demand of any regulatory agency or authority or self-regulatory body, (d) which had been publicly disclosed other than as a result of a disclosure by the Administrative Agent or any Lender prohibited by this

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Agreement, (e) in connection with any litigation to which the Administrative Agent, any Lender or any Affiliate or their respective subsidiaries or Parent may be a party, (f) to the extent necessary in connection with the exercise of any remedy hereunder or other engagement or matter, (g) to such Lender’s, Affiliate’s or the Administrative Agent’s legal counsel and independent auditors, (h) subject to provisions substantially similar to those contained in this Section 9.08, to any actual or proposed Participant or Assignee, (i) to any direct, indirect, actual or prospective counterparty (and its advisor) to any swap, derivative or securitization transaction related to the obligations under this Agreement, (j) on a confidential basis to the CUSIP Service Bureau or any similar agency in connection with the issuance and monitoring of CUSIP numbers with respect to the loans and (k) with the consent of the Borrower.

Section 9.09.Governing Law; Submission to Jurisdiction. This Agreement and each Note (if any) shall be construed in accordance with and governed by the law of the State of New York. The Borrower and each Lender Party hereby submits to the exclusive jurisdiction of the United States District Court for the Southern District of New York and of any New York State court sitting in New York County for purposes of all legal proceedings arising out of or relating to this Agreement or the transactions contemplated hereby. The Borrower and each Lender Party irrevocably waives, to the fullest extent permitted by law, any objection which it may now or hereafter have to the laying of the venue of any such proceeding brought in such a court and any claim that any such proceeding brought in such a court has been brought in an inconvenient forum.

Section 9.10.Counterparts; Integration. This Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument. Delivery of an executed signature page of this Agreement by facsimile or electronic transmission shall be effective as delivery of a manually executed counterpart hereof. This Agreement constitutes the entire agreement and understanding among the parties hereto and supersedes any and all prior agreements and understandings, oral or written, relating to the subject matter hereof.

Section 9.11.WAIVER OF JURY TRIAL. EACH OF THE BORROWER, THE ADMINISTRATIVE AGENT AND THE LENDERS, TO THE FULLEST EXTENT IT MAY EFFECTIVELY DO SO UNDER APPLICABLE LAW, HEREBY IRREVOCABLY WAIVES ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED HEREBY.

Section 9.12.USA Patriot Act. Each Lender hereby notifies the Borrower that pursuant to the requirements of the USA Patriot Act, Title III of Pub. L. 107-56 (signed into law October 26, 2001) (the “Act”), it is required to obtain, verify and record information that identifies the Borrower, which information includes the name and address of the Borrower and other information that will allow such Lender to identify the Borrower in accordance with the Act.

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Section 9.13.[Reserved].

Section 9.14.No Fiduciary Duty. The Borrower agrees that in connection with all aspects of the Loans contemplated by this Agreement and any communications in connection therewith, the Borrower and its Subsidiaries, on the one hand, and the Administrative Agent, the Lenders and their respective affiliates, on the other hand, will have a business relationship that does not create, by implication or otherwise, any fiduciary duty on the part of the Administrative Agent, the Lenders or their respective affiliates, and no such duty will be deemed to have arisen in connection with any such transactions or communications.

Section 9.15.Survival. Each party’s rights and obligations under Articles 7, 8 and 9 shall survive the resignation or replacement of the Administrative Agent or any assignment of rights by, or the replacement of, a Lender, the termination of the Commitments and the repayment, satisfaction or discharge of all obligations hereunder or under any Note.

Section 9.16.Acknowledgment and Consent to Bail-In of EEA Financial Institutions. Notwithstanding anything to the contrary in any Loan Document or in any other agreement, arrangement or understanding among any such parties, each party hereto acknowledges that any liability of any EEA Financial Institution arising under any Loan Document, to the extent such liability is unsecured, may be subject to the write-down and conversion powers of an EEA Resolution Authority and agrees and consents to, and acknowledges and agrees to be bound by:

(a)    the application of any Write-Down and Conversion Powers by an EEA Resolution Authority to any such liabilities arising hereunder which may be payable to it by any party hereto that is an EEA Financial Institution; and

(b)    the effects of any Bail-in Action on any such liability, including, if applicable:

(i)    a reduction in full or in part or cancellation of any such liability;

(ii)    a conversion of all, or a portion of, such liability into shares or other instruments of ownership in such EEA Financial Institution, its parent undertaking, or a bridge institution that may be issued to it or otherwise conferred on it, and that such shares or other instruments of ownership will be accepted by it in lieu of any rights with respect to any such liability under this Agreement or any other Loan Document; or

(iii)    the variation of the terms of such liability in connection with the exercise of the write-down and conversion powers of any EEA Resolution Authority.

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COMMITMENT SCHEDULE

Lender	Total Commitments
The Bank of Tokyo-Mitsubishi UFJ, Ltd.	$500,000,000
Santander Bank, N.A.	$375,000,000
TD Bank, N.A.	$375,000,000
U.S. Bank National Association	$250,000,000

Pricing Schedule

“Applicable Margin” means, for any date, the rate set forth below in the applicable row and column corresponding to the credit rating of the Borrower that exists on such date:

(basis points per annum)

Borrower’s Credit Rating	at least A- by S&P or A3 by Moody’s	at least BBB+ by S&P or Baa1 by Moody’s	less than BBB+ by S&P or Baa1 by Moody’s
Euro-Dollar Loans	75.0	87.5	100.0

For purposes of the above Pricing Schedule a “Borrower Credit Rating” means, as of any date of determination with respect to the Borrower, the rating asdetermined by one or more of Standard & Poor’s Financial Services LLC, together with its successors (“S&P”) or Moody’s Investors Service, together with its successors (“Moody’s”), of the Borrower’s non-credit-enhanced, senior unsecured long-term debt, regardless of whether any such debt is outstanding; provided that (a) if the two ratings differ by one level, then the pricing level for the higher of such ratings shall apply; (b) if the two ratings differ by more than one level, then the pricing level that is one level lower than the pricing level of the higher rating shall apply; (c) if only one rating exists, the pricing level shall be determined based on that rating; and (d) if no such rating exists for the Borrower, the highest pricing level (less than “BBB+” pricing level) shall apply. A change in rating will result in an immediate change in the applicable pricing.

54

EXHIBIT A

NOTE

New York, New York

______ __, 20__

For value received, Duke Energy Corporation., a Delaware corporation (the “Borrower”), promises to pay to [ ] (the “Lender”) or its registered assigns, for the account of its Applicable Lending Office, the unpaid principal amount of each Loan made by the Lender to the Borrower pursuant to the Credit Agreement referred to below on the date specified in the Credit Agreement. The Borrower promises to pay interest on the unpaid principal amount of each such Loan on the dates and at the rate or rates provided for in the Credit Agreement. All such payments of principal and interest shall be made in lawful money of the United States in Federal or other immediately available funds at the office of The Bank of Tokyo-Mitsubishi UFJ, Ltd..

All Loans made by the Lender, the respective types and maturities thereof and all repayments of the principal thereof shall be recorded by the Lender, and the Lender, if the Lender so elects in connection with any transfer or enforcement of its Note, may endorse on the schedule attached hereto appropriate notations to evidence the foregoing information with respect to the Loans then outstanding; provided that the failure of the Lender to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement.

This note is one of the Notes referred to in the Amended and Restated Term Loan Credit Agreement dated as of August 1, 2016 among Duke Energy Corporation, the Lenders party thereto and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Administrative Agent (as the same may be amended from time to time, the “Credit Agreement”). Terms defined in the Credit Agreement are used herein with the same meanings. Reference is made to the Credit Agreement for provisions for the prepayment hereof and the acceleration of the maturity hereof.

A-1

DUKE ENERGY CORPORATION
By:
	Title:

A-2

Note (cont’d)

LOANS AND PAYMENTS OF PRINCIPAL

Date Amount of Loan Type of Loan Amount of Principal Repaid Maturity Date Notation Made By

A-3

EXHIBIT B

OPINION OF INTERNAL COUNSEL OF THE BORROWER

[Effective Date]

To the Lenders and the Administrative Agent
Referred to Below

c/o The Bank of Tokyo-Mitsubishi UFJ, Ltd.
as Administrative Agent

1221 Avenue of the Americas

New York, NY 10020

Attn: _________________________

Ladies and Gentlemen:

I am Assistant Secretary of Duke Energy Corporation (the “Borrower”) and have acted as its counsel in connection with the Amended and Restated Term Loan Credit Agreement (the “Credit Agreement”), dated as of August 1, 2016, among the Borrower, the Lenders party thereto and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Administrative Agent. Capitalized terms defined in the Credit Agreement are used herein as therein defined. This opinion letter is being delivered pursuant to Section 3.01(b) of the Credit Agreement.

In such capacity, I or attorneys under my direct supervision have examined originals or copies, certified or otherwise identified to my satisfaction, of such documents, corporate records, certificates of public officials and other instruments and have conducted such other investigations of fact and law as I have deemed necessary or advisable for purposes of this opinion.

Upon the basis of the foregoing, I am of the opinion that:

1.    The Borrower is a Delaware corporation.

2.    The execution, delivery and performance by the Borrower of the Credit Agreement and any Notes are within the Borrower’s corporate powers, have been duly authorized by all necessary corporate action, require no action by or in respect of, or filing with, any governmental body, agency or official, which have been obtained or made, as the case may be, and are in full force and effect) and do not contravene, or constitute a default under, any provision of applicable law or regulation or of the articles of incorporation or by-laws of the Borrower or, to my knowledge, of any material

B-1

To the Lenders and the Administrative Agent

August [_], 2016

Page 2

agreement, judgment, injunction, order, decree or other instrument binding upon the Borrower or, to my knowledge, result in the creation or imposition of any Lien on any asset of the Borrower or any of its Material Subsidiaries.

3.    The Credit Agreement and any Notes executed and delivered as of the date hereof have been duly executed and delivered by the Borrower.

4.    Except as publicly disclosed prior to the Effective Date, to my knowledge (but without independent investigation), there is no action, suit or proceeding pending or threatened against or affecting, the Borrower or any of its Subsidiaries before any court or arbitrator or any governmental body, agency or official, which would be likely to be decided adversely to the Borrower or such Subsidiary and, as a result, to have a material adverse effect upon the business, consolidated financial position or consolidated results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or which in any manner draws into question the validity of the Credit Agreement or any Notes.

The phrase “to my knowledge”, as used in the foregoing opinion, refers to my actual knowledge without any independent investigation as to any such matters.

The opinions set forth in paragraphs 1 – 3 above are limited to matters governed by the Delaware General Corporation Law (“DGCL”), provided that I do not express any opinion as to any judicial decisions construing the DGCL or on any other matters of Delaware law other than the text of the DGCL. No opinion is expressed herein with respect to such opinions as to any other laws, including the laws of any other jurisdiction. I express no opinion concerning any matter respecting or affected by any laws other than laws that a lawyer in North Carolina exercising customary professional diligence would reasonably recognize as being directly applicable to the Borrower.

The opinions expressed herein are limited to the matters expressly stated herein, and no opinion is to be inferred or may be implied beyond the matters expressly so stated. This opinion is rendered to you in connection with the above-referenced matter and may not be relied upon by you for any other purpose, or relied upon by, or furnished to, any other Person, firm or corporation without my prior written consent, except for Assignees. My opinions expressed herein are as of the date hereof, and I undertake no obligation to advise you of any changes of applicable law or any other matters that may come to my attention after the date hereof that may affect my opinions expressed herein.

Very truly yours,

B-2

EXHIBIT C

OPINION OFROBINSON, BRADSHAW & HINSON, P.A.,
SPECIAL COUNSEL FOR THE BORROWER

[Effective Date]

To the Lenders and the Administrative Agent
Referred to Below

c/o The Bank of Tokyo-Mitsubishi UFJ, Ltd.
as Administrative Agent

1221 Avenue of the Americas

New York, NY 10020

Attn: ______________________________

Ladies and Gentlemen:

We have acted as counsel to Duke Energy Corporation, a Delaware corporation (the “Borrower”), in connection with the Amended and Restated Term Loan Credit Agreement (the “Credit Agreement”), dated as of August 1, 2016, among the Borrower, the Lenders party thereto and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Administrative Agent. Capitalized terms used herein and not defined shall have the meanings given to them in the Credit Agreement. This opinion letter is being delivered pursuant to Section 3.01(b)(ii) of the Credit Agreement.

In connection with this opinion, we also examined originals, or copies identified to our satisfaction, of such other documents and considered such matters of law and fact as we, in our professional judgment, have deemed appropriate to render the opinions contained herein. Where we have considered it appropriate, as to certain facts we have relied, without investigation or analysis of any underlying data contained therein, upon certificates or other comparable documents of public officials and officers or other appropriate representatives of the Borrower.

In rendering the opinions contained herein, we have assumed, among other things, that the Credit Agreement and any Notes to be executed (i) are within the Borrower’s corporate powers, (ii) have been duly authorized by all necessary corporate action, (iii) have been duly executed and delivered, (iv) require no action by or in respect of, or filing with, any governmental body, agency of official and (v) do not contravene, or constitute a default under, any provision of applicable law or regulation or of the Borrower’s certificate of incorporation or by-laws or any agreement, judgment, injunction, order, decree or other instrument binding upon the Borrower or result in the creation or imposition of any Lien on

C-1

To the Lenders and the Administrative Agent

August [_], 2016

Page 2

any asset of the Borrower. In addition, we have assumed that the Credit Agreement fully states the agreement between the Borrower and the Lenders with respect to the matters addressed therein, and that the Credit Agreement constitutes a legal, valid and binding obligation of each Lender, enforceable in accordance with its respective terms.

The opinions set forth herein are limited to matters governed by the laws of the State of North Carolina and the federal laws of the United States, and no opinion is expressed herein as to the laws of any other jurisdiction. For purposes of our opinions, we have disregarded the choice of law provisions in the Credit Agreement and, instead, have assumed with your permission that the Credit Agreement and the Notes are governed exclusively by the internal, substantive laws and judicial interpretations of the State of North Carolina. We express no opinion concerning any matter respecting or affected by any laws other than laws that a lawyer in North Carolina exercising customary professional diligence would reasonably recognize as being directly applicable to the Borrower, the Loans, or any of them.

Based upon and subject to the foregoing and the further limitations and qualifications hereinafter expressed, it is our opinion that the Credit Agreement constitutes the legal, valid and binding obligation of the Borrower and the Notes, if and when issued, will constitute legal, valid and binding obligations of the Borrower, in each case, enforceable against the Borrower in accordance with its terms.

The opinions expressed above are subject to the following qualifications and limitations:

1.     Enforcement of the Credit Agreement and the Notes is subject to the effect of applicable bankruptcy, insolvency, reorganization, fraudulent conveyance, moratorium and similar laws affecting the enforcement of creditors’ rights generally.

2.    Enforcement of the Credit Agreement and the Notes is subject to the effect of general principles of equity (regardless of whether considered in a proceeding in equity or at law) by which a court with proper jurisdiction may deny rights of specific performance, injunction, self-help, possessory remedies or other remedies.

3.    We do not express any opinion as to the enforceability of any provisions contained in the Credit Agreement or any Note that (i) purport to excuse a party for liability for its own acts, (ii) purport to make void any act done in contravention thereof, (iii) purport to authorize a party to act in its sole discretion, (iv) require waivers or amendments to be made only in writing, (v) purport to effect waivers of constitutional, statutory or equitable rights or the effect of applicable laws, (vi) impose liquidated damages, penalties or forfeiture, or (vii) purport to indemnify a party for its own negligence or willful misconduct. Indemnification provisions in the Credit Agreement are subject to and may be rendered unenforceable by applicable law or public policy, including applicable securities law.

4.    We do not express any opinion as to the enforceability of any provisions contained in the Credit Agreement or the Notes purporting to require a party thereto to pay or reimburse attorneys’ fees incurred by another party, or to indemnify another party therefor,

C-2

To the Lenders and the Administrative Agent

August [_], 2016

Page 3

which may be limited by applicable statutes and decisions relating to the collection and award of attorneys’ fees, including but not limited to North Carolina General Statutes §§ 6-21.2 and 6-21.6.

5.    We do not express any opinion as to the enforceability of any provisions contained in the Credit Agreement purporting to waive the right of jury trial. Under North Carolina General Statutes § 22B-10, a provision for the waiver of the right to a jury trial is unconscionable and unenforceable.

6.    We do not express any opinion as to the enforceability of any provisions contained in the Credit Agreement concerning choice of forum or consent to the jurisdiction of courts, venue of actions or means of service of process.

7.    It is likely that North Carolina courts will enforce the provisions of the Credit Agreement providing for interest at a higher rate resulting from a Default or Event of Default (a “Default Rate”) which rate is higher than the rate otherwise stipulated in the Credit Agreement. The law, however, disfavors penalties, and it is possible that interest at the Default Rate may be held to be an unenforceable penalty, to the extent such rate exceeds the rate applicable prior to a default under the Credit Agreement.

8.    We do not express any opinion as to the enforceability of any provisions contained in the Credit Agreement relating to evidentiary standards or other standards by which the Credit Agreement are to be construed.

This opinion letter is delivered solely for your benefit in connection with the Credit Agreement and, except for any Assignee which becomes a Lender pursuant to Section 8.06 or Section 9.06(c) of the Credit Agreement, may not be used or relied upon by any other Person or for any other purpose without our prior written consent in each instance. Our opinions expressed herein are as of the date hereof, and we undertake no obligation to advise you of any changes of applicable law or any other matters that may come to our attention after the date hereof that may affect our opinions expressed herein.

Very truly yours,

C-3

EXHIBIT D

ASSIGNMENT AND ASSUMPTION AGREEMENT

AGREEMENT dated as of _________, 20__ among [ASSIGNOR] (the “Assignor”), [ASSIGNEE] (the “Assignee”), [DUKE ENERGY CORPORATION] and THE BANK OF TOKYO-MITSUBISHI UFJ, LTD., as Administrative Agent (the “Administrative Agent”).

WITNESSETH

WHEREAS, this Assignment and Assumption Agreement (the “Agreement”) relates to the Amended and Restated Term Loan Credit Agreement dated as of August 1, 2016 among Duke Energy Corporation, the Assignor and the other Lenders party thereto, as Lenders and the Administrative Agent (the “Credit Agreement”);

WHEREAS, as provided under the Credit Agreement, the Assignor has a Commitment to make Loans to the Borrower in an aggregate principal amount at any time outstanding not to exceed $__________;

WHEREAS, Loans made to the Borrower by the Assignor under the Credit Agreement in the aggregate principal amount of $__________ are outstanding at the date hereof; and

WHEREAS, the Assignor proposes to assign to the Assignee all of the rights of the Assignor under the Credit Agreement in respect of a portion of its [Commitment /outstanding Loan] thereunder in an amount equal to $__________ (the “Assigned Amount”), and the Assignee proposes to accept assignment of such rights and assume the corresponding obligations from the Assignor on such terms;*

NOW, THEREFORE, in consideration of the foregoing and the mutual agreements contained herein, the parties hereto agree as follows:

SECTION 1.    Definitions. All capitalized terms not otherwise defined herein shall have the respective meanings set forth in the Credit Agreement.

SECTION 2.    Assignment. The Assignor hereby assigns and sells to the Assignee all of the rights of the Assignor under the Credit Agreement to the extent of the Assigned Amount, and the Assignee hereby accepts such assignment from the Assignor and assumes all of the obligations of the Assignor under the Credit Agreement to the extent of the Assigned Amount, including the purchase from the Assignor of the corresponding portion of the principal amount of the Loans made by the Assignor outstanding at the date hereof. Upon the execution and delivery hereof by the Assignor, the Assignee [, Duke Energy Corporation] and the Administrative Agent, and the payment of the amounts specified in Section 3 required to be paid on the date hereof (i) the Assignee shall, as of the date hereof, succeed to the rights and be obligated to perform the obligations of a

D-1

Lender under the Credit Agreement with a Commitment in an amount equal to the Assigned Amount, and (ii) the Commitment of the Assignor shall, as of the date hereof, be reduced by a like amount and the Assignor released from its obligations under the Credit Agreement to the extent such obligations have been assumed by the Assignee. The assignment provided for herein shall be without recourse to the Assignor.

SECTION 3.    Payments. As consideration for the assignment and sale contemplated in Section 2 hereof, the Assignee shall pay to the Assignor on the date hereof in Federal funds the amount heretofore agreed between them. Each of the Assignor and the Assignee hereby agrees that if it receives any amount under the Credit Agreement which is for the account of the other party hereto, it shall receive the same for the account of such other party to the extent of such other party’s interest therein and shall promptly pay the same to such other party.

SECTION 4.    Consent to Assignment. This Agreement is conditioned upon the consent of [Duke Energy Corporation,] and the Administrative Agent pursuant to Section 9.06(c) of the Credit Agreement. The execution of this Agreement by [Duke Energy Corporation,] and the Administrative Agent is evidence of this consent. Pursuant to Section 9.06(c) the Borrower agrees to execute and deliver a Note, if required by the Assignee, payable to the order of the Assignee to evidence the assignment and assumption provided for herein.

SECTION 5.    Non-reliance on Assignor. The Assignor makes no representation or warranty in connection with, and shall have no responsibility with respect to, the solvency, financial condition, or statements of the Borrower, or the validity and enforceability of the obligations of the Borrower in respect of the Credit Agreement or any Note. The Assignee acknowledges that it has, independently and without reliance on the Assignor, and based on such documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Agreement and will continue to be responsible for making its own independent appraisal of the business, affairs and financial condition of the Borrower.

SECTION 6.    Governing Law. This Agreement shall be governed by and construed in accordance with the laws of the State of New York.

SECTION 7.    Counterparts. This Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument.

SECTION 8.    Administrative Questionnaire. Attached is an Administrative Questionnaire duly completed by the Assignee.

D-2

IN WITNESS WHEREOF, the parties have caused this Agreement to be executed and delivered by their duly authorized officers as of the date first above written.

[ASSIGNOR]
By:
	Title:

[ASSIGNEE]
By:
	Title:

[DUKE ENERGY CORPORATION]
By:
	Title:

[THE BANK OF TOKYO-MITSUBISHI UFJ, LTD.] as Administrative Agent
By:
	Title:

D-3

EX-12

EXHIBIT 12

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES - DUKE ENERGY CORPORATION

The ratio of earnings to fixed charges is calculated using the Securities and Exchange Commission guidelines.

	Six Months Ended June 30,		Years Ended December 31,
(in millions)	2016		2015		2014		2013		2012 (a)		2011
Earnings as defined for fixed charges calculation
Add:
Pretax income from continuing operations(b)	$	1,630	$	4,053	$	3,998	$	3,657	$	2,068	$	1,975
Fixed charges	1,071		1,859		1,871		1,886		1,510		1,057
Distributed income of equity investees	18		104		136		109		151		149
Deduct:
Preferred dividend requirements of subsidiaries	—		—		—		—		3		—
Interest capitalized	8		18		7		8		30		46
Total earnings	$	2,711	$	5,998	$	5,998	$	5,644	$	3,696	$	3,135
Fixed charges:
Interest on debt, including capitalized portions	$	1,039	$	1,733	$	1,733	$	1,760	$	1,420	$	1,026
Estimate of interest within rental expense	32		126		138		126		87		31
Preferred dividend requirements	—		—		—		—		3		—
Total fixed charges	$	1,071	$	1,859	$	1,871	$	1,886	$	1,510	$	1,057
Ratio of earnings to fixed charges	2.5		3.2		3.2		3.0		2.4		3.0
Ratio of earnings to fixed charges and preferred dividends combined(c)	2.5		3.2		3.2		3.0		2.4		3.0

(a)    Includes the results of Progress Energy, Inc. beginning on July 2, 2012.

(b)    Excludes amounts attributable to noncontrolling interests and income or loss from equity investees.

(c)    For the periods presented, Duke Energy Corporation had no preferred stock outstanding.

EX-31.1.1

EXHIBIT 31.1.1

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Corporation;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ LYNN J. GOOD

Lynn J. Good

Chairman, President and

Chief Executive Officer

EX-31.1.2

EXHIBIT 31.1.2

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Carolinas, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.3

EXHIBIT 31.1.3

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Progress Energy, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.4

EXHIBIT 31.1.4

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Progress, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.5

EXHIBIT 31.1.5

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Florida, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.6

EXHIBIT 31.1.6

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Ohio, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.7

EXHIBIT 31.1.7

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Indiana, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.2.1

EXHIBIT 31.2.1

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Corporation;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.2

EXHIBIT 31.2.2

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Carolinas, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.3

EXHIBIT 31.2.3

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Progress Energy, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer 

EX-31.2.4

EXHIBIT 31.2.4

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Progress, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.5

EXHIBIT 31.2.5

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Florida, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.6

EXHIBIT 31.2.6

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Ohio, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.7

EXHIBIT 31.2.7

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Indiana, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 4, 2016

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-32.1.1

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Corporation (“Duke Energy”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chairman, President and Chief Executive Officer of Duke Energy, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy.

/s/ LYNN J. GOOD

Lynn J. Good

Chairman, President and

Chief Executive Officer

August 4, 2016

EX-32.1.2

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Carolinas, LLC (“Duke Energy Carolinas”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Carolinas, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Carolinas.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

August 4, 2016

EX-32.1.3

EXHIBIT 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

In connection with the Quarterly Report of Progress Energy, Inc. (“Progress Energy”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Progress Energy, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Progress Energy.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

August 4, 2016

EX-32.1.4

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Progress, LLC (“Duke Energy Progress”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Progress, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Progress.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

August 4, 2016

EX-32.1.5

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Florida, LLC (“Duke Energy Florida”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Florida, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Florida.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

August 4, 2016

EX-32.1.6

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Ohio, Inc. (“Duke Energy Ohio”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Ohio, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Ohio.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

August 4, 2016

EX-32.1.7

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Indiana, LLC (“Duke Energy Indiana”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Indiana, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Indiana.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

August 4, 2016

EX-32.2.1

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Corporation (“Duke Energy”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

August 4, 2016

EX-32.2.2

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Carolinas, LLC (“Duke Energy Carolinas”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Carolinas, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Carolinas.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

August 4, 2016

EX-32.2.3

EXHIBIT 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

In connection with the Quarterly Report of Progress Energy, Inc. (“Progress Energy”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Progress Energy, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Progress Energy.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

August 4, 2016

EX-32.2.4

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Progress, LLC (“Duke Energy Progress”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Progress, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Progress.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

August 4, 2016

EX-32.2.5

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Florida, LLC (“Duke Energy Florida”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Florida, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Florida.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

August 4, 2016

EX-32.2.6

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Ohio, Inc. (“Duke Energy Ohio”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Ohio, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Ohio.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

August 4, 2016

EX-32.2.7

EXHIBIT 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

In connection with the Quarterly Report of Duke Energy Indiana, LLC (“Duke Energy Indiana”) on Form 10-Q for the period ending June 30, 2016 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Indiana, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Indiana.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

August 4, 2016

XML

Document and Entity Information	6 Months Ended
	Jun. 30, 2016 shares
Document Information [Line Items]
Entity Registrant Name	Duke Energy Corporation
Entity Central Index Key	0001326160
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding	688,933,508
Duke Energy Carolinas [Member]
Document Information [Line Items]
Entity Registrant Name	Duke Energy Carolinas, LLC
Entity Central Index Key	0000030371
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Progress Energy [Member]
Document Information [Line Items]
Entity Registrant Name	Progress Energy, Inc
Entity Central Index Key	0001094093
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Duke Energy Progress [Member]
Document Information [Line Items]
Entity Registrant Name	Duke Energy Progress, LLC
Entity Central Index Key	0000017797
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Duke Energy Florida [Member]
Document Information [Line Items]
Entity Registrant Name	Duke Energy Florida, LLC
Entity Central Index Key	0000037637
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Duke Energy Ohio [Member]
Document Information [Line Items]
Entity Registrant Name	Duke Energy Ohio, Inc.
Entity Central Index Key	0000020290
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Duke Energy Indiana [Member]
Document Information [Line Items]
Entity Registrant Name	Duke Energy Indiana, LLC
Entity Central Index Key	0000081020
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

XML

Condensed Consolidated Statements of Operations and Comprehensive Income - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Operating Revenues
Regulated electric	$ 4,965	$ 5,090	$ 10,018	$ 10,547
Nonregulated electric and other	422	403	822	780
Regulated natural gas	97	96	266	327
Total operating revenues	5,484	5,589	11,106	11,654
Operating Expenses
Fuel used in electric generation and purchased power – regulated	1,509	1,721	3,086	3,662
Fuel used in electric generation and purchased power – nonregulated	82	118	140	222
Cost of natural gas	21	26	81	137
Operation, maintenance and other	1,431	1,422	2,920	2,848
Depreciation and amortization	813	790	1,627	1,567
Property and other taxes	293	279	590	543
Impairment charges	195		198
Total operating expenses	4,344	4,356	8,642	8,979
Gains on Sales of Other Assets and Other, net	5	13	14	27
Operating Income	1,145	1,246	2,478	2,702
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	15	23	23	36
Other income and expenses, net	92	72	171	146
Total other income and expenses	107	95	194	182
Interest Expense	500	403	1,011	806
Income From Continuing Operations Before Income Taxes	752	938	1,661	2,078
Income Tax Expense from Continuing Operations	239	334	452	698
Income from Continuing Operations	513	604	1,209	1,380
(Loss) Income From Discontinued Operations, net of tax	(1)	(57)	2	34
Net income	512	547	1,211	1,414
Less: Net Income Attributable to Noncontrolling Interests	3	4	8	7
Net Income (Loss) Attributable to Parent	509	543	1,203	1,407
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments	2	7	2	2
Reclassification into earnings from cash flow hedges		1	2	5
Unrealized (losses) gains on available-for-sale securities	3	(3)	7	(3)
Other Comprehensive Income, net of tax	52	23	93	(110)
Comprehensive Income	564	570	1,304	1,304
Less: Comprehensive Income Attributable to Noncontrolling Interests	6	3	12	2
Comprehensive Income Attributable to Parent	$ 558	$ 567	$ 1,292	$ 1,302
Income from continuing operations attributable to Duke Energy Corporation common stockholders
Basic (usd per share)	$ 0.74	$ 0.87	$ 1.74	$ 1.96
Diluted (usd per share)	0.74	0.87	1.74	1.96
(Loss) Income from discontinued operations attributable to Duke Energy Corporation common stockholders
Basic (usd per share)		(0.09)		0.05
Diluted (usd per share)		(0.09)		0.05
Net income attributable to Duke Energy Corporation common stockholders
Basic (usd per share)	0.74	0.78	1.74	2.01
Diluted (usd per share)	$ 0.74	$ 0.78	$ 1.74	$ 2.01
Weighted average shares outstanding
Basic (shares)	689	692	689	700
Diluted (shares)	690	692	689	700
Duke Energy Carolinas [Member]
Operating Revenues
Total operating revenues	$ 1,675	$ 1,707	$ 3,415	$ 3,608
Operating Expenses
Fuel used in electric generation and purchased power – regulated	389	427	810	1,005
Operation, maintenance and other	476	469	988	958
Depreciation and amortization	275	261	534	510
Property and other taxes	71	67	138	137
Total operating expenses	1,211	1,224	2,470	2,610
Operating Income	464	483	945	998
Other Income and Expenses
Other income and expenses, net	45	41	82	83
Interest Expense	107	106	214	208
Income From Continuing Operations Before Income Taxes	402	418	813	873
Income Tax Expense from Continuing Operations	141	153	281	316
Net Income (Loss) Attributable to Parent	261	265	532	557
Other Comprehensive Income (Loss), net of tax
Reclassification into earnings from cash flow hedges			1
Other Comprehensive Income, net of tax			1
Comprehensive Income Attributable to Parent	261	265	533	557
Progress Energy [Member]
Operating Revenues
Total operating revenues	2,348	2,476	4,680	5,012
Operating Expenses
Fuel used in electric generation and purchased power – regulated	852	1,003	1,712	2,035
Operation, maintenance and other	525	568	1,117	1,133
Depreciation and amortization	296	283	586	570
Property and other taxes	120	124	239	235
Impairment charges	1		3
Total operating expenses	1,794	1,978	3,657	3,973
Gains on Sales of Other Assets and Other, net	6	6	12	14
Operating Income	560	504	1,035	1,053
Other Income and Expenses
Other income and expenses, net	28	19	48	46
Interest Expense	160	166	320	334
Income From Continuing Operations Before Income Taxes	428	357	763	765
Income Tax Expense from Continuing Operations	154	140	277	284
Income from Continuing Operations	274	217	486	481
(Loss) Income From Discontinued Operations, net of tax				(1)
Net income	274	217	486	480
Less: Net Income Attributable to Noncontrolling Interests	2	2	5	5
Net Income (Loss) Attributable to Parent	272	215	481	475
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments	1	1	2	2
Reclassification into earnings from cash flow hedges	2	1	3	(1)
Unrealized (losses) gains on available-for-sale securities		(1)	1	(1)
Other Comprehensive Income, net of tax	3	1	6
Comprehensive Income	277	218	492	480
Less: Comprehensive Income Attributable to Noncontrolling Interests	2	2	5	5
Comprehensive Income Attributable to Parent	275	216	487	475
Duke Energy Progress [Member]
Operating Revenues
Total operating revenues	1,213	1,193	2,520	2,642
Operating Expenses
Fuel used in electric generation and purchased power – regulated	424	449	872	1,024
Operation, maintenance and other	321	362	707	737
Depreciation and amortization	175	163	350	315
Property and other taxes	38	35	79	67
Total operating expenses	958	1,009	2,008	2,143
Gains on Sales of Other Assets and Other, net			1	1
Operating Income	255	184	513	500
Other Income and Expenses
Other income and expenses, net	12	15	29	35
Interest Expense	64	56	127	116
Income From Continuing Operations Before Income Taxes	203	143	415	419
Income Tax Expense from Continuing Operations	72	58	147	151
Net Income (Loss) Attributable to Parent	131	85	268	268
Duke Energy Florida [Member]
Operating Revenues
Total operating revenues	1,133	1,281	2,157	2,367
Operating Expenses
Fuel used in electric generation and purchased power – regulated	429	554	841	1,011
Operation, maintenance and other	199	202	404	390
Depreciation and amortization	122	122	236	256
Property and other taxes	82	88	160	168
Impairment charges	1		3
Total operating expenses	833	966	1,644	1,825
Operating Income	300	315	513	542
Other Income and Expenses
Other income and expenses, net	14	4	19	10
Interest Expense	40	50	81	99
Income From Continuing Operations Before Income Taxes	274	269	451	453
Income Tax Expense from Continuing Operations	103	104	170	175
Net Income (Loss) Attributable to Parent	171	165	281	278
Other Comprehensive Income (Loss), net of tax
Unrealized (losses) gains on available-for-sale securities			1
Other Comprehensive Income, net of tax			1
Comprehensive Income Attributable to Parent	171	165	282	278
Duke Energy Ohio [Member]
Operating Revenues
Regulated electric	323	299	663	638
Nonregulated electric and other	6	9	12	23
Regulated natural gas	99	97	269	330
Total operating revenues	428	405	944	991
Operating Expenses
Fuel used in electric generation and purchased power – regulated	100	107	211	222
Fuel used in electric generation and purchased power – nonregulated	13	12	23	26
Cost of natural gas	9	12	58	109
Operation, maintenance and other	122	118	241	246
Depreciation and amortization	64	58	125	115
Property and other taxes	65	57	136	127
Total operating expenses	373	364	794	845
Gains on Sales of Other Assets and Other, net		2	1	8
Operating Income	55	43	151	154
Other Income and Expenses
Other income and expenses, net	1	(5)	3	(2)
Interest Expense	21	18	41	38
Income From Continuing Operations Before Income Taxes	35	20	113	114
Income Tax Expense from Continuing Operations	12	7	33	42
Income from Continuing Operations	23	13	80	72
(Loss) Income From Discontinued Operations, net of tax		(65)	2	25
Net Income (Loss) Attributable to Parent	23	(52)	82	97
Duke Energy Indiana [Member]
Operating Revenues
Total operating revenues	702	686	1,416	1,474
Operating Expenses
Fuel used in electric generation and purchased power – regulated	220	235	448	529
Operation, maintenance and other	189	180	351	361
Depreciation and amortization	97	107	222	211
Property and other taxes	22	19	45	18
Total operating expenses	528	541	1,066	1,119
Gains on Sales of Other Assets and Other, net		1		1
Operating Income	174	146	350	356
Other Income and Expenses
Other income and expenses, net	6	4	10	9
Interest Expense	47	43	91	88
Income From Continuing Operations Before Income Taxes	133	107	269	277
Income Tax Expense from Continuing Operations	48	39	89	101
Net Income (Loss) Attributable to Parent	85	68	180	176
Other Comprehensive Income (Loss), net of tax
Reclassification into earnings from cash flow hedges			(1)	(1)
Other Comprehensive Income, net of tax			(1)	(1)
Comprehensive Income Attributable to Parent	$ 85	$ 68	$ 179	$ 175

XML

Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest [Abstract]
Net income (loss)	$ 512	$ 547	$ 1,211	$ 1,414
Other Comprehensive Income (Loss), net of tax
Foreign currency translation adjustments	58	9	107	(116)
Pension and OPEB adjustments	2	7	2	2
Net unrealized (losses) gains on cash flow hedges	(11)	9	(25)	2
Reclassification into earnings from cash flow hedges		1	2	5
Unrealized gains (losses) on available-for-sale securities	3	(3)	7	(3)
Other Comprehensive Income (Loss), net of tax	52	23	93	(110)
Comprehensive Income	564	570	1,304	1,304
Less: Comprehensive Income Attributable to Noncontrolling Interests	6	3	12	2
Comprehensive Income Attributable to Parent	$ 558	$ 567	$ 1,292	$ 1,302

XML

Condensed Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents	$ 676	$ 857
Receivables (net of allowance for doubtful accounts)	575	703
Receivables of VIEs (net of allowance for doubtful accounts)	1,943	1,748
Inventory	3,627	3,810
Regulatory assets	825	877
Other	451	327
Total current assets	8,097	8,322
Investments and Other Assets
Investments in equity method unconsolidated affiliates	613	499
Nuclear decommissioning trust funds	5,966	5,825
Goodwill	16,357	16,343
Other	2,972	3,042
Total investments and other assets	25,908	25,709
Property, Plant and Equipment
Cost	115,143	112,826
Accumulated depreciation and amortization	(38,412)	(37,665)
Generation facilities to be retired, net	598	548
Net property, plant and equipment	77,329	75,709
Regulatory Assets and Deferred Debits
Regulatory assets	11,290	11,373
Other	30	43
Total regulatory assets and deferred debits	11,320	11,416
Total Assets	122,654	121,156
Current Liabilities
Accounts payable	2,221	2,400
Notes payable and commercial paper	2,312	3,633
Taxes accrued	467	348
Interest accrued	448	430
Current maturities of long-term debt	2,342	2,074
Regulatory liabilities	332	400
Other	1,784	2,115
Total current liabilities	9,906	11,400
Long-Term Debt	39,931	37,495
Deferred Credits and Other Liabilities
Deferred income taxes	13,038	12,705
Investment tax credits	492	472
Accrued pension and other post-retirement benefit costs	1,044	1,088
Asset retirement obligations	10,231	10,264
Regulatory liabilities	6,334	6,255
Other	1,730	1,706
Total deferred credits and other liabilities	32,869	32,490
Commitments and Contingencies
Equity
Common stock	1	1
Additional paid-in capital	37,984	37,968
Retained earnings	2,627	2,564
Accumulated other comprehensive income (loss)	(717)	(806)
Total Duke Energy Corporation stockholders' equity	39,895	39,727
Noncontrolling interests	53	44
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	39,948	39,771
Total Liabilities and Equity	122,654	121,156
Duke Energy Carolinas [Member]
Current Assets
Cash and cash equivalents	16	13
Receivables (net of allowance for doubtful accounts)	112	142
Receivables of VIEs (net of allowance for doubtful accounts)	696	596
Receivables from affiliated companies	71	107
Notes receivable from affiliated companies	252	163
Inventory	1,169	1,276
Regulatory assets	262	305
Other	86	128
Total current assets	2,664	2,730
Investments and Other Assets
Nuclear decommissioning trust funds	3,133	3,050
Other	916	999
Total investments and other assets	4,049	4,049
Property, Plant and Equipment
Cost	40,285	39,398
Accumulated depreciation and amortization	(13,880)	(13,521)
Net property, plant and equipment	26,405	25,877
Regulatory Assets and Deferred Debits
Regulatory assets	2,856	2,766
Other	3	4
Total regulatory assets and deferred debits	2,859	2,770
Total Assets	35,977	35,426
Current Liabilities
Accounts payable	565	753
Accounts payable to affiliated companies	173	229
Taxes accrued	137	25
Interest accrued	108	95
Current maturities of long-term debt	468	356
Regulatory liabilities	91	39
Other	400	519
Total current liabilities	1,942	2,016
Long-Term Debt	8,592	7,711
Long-Term Debt Payable to Affiliated Companies	300	300
Deferred Credits and Other Liabilities
Deferred income taxes	6,472	6,146
Investment tax credits	196	199
Accrued pension and other post-retirement benefit costs	96	107
Asset retirement obligations	3,910	3,918
Regulatory liabilities	2,885	2,802
Other	645	621
Total deferred credits and other liabilities	14,204	13,793
Commitments and Contingencies
Equity
Member's equity	10,949	11,617
Accumulated other comprehensive income (loss)	(10)	(11)
Members' Equity	10,939	11,606
Total Liabilities and Equity	35,977	35,426
Progress Energy [Member]
Current Assets
Cash and cash equivalents	34	44
Receivables (net of allowance for doubtful accounts)	100	151
Receivables of VIEs (net of allowance for doubtful accounts)	776	658
Receivables from affiliated companies	11	375
Inventory	1,725	1,751
Regulatory assets	322	362
Other	168	156
Total current assets	3,136	3,497
Investments and Other Assets
Nuclear decommissioning trust funds	2,834	2,775
Goodwill	3,655	3,655
Other	852	834
Total investments and other assets	7,341	7,264
Property, Plant and Equipment
Cost	43,720	42,666
Accumulated depreciation and amortization	(15,087)	(14,867)
Generation facilities to be retired, net	506	548
Net property, plant and equipment	29,139	28,347
Regulatory Assets and Deferred Debits
Regulatory assets	5,298	5,435
Other	4	5
Total regulatory assets and deferred debits	5,302	5,440
Total Assets	44,918	44,548
Current Liabilities
Accounts payable	690	722
Accounts payable to affiliated companies	232	311
Notes payable to affiliated companies	916	1,308
Taxes accrued	162	53
Interest accrued	185	195
Current maturities of long-term debt	300	315
Regulatory liabilities	166	286
Other	702	891
Total current liabilities	3,353	4,081
Long-Term Debt	15,036	13,999
Long-Term Debt Payable to Affiliated Companies	150	150
Deferred Credits and Other Liabilities
Deferred income taxes	5,044	4,790
Accrued pension and other post-retirement benefit costs	519	536
Asset retirement obligations	5,386	5,369
Regulatory liabilities	2,409	2,387
Other	328	383
Total deferred credits and other liabilities	13,686	13,465
Commitments and Contingencies
Equity
Additional paid-in capital	8,092	8,092
Retained earnings	4,661	4,831
Accumulated other comprehensive income (loss)	(42)	(48)
Total Duke Energy Corporation stockholders' equity	12,711	12,875
Noncontrolling interests	(18)	(22)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	12,693	12,853
Total Liabilities and Equity	44,918	44,548
Duke Energy Progress [Member]
Current Assets
Cash and cash equivalents	8	15
Receivables (net of allowance for doubtful accounts)	35	87
Receivables of VIEs (net of allowance for doubtful accounts)	421	349
Receivables from affiliated companies	9	16
Inventory	1,068	1,088
Regulatory assets	187	264
Other	35	121
Total current assets	1,763	1,940
Investments and Other Assets
Nuclear decommissioning trust funds	2,110	2,035
Other	509	486
Total investments and other assets	2,619	2,521
Property, Plant and Equipment
Cost	27,771	27,313
Accumulated depreciation and amortization	(10,350)	(10,141)
Generation facilities to be retired, net	506	548
Net property, plant and equipment	17,927	17,720
Regulatory Assets and Deferred Debits
Regulatory assets	2,744	2,710
Other	2	3
Total regulatory assets and deferred debits	2,746	2,713
Total Assets	25,055	24,894
Current Liabilities
Accounts payable	300	399
Accounts payable to affiliated companies	134	190
Notes payable to affiliated companies	78	209
Taxes accrued	71	15
Interest accrued	96	96
Current maturities of long-term debt	252	2
Regulatory liabilities	84	85
Other	314	412
Total current liabilities	1,329	1,408
Long-Term Debt	6,163	6,366
Long-Term Debt Payable to Affiliated Companies	150	150
Deferred Credits and Other Liabilities
Deferred income taxes	3,167	3,027
Investment tax credits	152	132
Accrued pension and other post-retirement benefit costs	249	262
Asset retirement obligations	4,594	4,567
Regulatory liabilities	1,901	1,878
Other	23	45
Total deferred credits and other liabilities	10,086	9,911
Commitments and Contingencies
Equity
Member's equity	7,327	7,059
Members' Equity	7,327	7,059
Total Liabilities and Equity	25,055	24,894
Duke Energy Florida [Member]
Current Assets
Cash and cash equivalents	8	8
Receivables (net of allowance for doubtful accounts)	64	60
Receivables of VIEs (net of allowance for doubtful accounts)	355	308
Receivables from affiliated companies	3	84
Inventory	657	663
Regulatory assets	135	98
Other	43	21
Total current assets	1,265	1,242
Investments and Other Assets
Nuclear decommissioning trust funds	724	740
Other	288	292
Total investments and other assets	1,012	1,032
Property, Plant and Equipment
Cost	15,938	15,343
Accumulated depreciation and amortization	(4,730)	(4,720)
Net property, plant and equipment	11,208	10,623
Regulatory Assets and Deferred Debits
Regulatory assets	2,553	2,725
Other	3	2
Total regulatory assets and deferred debits	2,556	2,727
Total Assets	16,041	15,624
Current Liabilities
Accounts payable	390	322
Accounts payable to affiliated companies	100	116
Notes payable to affiliated companies	406	813
Taxes accrued	156	132
Interest accrued	40	43
Current maturities of long-term debt	48	13
Regulatory liabilities	82	200
Other	361	452
Total current liabilities	1,583	2,091
Long-Term Debt	5,492	4,253
Deferred Credits and Other Liabilities
Deferred income taxes	2,571	2,460
Accrued pension and other post-retirement benefit costs	238	242
Asset retirement obligations	792	802
Regulatory liabilities	508	509
Other	103	146
Total deferred credits and other liabilities	4,212	4,159
Commitments and Contingencies
Equity
Member's equity	4,753	5,121
Accumulated other comprehensive income (loss)	1
Members' Equity	4,754	5,121
Total Liabilities and Equity	16,041	15,624
Duke Energy Ohio [Member]
Current Assets
Cash and cash equivalents	10	14
Receivables (net of allowance for doubtful accounts)	63	66
Receivables from affiliated companies	35	84
Notes receivable from affiliated companies	186
Inventory	110	105
Regulatory assets	54	36
Other	65	110
Total current assets	523	415
Investments and Other Assets
Goodwill	920	920
Other	16	20
Total investments and other assets	936	940
Property, Plant and Equipment
Cost	7,906	7,750
Accumulated depreciation and amortization	(2,536)	(2,507)
Net property, plant and equipment	5,370	5,243
Regulatory Assets and Deferred Debits
Regulatory assets	472	497
Other	2	2
Total regulatory assets and deferred debits	474	499
Total Assets	7,303	7,097
Current Liabilities
Accounts payable	218	207
Accounts payable to affiliated companies	76	53
Notes payable to affiliated companies		103
Taxes accrued	108	171
Interest accrued	19	18
Current maturities of long-term debt	54	106
Regulatory liabilities	18	12
Other	82	153
Total current liabilities	575	823
Long-Term Debt	1,808	1,467
Long-Term Debt Payable to Affiliated Companies	25	25
Deferred Credits and Other Liabilities
Deferred income taxes	1,476	1,407
Accrued pension and other post-retirement benefit costs	52	56
Asset retirement obligations	125	125
Regulatory liabilities	241	245
Other	160	165
Total deferred credits and other liabilities	2,054	1,998
Commitments and Contingencies
Equity
Common stock	762	762
Additional paid-in capital	2,695	2,720
Retained earnings	(616)	(698)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,841	2,784
Total Liabilities and Equity	7,303	7,097
Duke Energy Indiana [Member]
Current Assets
Cash and cash equivalents	12	9
Receivables (net of allowance for doubtful accounts)	87	96
Receivables from affiliated companies	60	71
Notes receivable from affiliated companies	147	83
Inventory	508	570
Regulatory assets	115	102
Other	45	15
Total current assets	974	946
Investments and Other Assets
Total investments and other assets	221	212
Property, Plant and Equipment
Cost	13,677	14,007
Accumulated depreciation and amortization	(4,219)	(4,484)
Generation facilities to be retired, net	93
Net property, plant and equipment	9,551	9,523
Regulatory Assets and Deferred Debits
Regulatory assets	825	716
Other	2	2
Total regulatory assets and deferred debits	827	718
Total Assets	11,573	11,399
Current Liabilities
Accounts payable	146	189
Accounts payable to affiliated companies	87	83
Taxes accrued	40	89
Interest accrued	59	56
Current maturities of long-term debt	221	547
Regulatory liabilities	57	62
Other	101	97
Total current liabilities	711	1,123
Long-Term Debt	3,566	3,071
Long-Term Debt Payable to Affiliated Companies	150	150
Deferred Credits and Other Liabilities
Deferred income taxes	1,732	1,657
Investment tax credits	137	138
Accrued pension and other post-retirement benefit costs	74	80
Asset retirement obligations	520	525
Regulatory liabilities	745	754
Other	72	65
Total deferred credits and other liabilities	3,280	3,219
Commitments and Contingencies
Equity
Member's equity	3,866
Common stock		1
Additional paid-in capital		1,384
Retained earnings		2,450
Accumulated other comprehensive income (loss)		1
Members' Equity	3,866
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest		3,836
Total Liabilities and Equity	$ 11,573	$ 11,399

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Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Receivables, allowance for doubtful accounts	$ 23	$ 18
Receivables of VIEs, allowance for doubtful accounts	56	53
Regulatory assets	825	877
Regulatory assets	11,290	11,373
Current maturities of long-term debt	2,342	2,074
Long-term Debt of VIEs	$ 39,931	$ 37,495
Common stock, par or stated value	$ 0.001	$ 0.001
Common stock, shares authorized	2,000,000,000	2,000,000,000
Common stock, shares outstanding	689,000,000	688,000,000
Variable Interest Entity [Member]
Regulatory assets	$ 34
Regulatory assets	1,194
Current maturities of long-term debt	197	$ 125
Long-term Debt of VIEs	3,383	2,197
Duke Energy Carolinas [Member]
Receivables, allowance for doubtful accounts	2	3
Receivables of VIEs, allowance for doubtful accounts	7	7
Regulatory assets	262	305
Regulatory assets	2,856	2,766
Current maturities of long-term debt	468	356
Long-term Debt of VIEs	8,592	7,711
Progress Energy [Member]
Receivables, allowance for doubtful accounts	6	6
Receivables of VIEs, allowance for doubtful accounts	8	8
Regulatory assets	322	362
Regulatory assets	5,298	5,435
Current maturities of long-term debt	300	315
Long-term Debt of VIEs	$ 15,036	$ 13,999
Common stock, par or stated value	$ 0.01	$ 0.01
Common stock, shares authorized	100	100
Common stock, shares outstanding	100	100
Progress Energy [Member] | Variable Interest Entity [Member]
Regulatory assets	$ 34
Regulatory assets	1,194
Current maturities of long-term debt	35
Long-term Debt of VIEs	1,768	$ 479
Duke Energy Progress [Member]
Receivables, allowance for doubtful accounts	4	4
Receivables of VIEs, allowance for doubtful accounts	5	5
Regulatory assets	187	264
Regulatory assets	2,744	2,710
Current maturities of long-term debt	252	2
Long-term Debt of VIEs	6,163	6,366
Duke Energy Florida [Member]
Receivables, allowance for doubtful accounts	2	2
Receivables of VIEs, allowance for doubtful accounts	3	3
Regulatory assets	135	98
Regulatory assets	2,553	2,725
Current maturities of long-term debt	48	13
Long-term Debt of VIEs	5,492	4,253
Duke Energy Florida [Member] | Variable Interest Entity [Member]
Regulatory assets	34
Regulatory assets	1,194
Current maturities of long-term debt	35
Long-term Debt of VIEs	1,468	225
Duke Energy Ohio [Member]
Receivables, allowance for doubtful accounts	2	2
Regulatory assets	54	36
Regulatory assets	472	497
Current maturities of long-term debt	54	106
Long-term Debt of VIEs	$ 1,808	$ 1,467
Common stock, par or stated value	$ 8.50	$ 8.50
Common stock, shares authorized	120,000,000	120,000,000
Common stock, shares outstanding	89,663,086	89,663,086
Duke Energy Indiana [Member]
Receivables, allowance for doubtful accounts	$ 1	$ 1
Regulatory assets	115	102
Regulatory assets	825	716
Current maturities of long-term debt	221	547
Long-term Debt of VIEs	$ 3,566	$ 3,071
Common stock, par or stated value		$ 0.01
Common stock, shares authorized		60,000,000
Common stock, shares outstanding		53,913,701

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Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	$ 1,211	$ 1,414
Net Income Attributable to Parent	1,203	1,407
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,868	1,784
Equity component of AFUDC	(87)	(82)
Gains on sales of other assets	(18)	(29)
Impairment charges	198	37
Deferred income taxes	285	699
Equity in earnings of unconsolidated affiliates	(23)	(36)
Accrued pension and other post-retirement benefit costs	8	36
Contributions to qualified pension plans		(132)
Payments for asset retirement obligations	(263)	(125)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	199	(29)
Receivables	(57)	105
Inventory	178	2
Other current assets	(51)	(161)
Increase (decrease) in
Accounts payable	(153)	(288)
Taxes accrued	216	(29)
Other current liabilities	(281)	(145)
Other assets	(9)	(63)
Other liabilities	(15)	(79)
Net cash provided by operating activities	3,206	2,879
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(3,393)	(3,062)
Investment expenditures	(136)	(98)
Acquisitions		(29)
Purchases of available-for-sale securities	(3,033)	(2,187)
Proceeds from sales and maturities of available-for-sale securities	3,059	2,200
Net proceeds from the sale of the Disposal Group		2,792
Net proceeds from the sales of equity investments and other assets	2	40
Change in restricted cash	(21)	(3)
Other	(86)	53
Net cash used in investing activities	(3,608)	(294)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	3,514	574
Proceeds from the issuance of common stock related to employee benefit plans	7	16
Payments for the redemption of long-term debt	(795)	(1,246)
Proceeds from issuance of short-term debt with original maturities greater than 90 days	500	287
Payments for the redemption of short-term debt with original maturities greater than 90 days	(492)	(664)
Notes payable and commercial paper	(1,349)	12
Distributions to noncontrolling interests	(3)	(7)
Dividends paid	(1,140)	(1,115)
Repurchase of common shares		(1,500)
Other	(21)	(18)
Net cash provided by (used in) financing activities	221	(3,661)
Net increase (decrease) in cash and cash equivalents	(181)	(1,076)
Cash and cash equivalents at beginning of period	857	2,036
Cash and cash equivalents at end of period	676	960
Significant non-cash transactions:
Accrued capital expenditures	670	547
Duke Energy Carolinas [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income Attributable to Parent	532	557
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	673	670
Equity component of AFUDC	(48)	(48)
Deferred income taxes	273	184
Accrued pension and other post-retirement benefit costs	2	7
Contributions to qualified pension plans		(42)
Payments for asset retirement obligations	(118)	(60)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3
Receivables	(48)	45
Receivable from affiliated companies	36	(31)
Inventory	102	(31)
Other current assets	24	34
Increase (decrease) in
Accounts payable	(226)	(200)
Accounts payable to affiliated companies	(56)	(13)
Taxes accrued	188	73
Other current liabilities	28	(33)
Other assets	22	58
Other liabilities	(14)	(49)
Net cash provided by operating activities	1,373	1,121
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,031)	(954)
Purchases of available-for-sale securities	(1,395)	(1,410)
Proceeds from sales and maturities of available-for-sale securities	1,395	1,410
Notes receivable from affiliated companies payments	(89)	(550)
Other	(41)	8
Net cash used in investing activities	(1,161)	(1,496)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	992	496
Payments for the redemption of long-term debt	(1)
Distributions to parent	(1,200)	(100)
Other		(6)
Net cash provided by (used in) financing activities	(209)	390
Net increase (decrease) in cash and cash equivalents	3	15
Cash and cash equivalents at beginning of period	13	13
Cash and cash equivalents at end of period	16	28
Significant non-cash transactions:
Accrued capital expenditures	228	160
Progress Energy [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	486	480
Net Income Attributable to Parent	481	475
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	696	648
Equity component of AFUDC	(30)	(26)
Gains on sales of other assets	(15)	(14)
Impairment charges	3
Deferred income taxes	285	358
Accrued pension and other post-retirement benefit costs	(12)	(3)
Contributions to qualified pension plans		(42)
Payments for asset retirement obligations	(126)	(61)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	32	5
Receivables	(66)	(103)
Receivable from affiliated companies	306	(55)
Inventory	25	62
Other current assets	45	215
Increase (decrease) in
Accounts payable	(26)	(182)
Accounts payable to affiliated companies	(79)	68
Taxes accrued	90	94
Other current liabilities	(162)	(9)
Other assets	(72)	(70)
Other liabilities	15	(32)
Net cash provided by operating activities	1,395	1,333
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,441)	(1,170)
Purchases of available-for-sale securities	(1,570)	(562)
Proceeds from sales and maturities of available-for-sale securities	1,594	624
Proceeds from Insurance	58
Notes receivable from affiliated companies		220
Change in restricted cash	(6)
Other	(14)	4
Net cash used in investing activities	(1,379)	(884)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,338
Payments for the redemption of long-term debt	(320)	(549)
Notes payable to affiliated companies	(392)	110
Distributions to noncontrolling interests	(1)	(4)
Dividends to parent	(651)
Other		(3)
Net cash provided by (used in) financing activities	(26)	(446)
Net increase (decrease) in cash and cash equivalents	(10)	3
Cash and cash equivalents at beginning of period	44	42
Cash and cash equivalents at end of period	34	45
Significant non-cash transactions:
Accrued capital expenditures	288	271
Duke Energy Progress [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income Attributable to Parent	268	268
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	451	389
Equity component of AFUDC	(20)	(23)
Gains on sales of other assets	(3)	(1)
Deferred income taxes	172	177
Accrued pension and other post-retirement benefit costs	(16)	(7)
Contributions to qualified pension plans		(21)
Payments for asset retirement obligations	(100)	(32)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(1)	(3)
Receivables	(19)	(64)
Receivable from affiliated companies	7	6
Inventory	20	53
Other current assets	131	156
Increase (decrease) in
Accounts payable	(28)	(128)
Accounts payable to affiliated companies	(56)	62
Taxes accrued	56	66
Other current liabilities	(12)	(15)
Other assets	(26)	(31)
Other liabilities	(6)	(21)
Net cash provided by operating activities	818	831
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(704)	(699)
Purchases of available-for-sale securities	(1,299)	(319)
Proceeds from sales and maturities of available-for-sale securities	1,284	301
Notes receivable from affiliated companies		237
Other	(19)	6
Net cash used in investing activities	(738)	(474)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	59
Payments for the redemption of long-term debt	(15)	(544)
Notes payable to affiliated companies	(131)	192
Other		(1)
Net cash provided by (used in) financing activities	(87)	(353)
Net increase (decrease) in cash and cash equivalents	(7)	4
Cash and cash equivalents at beginning of period	15	9
Cash and cash equivalents at end of period	8	13
Significant non-cash transactions:
Accrued capital expenditures	73	135
Duke Energy Florida [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income Attributable to Parent	281	278
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	239	258
Equity component of AFUDC	(9)	(2)
Impairment charges	3
Deferred income taxes	113	237
Accrued pension and other post-retirement benefit costs	1	3
Contributions to qualified pension plans		(21)
Payments for asset retirement obligations	(25)	(28)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	34	5
Receivables	(49)	(40)
Receivable from affiliated companies	23	(53)
Inventory	5	10
Other current assets	(13)	10
Increase (decrease) in
Accounts payable	3	(53)
Accounts payable to affiliated companies	(16)	3
Taxes accrued	5	65
Other current liabilities	(142)	5
Other assets	(47)	(44)
Other liabilities	20	(19)
Net cash provided by operating activities	426	614
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(737)	(471)
Purchases of available-for-sale securities	(271)	(243)
Proceeds from sales and maturities of available-for-sale securities	310	323
Proceeds from Insurance	58
Change in restricted cash	(6)
Other	5	1
Net cash used in investing activities	(641)	(390)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,278
Payments for the redemption of long-term debt	(5)	(5)
Notes payable to affiliated companies	(407)	137
Dividends to parent		(350)
Distributions to parent	(649)
Other	(2)	(1)
Net cash provided by (used in) financing activities	215	(219)
Net increase (decrease) in cash and cash equivalents		5
Cash and cash equivalents at beginning of period	8	8
Cash and cash equivalents at end of period	8	13
Significant non-cash transactions:
Accrued capital expenditures	215	136
Duke Energy Ohio [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income Attributable to Parent	82	97
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	127	117
Equity component of AFUDC	(2)	(2)
Gains on sales of other assets	(1)	(8)
Impairment charges		40
Deferred income taxes	68	62
Accrued pension and other post-retirement benefit costs	3	4
Contributions to qualified pension plans		(1)
Payments for asset retirement obligations	(3)	(1)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(2)	(12)
Receivables	3	6
Receivable from affiliated companies	49	46
Inventory	(5)	3
Other current assets	49	32
Increase (decrease) in
Accounts payable	8	(12)
Accounts payable to affiliated companies	23	19
Taxes accrued	(68)	(68)
Other current liabilities	(66)	99
Other assets	(8)	19
Other liabilities	(9)	(52)
Net cash provided by operating activities	248	388
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(214)	(166)
Notes receivable from affiliated companies payments	(186)
Notes receivable from affiliated companies		130
Other	(13)	(4)
Net cash used in investing activities	(413)	(40)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	341
Payments for the redemption of long-term debt	(52)	(152)
Notes payable to affiliated companies	(103)	(193)
Dividends to parent	(25)
Other		(1)
Net cash provided by (used in) financing activities	161	(346)
Net increase (decrease) in cash and cash equivalents	(4)	2
Cash and cash equivalents at beginning of period	14	20
Cash and cash equivalents at end of period	10	22
Significant non-cash transactions:
Accrued capital expenditures	30	19
Distribution of membership interest of Duke Energy SAM, LLC to parent		1,912
Duke Energy Indiana [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income Attributable to Parent	180	176
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	223	214
Equity component of AFUDC	(7)	(6)
Gains on sales of other assets		(1)
Deferred income taxes	36	232
Accrued pension and other post-retirement benefit costs	4	6
Contributions to qualified pension plans		(9)
Payments for asset retirement obligations	(16)	(3)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions		(2)
Receivables	12	(1)
Receivable from affiliated companies	11	6
Inventory	62	(42)
Other current assets	(19)	87
Increase (decrease) in
Accounts payable	(22)	26
Accounts payable to affiliated companies	4	2
Taxes accrued	(42)	(21)
Other current liabilities	(60)	5
Other assets	(29)	(31)
Other liabilities	44	(43)
Net cash provided by operating activities	381	595
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(325)	(380)
Purchases of available-for-sale securities	(7)	(4)
Proceeds from sales and maturities of available-for-sale securities	5	3
Net proceeds from the sales of equity investments and other assets		14
Notes receivable from affiliated companies payments	(64)	(25)
Other	(6)	25
Net cash used in investing activities	(397)	(367)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	495
Payments for the redemption of long-term debt	(326)
Notes payable to affiliated companies		(71)
Dividends to parent		(150)
Distributions to parent	(149)
Other	(1)	(1)
Net cash provided by (used in) financing activities	19	(222)
Net increase (decrease) in cash and cash equivalents	3	6
Cash and cash equivalents at beginning of period	9	6
Cash and cash equivalents at end of period	12	12
Significant non-cash transactions:
Accrued capital expenditures	$ 43	$ 46

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Condensed Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Foreign Currency Translation Adjustments [Member]	Net Gains (Losses) on Cash Flow Hedges [Member]	Net Gains (Losses) on Available for Sale Securities [Member]	Pension and OPEB Related Adjustments [Member]	Common Stockholders' Equity [Member]	Noncontrolling Interest [Member]		Duke Energy Carolinas [Member]	Duke Energy Carolinas [Member] Members Equity [Member]	Duke Energy Carolinas [Member] Net Gains (Losses) on Cash Flow Hedges [Member]	Duke Energy Carolinas [Member] Net Gains (Losses) on Available for Sale Securities [Member]	Progress Energy [Member]	Progress Energy [Member] Additional Paid-in Capital [Member]	Progress Energy [Member] Retained Earnings [Member]	Progress Energy [Member] Net Gains (Losses) on Cash Flow Hedges [Member]	Progress Energy [Member] Net Gains (Losses) on Available for Sale Securities [Member]	Progress Energy [Member] Pension and OPEB Related Adjustments [Member]	Progress Energy [Member] Common Stockholders' Equity [Member]	Progress Energy [Member] Noncontrolling Interest [Member]	Duke Energy Progress [Member]	Duke Energy Progress [Member] Common Stock [Member]	Duke Energy Progress [Member] Retained Earnings [Member]	Duke Energy Progress [Member] Members Equity [Member]	Duke Energy Florida [Member]	Duke Energy Florida [Member] Common Stock [Member]	Duke Energy Florida [Member] Retained Earnings [Member]	Duke Energy Florida [Member] Members Equity [Member]	Duke Energy Florida [Member] Net Gains (Losses) on Available for Sale Securities [Member]	Duke Energy Ohio [Member]	Duke Energy Ohio [Member] Common Stock [Member]	Duke Energy Ohio [Member] Additional Paid-in Capital [Member]	Duke Energy Ohio [Member] Retained Earnings [Member]	Duke Energy Indiana [Member]	Duke Energy Indiana [Member] Common Stock [Member]	Duke Energy Indiana [Member] Additional Paid-in Capital [Member]	Duke Energy Indiana [Member] Retained Earnings [Member]	Duke Energy Indiana [Member] Members Equity [Member]	Duke Energy Indiana [Member] Net Gains (Losses) on Cash Flow Hedges [Member]
Balance at Dec. 31, 2014	$ 40,899	$ 1	$ 39,405	$ 2,012	$ (439)	$ (59)	$ 3	$ (48)	$ 40,875	$ 24						$ 11,176	$ 7,467	$ 3,782	$ (35)	$ 1	$ (7)	$ 11,208	$ (32)	$ 5,867	$ 2,159	$ 3,708		$ 5,222	$ 1,762	$ 3,460			$ 4,674	$ 762	$ 4,782	$ (870)	$ 3,848	$ 1	$ 1,384	$ 2,460		$ 3
Balance, in shares at Dec. 31, 2014		707,000,000
Beginning member's equity at Dec. 31, 2014												$ 10,924	$ 10,937	$ (12)	$ (1)
Net Income	1,414			1,407					1,407	7						480		475				475	5
Net Income Attributable to Parent	1,407											557	557			475								268		268		278		278			97			97	176			176
Distribution of membership interest of Duke Energy SAM, LLC to parent																																	(1,912)		(1,912)
Other comprehensive (loss) income, net of tax	(110)				(111)	7	(3)	2	(105)	(5)									(1)	(1)	2																(1)					(1)
Common stock issuances, including dividend reinvestment and employee benefits, shares		1,000,000
Common stock issuances, including dividend reinvestment and employee benefits	28		28						28
Stock Repurchased During Period, Shares		(20,000,000)
Stock Repurchased During Period, Value	(1,500)		(1,500)						(1,500)
Common stock dividends	(1,115)			(1,115)					(1,115)																			(350)		(350)							(150)			(150)
Distributions to parent												(100)	(100)
Distributions to noncontrolling interest in subsidiaries	(7)									(7)						(4)							(4)
Other	8			(10)					(10)	18	[1]					2		(2)				(2)	4
Balance at Jun. 30, 2015	39,617	$ 1	37,933	2,294	(550)	(52)		(46)	39,580	37						11,654	7,467	4,255	(36)		(5)	11,681	(27)	6,135	$ 2,159	$ 3,976		5,150	$ 1,762	$ 3,388			2,859	762	2,870	(773)	3,873	1	1,384	2,486		2
Balance, in shares at Jun. 30, 2015		688,000,000
Ending member's equity at Jun. 30, 2015												11,381	11,394	(12)	$ (1)
Balance at Dec. 31, 2015	$ 39,771	$ 1	37,968	2,564	(692)	(50)	(3)	(61)	39,727	44						$ 12,853	8,092	4,831	(31)		(17)	12,875	(22)										$ 2,784	762	2,720	(698)	$ 3,836	1	1,384	2,450		1
Balance, in shares at Dec. 31, 2015	688,000,000	688,000,000														100																	89,663,086				53,913,701
Beginning member's equity at Dec. 31, 2015												11,606	11,617	(11)										7,059			$ 7,059	5,121			$ 5,121
Net Income	$ 1,211			1,203					1,203	8						$ 486		481				481	5
Net Income Attributable to Parent	1,203											532	532			481								268			268	281			281		$ 82			82	$ 180				$ 180
Other comprehensive (loss) income, net of tax	93				103	(23)	7	2	89	4		1		1		6			3	1	2	6						1				$ 1					(1)					$ (1)
Common stock issuances, including dividend reinvestment and employee benefits, shares		1,000,000
Common stock issuances, including dividend reinvestment and employee benefits	16		16						16
Common stock dividends	(1,140)			(1,140)					(1,140)							(651)		(651)				(651)											(25)		(25)
Distributions to parent												(1,200)	(1,200)															(649)			(649)						(149)				(149)
Distributions to noncontrolling interest in subsidiaries	(3)									(3)						(1)							(1)
Other																																						$ (1)	$ (1,384)	$ (2,450)	3,835
Balance at Jun. 30, 2016	$ 39,948	$ 1	$ 37,984	$ 2,627	$ (589)	$ (73)	$ 4	$ (59)	$ 39,895	$ 53						$ 12,693	$ 8,092	$ 4,661	$ (28)	$ 1	$ (15)	$ 12,711	$ (18)										$ 2,841	$ 762	$ 2,695	$ (616)
Balance, in shares at Jun. 30, 2016	689,000,000	689,000,000														100																	89,663,086
Ending member's equity at Jun. 30, 2016												$ 10,939	$ 10,949	$ (10)										$ 7,327			$ 7,327	$ 4,754			$ 4,753	$ 1					$ 3,866				$ 3,866

[1] The $18 million change in Noncontrolling Interests is primarily related to an acquisition of majority interest in a solar company for an insignificant amount of cash consideration.

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Organization and Basis of Presentation

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Organization and Basis of Presentation

Index to Combined Notes to Condensed Consolidated Financial Statements

The unaudited notes to the condensed consolidated financial statements that follow are a combined presentation. The following list indicates the registrants to which the footnotes apply. Tables within the notes may not sum across due to Progress Energy's consolidation of Duke Energy Progress, Duke Energy Florida and other subsidiaries that are not registrants. In addition, the Duke Energy amounts include balances from subsidiaries that are not registrants.

Applicable Notes

Registrant

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Duke Energy Corporation

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Duke Energy Carolinas, LLC

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Progress Energy, Inc.

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Duke Energy Progress, LLC

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Duke Energy Florida, LLC

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Duke Energy Ohio, Inc.

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Duke Energy Indiana, LLC

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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, LLC (Duke Energy Progress); Duke Energy Florida, LLC (Duke Energy Florida); Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, LLC (Duke Energy Indiana, formerly Duke Energy Indiana, Inc.). 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 (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 primarily engaged in the transmission and distribution of electricity in portions of Ohio and Kentucky, the generation and sale of electricity in portions of Kentucky, and the transportation and sale of natural gas in portions of Ohio and Kentucky. Duke Energy Ohio conducts competitive auctions for retail electricity supply in Ohio whereby the energy price is recovered from retail customers and recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Operations in Kentucky are conducted through its wholly owned subsidiary, Duke Energy Kentucky, Inc. (Duke Energy Kentucky). References herein to Duke Energy Ohio collectively 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. On April 2, 2015, Duke Energy completed the sale of its nonregulated Midwest generation business, which sold power into wholesale energy markets, to a subsidiary of Dynegy Inc. (Dynegy). See Note 2 for additional information. Substantially all of Duke Energy Ohio’s operations that remain after the sale qualify for regulatory accounting.

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 FERC. Substantially all of Duke Energy Indiana’s operations qualify for regulatory accounting. On January 1, 2016, Duke Energy Indiana, an Indiana corporation, converted into an Indiana limited liability company.

BASIS OF PRESENTATION

Duke Energy completed the sale of Duke Energy Ohio's nonregulated Midwest generation business and Duke Energy Retail Sales (collectively, the Disposal Group), a retail sales business owned by Duke Energy, to Dynegy on April 2, 2015. The results of operations of these businesses prior to the date of sale have been classified as Discontinued Operations on the Condensed Consolidated Statements of Operations. Duke Energy has elected to present cash flows of discontinued operations combined with cash flows of continuing operations. Unless otherwise noted, the notes to these Condensed Consolidated Financial Statements exclude amounts related to discontinued operations. See Note 2 for additional information.

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. Since 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, 2015.

The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to Combined Notes to Condensed Consolidated Financial Statements. However, none of the registrants make any representations as to information related solely to Duke Energy or the subsidiaries of Duke Energy other than itself.

These Condensed Consolidated Financial Statements, in the opinion of the respective companies’ management, reflect all normal recurring adjustments 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 natural gas are recognized when service is provided or the product is delivered. 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, customer mix, average price in effect for customer classes, timing of rendering customer bills and meter reading schedules.

Unbilled revenues, which are included within Receivables and Receivables of variable interest entities (VIEs) on the Condensed Consolidated Balance Sheets, are presented in the following table.

(in millions)	June 30, 2016		December 31, 2015
Duke Energy	$	840	$	748
Duke Energy Carolinas	330		283
Progress Energy	209		172
Duke Energy Progress	104		102
Duke Energy Florida	105		70
Duke Energy Ohio	2		3
Duke Energy Indiana	38		31

Additionally, Duke Energy Ohio and Duke Energy Indiana sell nearly all of their retail accounts receivable to an affiliate, Cinergy Receivables Company, LLC (CRC), on a revolving basis. These transfers of receivables are accounted for as sales and include receivables for unbilled revenues. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 12 for further information. These receivables for unbilled revenues are shown in the table below.

(in millions)	June 30, 2016		December 31, 2015
Duke Energy Ohio	$	70	$	71
Duke Energy Indiana	109		97

AMOUNTS ATTRIBUTABLE TO CONTROLLING INTERESTS

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

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, excise taxes are accounted for net.

Excise taxes accounted for on a gross basis as both operating revenues and property and other taxes on the Condensed Consolidated Statements of Operations were as follows.

	Three Months Ended June 30,				Six Months Ended June 30,
(in millions)	2016		2015		2016		2015
Duke Energy	$	87	$	97	$	178	$	197
Duke Energy Carolinas	7		9		15		18
Progress Energy	50		57		96		106
Duke Energy Progress	4		4		9		8
Duke Energy Florida	46		53		87		98
Duke Energy Ohio	22		23		51		55
Duke Energy Indiana	8		8		16		18

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2016 and 2015 had no material impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. The following accounting standard was adopted by the Duke Energy Registrants during 2015.

Balance Sheet Presentation of Debt Issuance Costs. In April and August of 2015, the Financial Accounting Standards Board (FASB) issued revised accounting guidance for the presentation of debt issuance costs. The core principle of this revised accounting guidance is that debt issuance costs are not assets, but adjustments to the carrying cost of debt. For Duke Energy, this revised accounting guidance was adopted retrospectively.

The implementation of this accounting standard resulted in a reduction of Other within Regulatory Assets and Deferred Debits and in Long-Term Debt of $192 million and $170 million on the Condensed Consolidated Balance Sheets as of June 30, 2016, and December 31, 2015, respectively.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of June 30, 2016.

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. The amendments in this update also require disclosure of sufficient information to allow users to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.

For Duke Energy, the revised accounting guidance is effective for interim and annual periods beginning January 1, 2018. The guidance can be applied retrospectively to all prior reporting periods presented or retrospectively with a cumulative effect as of the initial date of application. Duke Energy is currently evaluating the requirements. The ultimate impact of the new standard has not yet been determined.

Leases. In February 2016, the FASB issued revised accounting guidance for leases. The core principle of this guidance is that a lessee should recognize the assets and liabilities that arise from leases on the balance sheet.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2019, although it can be early adopted. The guidance is applied using a modified retrospective approach. Duke Energy is currently evaluating the requirements. Other than an expected increase in assets and liabilities, the ultimate impact of the new standard has not yet been determined.

Stock-Based Compensation and Income Taxes. In March 2016, the FASB issued revised accounting guidance for stock-based compensation and the associated income taxes. This standard changes certain aspects of accounting for stock-based payment awards to employees including the accounting for income taxes, statutory tax withholding requirements, as well as the classification on the Condensed Consolidated Statements of Cash Flows. This guidance will be applied prospectively, retrospectively, or using a modified retrospective transition method depending on the item changed.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2017, although it can be early adopted. Duke Energy is currently evaluating the requirements. The primary change expected is an increase in the volatility of income tax expense.

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Acquisitions and Dispositions

6 Months Ended

Jun. 30, 2016

Business Combinations [Abstract]

Acquisitions and Dispositions

ACQUISITIONS AND DISPOSITIONS

ACQUISITIONS

The Duke Energy Registrants consolidate assets and liabilities from acquisitions as of the purchase date, and include earnings from acquisitions in consolidated earnings after the purchase date.

Acquisition of Piedmont Natural Gas

On October 24, 2015, Duke Energy entered into an Agreement and Plan of Merger (Merger Agreement) with Piedmont Natural Gas Company, Inc. (Piedmont), a North Carolina corporation. Under the terms of the Merger Agreement, Duke Energy will acquire Piedmont for approximately $4.9 billion in cash and Piedmont will become a wholly owned subsidiary of Duke Energy. In addition, Duke Energy will assume Piedmont's existing debt, which was approximately $2.0 billion at April 30, 2016, the end of Piedmont's most recent filed quarter. The excess of the purchase price over the fair value of Piedmont's assets and liabilities on the acquisition date will be recorded as goodwill. Duke Energy estimates the transaction would result in incremental goodwill of approximately $3.5 billion. Duke Energy expects to finance the transaction with a combination of debt, equity issuances and other cash sources. As of June 30, 2016, Duke Energy had entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. For additional information on the forward-starting swaps, see Note 9.

In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into equity forward sale agreements (the Equity Forwards) with Barclays Capital, Inc. (Barclays). Duke Energy expects to settle the Equity Forwards on or around the closing date of the Piedmont acquisition. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont. For additional information regarding the Equity Forwards, see Note 13.

In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion senior unsecured bridge financing facility (Bridge Facility) with Barclays. The Bridge Facility, if drawn upon, may be used to (i) fund the cash consideration for the transaction and (ii) pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to approximately $3.2 billion as a result of the Equity Forwards and $1 billion of the commitments under a term loan amended and restated as of August 1, 2016. See Note 6, Term Loan Facility, for more information.

Piedmont's shareholders have approved the company's acquisition by Duke Energy and the Federal Trade Commission (FTC) has granted early termination of the 30-day waiting period under the federal Hart-Scott-Rodino Antitrust Improvements Act of 1976. On January 15, 2016, Duke Energy and Piedmont filed an application with the NCUC for approval of the proposed business combination and associated financing transactions. On January 29, 2016, the NCUC approved Duke Energy's proposed financing transactions. On March 7, 2016, the KPSC granted Duke Energy's declaratory request that the transaction does not constitute a change in control and does not require KPSC approval. The Tennessee Regulatory Authority approved Duke Energy's and Piedmont's request of the change in control resulting from the transaction at its March 14, 2016, meeting. On June 10, 2016 the North Carolina Public Staff reached an agreement with Duke Energy and Piedmont on certain stipulations and conditions for approval of the transaction. Duke Energy and Piedmont have also entered into settlement agreements with the Environmental Defense Fund (EDF) and the Carolina Utility Customers Association, Inc. (CUCA) resolving EDF's and CUCA's issues in the case.

On July 19, 2016, the NCUC concluded an evidentiary hearing for the proposed business combination. Proposed orders are due from all parties by August 25, 2016, after which the NCUC will rule on the application. Subject to receipt of NCUC approval and meeting closing conditions, Duke Energy and Piedmont expect to close the transaction by the end of 2016.

The Merger Agreement contains certain termination rights for both Duke Energy and Piedmont, and provides that, upon termination of the Merger Agreement under specified circumstances, Duke Energy would be required to pay a termination fee of $250 million to Piedmont and Piedmont would be required to pay Duke Energy a termination fee of $125 million.

See Note 4 for additional information regarding Duke Energy and Piedmont's joint investment in Atlantic Coast Pipeline, LLC (ACP).

Purchase of NCEMPA's Generation

On July 31, 2015, Duke Energy Progress completed the purchase of North Carolina Eastern Municipal Power Agency’s (NCEMPA) ownership interests in certain generating assets, fuel and spare parts inventory jointly owned with and operated by Duke Energy Progress for approximately $1.25 billion. This purchase was accounted for as an asset acquisition. The purchase resulted in the acquisition of a total of approximately 700 megawatts (MW) of generating capacity at Brunswick Nuclear Plant, Shearon Harris Nuclear Plant, Mayo Steam Plant and Roxboro Steam Plant. In connection with this transaction, Duke Energy Progress and NCEMPA entered into a 30-year wholesale power agreement, whereby Duke Energy Progress will sell power to NCEMPA to continue to meet the needs of NCEMPA customers.

The purchase price exceeded the historical carrying value of the acquired assets by $350 million, which was recognized as an acquisition adjustment and recorded in property, plant and equipment. Duke Energy Progress established a rider in North Carolina to recover the costs to acquire, operate and maintain interests in the assets purchased as allocated to its North Carolina retail operations, including the purchase acquisition adjustment, and included the purchase acquisition adjustment in wholesale power formula rates. Duke Energy Progress received an order from the PSCSC to defer the recovery of the South Carolina retail allocated costs of the asset purchased until the Duke Energy Progress' next general rate case, which was filed in July 2016. See Note 4, for additional information on the South Carolina Rate Case.

DISPOSITIONS

Potential Sale of International Energy

In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the equity method investment in National Methanol Company (NMC). Duke Energy is actively marketing the business. Non-binding offers have been received and are being evaluated. There is no assurance that this process will result in a transaction and the timing for execution of a potential transaction is uncertain. Proceeds from a successful sale would be used by Duke Energy to reduce debt and fund the operations and growth of domestic businesses. If the potential of a sale were to progress, it could result in classification of International Energy as assets held for sale and as a discontinued operation.

Based upon the advancement of the marketing efforts, Duke Energy performed recoverability tests of the long-lived asset groups of International Energy as of June 30, 2016. As a result, Duke Energy determined the carrying value of certain assets in Central America is not fully recoverable and recorded a pretax impairment charge of $194 million, which is included within Impairment Charges on the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2016. The impairment charge represents the excess of carrying value over the estimated fair value of the assets. The fair value of the assets was primarily determined from the income approach using discounted cash flows but also considered market information obtained in 2016.

As of June 30, 2016, the International Energy segment had a carrying value of approximately $2.4 billion, adjusted for approximately $589 million of cumulative foreign currency translation losses currently classified as accumulated other comprehensive loss.

Midwest Generation Exit

Duke Energy, through indirect subsidiaries, completed the sale of the Disposal Group to a subsidiary of Dynegy on April 2, 2015, for approximately $2.8 billion in cash. The nonregulated Midwest generation business included generation facilities with approximately 5,900 MW of owned capacity located in Ohio, Pennsylvania and Illinois. On April 1, 2015, prior to the sale, Duke Energy Ohio distributed its indirect ownership interest in the nonregulated Midwest generation business to a subsidiary of Duke Energy Corporation.

The Disposal Group's results of operations are classified as discontinued operations in the accompanying Condensed Consolidated Statements of Operations and Comprehensive Income. The following table presents the results of discontinued operations for the three and six months ended June 30, 2015.

	Three Months Ended						Six Months Ended
	June 30, 2015						June 30, 2015
				Duke						Duke
	Duke			Energy			Duke			Energy
(in millions)	Energy			Ohio			Energy			Ohio
Operating Revenues	$	—		$	—		$	543		$	412
Gain (Loss) on disposition	6			—			(37		)	(44		)
(Loss) Income before income taxes(a)	$	(80	)	$	(88	)	$	67		$	52
Income tax (benefit) expense	(21		)	(23		)	30			27
(Loss) Income from discontinued operations of the Disposal Group	(59		)	(65		)	37			25
Other, net of tax(b)	2			—			(3		)	—
(Loss) Income from Discontinued Operations, net of tax	$	(57	)	$	(65	)	$	34		$	25

(a) The (Loss) Income before income taxes includes the pretax impact of a $71 million and $81 million charge for the agreement in principle reached in a lawsuit related to the Disposal Group for the three and six months ended June 30, 2015, respectively. Refer to Note 5 for further information related to the lawsuit.

(b) Relates to discontinued operations of businesses not related to the Disposal Group and includes indemnifications provided for certain legal, tax and environmental matters, and foreign currency translation adjustments.

Commercial Portfolio utilized a revolving credit agreement (RCA) to support the operations of the nonregulated Midwest generation business. Interest expense associated with the RCA was allocated to discontinued operations. No other interest expense related to corporate level debt was allocated to discontinued operations. Duke Energy Ohio had a power purchase agreement with the Disposal Group for a portion of its standard service offer (SSO) supply requirement. The agreement and the SSO expired in May 2015.

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Business Segments

6 Months Ended

Jun. 30, 2016

Segment Reporting [Abstract]

Business Segments

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.

Operating segments are determined based on information used by the chief operating decision-maker in deciding how to allocate resources and evaluate the performance of the business. During the first quarter of 2016, the Duke Energy chief operating decision-maker began to evaluate interim period segment performance based on financial information that includes the impact of income tax levelization within segment income. This represents a change from the previous measure, where the interim period impacts of income tax levelization were included within Other, and therefore excluded from segment income. As a result, prior period segment results presented have been recast to conform to this change.

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 Portfolio.

RegulatedUtilities conducts electric and natural gas operations that are substantially all regulated and, accordingly, qualify for regulatory accounting treatment. These operations are primarily conducted through the Subsidiary Registrants and are subject to the rules and regulations of the FERC, NRC, NCUC, PSCSC, FPSC, PUCO, IURC and KPSC.

International Energy 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 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. In February 2016, Duke Energy announced it had initiated a process to potentially divest its International Energy business segment, excluding the investment in NMC. See Note 2 for further information.

Commercial Portfolio builds, develops and operates wind and solar renewable generation and storage and energy transmission projects throughout the U.S. For periods subsequent to the sale of the Disposal Group, beginning in the second quarter of 2015, certain immaterial results of operations and related assets previously presented in the Commercial Portfolio segment are presented in Regulated Utilities and Other.

Theremainder of Duke Energy’s operations is presented as Other, which is primarily comprised of unallocated corporate interest expense, unallocated corporate costs, contributions to the Duke Energy Foundation and the operations of Duke Energy’s wholly owned captive insurance subsidiary, Bison Insurance Company Limited (Bison).

	Three Months Ended June 30, 2016
								Total
	Regulated		International			Commercial		Reportable
(in millions)	Utilities		Energy			Portfolio		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,090	$	270		$	112	$	5,472	$	12		$	—		$	5,484
Intersegment revenues	9		—			—		9		17			(26		)	—
Total revenues	$	5,099	$	270		$	112	$	5,481	$	29		$	(26	)	$	5,484
Segment income (loss)(a)(b)	$	718	$	(102	)	$	14	$	630	$	(120	)	$	—		$	510
Add back noncontrolling interests																3
Loss from discontinued operations, net of tax																(1		)
Net income																$	512
Segment assets	$	112,754	$	3,131		$	4,329	$	120,214	$	2,260		$	180		$	122,654

(a) Other includes after-tax charges for costs to achieve mergers of $69 million, primarily due to unrealized losses on forward-starting interest rate swaps related to the Piedmont acquisition, and cost savings initiatives of $15 million primarily due to severance costs. See Notes 2 and 9 for additional information related to the forward-starting interest rate swaps.

(b) International Energy includes an after-tax impairment charge of $145 million. See Note 2 for additional information.

	Three Months Ended June 30, 2015
								Total
	Regulated		International		Commercial			Reportable
(in millions)	Utilities		Energy		Portfolio			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,211	$	287	$	75		$	5,573	$	16		$	—		$	5,589
Intersegment revenues	9		—		—			9		18			(27		)	—
Total revenues	$	5,220	$	287	$	75		$	5,582	$	34		$	(27	)	$	5,589
Segment income (loss)(a)(b)	$	632	$	52	$	(30	)	$	654	$	(51	)	$	(3	)	$	600
Add back noncontrolling interests																4
Loss from discontinued operations, net of tax(c)																(57		)
Net income																$	547

(a)    Other includes after-tax costs to achieve the Progress Energy merger of $14 million.

(b) Commercial Portfolio includes state tax expense of $41 million, resulting from changes to state apportionment factors due to the sale of the Disposal Group, that does not qualify for discontinued operations. Refer to Note 2 for further information related to the sale.

(c) Includes the after-tax impact of $46 million for the agreement in principle reached in a lawsuit related to the Disposal Group. Refer to Note 5 for further information related to the lawsuit.

	Six Months Ended June 30, 2016
							Total
	Regulated		International		Commercial		Reportable
(in millions)	Utilities		Energy		Portfolio		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	10,340	$	516	$	227	$	11,083	$	23		$	—		$	11,106
Intersegment revenues	18		—		—		9		35			(53		)	—
Total revenues	$	10,358	$	516	$	227	$	11,092	$	58		$	(53	)	$	11,106
Segment income (loss)(a)(b)	$	1,413	$	21	$	41	$	1,475	$	(274	)	$	—		$	1,201
Add back noncontrolling interests															8
Income from discontinued operations, net of tax															2
Net income															$	1,211

(a) Other includes after-tax charges for costs to achieve mergers of $143 million, primarily due to unrealized losses on forward-starting interest rate swaps related to the Piedmont acquisition, and cost savings initiatives of $27 million primarily due to severance costs. See Notes 2 and 9 for additional information related to the forward-starting interest rate swaps.

(b) International Energy includes an after-tax impairment charge of $145 million. See Note 2 for additional information.

	Six Months Ended June 30, 2015
								Total
	Regulated		International		Commercial			Reportable
(in millions)	Utilities		Energy		Portfolio			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	10,924	$	560	$	148		$	11,632	$	22		$	—		$	11,654
Intersegment revenues	19		—		—			19		39			(58		)	—
Total revenues	$	10,943	$	560	$	148		$	11,651	$	61		$	(58	)	$	11,654
Segment income (loss)(a)(b)	$	1,406	$	88	$	(23	)	$	1,471	$	(94	)	$	(4	)	$	1,373
Add back noncontrolling interests																7
Income from discontinued operations, net of tax(c)																34
Net income																$	1,414

(a)    Other includes after-tax costs to achieve the Progress Energy merger of $27 million.

(b) Commercial Portfolio includes state tax expense of $41 million, resulting from changes to state apportionment factors due to the sale of the Disposal Group, that does not qualify for discontinued operations. Refer to Note 2 for further information related to the sale.

(c) Includes after-tax impact of $53 million for the agreement in principle reached in a lawsuit related to the Disposal Group. Refer to Note 5 for further information related to the lawsuit.

SUBSIDIARY REGISTRANTS

The Subsidiary Registrants each have one reportable operating segment, Regulated Utilities, which generates, transmits, distributes and sells electricity, and for Duke Energy Ohio, also transports and sells natural gas. The remainder of operations is primarily comprised of unallocated corporate costs and classified as Other. The following table provides the amount of Other net expense.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
(in millions)	2016			2015			2016			2015
Duke Energy Carolinas	$	(17	)	$	(10	)	$	(34	)	$	(18	)
Progress Energy(a)	(45		)	(42		)	(94		)	(84		)
Duke Energy Progress	(8		)	(4		)	(16		)	(8		)
Duke Energy Florida	(5		)	(3		)	(9		)	(6		)
Duke Energy Ohio	(10		)	(6		)	(19		)	(8		)
Duke Energy Indiana	(5		)	(2		)	(7		)	(4		)

(a) Other for Progress Energy also includes interest expense on corporate debt instruments of $55 million and $111 million for the three and six months endedJune 30, 2016, respectively, and $59 million and $119 million for the three and six months endedJune 30, 2015, respectively.

The assets of the Subsidiary Registrants are substantially all included within the Regulated Utilities segment at June 30, 2016.

Duke Energy Ohio

Duke Energy Ohio had two reportable operating segments, Regulated Utilities and Commercial Portfolio, during 2015 prior to the sale of the nonregulated Midwest generation business. Duke Energy Ohio's Commercial Portfolio segment had total revenues of $14 million and segment loss of $9 million for the six months ended June 30, 2015. As a result of the sale discussed in Note 2, Commercial Portfolio no longer qualifies as a Duke Energy Ohio reportable operating segment. Therefore, beginning in the second quarter of 2015, all of the remaining assets and related results of operations previously presented in Commercial Portfolio are presented in Regulated Utilities and Other.

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Regulatory Matters

6 Months Ended

Jun. 30, 2016

Regulated Operations [Abstract]

Regulatory Matters

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, Kentucky and Indiana), as well as sales of transmission service.

Duke Energy Carolinas and Duke Energy Progress

Ash Basin Closure Costs Deferral

On July 13, 2016, in response to a joint petition of Duke Energy Carolinas and Duke Energy Progress the PSCSC issued an accounting order for the deferment into a regulatory account of certain costs incurred in connection with federal and state environmental remediation requirements related to the permanent closure of ash basins and other ash storage units at coal-fired generating facilities that have provided or are providing generation to customers located in South Carolina. The decision allows for ash basin closure expenses to be partially offset with excess regulatory liability amounts from the deferral of nuclear decommissioning costs that are collected from South Carolina retail customers and for Duke Energy Progress to offset incurred ash basin closure costs with costs of removal amounts collected from customers. The PSCSC's ruling does not change retail rates or the tariff amounts and in no way limits the PSCSC's ability to challenge the reasonableness of expenditures in subsequent proceedings.

FERC Transmission Return on Equity Complaints

On January 7, 2016, a group of transmission service customers filed a complaint with the FERC that the rate of return on equity of 10.2 percent in Duke Energy Carolinas' transmission formula rates is excessive and should be reduced to no higher than 8.49 percent, effective upon the complaint date. On the same date a similar complaint was filed with the FERC claiming that the rate of return on equity of 10.8 percent in Duke Energy Progress' transmission formula rates is excessive and should be reduced to no higher than 8.49 percent, effective upon the complaint date. On April 21, 2016, the FERC issued an order which consolidated the cases, set a refund effective date of January 7, 2016, and set the consolidated case for settlement and hearing. Duke Energy Carolinas and Duke Energy Progress do not expect the potential impact on results of operations, cash flows or financial position to be material.

Duke Energy Carolinas

Advanced Metering Infrastructure Deferral

On July 12, 2016, the PSCSC issued an accounting order for Duke Energy Carolinas to defer the financial effects of depreciation expense incurred for the installation of advanced metering infrastructure (AMI) meters, the carrying costs on the investment at its weighted average cost of capital and the carrying costs on the deferred costs at its weighted average cost of capital not to exceed $45 million. The decision also allows Duke Energy Carolinas to continue to depreciate the non-AMI meters to be replaced. Current retail rates will not change as a result of the decision and the PSCSC's ability to challenge the reasonableness of expenditures in subsequent proceedings is not limited.

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 Duke Energy Carolinas' existing William States Lee Generating Station in Anderson, South Carolina. Duke Energy Carolinas began construction in July 2015 and estimates a cost to build of $600 million for its share of the facility, including 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 (SCCL) and Southern Alliance for Clean Energy (SACE) jointly filed a Notice of Appeal with the Court of Appeals of South Carolina (S.C. Court of Appeals) seeking the court's review of the PSCSC's decision, claiming the PSCSC did not properly consider a request related to a proposed solar facility prior to granting approval of the CECPCN. The S.C. Court of Appeals affirmed the PSCSC's decision on February 10, 2016, and on March 24, 2016, denied a request for rehearing filed by SCCL and SACE. On April 21, 2016, SCCL and SACE petitioned the South Carolina Supreme Court for review of the S.C. Court of Appeals decision. Duke Energy Carolinas filed its response on June 13, 2016, and SCCL and SACE filed a reply on June 23, 2016. Duke Energy Carolinas cannot predict the outcome of this matter.

Duke Energy Progress

South Carolina Rate Case

On July 1, 2016, Duke Energy Progress filed an application with the PSCSC requesting an average 14.5 percent increase in retail revenues. The requested rate change would increase annual revenues by approximately $79 million, with a rate of return on equity of 10.75 percent. The increase is designed to recover the cost of investment in new generation infrastructure, environmental expenditures including allocated historical ash basin closure costs and increased nuclear operating costs. Duke Energy Progress has requested new rates to be effective January 1, 2017. A hearing has been scheduled to begin on October 31, 2016. Duke Energy Progress cannot predict the outcome of this matter.

Western Carolinas Modernization Plan

On November 4, 2015, in response to community feedback, Duke Energy Progress announced a revised Western Carolinas Modernization Plan with an estimated cost of $1.1 billion. The revised plan includes retirement of the existing Asheville coal-fired plant, the construction of two 280 MW combined-cycle natural gas plants having dual fuel capability, with the option to build a third natural gas simple cycle unit in 2023 based upon the outcome of initiatives to reduce the region's power demand. The revised plan includes upgrades to existing transmission lines and substations, but eliminates the need for a new transmission line and a new substation associated with the project in South Carolina. The revised plan has the same overall project cost as the original plan and the plans to install solar generation remain unchanged. Duke Energy Progress has also proposed to add a pilot battery storage project. These investments will be made within the next seven years. Duke Energy Progress is also working with the local natural gas distribution company to upgrade an existing natural gas pipeline to serve the natural gas plant. The plan requires various approvals including regulatory approvals in North Carolina.

Duke Energy Progress filed for a Certificate of Public Convenience and Necessity (CPCN) with the NCUC for the new natural gas units on January 15, 2016. On March 28, 2016, the NCUC issued an order approving the CPCN for the new combined-cycle natural gas plants, but denying the CPCN for the contingent simple cycle unit without prejudice to Duke Energy Progress to refile for approval in the future. Construction of these plants is scheduled to begin in 2016 and the plants are expected to be in service by late 2019. Duke Energy Progress plans to file for future approvals related to the proposed solar generation and pilot battery storage project.

On May 27, 2016, NC WARN and The Climate Times filed a notice of appeal from the CPCN order to the N.C. Court of Appeals. On May 31, 2016, Duke Energy Progress filed a motion to dismiss the notice of appeal with the NCUC due to NC WARN's and The Climate Times' failure to post a required appeal bond. After a series of filings, an NCUC order, petitions to the N.C. Court of Appeals and an evidentiary hearing, on July 8, 2016, the NCUC issued an order setting NC WARN's and The Climate Times' appeal bond at $98 million. On July 28, 2016, NC WARN and The Climate Times filed a notice of appeal and exceptions from the NCUC's July 8, 2016, appeal bond order. On August 2, 2016, the NCUC granted Duke Energy Progress' motion to dismiss NC WARN's and The Climate Times' notice of appeal from the CPCN order due to failure to post the requisite bond. Duke Energy Progress cannot predict the outcome of this matter.

The carrying value of the 376 MW Asheville coal-fired plant, including associated ash basin closure costs, of $506 million and $548 million are included in Generation facilities to be retired, net on Duke Energy Progress' Condensed Consolidated Balance Sheet as of June 30, 2016 and December 31, 2015, respectively.

Duke Energy Florida

Hines Chiller Uprate Project

On May 20, 2016, Duke Energy Florida filed a petition seeking approval to include in base rates the revenue requirement for a Chiller Uprate Project (Uprate Project) at the Hines station. Duke Energy Florida proposes to complete the Uprate Project in two phases: phase one work on Hines Units 1-3 and the common equipment to be completed and placed into service in October 2016; and phase two work on Hines Unit 4 to be completed and placed into service in January 2017. The final construction cost estimate for both phases of approximately $150 million is below the cost estimate provided during the need determination proceeding. Duke Energy Florida estimates the annual retail revenue requirements for phases one and two to be approximately $16 million and $3 million, respectively. Duke Energy Florida’s petition seeks approval of both revenue requirements, but only seeks to include the phase one revenue requirement in base rates and customer bills beginning November 2016, and will separately petition to include the phase two revenue requirement in base rates and customer bills beginning February 2017. Duke Energy Florida cannot predict the outcome of this matter.

Purchase of Osprey Energy Center

In December 2014, Duke Energy Florida and Osprey Energy Center, LLC, a wholly owned subsidiary of Calpine Corporation (Calpine), entered into an Asset Purchase and Sale Agreement for the purchase of a 599 MW combined-cycle natural gas plant in Auburndale, Florida (Osprey Plant acquisition) for approximately $166 million. In July 2015, the FERC and the FPSC issued separate orders of approval for the Osprey Plant acquisition. The Hart-Scott-Rodino waiting period expired on May 2, 2016. Closing of the acquisition is expected to occur by the first quarter of 2017, upon the expiration of an existing Power Purchase Agreement between Calpine and Duke Energy Florida. In anticipation of closing, in August 2016, Duke Energy Florida filed a petition seeking approval to include in base rates the revenue requirements for the Osprey Plant acquisition to be included in customer bills beginning in February 2017. Duke Energy Florida estimates the retail revenue requirements to be approximately $48 million.

Crystal River Unit 3 Regulatory Asset

In June 2015, the governor of Florida signed legislation to allow utilities to issue nuclear asset-recovery bonds to finance the recovery of certain retired nuclear generation assets, with approval of the FPSC. In November 2015, the FPSC issued a financing order approving Duke Energy Florida’s request to issue nuclear asset-recovery bonds to finance its unrecovered regulatory asset related to Crystal River Unit 3 (Crystal River 3) through a wholly owned special purpose entity. Nuclear asset-recovery bonds replace the base rate recovery methodology authorized by the 2013 Revised and Restated Stipulation and Settlement Agreement (2013 Agreement) and result in a lower rate impact to customers with a recovery period of approximately 20 years.

Pursuant to provisions in Florida Statutes and the FPSC financing order, in 2016, Duke Energy Florida formed Duke Energy Florida Project Finance, LLC (DEFPF), a wholly owned, bankruptcy remote special purpose subsidiary for the purpose of issuing nuclear asset-recovery bonds. In June 2016, DEFPF issued $1,294 million aggregate principal amount of senior secured bonds (nuclear asset-recovery bonds) to finance the recovery of Duke Energy Florida's Crystal River 3 regulatory asset.

In connection with this financing, net proceeds to DEFPF of approximately $1,287 million, after underwriting costs, were used to acquire nuclear asset-recovery property from Duke Energy Florida and to pay transaction related expenses. The nuclear asset-recovery property includes the right to impose, bill, collect and adjust a non-bypassable nuclear asset-recovery charge, to be collected on a per kilowatt-hour basis from all Duke Energy Florida retail customers until the bonds are paid in full. Duke Energy Florida began collecting the nuclear asset-recovery charge on behalf of DEFPF in customer rates in July 2016.

See Notes 6 and 12 for additional information.

Duke Energy Ohio

Natural Gas Pipeline Extension

Duke Energy Ohio is proposing to install a new natural gas pipeline in its Ohio service territory to increase system reliability and enable the retirement of older infrastructure. The proposed project involves the installation of a natural gas line and is estimated to cost between $100 million and $150 million. Duke Energy Ohio is currently evaluating potential routes and has conducted public informational meetings. Duke Energy Ohio will narrow the route options to two and then make a filing with the Ohio Power Siting Board for approval of one of the two proposed routes.

Advanced Metering Infrastructure

On April 25, 2016, Duke Energy Kentucky filed with the KPSC an application for approval of a certificate of public convenience and necessity for the construction of advanced metering infrastructure. Duke Energy Kentucky anticipates that the estimated $49 million project, if approved, will take about two years to complete. Duke Energy Kentucky also requested approval to establish a regulatory asset of approximately $10 million for the remaining book value of existing meter equipment and inventory that will be replaced. On July 20, 2016, the Kentucky Attorney General, the only intervenor in the proceeding, moved to dismiss the application. Duke Energy Kentucky filed its opposition to the Kentucky Attorney General's motion to dismiss on July 27, 2016. Duke Energy Kentucky cannot predict the outcome of this matter.

Accelerated Natural Gas Service Line Replacement Rider

On January 20, 2015, Duke Energy Ohio filed an application for approval of an accelerated natural gas service line replacement program (ASRP). Under the ASRP, Duke Energy Ohio proposes to replace certain natural gas service lines on an accelerated basis. The program is proposed to last 10 years. Through the ASRP, Duke Energy Ohio also proposes to complete preliminary survey and investigation work related to natural gas service lines that are customer owned and for which it does not have valid records and, further, to relocate interior natural gas meters to suitable exterior locations where such relocation can be accomplished. Duke Energy Ohio projects total capital and operations and maintenance expenditures under the ASRP to approximate $320 million. The filing also seeks approval of Rider ASRP to recover related expenditures. Duke Energy Ohio proposes to update Rider ASRP on an annual basis. Duke Energy Ohio’s application is pending before the PUCO and it is uncertain when an order will be issued. Intervenors oppose the ASRP, primarily because they believe the program is neither required nor necessary under federal pipeline regulation. The hearing concluded on November 19, 2015, and initial and reply briefs were filed, with briefing complete on December 23, 2015. Duke Energy Ohio cannot predict the outcome of this matter.

Energy Efficiency Cost Recovery

On March 28, 2014, Duke Energy Ohio filed an application for recovery of program costs, lost distribution revenue and performance incentives related to its energy efficiency and peak demand reduction programs. These programs are undertaken to comply with environmental mandates set forth in Ohio law. After a comment period, the PUCO approved Duke Energy Ohio’s application, but found that Duke Energy Ohio was not permitted to use banked energy savings from previous years in order to calculate the amount of allowed incentive. This conclusion represented a change to the cost recovery mechanism that had been agreed to by intervenors and approved by the PUCO in previous cases. The PUCO granted the applications for rehearing filed by Duke Energy Ohio and an intervenor on July 8, 2015. Substantive ruling on the application for rehearing is pending. On January 6, 2016, Duke Energy Ohio and PUCO Staff entered into a stipulation pending PUCO approval, resolving the issues related to, among other things, performance incentives and the PUCO Staff audit of 2013 costs. Based on the stipulation, in December 2015, Duke Energy Ohio re-established approximately $20 million of revenues that had been reversed in the second quarter of 2015. A hearing on the stipulation commenced on March 10, 2016, and the post-hearing briefing has concluded. Duke Energy Ohio cannot predict the outcome of this matter.

2012 Natural Gas Rate Case/Manufactured Gas Plant Cost Recovery

On November 13, 2013, the PUCO issued an order approving a settlement of Duke Energy Ohio’s natural gas base rate case and authorizing the recovery of costs incurred between 2008 and 2012 for environmental investigation and remediation of two former manufactured gas plant (MGP) sites. The order contained deadlines for the recovery of such costs. Specifically, for the property known as the East End site, PUCO established a deadline of December 31, 2016, and for the West End site, a deadline of December 31, 2019. The PUCO authorized Duke Energy Ohio to seek to extend these deadlines due to certain circumstances. On May 16, 2016, Duke Energy Ohio filed an application to extend the deadline for cost recovery applicable to the East End site. The order also authorized Duke Energy Ohio to continue deferring environmental investigation and remediation costs incurred subsequent to 2012 and to submit annual filings to adjust the MGP rider for future costs. Duke Energy Ohio submitted MGP rider update filings in 2014, 2015, and 2016 for recovery of costs incurred in 2013, 2014, and 2015, which are pending approval. Duke Energy Ohio cannot predict the outcome of this matter.

Regional Transmission Organization 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. The PUCO approved a settlement related to Duke Energy Ohio’s recovery of certain costs of the Regional Transmission Organization (RTO) realignment via a non-bypassable rider. Duke Energy Ohio is allowed to recover all MISO Transmission Expansion 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. The KPSC also approved a 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.

Duke Energy Ohio had a recorded liability for its exit obligation and share of MTEP costs, excluding MVP, of $91 million and $92 million, respectively, at June 30, 2016 and December 31, 2015, within Other in Current liabilities and Other in Deferred credits and other liabilities on Duke Energy Ohio’s Condensed Consolidated Balance Sheets. The retail portion of MTEP costs billed by MISO are recovered by Duke Energy Ohio through a non-bypassable rider. As of June 30, 2016 and December 31, 2015, Duke Energy Ohio had $72 million recorded in Regulatory assets on the Condensed Consolidated Balance Sheets.

MVP. MISO approved 17 MVP proposals prior to Duke Energy Ohio’s exit from MISO on December 31, 2011. Construction of these projects is expected to continue through 2020. Costs of these projects, including operating and maintenance costs, property and income taxes, depreciation and an allowed return, are allocated and billed to MISO transmission owners.

On December 29, 2011, MISO filed a tariff with the FERC providing for the allocation of MVP costs to a withdrawing owner based on monthly energy usage. The FERC set for hearing (i) whether MISO’s proposed cost allocation methodology to transmission owners who withdrew from MISO prior to January 1, 2012, is consistent with the tariff at the time of their withdrawal from MISO and, (ii) if not, what the amount of and methodology for calculating any MVP cost responsibility should be. 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. 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 FERC to overturn the ALJ’s decision.

On October 29, 2015, the FERC issued an order reversing the ALJ's decision. The FERC ruled the cost allocation methodology is not consistent with the MISO tariff and that Duke Energy Ohio has no liability for MVP costs after its withdrawal from MISO. On May 19, 2016, the FERC denied the request for rehearing filed by MISO and the MISO Transmission Owners. On July 15, 2016, the MISO Transmission Owners filed a petition for review with the U.S. Court of Appeals for the Sixth Circuit. Duke Energy Ohio cannot predict the outcome of this matter.

Duke Energy Indiana

Coal Combustion Residual Plan

On March 17, 2016, Duke Energy Indiana filed with the IURC a request for approval of its first group of federally mandated Coal Combustion Residual (CCR) rule compliance projects (Phase I CCR Compliance Projects) to comply with the U.S. Environmental Protection Agency's (EPA) CCR rule. The projects in this Phase I filing are CCR compliance projects, including the conversion of Cayuga and Gibson Stations to dry bottom ash handling and related water treatment. Duke Energy Indiana has requested timely recovery of approximately $380 million in retail capital costs and incremental operating and maintenance costs under a federal mandate tracker which provides for timely recovery of 80 percent of such costs and deferral with carrying costs of 20 percent of such costs for recovery in a subsequent retail base rate case. An evidentiary hearing is scheduled for November 2016. Duke Energy Indiana cannot predict the outcome of this matter.

Edwardsport Integrated Gasification Combined Cycle Plant

On November 20, 2007, the IURC granted Duke Energy Indiana a CPCN for the construction of the Edwardsport Integrated Gasification Combined Cycle (IGCC) Plant. 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. The Edwardsport IGCC Plant 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.

The ninth semi-annual IGCC rider order was appealed by the Joint Intervenors. The proceeding has been remanded to the IURC for further proceedings and additional findings on the tax in-service issue. An evidentiary hearing has been set for September 13, 2016.

The 11th through 15th semi-annual IGCC riders and a subdocket to Duke Energy Indiana's fuel adjustment clause remain pending at the IURC. Issues in these filings include the determination whether the IGCC plant was properly declared in-service for ratemaking purposes in June 2013 and a review of the operational performance of the plant. On September 17, 2015, Duke Energy Indiana, the Office of Utility Consumer Counselor, the Industrial Group and Nucor Steel Indiana reached a settlement agreement to resolve these pending issues. On January 15, 2016, The Citizens Action Coalition of Indiana, Inc., Sierra Club, Save the Valley and Valley Watch joined a revised settlement (IGCC settlement). The IGCC settlement will result in customers not being billed for previously incurred operating costs of $87.5 million, and for additional Duke Energy Indiana payments and commitments of $5.5 million for attorneys’ fees and amounts to fund consumer programs. Attorneys’ fees and expenses for the new settling parties will be addressed in a separate proceeding. Duke Energy Indiana recognized pretax impairment and related charges of $93 million in 2015. Additionally, under the IGCC settlement, the operating and maintenance expenses and ongoing maintenance capital at the plant are subject to certain caps during the years of 2016 and 2017. The IGCC settlement also includes a commitment to either retire or stop burning coal by December 31, 2022, at the Gallagher Station. Pursuant to the IGCC settlement, the in-service date used for accounting and ratemaking will remain as June 2013. Remaining deferred costs will be recovered over eight years and not earn a carrying cost. The IGCC settlement, which is opposed by an intervenor, is subject to IURC approval. An evidentiary hearing on the IGCC settlement was held on April 18, 2016, and a decision is expected in the third quarter of 2016. As of June 30, 2016, deferred costs related to the project are approximately $175 million. Under the IGCC settlement, future IGCC riders will be filed annually, rather than every six months, with the next filing scheduled for first quarter 2017.

Duke Energy Indiana cannot predict the outcome of these matters or future IGCC rider proceedings.

FERC Transmission Return on Equity Complaint

Customer groups have filed with the FERC complaints against MISO and its transmission-owning members, including Duke Energy Indiana, alleging, among other things, that the current base rate of return on equity earned by MISO transmission owners of 12.38 percent is unjust and unreasonable. The latest complaint, filed on February 12, 2015, claims the base rate of return on equity should be reduced to 8.67 percent and requests a consolidation of complaints. The motion to consolidate complaints was denied. On January 5, 2015, the FERC issued an order accepting the MISO transmission owners 0.50 percent adder to the base rate of return on equity based on participation in an RTO subject to it being applied to a return on equity that is shown to be just and reasonable in the pending return on equity complaints. A hearing in the base return on equity proceeding was held in August 2015. On December 22, 2015, the presiding FERC ALJ in the first complaint issued an Initial Decision in which he set the base rate of return on equity at 10.32 percent. On June 30, 2016, the presiding FERC ALJ in the second complaint issued an Initial Decision setting the base rate of return on equity at 9.70 percent. The Initial Decisions will be reviewed by the FERC. Duke Energy Indiana currently believes these matters will have an immaterial impact on its results of operations, cash flows and financial position.

Grid Infrastructure Improvement Plan

On August 29, 2014, pursuant to a new statute, 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. The plan also provided for cost recovery through a transmission and distribution rider (T&D Rider). In May 2015, the IURC denied the original proposal due to an insufficient level of detailed projects and cost estimates in the plan. On December 7, 2015, Duke Energy Indiana filed a revised infrastructure improvement plan with an estimated cost of $1.8 billion in response to guidance from IURC orders and the Indiana Court of Appeals decisions related to this new statute. The revised plan uses a combination of advanced technology and infrastructure upgrades to improve service to customers and provide them with better information about their energy use. It also provides for cost recovery through a T&D rider. In March 2016, Duke Energy Indiana entered into a settlement with all parties to the proceeding except the Citizens Action Coalition of Indiana, Inc. The settlement agreement decreased the capital expenditures eligible for timely recovery of costs in the seven-year plan to approximately $1.4 billion, including the removal of an AMI project. The settlement provided for deferral accounting for depreciation and post-in-service carrying costs for AMI projects outside the seven-year plan. Duke Energy Indiana withdrew its request for a regulatory asset for current meters and will retain any savings associated with future AMI installation until the next retail base rate case, which is required to be filed prior to the end of the seven-year plan. Under the settlement, the return on equity to be used in the T&D Rider is 10 percent. The IURC approved the settlement and issued a final order on June 29, 2016.

OTHER REGULATORY MATTERS

Atlantic Coast Pipeline

On September 2, 2014, Duke Energy, Dominion Resources (Dominion), Piedmont and AGL Resources announced the formation of a company, ACP, to build and own the proposed Atlantic Coast Pipeline (the pipeline), a 564-mile interstate natural gas pipeline. The pipeline is designed to meet the needs identified in requests for proposals by Duke Energy Carolinas, Duke Energy Progress and Piedmont. Dominion will build and operate the pipeline and has a 45 percent ownership percentage in ACP. Duke Energy has a 40 percent ownership interest in ACP through its Commercial Portfolio segment. Piedmont owns 10 percent and the remaining share is owned by 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. On September 18, 2015, ACP filed an application with the FERC requesting a CPCN authorizing ACP to construct the pipeline. FERC approval of the application is expected in early 2017 and construction is projected to begin in summer of 2017, with a targeted in-service date of late 2018. ACP is working with various agencies to develop the final pipeline route. ACP also requested approval of an open access tariff and the precedent agreements it entered into with future pipeline customers, including Duke Energy Carolinas and Duke Energy Progress.

On October 24, 2015, Duke Energy entered into a Merger Agreement with Piedmont. The ACP partnership agreement includes provisions to allow Dominion an option to purchase additional ownership interest in ACP to maintain a leading ownership percentage. Any change in ownership interests is not expected to be material to Duke Energy. Refer to Note 2 for further information related to Duke Energy's proposed acquisition of Piedmont.

Sabal Trail Transmission, LLC Pipeline

On May 4, 2015, Duke Energy acquired a 7.5 percent ownership interest from Spectra Energy in the proposed 500-mile Sabal Trail natural gas pipeline. Spectra Energy will continue to own 59.5 percent of the Sabal Trail pipeline and NextEra Energy will own the remaining 33 percent. The Sabal Trail pipeline will traverse Alabama, Georgia and Florida to meet rapidly growing demand for natural gas in those states. The primary customers of the Sabal Trail pipeline, Duke Energy Florida and Florida Power & Light Company (FP&L), have each contracted to buy pipeline capacity for 25-year initial terms. On February 3, 2016, the FERC issued an order granting the request for a CPCN to construct and operate the Sabal Trail pipeline. The Sabal Trail pipeline requires additional regulatory approvals and is scheduled to begin service in mid-2017.

Progress Energy Merger FERC Mitigation

In June 2012, the FERC approved the merger with Progress Energy, including Duke Energy and Progress Energy’s revised market power mitigation plan, the Joint Dispatch Agreement (JDA) and the joint Open Access Transmission Tariff. The revised market power mitigation plan provided for the acceleration of one transmission project and the completion of seven other transmission projects (Long-Term FERC Mitigation) and interim firm power sale agreements during the completion of the transmission projects (Interim FERC Mitigation). The Long-Term FERC Mitigation 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.

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. The city of New Bern filed a protest and requested that FERC order additional mitigation. On October 29, 2014, the FERC ordered that the amount of the stub mitigation be increased from 25 MW to 129 MW. The stub mitigation is Duke Energy’s commitment to set aside for third parties a certain quantity of firm transmission capacity from Duke Energy Carolinas to Duke Energy Progress during summer off-peak hours. The 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. The costs to comply with this order are not material. The FERC also referred Duke Energy’s failure to expressly designate the phase shifter reactivation as a mitigation project in the original mitigation plan filing in March 2012 to the FERC Office of Enforcement for further inquiry. In response, and since December 2014, the FERC Office of Enforcement has conducted a nonpublic investigation of Duke Energy's market power analyses included in the Progress merger filings submitted to FERC. Duke Energy cannot predict the outcome of this investigation.

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 long term (10 to 20 years), 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 Florida and Indiana earlier than their current estimated useful lives. These facilities do not have the requisite emission control equipment, primarily to meet EPA regulations recently approved or proposed.

The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement due to a lack of requisite environmental control equipment. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of June 30, 2016.

		Remaining Net
	Capacity	Book Value(a)
	(in MW)	(in millions)
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2	873	126
Duke Energy Indiana
Wabash River Unit 6(b)	318	34
Gallagher Units 2 and 4(c)	280	135
Total Duke Energy	1,471	295

(a) Remaining net book value amounts exclude any capitalized asset retirement costs.

(b) In April 2016, Wabash River 6 terminated coal burning operations and is targeted for retirement by the end of 2016. The total net book value of $93 million for the retail portion of Wabash River Unit 6 and the retail portion of capitalized asset retirement costs for Wabash River Units 2 through 6 is classified as Generation facilities to be retired, net on Duke Energy Indiana's Condensed Consolidated Balance Sheet at June 30, 2016.

(c) Duke Energy Indiana committed to either retire or stop burning coal at Gallagher Units 2 and 4 by December 31, 2022, as part of the proposed settlement of Edwardsport IGCC matters.

On October 23, 2015, the EPA published in the Federal Register the Clean Power Plan (CPP) rule for regulating carbon dioxide (CO2) emissions from existing fossil fuel-fired electric generating units (EGUs). The CPP establishes CO2 emission rates and mass cap goals that apply to fossil fuel-fired generation. Under the CPP, states are required to develop and submit a final compliance plan, or an initial plan with an extension request, to the EPA by September 6, 2016, or no later than September 6, 2018, with an approved extension. These state plans are subject to EPA approval, with a federal plan applied to states that fail to submit a plan to the EPA or if a state plan is not approved. Legal challenges to the CPP have been filed by stakeholders and motions to stay the requirements of the rule pending the outcome of the litigation were granted by the U.S. Supreme Court in February 2016. Final resolution of these legal challenges could take several years. Compliance with CPP could cause the industry to replace coal generation with natural gas and renewables, especially in states that have significant CO2 reduction targets under the rule. Costs to operate coal-fired generation plants continue to grow due to increasing environmental compliance requirements, including ash management costs unrelated to CPP, and this may result in the retirement of coal-fired generation plants earlier than the current end of useful lives. Duke Energy continues to evaluate the need to retire generating facilities and plans to seek regulatory recovery, where appropriate, for amounts that have not been recovered upon asset retirements. However, recovery is subject to future regulatory approval, including the recovery of carrying costs on remaining book values, and therefore cannot be assured.

Refer to the "Western Carolinas Modernization Plan" discussion above for details of Duke Energy Progress' planned retirements.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Commitments And Contingencies

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.

Remediation Activities

In addition to Asset Retirement Obligations recorded as a result of various environmental regulations, the Duke Energy Registrants are responsible for environmental remediation at various sites. These include certain 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, remediation activities vary based upon site conditions and location, 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 environmental impacts 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 tables contain 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, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Balance at beginning of period	$	97		$	10		$	17		$	3		$	14		$	54		$	12
Provisions/adjustments	28			3			4			1			3			1			21
Cash reductions	(7		)	(2		)	(4		)	(1		)	(3		)	(1		)	(1		)
Balance at end of period	$	118		$	11		$	17		$	3		$	14		$	54		$	32

	Six Months Ended June 30, 2015
				Duke					Duke			Duke			Duke			Duke
	Duke			Energy		Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas		Energy			Progress			Florida			Ohio			Indiana
Balance at beginning of period	$	97		$	10	$	17		$	5		$	12		$	54		$	10
Provisions/adjustments	5			—		2			—			2			1			3
Cash reductions	(4		)	—		(2		)	(1		)	(1		)	(1		)	(1		)
Balance at end of period	$	98		$	10	$	17		$	4		$	13		$	54		$	12

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 not material except as presented in the table below.

(in millions)
Duke Energy	$	75
Duke Energy Carolinas	22
Duke Energy Ohio	42
Duke Energy Indiana	7

North Carolina and South Carolina Ash Basins

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy Carolinas’ retired Dan River Steam Station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy Carolinas estimates 30,000 to 39,000 tons of ash and 24 million to 27 million gallons of basin water were released into the river. In July 2014, Duke Energy completed remediation work identified by the EPA and continues to cooperate with the EPA's civil enforcement process. Future costs related to the Dan River release, including pending or future state or federal civil enforcement proceedings, future regulatory directives, natural resources damages, additional pending litigation, future claims or litigation and long-term environmental impact costs, cannot be reasonably estimated at this time.

North Carolina Department of Environmental Quality (NCDEQ), formerly the North Carolina Department of Environment and Natural Resources, has historically assessed Duke Energy Carolinas and Duke Energy Progress with Notice of Violations (NOV) for violations that were most often resolved through satisfactory corrective actions and minor, if any, fines or penalties. Subsequent to the Dan River matter discussed above, Duke Energy Carolinas and Duke Energy Progress have been served with a higher level of Notices of Violation (NOVs), including for violations at L.V. Sutton Plant and Dan River Steam Station. In August 2014, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' L.V. Sutton Plant. On March 10, 2015, NCDEQ issued a civil penalty of approximately $25 million to Duke Energy Progress for environmental damages related to groundwater contamination at the L.V. Sutton Plant. On February 8, 2016, NCDEQ assessed a penalty of approximately $6.8 million, including enforcement costs, against Duke Energy Carolinas related to stormwater pipes and associated discharges at the Dan River Steam Station. Duke Energy Carolinas recorded a charge in December 2015 for this penalty. See "Litigation" section below for additional discussion of matters related to these penalties. These fines and penalties are unprecedented and were not consistent with historic enforcement practices of NCDEQ. Based on historic practices the expected liability of any existing notice of violations would not be material. Duke Energy Carolinas and Duke Energy Progress cannot predict whether the NCDEQ will assess future penalties related to existing NOVs and if such penalties would be material.

Asset retirement obligations recorded on the Duke Energy Carolinas and Duke Energy Progress Condensed Consolidated Balance Sheets at June 30, 2016 and December 31, 2015, include the legal obligation for closure of coal ash basins and the disposal of related ash as a result of the North Carolina Coal Ash Management Act of 2014, as amended (Coal Ash Act), and other agreements. In January 2016, NCDEQ published draft proposed risk classifications for sites not specifically delineated by the Coal Ash Act as high priority. These risk rankings were generally determined based on three primary criteria: structural integrity of the impoundments and impact to both surface and groundwater. NCDEQ categorized 12 basins at four sites as intermediate risk and four basins at 3 plants as low risk. Basins at high priority sites (Dan River, Riverbend, Asheville and Sutton) require closure through excavation including a combination of transferring the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of high priority basins is required to be completed no later than August 1, 2019, except for Asheville which is required to be completed no later than August 1, 2022. Intermediate risk basins require closure through excavation including a combination of converting the basin to a lined industrial landfill, transferring of the ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of intermediate risk basins is required to be completed no later than December 31, 2024. Low risk basins require closure through either the combination of the installation and maintenance of a cap system and groundwater monitoring system designed to minimize infiltration and erosion or other closure options available to intermediate-risk basins. Closure of low risk basins is required to be completed no later than December 31, 2029. NCDEQ also categorized nine basins at six plants as “low-to-intermediate” risk, thereby not assigning a definitive risk ranking at that time. On May 18, 2016, NCDEQ issued new proposed risk classifications, ranking all originally proposed low risk and "low-intermediate" risk sites as intermediate.

On July 14, 2016, the Governor of North Carolina signed legislation which amends the Coal Ash Act and requires Duke Energy to undertake dam improvement projects and to provide access to a permanent alternative drinking water source to certain residents within a half mile of coal ash basin compliance boundaries and to certain other potentially impacted residents. The new legislation also ranks basins at the H.F. Lee, Cape Fear and Weatherspoon stations as intermediate risk consistent with Duke Energy's previously announced plans to excavate those basins. These specific intermediate basins require closure through excavation including a combination of transferring ash to an appropriate engineered landfill or conversion of the ash for beneficial use. Closure of these specific intermediate basins is required to be completed no later than August 1, 2028. Additionally, the new legislation requires the installation and operation of three large-scale coal ash beneficiation projects which are expected to produce reprocessed ash for use in the concrete industry. Closure of basins at sites with these beneficiation projects are required to be completed no later than December 31, 2029. Upon satisfactory completion of the dam improvement projects and installation of alternate drinking water sources by October 15, 2018, the legislation requires NCDEQ to reclassify intermediate risk sites, excluding H.F. Lee, Cape Fear and Weatherspoon, as low risk.

Per the Coal Ash Act, final proposed classifications were to be subject to Coal Ash Management Commission (Coal Ash Commission) approval. In March 2016, the Coal Ash Commission created by the Coal Ash Act was disbanded by the Governor of North Carolina based on a North Carolina Supreme Court ruling regarding the constitutionality of the body. The new legislation eliminates the Coal Ash Commission and transfers responsibility for ash basin closure oversight to the NCDEQ.

Estimated asset retirement obligations, including impacts from the legislation signed by the Governor of North Carolina on July 14, 2016, have been recognized based on the assigned risk categories or a probability weighting of potential closure methods. Actual closure costs incurred could be materially different from current estimates that form the basis of the recorded asset retirement obligations. Costs incurred have been deferred as regulatory assets and recovery will be pursued through the normal ratemaking process with federal and state utility commissions, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations.

Coal Combustion Residuals

On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. The federal regulation, which became effective in October 2015, classifies CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act and allows for beneficial use of CCR with some restrictions. The regulation applies to all new and existing landfills, new and existing surface impoundments receiving CCR and existing surface impoundments that are no longer receiving CCR but contain liquid located at stations currently generating electricity (regardless of fuel source). The rule establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. Various industry and environmental parties have appealed the EPA's CCR rule in the D.C. Circuit Court of Appeals. On April 18, 2016, the EPA filed an unopposed motion with the federal court to settle five issues raised in litigation. On June 14, 2016, the court approved the motion with respect to all of those issues. Duke Energy does not expect a material impact from the settlement or that it will result in additional asset retirement obligation adjustments.

In addition to the requirements of the federal CCR regulation, CCR landfills and surface impoundments will continue to be independently regulated by most states. As a result of the EPA rule, the Subsidiary Registrants recorded asset retirement obligation amounts during 2015.

LITIGATION

Duke Energy

Ash Basin Shareholder Derivative Litigation

Five shareholder derivative lawsuits were filed in Delaware Chancery Court relating to the release at Dan River and to the management of Duke Energy’s ash basins. On October 31, 2014, the five lawsuits were consolidated in a single proceeding titled In Re Duke Energy Corporation Coal Ash Derivative Litigation. On December 2, 2014, plaintiffs filed a Corrected Verified Consolidated Shareholder Derivative Complaint (Consolidated Complaint). The Consolidated Complaint names as defendants several current and former Duke Energy officers and directors (Duke Energy Defendants). Duke Energy is named as a nominal defendant.

The Consolidated Complaint alleges the Duke Energy Defendants breached their fiduciary duties by failing to adequately oversee Duke Energy’s ash basins and that these breaches of fiduciary duty may have contributed to the incident at Dan River and continued thereafter. The lawsuit also asserts 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 lawsuit seeks both injunctive relief against Duke Energy and restitution from the Duke Energy Defendants. On January 21, 2015, the Duke Energy Defendants filed a Motion to Stay and an alternative Motion to Dismiss. On August 31, 2015, the court issued an order staying the case which was lifted on March 24, 2016. On April 22, 2016, plaintiffs filed an Amended Verified Consolidated Shareholder Derivative Complaint (Amended Complaint) making the same allegations as in the Consolidated Complaint. The Duke Energy Defendants filed a motion to dismiss the Amended Complaint on June 21, 2016.

On March 5, 2015, shareholder Judy Mesirov filed a shareholder derivative complaint (Mesirov Complaint) in North Carolina state court. The lawsuit, styled Mesirov v. Good, is similar to the consolidated derivative action pending in Delaware Chancery Court and was filed against the same current directors and former directors and officers as the Delaware litigation. Duke Energy Corporation, Duke Energy Progress and Duke Energy Carolinas are named as nominal defendants. The Mesirov Complaint alleges that the Duke Energy Board of Directors was aware of Clean Water Act (CWA) compliance issues and failures to maintain structures in ash basins, but that the Board of Directors did not require Duke Energy Carolinas and Duke Energy Progress to take action to remedy deficiencies. The Mesirov Complaint further alleges that the Board of Directors sanctioned activities to avoid compliance with the law by allowing improper influence of NCDEQ to minimize regulation and by opposing previously anticipated citizen suit litigation. The Mesirov Complaint seeks corporate governance reforms and damages relating to costs associated with the Dan River release, remediation of ash basins that are out of compliance with the CWA and defending and payment of fines, penalties and settlements relating to criminal and civil investigations and lawsuits. The case was stayed until July 1, 2016. On July 5, 2016, the plaintiff filed a Notice of Voluntary Dismissal Without Prejudice, closing this matter.

In addition to the above derivative complaints, in 2014, Duke Energy also received two shareholder litigation demand letters. The letters alleged that the members of the Board of Directors and certain officers breached their fiduciary duties by allowing the company to illegally dispose of and store coal ash pollutants. One of the letters also alleged a breach of fiduciary duty in the decision-making relating to the leadership changes following the close of the Progress Energy merger in July 2012.

By letter dated September 4, 2015, attorneys for the shareholders were informed that, on the recommendation of the Demand Review Committee formed to consider such matters, the Board of Directors concluded not to pursue potential claims against individuals. One of the shareholders, Mitchell Pinsly, sent a formal demand for records and Duke Energy responded to this request.

On October 30, 2015, shareholder Saul Bresalier filed a shareholder derivative complaint (Bresalier Complaint) in the U.S. District Court for the District of Delaware. The lawsuit alleges that several current and former Duke Energy officers and directors (Bresalier Defendants) breached their fiduciary duties in connection with coal ash environmental issues, the post-merger change in Chief Executive Officer (CEO) and oversight of political contributions. Duke Energy is named as a nominal defendant. The Bresalier Complaint contends that the Demand Review Committee failed to appropriately consider the shareholder’s earlier demand for litigation and improperly decided not to pursue claims against the Bresalier Defendants. The Bresalier Defendants filed a Motion to Dismiss the Bresalier litigation on January 15, 2016. In lieu of a response to the Motion to Dismiss, the plaintiff filed a Motion to Convert the Bresalier Defendants' Motion to Dismiss into a Motion for Summary Judgment and also for limited discovery. Following a hearing on June 15, 2016, the court denied the plaintiff's Motion to Convert and is requiring the parties to complete briefing on the Bresalier Defendants' Motion to Dismiss. On July 29, 2016, the Bresalier Defendants filed an Amended Motion to Dismiss.

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

Progress Energy Merger Shareholder Litigation

On May 31, 2013, the Delaware Chancery Court consolidated four shareholder derivative lawsuits filed in 2012. The Court also appointed a lead plaintiff and counsel for plaintiffs and designated the case as In Re Duke Energy Corporation Derivative Litigation. The lawsuit names as defendants the 11 members of the Board of Directors who were also members of the pre-merger Board of Directors (Legacy Duke Energy Directors). Duke Energy is named as a nominal defendant. The case alleges claims for breach of fiduciary duties of loyalty and care in connection with the post-merger change in CEO. On December 10, 2015, the Legacy Duke Energy Directors filed a Motion to Dismiss the litigation. The court heard oral argument on the motion on May 9, 2016.

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 against the Legacy Duke Energy Directors 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 December 21, 2015, Plaintiff filed a Consolidated Amended Complaint asserting the same claims contained in the original complaints. The Legacy Duke Energy Directors filed a Motion to Dismiss on February 19, 2016. On March 18, 2016, the Chancery Court Plaintiffs moved to intervene in the Tansey proceeding, asking the federal district court to stay the federal litigation in favor of the Delaware Chancery litigation, which was denied on June 27, 2016. Oral argument on the Legacy Duke Energy Directors' Motion to Dismiss is scheduled for August 24, 2016.

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 litigation.

Price Reporting Cases

Duke Energy Trading and Marketing, LLC (DETM), a non-operating Duke Energy affiliate, was a defendant, along with numerous other energy companies, in four class action lawsuits and a fifth single-plaintiff lawsuit pending in a consolidated federal court proceeding in Nevada. Each of these lawsuits contains 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.

In February 2016, DETM reached agreements in principle to settle all of the pending lawsuits. Settlement of the single-plaintiff settlement was finalized and paid in March 2016. Settlement of the class action lawsuits are currently being finalized and will be subject to court approval. The settlement amounts are not material to Duke Energy.

Brazil Expansion Lawsuit

On August 9, 2011, the State of São Paulo sued Duke Energy International Geracao Paranapenema S.A. (DEIGP) in Brazilian state court. The lawsuit claims DEIGP is under a continuing obligation to expand installed generation capacity in the State of São Paulo by 15 percent pursuant to a stock purchase agreement under which DEIGP purchased generation assets from the state. On August 10, 2011, a judge granted an injunction ordering DEIGP to present a detailed expansion plan in satisfaction of the 15 percent obligation. DEIGP has previously taken a position that 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. In January 2013, DEIGP filed appeals in the federal courts, which are still pending, regarding various procedural issues. A decision on the merits in the first instance court is also pending. It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with this matter.

Brazil Generation

Record drought conditions in Brazil during 2014 and 2015 negatively impacted DEIGP. A number of electric generators have filed lawsuits seeking relief in the Brazilian courts to mitigate hydrological exposure and diminishing dispatch levels. Some courts have granted injunction orders to limit the financial exposure of certain generators. The implication of these orders is that other electricity market participants not covered by the injunctions may be required to compensate for the financial impact of the liability limitations. The Independent Power Producer Association (APINE) filed one such lawsuit on behalf of DEIGP and other hydroelectric generators against the Brazilian electric regulatory agency (ANEEL). On July 2, 2015, an injunction was granted in favor of APINE limiting the financial exposure of DEIGP and the other plaintiff generators, until the merits of the lawsuit are determined. ANEEL's appeal of the injunction was denied on December 18, 2015. The outcome of these lawsuits is uncertain. It is not possible to predict the impact to Duke Energy from the outcome of these matters.

Duke Energy Carolinas and Duke Energy Progress

NCDEQ Notices of Violation

In August 2014, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' L.V. Sutton Plant. On March 10, 2015, NCDEQ issued a civil penalty of approximately $25 million to Duke Energy Progress for environmental damages related to the groundwater contamination at the L.V. Sutton Plant. On April 9, 2015, Duke Energy Progress filed a Petition for Contested Case hearing in the Office of Administrative Hearings. In February 2015, NCDEQ issued an NOV for alleged groundwater violations at Duke Energy Progress' Asheville Plant. Duke Energy Progress responded to NCDEQ regarding this NOV.

On September 29, 2015, Duke Energy Progress and Duke Energy Carolinas entered into a settlement agreement with NCDEQ resolving all former, current and future groundwater penalties at all Duke Energy Carolinas and Duke Energy Progress coal facilities in North Carolina. Under the agreement, Duke Energy Progress paid approximately $6 million and Duke Energy Carolinas paid approximately $1 million. In addition to these payments, Duke Energy Progress and Duke Energy Carolinas will accelerate remediation actions at the Sutton, Asheville, Belews Creek and H.F. Lee plants. The ALJ entered a consent order resolving the contested case relating to the Sutton Plant and NCDEQ rescinded the NOVs relating to alleged groundwater violations at both the Sutton and Asheville plants.

On October 13, 2015, the Southern Environmental Law Center (SELC), representing multiple conservation groups, filed a lawsuit in North Carolina Superior Court seeking judicial review of the order approving the settlement agreement with NCDEQ. The conservation groups contend that the ALJ exceeded his statutory authority in approving a settlement that provided for past, present, and future resolution of groundwater issues at facilities which were not at issue in the penalty appeal. On December 18, 2015, Duke Energy Carolinas and Duke Energy Progress filed a Motion to Dismiss the complaint. On February 12, 2016, the ALJ entered a new order clarifying that the dismissal of the contested case only applied to the specific issues before the ALJ in the Petition for Contested Case. On March 10, 2016, the court dismissed the SELC lawsuit based on the ALJ's entry of the new order.

On February 8, 2016, NCDEQ assessed a penalty of approximately $6.8 million, including enforcement costs, against Duke Energy Carolinas related to storm water pipes and associated discharges at the Dan River Steam Station. Duke Energy Carolinas recorded a charge in December 2015 for this penalty. In March 2016, Duke Energy Carolinas filed an appeal of this penalty. A summary judgment hearing is set for August 22, 2016, for this proceeding. Duke Energy Carolinas cannot predict the outcome of this matter.

NCDEQ State Enforcement Actions

In the first quarter of 2013, SELC sent notices of intent to sue Duke Energy Carolinas and Duke Energy Progress related to alleged CWA violations from coal ash basins at two of their coal-fired power plants in North Carolina. NCDEQ filed enforcement actions against Duke Energy Carolinas and Duke Energy Progress alleging violations of water discharge permits and North Carolina groundwater standards. The cases have been consolidated and are being heard before a single judge.

On August 16, 2013, NCDEQ filed an enforcement action against Duke Energy Carolinas and Duke Energy Progress related to their remaining plants in North Carolina, alleging violations of the CWA and violations of the North Carolina groundwater standards. Both of these cases have been assigned to the judge handling the enforcement actions discussed above. SELC is representing several environmental groups who have been permitted to intervene in these cases.

On July 10, 2015, Duke Energy Carolinas and Duke Energy Progress filed two Motions for Partial Summary Judgment in the case on the basis that there is no longer either a genuine controversy or disputed material facts about the relief for seven of the 14 North Carolina plants with coal ash basins. On September 14, 2015, the court granted the Motions for Partial Summary Judgment pending court approval of the terms through an order. On April 4, 2016, the court issued an order granting Duke Energy Progress' Motion for Partial Summary Judgment for cases involving the H.F. Lee, Cape Fear and Weatherspoon plants. On June 1, 2016, the court issued an order granting Duke Energy Carolinas' and Duke Energy Progress' Motion for Partial Summary Judgment for cases involving the Asheville, Dan River, Riverbend and Sutton plants. The litigation is concluded for these seven plants. Litigation continues for the remaining seven plants.

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.

Federal Citizens Suits

There are currently three cases filed in various North Carolina federal courts related to the Sutton, Buck and Mayo plants. Three other previously filed cases involving the Riverbend, Cape Fear and H.F. Lee plants were dismissed on June 7, 2016.

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 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. In response to a motion filed by the SELC on August 1, 2014, the court modified the original 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 permits are back in the case. On August 26, 2015, the court suspended the proceedings until further order from the court.

On September 3, 2014, three citizen suits 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 surface water and groundwater violations at the Cape Fear Plant; (ii) in the United States Court for the Eastern District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the H.F. Lee Plant; and (iii) in the United States Court for the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Buck Steam Station. Motions to Stay or Dismiss the proceedings were filed in each of the three cases. The proceedings related to Cape Fear and H.F. Lee were dismissed on June 8, 2016, closing these matters. On October 20, 2015, the court issued an order denying the motions to stay or dismiss in the Buck proceedings. Duke Energy Carolinas' motion seeking appellate review of the District Court's decision relating to Buck was denied on January 29, 2016. The court has set an April 2017 trial date in the Buck proceeding.

On June 13, 2016, the Roanoke River Basin Association filed a federal citizen suit in the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Mayo Plant. Duke Energy Progress expects to file a response to the complaint in third quarter of 2016.

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.

Potential Groundwater Contamination Claims

Beginning in May 2015, a number of residents living in the vicinity of the North Carolina facilities with ash basins received letters from NCDEQ advising them not to drink water from the private wells on their land tested by NCDEQ as the samples were found to have certain substances at levels higher than the criteria set by the North Carolina Department of Health and Human Services (DHHS). The criteria, in some cases, are considerably more stringent than federal drinking water standards established to protect human health and welfare. The Coal Ash Act requires additional groundwater monitoring and assessments for each of the 14 coal-fired plants in North Carolina, including sampling of private water supply wells. The data gathered through these Comprehensive Site Assessments (CSAs) will be used by NCDEQ to determine whether the water quality of these private water supply wells has been adversely impacted by the ash basins. Duke Energy has submitted CSAs documenting the results of extensive groundwater monitoring around coal ash basins at all 14 of the plants with coal ash basins. Generally, the data gathered through the installation of new monitoring wells and soil and water samples across the state have been consistent with historical data provided to state regulators over many years. The DHHS and NCDEQ sent follow-up letters on October 15, 2015, to residents near coal ash basins who have had their wells tested, stating that private well samplings at a considerable distance from coal ash impoundments, as well as some municipal water supplies, contain similar levels of vanadium and hexavalent chromium which leads investigators to believe these constituents are naturally occurring. In March 2016, DHHS rescinded the advisories. It is not possible to estimate the maximum exposure of loss, if any, that may occur in connection with claims which might be made by these residents.

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 30, 2016, there were 89 asserted claims for non-malignant cases with the cumulative relief sought of up to $24 million, and 83 asserted claims for malignant cases with the cumulative relief sought of up to $15 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 $515 million at June 30, 2016 and $536 million at December 31, 2015. 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. 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 $847 million in excess of the self-insured retention. Receivables for insurance recoveries were $600 million at June 30, 2016 and $599 million at December 31, 2015. 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.

Duke Energy Florida

Class Action Lawsuit

On February 22, 2016, a lawsuit was filed in the U.S. District Court for the Southern District of Florida on behalf of a putative class of Duke Energy Florida and FP&L’s customers in Florida. The suit alleges the State of Florida’s nuclear power plant cost recovery statutes (NCRS) are unconstitutional and pre-empted by federal law. Plaintiffs claim they are entitled to repayment of all money paid by customers of Duke Energy Florida and FP&L as a result of the NCRS, as well as an injunction against any future charges under those statutes. The constitutionality of the NCRS has been challenged unsuccessfully in a number of prior cases on alternative grounds. Duke Energy Florida and FP&L filed motions to dismiss the complaint on May 5, 2016. Duke Energy Florida cannot predict the outcome of this matter.

Westinghouse Contract Litigation

On March 28, 2014, Duke Energy Florida filed a lawsuit against 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 Engineering, Procurement and Construction agreement (EPC) 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. Duke Energy Florida recognized an exit obligation as a result of the termination of the EPC contract.

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 alleged damages under the EPC 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. In November 2014, Westinghouse filed a Motion for Partial Judgment on the pleadings, which was denied on March 30, 2015. The trial date is set for October 17, 2016. On July 11, 2016, Duke Energy Florida and Westinghouse filed separate Motions for Summary Judgment. It is not possible to predict the outcome of the litigation, whether Duke Energy Florida will ultimately have any liability for terminating the EPC contract 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 nonpublic option agreements in exchange for their withdrawal of challenges to Duke Energy Ohio’s Rate Stabilization Plan implemented in early 2005. In March 2014, a federal judge certified this matter as a class action. Plaintiffs alleged claims of antitrust violations under the federal Robinson Patman Act as well as fraud and conspiracy allegations under the federal Racketeer Influenced and Corrupt Organizations statute and the Ohio Corrupt Practices Act.

During 2015, the parties received preliminary court approval of a settlement agreement. Duke Energy Ohio included a litigation reserve of $81 million in Other within Current Liabilities on the Consolidated Balance Sheet at December 31, 2015. Duke Energy Ohio recognized pretax charges of $71 million and $81 million in (Loss) Income from Discontinued Operations, net of tax in the Condensed Consolidated Statements of Operations and Comprehensive Income for the three and six months ended June 30, 2015, respectively. The settlement agreement was approved at a federal court hearing on April 19, 2016.

W.C. Beckjord Fuel Release

On August 18, 2014, approximately 9,000 gallons of fuel oil were inadvertently discharged into the Ohio River during a fuel oil transfer at the W.C. Beckjord generating station. The Ohio Environmental Protection Agency (Ohio EPA) issued a NOV related to the discharge. Duke Energy Ohio is cooperating with the Ohio EPA, the EPA and the U.S. Attorney for the Southern District of Ohio. No NOV has been issued by the EPA and no penalty has been assessed. Total repair and remediation costs related to the release were not material. Other costs related to the release, including state or federal civil or criminal enforcement proceedings, cannot be reasonably estimated at this time.

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, excluding asbestos related reserves and the exit obligation discussed above related to the termination of an EPC contract. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Accounts payable and Other within Current Liabilities. The reasonably possible range of loss in excess of recorded reserves is not material, other than as described above.

(in millions)	June 30, 2016		December 31, 2015
Reserves for Legal Matters
Duke Energy	$	110	$	166
Duke Energy Carolinas	14		11
Progress Energy	52		54
Duke Energy Progress	6		6
Duke Energy Florida	30		31
Duke Energy Ohio	4		80

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, noncancelable 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.

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Debt and Credit Facilities

6 Months Ended

Jun. 30, 2016

Debt Disclosure [Abstract]

Debt And Credit Facilities

DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

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

				Six Months Ended
				June 30, 2016
						Duke		Duke		Duke		Duke		Duke
	Maturity	Interest		Duke		Energy		Energy		Energy		Energy		Energy
Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Florida		Ohio		Indiana
Unsecured
April 2016(a)	April 2023	2.875	%	$	350	$	350	$	—	$	—	$	—	$	—
First Mortgage Bonds
March 2016(b)	March 2023	2.500	%	500		—		500		—		—		—
March 2016(b)	March 2046	3.875	%	500		—		500		—		—		—
May 2016(c)	May 2046	3.750	%	500		—		—		—		—		500
June 2016(b)	June 2046	3.700	%	250		—		—		—		250		—
Secured Debt
June 2016(d)	March 2020	1.196	%	183		—		—		183		—		—
June 2016(d)	September 2022	1.731	%	150		—		—		150		—		—
June 2016(d)	September 2029	2.538	%	436		—		—		436		—		—
June 2016(d)	March 2033	2.858	%	250		—		—		250		—		—
June 2016(d)	September 2036	3.112	%	275		—		—		275		—		—
Total issuances				$	3,394	$	350	$	1,000	$	1,294	$	250	$	500

(a) Proceeds were used to pay down outstanding commercial paper and for general corporate purposes.

(b) Proceeds were used to fund capital expenditures for ongoing construction, capital maintenance and for general corporate purposes.

(c) Proceeds were used to repay $325 million of unsecured debt due June 2016, $150 million of first mortgage bonds due July 2016 and for general corporate purposes.

(d) Proceeds from the nuclear asset recovery bonds issued by DEFPF, a bankruptcy remote subsidiary of Duke Energy Florida, were used to acquire nuclear asset-recovery property from its parent, Duke Energy Florida. The nuclear asset-recovery bonds are payable only from and secured by the nuclear asset-recovery property. DEFPF is consolidated for financial reporting purposes; however, the nuclear asset-recovery bonds do not constitute a debt, liability or other legal obligation of, or interest in, Duke Energy Florida or any of its affiliates other than DEFPF. The assets of DEFPF, including the nuclear asset-recovery property, are not available to pay creditors of Duke Energy Florida or any of its affiliates. Duke Energy Florida used the proceeds from the sale to repay short-term borrowings under the intercompany money pool borrowing arrangement and make an equity distribution of $649 million to the ultimate parent, Duke Energy (Parent), which repaid short-term borrowings. The nuclear asset-recovery bonds are sequential pay amortizing bonds. The maturity date above represents the scheduled final maturity date for the bonds. See Notes 4 and 12 for additional information.

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		June 30, 2016
Unsecured Debt
Duke Energy (Parent)	November 2016	2.150	%	$	500
Duke Energy (Parent)	April 2017	1.009	%	400
Duke Energy	May 2017	15.530	%	56
Secured Debt
Duke Energy	June 2017	2.075	%	45
First Mortgage Bonds
Duke Energy Indiana	July 2016	0.979	%	150
Duke Energy Carolinas	December 2016	1.750	%	350
Duke Energy Progress	March 2017	0.880	%	250
Tax-exempt Bonds
Duke Energy Carolinas	February 2017	3.600	%	77
Duke Energy Ohio(a)	August 2027	1.280	%	50
Duke Energy Indiana(b)	May 2035	1.092	%	44
Other(c)				420
Current maturities of long-term debt				$	2,342

(a) Represents Duke Energy Kentucky's bonds with a mandatory put in December 2016.

(b) The bonds have a mandatory put in December 2016.

(c) Includes capital lease obligations, amortizing debt and small bullet maturities.

AVAILABLE CREDIT FACILITIES

Master Credit Facility

Duke Energy has a Master Credit Facility with a capacity of $7.5 billion through January 2020. The Duke Energy Registrants, excluding Progress Energy (Parent), have borrowing capacity under the Master Credit Facility up to a specified sublimit 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. Duke Energy Carolinas and Duke Energy Progress are also required to each maintain $250 million of available capacity under the Master Credit Facility as security to meet obligations under plea agreements reached with the U.S. Department of Justice in 2015 related to violations at North Carolina facilities with ash basins. The table below includes the current borrowing sublimits and available capacity under the Master Credit Facility.

	June 30, 2016
				Duke			Duke			Duke			Duke			Duke			Duke
	Duke			Energy			Energy			Energy			Energy			Energy			Energy
(in millions)	Energy			(Parent)			Carolinas			Progress			Florida			Ohio			Indiana
Facility size(a)	$	7,500		$	3,475		$	800		$	1,000		$	1,200		$	425		$	600
Reduction to backstop issuances
Commercial paper(b)	(1,673		)	(992		)	(300		)	(159		)	(47		)	(25		)	(150		)
Outstanding letters of credit	(77		)	(70		)	(4		)	(2		)	(1		)	—			—
Tax-exempt bonds	(116		)	—			(35		)	—			—			—			(81		)
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—
Available capacity	$	5,134		$	2,413		$	211		$	589		$	1,152		$	400		$	369

(a) Represents the sublimit of each borrower.

(b) Duke Energy issued $625 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana. The balances are classified as Long-Term Debt Payable to Affiliated Companies in the Condensed Consolidated Balance Sheets.

Piedmont Bridge Facility

In connection with the Merger Agreement with Piedmont, Duke Energy entered into a $4.9 billion Bridge Facility with Barclays. The Bridge Facility, if drawn upon, may be used (i) to fund the cash consideration for the transaction and (ii) to pay certain fees and expenses in connection with the transaction. In November 2015, Barclays syndicated its commitment under the Bridge Facility to a broader group of lenders. Duke Energy does not expect to draw upon the Bridge Facility. The amount of the Bridge Facility is reduced by any financings related to the Piedmont acquisition entered into by Duke Energy, and has accordingly been reduced to approximately $3.2 billion as a result of the Equity Forwards described in Note 13 and $1 billion of commitments under a term loan amended and restated as of August 1, 2016, described below. Refer to Note 2 for additional information on the Piedmont acquisition.

Term Loan Facility

On February 22, 2016, Duke Energy entered into a six-month term loan facility with commitments totaling $1.0 billion (the February 2016 Term Loan). As of June 30, 2016, $100 million was outstanding under the February 2016 Term Loan. On August 1, 2016, Duke Energy and each of the lenders under the February 2016 Term Loan amended and restated certain terms of this facility, resulting in aggregate commitments of $1.5 billion and extending the maturity date to July 31, 2017. 

As of August 1, 2016, $100 million has been drawn under the amended and restated term loan (the August 2016 Term Loan). The remaining $1.4 billion of commitments under the August 2016 Term Loan can be drawn in up to two separate borrowings, which must occur no later than 90 calendar days following August 1, 2016. Any borrowings under the August 2016 Term Loan will be used to manage short-term liquidity, including funding a portion of the Piedmont acquisition, and for general corporate purposes. The terms and conditions of the August 2016 Term Loan are generally consistent with those governing Duke Energy’s Master Credit Facility.

Solar Facilities Financing

In August 2016, Emerald State Solar, LLC, an indirect wholly owned subsidiary of Duke Energy, entered into a portfolio financing of approximately 22 North Carolina Solar facilities. The $333 million term loan facility consists of Tranche A of $228 million due in June 2034 secured by substantially all the assets of the solar facilities and Tranche B of $105 million due in June 2020 secured by an Equity Contribution Agreement with Duke Energy. The initial interest rate on the loans is six months London Interbank Offered Rate (LIBOR) plus an applicable margin. The initial applicable margin is 1.75 percent with 0.125 percent increases every three years thereafter. In connection with this debt issuance, Emerald State Solar, LLC entered into two interest rate swaps to convert the substantial majority of the loan interest payments from variable rates to fixed rates of approximately 1.81 percent for Tranche A and 1.38 percent for Tranche B, plus the applicable margin.

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Goodwill and Intangible Assets

6 Months Ended

Jun. 30, 2016

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill

GOODWILL AND INTANGIBLE ASSETS

GOODWILL

The following table presents goodwill by reportable operating segment for Duke Energy.

Duke Energy

	Regulated		International		Commercial
(in millions)	Utilities		Energy		Portfolio		Total
Goodwill at December 31, 2015	$	15,950	$	271	$	122	$	16,343
Foreign exchange changes	—		14		—		14
Goodwill at June 30, 2016	$	15,950	$	285	$	122	$	16,357

Duke Energy Ohio

Duke Energy Ohio's Goodwill balance of $920 million is included in the Regulated Utilities operating segment and presented net of accumulated impairment charges of $216 million on the Condensed Consolidated Balance Sheets at June 30, 2016 and December 31, 2015.

Progress Energy

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

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Related Party Transactions

6 Months Ended

Jun. 30, 2016

Related Party Transactions [Abstract]

Related Party Transactions

RELATED PARTY TRANSACTIONS

The Subsidiary Registrants engage in related party transactions in accordance with 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,
(in millions)	2016		2015		2016		2015
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	202	$	416	$	421
Indemnification coverages(b)	5		6		11		12
JDA revenue(c)	2		14		11		40
JDA expense(c)	50		38		91		95
Progress Energy
Corporate governance and shared service expenses(a)	$	160	$	172	$	334	$	339
Indemnification coverages(b)	9		9		17		19
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	89	$	93	$	189	$	194
Indemnification coverages(b)	4		4		7		8
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	79	$	145	$	145
Indemnification coverages(b)	5		5		10		11
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	87	$	103	$	172	$	188
Indemnification coverages(b)	1		1		2		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	89	$	83	$	183	$	172
Indemnification coverages(b)	2		2		4		4

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, 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) Duke Energy Carolinas and Duke Energy Progress participate in a JDA which 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.

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 months ended June 30, 2016 and 2015 for the Subsidiary Registrants.

As discussed in Note 12, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to CRC, an affiliate formed by a subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but also include a subordinated note from the affiliate for a portion of the purchase price.

Duke Energy Ohio's nonregulated indirect subsidiary, Duke Energy Commercial Asset Management (DECAM), owned generating plants included in the Disposal Group sold to Dynegy on April 2, 2015. On April 1, 2015, Duke Energy Ohio distributed its indirect ownership interest in DECAM to a Duke Energy subsidiary and non-cash settled DECAM's intercompany loan payable of $294 million. Refer to Note 2 for further information on the sale of the Disposal Group.

Intercompany Income Taxes

Duke Energy and the Subsidiary Registrants file a consolidated federal income tax return and other state and jurisdictional returns. The Subsidiary Registrants have a tax sharing agreement with Duke Energy for the allocation of consolidated tax liabilities and benefits. Income taxes recorded represent amounts the Subsidiary Registrants would incur as separate C-Corporations. The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana
June 30, 2016
Intercompany income tax receivable	$	10	$	90	$	—	$	—	$	15	$	6
Intercompany income tax payable	—		—		11		48		—		—
December 31, 2015
Intercompany income tax receivable	$	122	$	120	$	104	$	—	$	54	$	—
Intercompany income tax payable	—		—		—		96		—		47

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Derivatives and Hedging

6 Months Ended

Jun. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives and Hedging

DERIVATIVES AND HEDGING

The Duke Energy Registrants use commodity and interest rate contracts to manage commodity price risk and interest rate risk. The primary use of 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 arrangements is offset against the collateralized derivatives on the Condensed Consolidated Balance Sheets. The cash impacts of settled derivatives are recorded as operating activities on the Condensed Consolidated Statements of Cash Flows.

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.

Cash Flow Hedges

For a derivative designated as hedging the exposure to variable cash flows of a future transaction, referred to as a cash flow hedge, the effective portion of the derivative's gain or loss is initially reported as a component of other comprehensive income and subsequently reclassified into earnings once the future transaction affects earnings. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt. Gains and losses reclassified out of Accumulated other comprehensive income (AOCI) for the three and six months ended June 30, 2016, were not material. Duke Energy's interest rate derivatives designated as hedges include interest rate swaps used to hedge existing debt within the International Energy and Renewables' businesses.

Undesignated Contracts

Undesignated contracts include contracts not designated as a hedge because they are accounted for under regulatory accounting and contracts that do not qualify for hedge accounting.

Duke Energy’s interest rate swaps for its Regulated Utilities operations employ regulatory accounting. With regulatory accounting, the mark-to-market gains or losses on the swaps are deferred as regulatory liabilities or regulatory assets, respectively. Regulatory assets and liabilities are amortized consistent with the treatment of the related costs in the ratemaking process. The accrual of interest on the swaps is recorded as Interest Expense.

As of June 30, 2016, Duke Energy has entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure for the expected financing of the Piedmont acquisition. The swaps do not qualify for hedge accounting and are marked-to-market, with any gains or losses included within earnings. Unrealized losses on the swaps of $75 million and $168 million were included within Interest Expense on the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2016. The swaps will be terminated in conjunction with the acquisition financing. See Note 2 for additional information related to the Piedmont acquisition.

The following table shows notional amounts of outstanding derivatives related to interest rate risk.

	June 30, 2016
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	663	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	2,327		400		500		250		250		27
Total notional amount	$	2,990	$	400	$	500	$	250	$	250	$	27

	December 31, 2015
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	700	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,827		400		500		250		250		27
Total notional amount	$	2,527	$	400	$	500	$	250	$	250	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $463 million at June 30, 2016 and $497 million at December 31, 2015.

COMMODITY PRICE RISK

The Duke Energy Registrants are exposed to the impact of changes in the 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.

Regulated public utilities may have cost-based rate regulations and various other cost recovery mechanisms that result in a limited exposure to market volatility of commodity fuel prices. Financial derivative contracts, where approved by the respective state regulatory commissions, can be used to manage the risk of price volatility. At June 30, 2016, substantially all of Duke Energy's open commodity derivative instruments were undesignated because they are accounted for under regulatory accounting. Mark-to-market gains or losses on contracts that use regulatory accounting are deferred as regulatory liabilities or regulatory assets, respectively. Undesignated contracts expire as late as 2020.

The Subsidiary Registrants utilize cost-tracking mechanisms, commonly referred to as fuel adjustment clauses. These clauses allow for the recovery of fuel and fuel-related costs, including settlements of undesignated derivatives for fuel commodities, and portions of purchased power costs through surcharges on customer rates. The difference between the costs incurred and the surcharge revenues is recorded as an adjustment to Fuel used in electric generation and purchased power – regulated or as Operating Revenues: Regulated electric on the Condensed Consolidated Statements of Operations, with an offsetting impact on regulatory assets or liabilities. Therefore, due to the regulatory accounting followed by the Subsidiary Registrants for undesignated derivatives, realized and unrealized gains and losses on undesignated commodity derivatives do not have an immediate impact on reported net income.

Volumes

The tables below show volumes of outstanding commodity derivatives. Amounts disclosed represent the absolute value of notional volumes of commodity contracts excluding NPNS. 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, 2016
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana
Electricity (gigawatt-hours)	7	—	—	—	—	—	7
Natural gas (millions of decatherms)	418	80	338	124	214	—	—

	December 31, 2015
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana
Electricity (gigawatt-hours)	70	—	—	—	—	34	36
Natural gas (millions of decatherms)	398	66	332	117	215	—	—

LOCATION AND FAIR VALUE OF DERIVATIVE ASSETS AND LIABILITIES RECOGNIZED IN THE CONDENSED CONSOLIDATED BALANCE SHEETS

The following tables show the fair value and balance sheet location of derivative instruments. 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.

Derivative Assets	June 30, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	64	$	8	$	20	$	8	$	12	$	5	$	31
Noncurrent	28		10		18		10		8		—		—
Total Derivative Assets – Commodity Contracts	$	92	$	18	$	38	$	18	$	20	$	5	$	31
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	$	3	$	—	$	3	$	1	$	2	$	—	$	—
Noncurrent	13		—		13		6		7		—		—
Total Derivative Assets – Interest Rate Contracts	$	16	$	—	$	16	$	7	$	9	$	—	$	—
Total Derivative Assets	$	108	$	18	$	54	$	25	$	29	$	5	$	31

Derivative Liabilities	June 30, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	84	$	7	$	77	$	18	$	59	$	—	$	1
Noncurrent	23		—		23		—		17		—		—
Total Derivative Liabilities – Commodity Contracts	$	107	$	7	$	100	$	18	$	76	$	—	$	1
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	9	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	52		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current(a)	170		—		—		—		—		1		—
Noncurrent	90		82		—		—		—		7		—
Total Derivative Liabilities – Interest Rate Contracts	$	321	$	82	$	—	$	—	$	—	$	8	$	—
Total Derivative Liabilities	$	428	$	89	$	100	$	18	$	76	$	8	$	1

(a) Duke Energy amount includes $168 million related to forward-starting interest rate swaps associated with the Piedmont acquisition.

Derivative Assets	December 31, 2015
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	12	$	—	$	1	$	—	$	1	$	3	$	7
Noncurrent	4		—		4		—		4		—		—
Total Derivative Assets – Commodity Contracts	$	16	$	—	$	5	$	—	$	5	$	3	$	7
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	4	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	6		—		6		2		2		—		—
Total Derivative Assets – Interest Rate Contracts	$	10	$	—	$	6	$	2	$	2	$	—	$	—
Total Derivative Assets	$	26	$	—	$	11	$	2	$	7	$	3	$	7

Derivative Liabilities	December 31, 2015
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	256	$	32	$	222	$	77	$	145	$	—	$	—
Noncurrent	100		8		92		16		71		—		—
Total Derivative Liabilities – Commodity Contracts	$	356	$	40	$	314	$	93	$	216	$	—	$	—
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	11	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	33		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	4		—		3		—		—		1		—
Noncurrent	15		5		5		5		—		6		—
Total Derivative Liabilities – Interest Rate Contracts	$	63	$	5	$	8	$	5	$	—	$	7	$	—
Total Derivative Liabilities	$	419	$	45	$	322	$	98	$	216	$	7	$	—

OFFSETTING ASSETS AND LIABILITIES

The following tables present the line items on the Condensed Consolidated Balance Sheets where derivatives are reported. Substantially all of Duke Energy's outstanding derivative contracts are subject to enforceable master netting arrangements. The Gross amounts offset in the tables below show the effect of these netting arrangements on financial position, and include collateral posted to offset the net position. The amounts shown are 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.

Derivative Assets	June 30, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	67		$	8		$	23		$	9		$	14		$	5	$	31
Gross amounts offset	(15		)	(3		)	(13		)	(6		)	(7		)	—		—
Net amounts presented in Current Assets: Other	$	52		$	5		$	10		$	3		$	7		$	5	$	31
Noncurrent
Gross amounts recognized	$	41		$	10		$	31		$	16		$	15		$	—	$	—
Gross amounts offset	(5		)	—			(5		)	—			(4		)	—		—
Net amounts presented in Investments and Other Assets: Other	$	36		$	10		$	26		$	16		$	11		$	—	$	—

Derivative Liabilities	June 30, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	263		$	7		$	77		$	18		$	59		$	1	$	1
Gross amounts offset	(15		)	(3		)	(13		)	(6		)	(7		)	—		—
Net amounts presented in Current Liabilities: Other	$	248		$	4		$	64		$	12		$	52		$	1	$	1
Noncurrent
Gross amounts recognized	$	165		$	82		$	23		$	—		$	17		$	7	$	—
Gross amounts offset	(5		)	—			(5		)	—			(4		)	—		—
Net amounts presented in Deferred Credits and Other Liabilities: Other	$	160		$	82		$	18		$	—		$	13		$	7	$	—

Derivative Assets	December 31, 2015
				Duke					Duke		Duke			Duke		Duke
	Duke			Energy		Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas		Energy			Progress		Florida			Ohio		Indiana
Current
Gross amounts recognized	$	18		$	—	$	7		$	2	$	3		$	3	$	7
Gross amounts offset	(3		)	—		(2		)	—		(2		)	—		—
Net amounts presented in Current Assets: Other	$	15		$	—	$	5		$	2	$	1		$	3	$	7
Noncurrent
Gross amounts recognized	$	8		$	—	$	4		$	—	$	4		$	—	$	—
Gross amounts offset	(4		)	—		(4		)	—		(4		)	—		—
Net amounts presented in Investments and Other Assets: Other	$	4		$	—	$	—		$	—	$	—		$	—	$	—

Derivative Liabilities	December 31, 2015
				Duke					Duke			Duke			Duke		Duke
	Duke			Energy		Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas		Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	271		$	32	$	225		$	77		$	145		$	1	$	—
Gross amounts offset	(22		)	—		(21		)	(1		)	(20		)	—		—
Net amounts presented in Current Liabilities: Other	$	249		$	32	$	204		$	76		$	125		$	1	$	—
Noncurrent
Gross amounts recognized	$	148		$	13	$	97		$	21		$	71		$	6	$	—
Gross amounts offset	(16		)	—		(15		)	—			(15		)	—		—
Net amounts presented in Deferred Credits and Other Liabilities: Other	$	132		$	13	$	82		$	21		$	56		$	6	$	—

OBJECTIVE CREDIT CONTINGENT FEATURES

Certain derivative contracts contain objective credit contingent features. These features include the requirement to post cash collateral or letters of credit 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 Ohio and Duke Energy Indiana were not material.

	June 30, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Aggregate fair value of derivatives in a net liability position	$	348	$	89	$	90	$	18	$	72
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	348		89		90		18		72

	December 31, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Aggregate fair value of derivatives in a net liability position	$	334	$	45	$	290	$	93	$	194
Fair value of collateral already posted	30		—		30		—		30
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	304		45		260		93		164

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 arrangement. Amounts disclosed below represent the receivables related to the right to reclaim cash collateral under master netting arrangements. All receivables presented below were offset against net derivative positions on the Condensed Consolidated Balance Sheets.

	June 30, 2016		December 31, 2015
(in millions)	Receivables		Receivables
Duke Energy	$	—	$	30
Progress Energy	—		30
Duke Energy Florida	—		30

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Investments in Debt and Equity Securities

6 Months Ended

Jun. 30, 2016

Investments, Debt and Equity Securities [Abstract]

Investments In Debt And Equity Securities

INVESTMENTS IN DEBT AND EQUITY SECURITIES

The Duke Energy Registrants classify their investments in debt and equity securities as available-for-sale.

Duke Energy’s available-for-sale securities are primarily comprised of investments held in (i) the nuclear decommissioning 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 Other Post-Retirement Benefit Obligations (OPEB) plans and (iii) Bison.

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

Investment Trusts

The investments within the NDTF investments 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 losses associated with debt and equity securities within the Investment Trusts are considered other-than-temporary impairments and are recognized immediately.

Investments within the Investment Trusts generally qualify for regulatory accounting, and accordingly realized and unrealized gains and losses are deferred as a regulatory asset or liability. However, certain investments held in Duke Energy Florida's NDTF, which were acquired in a settlement with Florida Municipal Joint Owners (FMJO), do not qualify for regulatory accounting. Except for other than temporary impairments of unrealized losses, unrealized gains and losses on these assets are included in other comprehensive income until realized. The other than temporary impairments of realized amounts and unrealized losses are included within Other income and expense, net on the Condensed Consolidated Statements of Operations. The value of these assets has not materially changed since the assets were acquired from FMJO. As a result, there is no material 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. 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. If an other than temporary impairment exists, the unrealized loss is included in earnings. There were no material credit losses as of June 30, 2016 and December 31, 2015.

DUKE ENERGY

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	189	$	—	$	—	$	179
Equity securities	1,869		78		3,834		1,823		58		3,590
Corporate debt securities	22		1		480		7		8		432
Municipal bonds	12		1		307		5		1		185
U.S. government bonds	38		—		1,038		11		5		1,254
Other debt securities	1		3		144		—		4		177
Total NDTF	$	1,942	$	83	$	5,992	$	1,846	$	76	$	5,817
Other Investments
Cash and cash equivalents	$	—	$	—	$	27	$	—	$	—	$	29
Equity securities	34		1		98		32		1		95
Corporate debt securities	2		1		97		1		3		92
Municipal bonds	6		1		80		3		1		74
U.S. government bonds	2		—		47		—		—		45
Other debt securities	—		1		57		—		2		62
Total Other Investments(a)	$	44	$	4	$	406	$	36	$	7	$	397
Total Investments	$	1,986	$	87	$	6,398	$	1,882	$	83	$	6,214

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

(b) Substantially all these amounts are considered other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	88
Due after one through five years	660
Due after five through 10 years	511
Due after 10 years	991
Total	$	2,250

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	64	$	28	$	118	$	130
Realized losses	42		17		92		31

DUKE ENERGY CAROLINAS

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	66	$	—	$	—	$	34
Equity securities	1,045		44		2,128		1,021		27		2,094
Corporate debt securities	13		1		309		3		5		292
Municipal bonds	2		—		42		1		—		33
U.S. government bonds	16		—		482		3		3		438
Other debt securities	1		3		136		—		4		147
Total NDTF	$	1,077	$	48	$	3,163	$	1,028	$	39	$	3,038
Other Investments
Other debt securities	$	—	$	1	$	3	$	—	$	1	$	3
Total Other Investments(a)	$	—	$	1	$	3	$	—	$	1	$	3
Total Investments	$	1,077	$	49	$	3,166	$	1,028	$	40	$	3,041

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	6
Due after one through five years	198
Due after five through 10 years	235
Due after 10 years	533
Total	$	972

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	33	$	17	$	67	$	107
Realized losses	19		11		56		23

PROGRESS ENERGY

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	123	$	—	$	—	$	145
Equity securities	824		34		1,706		802		31		1,496
Corporate debt securities	9		—		171		4		3		140
Municipal bonds	10		1		265		4		1		152
U.S. government bonds	22		—		556		8		2		816
Other debt securities	—		—		8		—		—		30
Total NDTF	$	865	$	35	$	2,829	$	818	$	37	$	2,779
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	18
Municipal bonds	4		—		47		3		—		45
Total Other Investments(a)	$	4	$	—	$	68	$	3	$	—	$	63
Total Investments	$	869	$	35	$	2,897	$	821	$	37	$	2,842

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	65
Due after one through five years	375
Due after five through 10 years	200
Due after 10 years	407
Total	$	1,047

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	31	$	9	$	50	$	21
Realized losses	23		5		36		6

DUKE ENERGY PROGRESS

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	58	$	—	$	—	$	110
Equity securities	614		28		1,379		596		25		1,178
Corporate debt securities	7		—		118		3		2		96
Municipal bonds	10		1		265		4		1		150
U.S. government bonds	14		—		281		6		2		486
Other debt securities	—		—		5		—		—		18
Total NDTF	$	645	$	29	$	2,106	$	609	$	30	$	2,038
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	1
Total Other Investments(a)	$	—	$	—	$	1	$	—	$	—	$	1
Total Investments	$	645	$	29	$	2,107	$	609	$	30	$	2,039

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	14
Due after one through five years	191
Due after five through 10 years	154
Due after 10 years	310
Total	$	669

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	27	$	8	$	42	$	17
Realized losses	20		4		31		5

DUKE ENERGY FLORIDA

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	65	$	—	$	—	$	35
Equity securities	210		6		327		206		6		318
Corporate debt securities	2		—		53		1		1		44
Municipal bonds	—		—		—		—		—		2
U.S. government bonds	8		—		275		2		—		330
Other debt securities	—		—		3		—		—		12
Total NDTF	$	220	$	6	$	723	$	209	$	7	$	741
Other Investments
Cash and cash equivalents	$	—	$	—	$	4	$	—	$	—	$	6
Municipal bonds	4		—		47		3		—		45
Total Other Investments(a)	$	4	$	—	$	51	$	3	$	—	$	51
Total Investments	$	224	$	6	$	774	$	212	$	7	$	792

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	51
Due after one through five years	184
Due after five through 10 years	46
Due after 10 years	97
Total	$	378

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	4	$	1	$	8	$	4
Realized losses	3		1		5		1

DUKE ENERGY INDIANA

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	2
Equity securities	28		—		73		27		—		71
Corporate debt securities	—		—		2		—		—		2
Municipal bonds	1		1		29		—		1		26
Total Other Investments(a)	$	29	$	1	$	104	$	27	$	1	$	101
Total Investments	$	29	$	1	$	104	$	27	$	1	$	101

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	2
Due after one through five years	16
Due after five through 10 years	8
Due after 10 years	5
Total	$	31

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 months ended June 30, 2016 and 2015.

XML

Fair Value Measurements

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurements

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.

Not Categorized – Certain investments are not categorized within the Fair Value hierarchy. These investments are measured based on the fair value of the underlying investments but may not be readily redeemable at that fair value.

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 during the three and six months endedJune 30, 2016 and 2015.

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 Composite (NASDAQ) and New York Stock Exchange (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 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 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 natural 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 the fair value of natural 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.

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. See Note 10 for additional information related to investments by major security type.

	June 30, 2016
(in millions)	Total Fair Value			Level 1			Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	3,834		$	3,666		$	1		$	—	$	167
Nuclear decommissioning trust fund debt securities	2,158			744			1,414			—		—
Other available-for-sale equity securities	98			98			—			—		—
Other available-for-sale debt securities	308			74			230			4		—
Derivative assets	108			2			72			34		—
Total assets	6,506			4,584			1,717			38		167
Derivative liabilities	(428		)	(1		)	(427		)	—		—
Net assets	$	6,078		$	4,583		$	1,290		$	38	$	167

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	3,590		$	3,418	$	—		$	—	$	172
Nuclear decommissioning trust fund debt securities	2,227			672		1,555			—		—
Other available-for-sale equity securities	95			95		—			—		—
Other available-for-sale debt securities	302			75		222			5		—
Derivative assets	26			—		16			10		—
Total assets	6,240			4,260		1,793			15		172
Derivative liabilities	(419		)	—		(419		)	—		—
Net assets	$	5,821		$	4,260	$	1,374		$	15	$	172

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. There was no change to the Level 3 balance during the three months endedJune 30, 2015.

	Three Months Ended June 30, 2016
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	4	$	2		$	6
Purchases, sales, issuances and settlements:
Purchases	—		34			34
Settlements	—		(6		)	(6		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		4			4
Balance at end of period	$	4	$	34		$	38

	Six Months Ended June 30, 2016
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	5		$	10		$	15
Purchases, sales, issuances and settlements:
Purchases	—			34			34
Sales	(1		)	—			(1		)
Settlements	—			(13		)	(13		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—			3			3
Balance at end of period	$	4		$	34		$	38

	Six Months Ended June 30, 2015
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	5	$	(1	)	$	4
Total pretax realized or unrealized gains included in earnings	—		18			18
Purchases, sales, issuances and settlements:
Purchases	—		24			24
Settlements	—		(22		)	(22		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		4			4
Balance at end of period	$	5	$	23		$	28

DUKE ENERGY CAROLINAS

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,128		$	1,960	$	1		$	—	$	167
Nuclear decommissioning trust fund debt securities	1,035			245		790			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	18			—		18			—		—
Total assets	3,184			2,205		809			3		167
Derivative liabilities	(89		)	—		(89		)	—		—
Net assets	$	3,095		$	2,205	$	720		$	3	$	167

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,094		$	1,922	$	—		$	—	$	172
Nuclear decommissioning trust fund debt securities	944			246		698			—		—
Other available-for-sale debt securities	3			—		—			3		—
Total assets	3,041			2,168		698			3		172
Derivative liabilities	(45		)	—		(45		)	—		—
Net assets	$	2,996		$	2,168	$	653		$	3	$	172

There was no change to the Level 3 balance during the three and six months ended June 30, 2016 and June 30, 2015.

PROGRESS 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. See Note 10 for additional information related to investments by major security type.

	June 30, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,706		$	1,706	$	—
Nuclear decommissioning trust fund debt securities	1,123			499		624
Other available-for-sale debt securities	68			21		47
Derivative assets	54			—		54
Total assets	2,951			2,226		725
Derivative liabilities	(100		)	—		(100		)
Net assets	$	2,851		$	2,226	$	625

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,496		$	1,496	$	—
Nuclear decommissioning trust fund debt securities	1,283			426		857
Other available-for-sale debt securities	63			18		45
Derivative assets	11			—		11
Total assets	2,853			1,940		913
Derivative liabilities	(322		)	—		(322		)
Net assets	$	2,531		$	1,940	$	591

DUKE ENERGY PROGRESS

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,379		$	1,379	$	—
Nuclear decommissioning trust fund debt securities and other	727			228		499
Other available-for-sale debt securities and other	1			1		—
Derivative assets	25			—		25
Total assets	2,132			1,608		524
Derivative liabilities	(18		)	—		(18		)
Net assets	$	2,114		$	1,608	$	506

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,178		$	1,178	$	—
Nuclear decommissioning trust fund debt securities and other	860			141		719
Other available-for-sale debt securities and other	1			1		—
Derivative assets	2			—		2
Total assets	2,041			1,320		721
Derivative liabilities	(98		)	—		(98		)
Net assets	$	1,943		$	1,320	$	623

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	327		$	327	$	—
Nuclear decommissioning trust fund debt securities and other	396			271		125
Other available-for-sale debt securities and other	51			4		47
Derivative assets	29			—		29
Total assets	803			602		201
Derivative liabilities	(76		)	—		(76		)
Net assets	$	727		$	602	$	125

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	318		$	318	$	—
Nuclear decommissioning trust fund debt securities and other	423			285		138
Other available-for-sale debt securities and other	51			6		45
Derivative assets	7			—		7
Total assets	799			609		190
Derivative liabilities	(216		)	—		(216		)
Net assets (liabilities)	$	583		$	609	$	(26	)

DUKE ENERGY OHIO

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 are disclosed in Note 9.

	June 30, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	5		$	—	$	—		$	5
Derivative liabilities	(8		)	—		(8		)	—
Net (liabilities) assets	$	(3	)	$	—	$	(8	)	$	5

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	3		$	—	$	—		$	3
Derivative liabilities	(7		)	—		(7		)	—
Net (liabilities) assets	$	(4	)	$	—	$	(7	)	$	3

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

	Derivatives (net)
	Three Months Ended June 30,
(in millions)	2016		2015
Balance at beginning of period	$	—	$	7
Total pretax realized or unrealized gains included in earnings	—		(4		)
Purchases, sales, issuances and settlements:
Purchases	5		—
Sales	—		5
Settlements	—		(3		)
Balance at end of period	$	5	$	5

	Derivatives (net)
	Six Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	3		$	(18	)
Total pretax realized or unrealized gains included in earnings	—			21
Purchases, sales, issuances and settlements:
Purchases	5			—
Sales	—			5
Settlements	(2		)	(3		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(1		)	—
Balance at end of period	$	5		$	5

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 9. See Note 10 for additional information related to investments by major security type.

	June 30, 2016
(in millions)	Total Fair Value			Level 1			Level 2		Level 3
Other available-for-sale equity securities	$	73		$	73		$	—	$	—
Other available-for-sale debt securities and other	31			—			31		—
Derivative assets	31			2			—		29
Total assets	135			75			31		29
Derivative liabilities	(1		)	(1		)	—		—
Net assets	$	134		$	74		$	31	$	29

	December 31, 2015
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Other available-for-sale equity securities	$	71	$	71	$	—	$	—
Other available-for-sale debt securities and other	30		2		28		—
Derivative assets	7		—		—		7
Net assets	$	108	$	73	$	28	$	7

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

	Derivatives (net)
	Three Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	2		$	3
Purchases, sales, issuances and settlements:
Purchases	29			18
Settlements	(6		)	(10		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4			6
Balance at end of period	$	29		$	17

	Derivatives (net)
	Six Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	7		$	14
Purchases, sales, issuances and settlements:
Purchases	29			18
Settlements	(11		)	(19		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4			4
Balance at end of period	$	29		$	17

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

The following table includes quantitative information about the Duke Energy Registrants' derivatives classified as Level 3. As of June 30, 2016 and December 31, 2015, all Level 3 derivatives were financial transmission rights (FTRs).

	June 30, 2016
	Fair Value of FTRs
	(in millions)		Valuation Technique	Unobservable Input	Range
Duke Energy	$	34	RTO auction pricing	FTR price – per Megawatt-Hour (MWh)	$	(1.64	)	-	$	8.64
Duke Energy Ohio	5		RTO auction pricing	FTR price – per MWh	0.36			-	2.47
Duke Energy Indiana	29		RTO auction pricing	FTR price – per MWh	(1.64		)	-	8.64

	December 31, 2015
	Fair Value of FTRs
	(in millions)		Valuation Technique	Unobservable Input	Range
Duke Energy	$	10	RTO auction pricing	FTR price – per MWh	$	(0.74	)	-	$	7.29
Duke Energy Ohio	3		RTO auction pricing	FTR price – per MWh	0.67			-	2.53
Duke Energy Indiana	7		RTO auction pricing	FTR price – per MWh	(0.74		)	-	7.29

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, 2016				December 31, 2015
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy	$	42,273	$	47,953	$	39,569	$	42,537
Duke Energy Carolinas	9,360		10,874		8,367		9,156
Progress Energy	15,486		16,715		14,464		15,856
Duke Energy Progress	6,565		7,344		6,518		6,757
Duke Energy Florida	5,540		5,226		4,266		4,908
Duke Energy Ohio	1,887		2,134		1,598		1,724
Duke Energy Indiana	3,937		4,717		3,768		4,219

At both June 30, 2016 and December 31, 2015, fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper, and non-recourse notes payable of VIEs 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.

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Variable Interest Entities

6 Months Ended

Jun. 30, 2016

Variable Interest Entities [Abstract]

Variable Interest Entities

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 activities of the VIE that most significantly impact its economic performance and (ii) what party has rights to receive benefits or is obligated to absorb losses that could potentially be significant to the VIE. The analysis of the party that consolidates a VIE is a continual reassessment.

CONSOLIDATED VIEs

The obligations of the consolidated VIEs discussed in the following paragraphs are nonrecourse to the Duke Energy registrants. The registrants have no requirement to provide liquidity to, purchase assets of or guarantee performance of these VIEs unless noted in the following paragraphs.

No financial support was provided to any of the consolidated VIEs during the six months ended June 30, 2016 and the year ended December 31, 2015, or is expected to be provided in the future, that was not previously contractually required.

Receivables Financing – DERF / DEPR / DEFR

Duke Energy Receivables Finance Company, LLC (DERF), Duke Energy Progress Receivables, LLC (DEPR) and Duke Energy Florida Receivables, LLC (DEFR) are bankruptcy remote, special purpose subsidiaries of Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively. DERF, DEPR and DEFR are wholly owned limited liability companies with separate legal existence from their parent companies, and their assets are not generally available to creditors of their parent companies. On a revolving basis, DERF, DEPR and DEFR buy certain accounts receivable arising from the sale of electricity and related services from their parent companies.

DERF, DEPR and DEFR borrow amounts under credit facilities to buy these receivables. Borrowing availability from the credit facilities is limited to the amount of qualified receivables purchased. The sole source of funds to satisfy the related debt obligations is cash collections from the receivables. Amounts borrowed under the credit facilities are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt.

The most significant activity that impacts the economic performance of DERF, DEPR and DEFR are the decisions made to manage delinquent receivables. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida consolidate DERF, DEPR and DEFR, respectively, as they make those decisions.

Receivables Financing – CRC

CRC is a bankruptcy remote, special purpose entity indirectly owned by Duke Energy. On a revolving basis, CRC buys certain accounts receivable arising from the sale of electricity and related services from Duke Energy Ohio and Duke Energy Indiana. CRC borrows amounts under a credit facility to buy the receivables from Duke Energy Ohio and Duke Energy Indiana. Borrowing availability from the credit facility is limited to the amount of qualified receivables sold to CRC. The sole source of funds to satisfy the related debt obligation is cash collections from the receivables. Amounts borrowed under the credit facility are reflected on Duke Energy's Condensed Consolidated Balance Sheets as Long-Term Debt.

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. Depending on collection experience, additional equity infusions to CRC may be required by Duke Energy to maintain a minimum equity balance of $3 million.

CRC is considered a VIE because (i) equity capitalization is insufficient to support its operations, (ii) power to direct the activities that most significantly impact the economic performance of the entity are not performed by the equity holder, and (iii) deficiencies in net worth of CRC are funded by Duke Energy. The most significant activities that impact the economic performance of CRC are decisions made to manage delinquent receivables. Duke Energy consolidates CRC as it makes these decisions. Neither Duke Energy Ohio nor Duke Energy Indiana consolidate CRC.

Receivables Financing – Credit Facilities

The following table summarizes the amounts and expiration dates of the credit facilities described above. Amounts borrowed under the credit facilities are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
	CRC		DERF		DEPR		DEFR
Expiration date	December 2018		December 2018		February 2019		April 2019
Credit facility amount (in millions)	$	325	$	425	$	300	$	225
Amounts borrowed at June 30, 2016	325		425		300		225
Amounts borrowed at December 31, 2015	325		425		254		225

Nuclear Asset-Recovery Bonds – DEFPF

DEFPF is a bankruptcy remote, wholly owned special purpose subsidiary of Duke Energy Florida. DEFPF was formed in 2016 for the sole purpose of issuing nuclear asset-recovery bonds to finance Duke Energy Florida's unrecovered regulatory asset related to Crystal River Unit 3.

In June 2016, DEFPF issued $1,294 million of senior secured bonds and used the proceeds to acquire nuclear asset-recovery property from Duke Energy Florida. The nuclear asset-recovery property acquired includes the right to impose, bill, collect and adjust a non-bypassable nuclear asset-recovery charge from all Duke Energy Florida retail customers until the bonds are paid in full and all financing costs have been recovered. The nuclear asset-recovery bonds are secured by the nuclear asset-recovery property, and cash collections from the nuclear asset-recovery charges are the sole source of funds to satisfy the debt obligation. The bondholders have no recourse to Duke Energy Florida. For additional information see Notes 4 and 6.

DEFPF is considered a VIE primarily because the equity capitalization is insufficient to support its operations. Duke Energy Florida has the power to direct the significant activities of the VIE as described above, and therefore Duke Energy Florida is considered the primary beneficiary and consolidates DEFPF.

The following table summarizes the impact of DEFPF on Duke Energy Florida's Condensed Consolidated Balance Sheets.

(in millions)	June 30, 2016
Regulatory Assets: Current	$	34
Current Assets: Other	7
Regulatory Assets and Deferred Debits: Regulatory assets	1,194
Current maturities of long-term debt	35
Long-Term Debt	1,243

Renewables

Certain Duke Energy renewable energy facilities are VIEs due to long-term fixed-price power purchase agreements. These fixed-price agreements effectively transfer commodity price risk to the buyer of the power. Certain other Duke Energy renewable energy facilities are VIEs due to Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. For certain VIEs, assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders. The activities that most significantly 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 is responsible for all of these decisions.

The table below presents material balances reported on Duke Energy's Condensed Consolidated Balance Sheets related to renewables VIEs.

(in millions)	June 30, 2016			December 31, 2015
Current Assets: Other	$	223		$	138
Property, plant and equipment, cost	2,578			2,015
Accumulated depreciation and amortization	(376		)	(321		)
Current maturities of long-term debt	154			108
Long-Term Debt	866			968
Deferred Credits and Other Liabilities: Deferred income taxes	31			289
Deferred Credits and Other Liabilities: Other	277			33

NON-CONSOLIDATED VIEs

The following tables summarize the impact of non-consolidated VIEs on the Condensed Consolidated Balance Sheets.

	June 30, 2016
	Duke Energy						Duke		Duke
							Energy		Energy
(in millions)	Renewables		Other		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	39	$	58
Investments in equity method unconsolidated affiliates	222		252		474		—		—
Total assets	$	222	$	252	$	474	$	39	$	58
Other current liabilities	—		3		3		—		—
Deferred credits and other liabilities	—		13		13		—		—
Total liabilities	$	—	$	16	$	16	$	—	$	—
Net assets	$	222	$	236	$	458	$	39	$	58

	December 31, 2015
	Duke Energy						Duke		Duke
							Energy		Energy
(in millions)	Renewables		Other		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	47	$	60
Investments in equity method unconsolidated affiliates	235		152		387		—		—
Total assets	$	235	$	152	$	387	$	47	$	60
Other current liabilities	—		3		3		—		—
Deferred credits and other liabilities	—		14		14		—		—
Total liabilities	$	—	$	17	$	17	$	—	$	—
Net assets	$	235	$	135	$	370	$	47	$	60

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 Ohio Valley Electric Corporation (OVEC), which is discussed below, and various guarantees, reflected in the table above as Deferred credits and other liabilities. For more information on various guarantees, refer to Note 5.

Renewables

Duke Energy has investments in various renewable energy project entities. Some of these entities are VIEs due to long-term fixed-price power purchase agreements. 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

Duke Energy holds a 50 percent equity interest in Duke-American Transmission Company, LLC (DATC). DATC is considered a VIE due to insufficient equity at risk to permit DATC to finance its own activities without additional subordinated financial support. The activities that most significantly impact DATC’s economic performance are the decisions related to investing in existing and development of new transmission facilities. The power to direct these activities is jointly and equally shared by Duke Energy and the other joint venture partner, and therefore Duke Energy does not consolidate DATC.

Duke Energy has a 40 percent equity interest and a 7.5 percent equity interest in ACP and Sabal Trail Transmission, LLC (Sabal Trail), respectively. These entities are considered VIEs as their equity is not sufficient to permit the entities to finance their activities without additional subordinated financial support. The activity that most significantly impacts the economic performance of both ACP and Sabal Trail is construction. Duke Energy does not control these activities and therefore does not consolidate ACP or Sabal Trail.

OVEC

Duke Energy Ohio’s 9 percent ownership interest in OVEC is considered a non-consolidated VIE. 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. Proposed environmental rulemaking could increase the costs of OVEC, which would be passed through to Duke Energy Ohio.

CRC

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

Amounts included in Receivables from affiliated companies 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. 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 turn over 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
	2016		2015		2016		2015
Anticipated credit loss ratio	0.5	%	0.6	%	0.3	%	0.3	%
Discount rate	1.4	%	1.2	%	1.4	%	1.2	%
Receivable turnover rate	13.2	%	12.9	%	10.6	%	10.6	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Receivables sold	$	208	$	233	$	279	$	260
Less: Retained interests	39		47		58		60
Net receivables sold	$	169	$	186	$	221	$	200

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

	Duke Energy Ohio								Duke Energy Indiana
	Three Months Ended				Six Months Ended				Three Months Ended				Six Months Ended
	June 30,				June 30,				June 30,				June 30,
(in millions)	2016		2015		2016		2015		2016		2015		2016		2015
Sales
Receivables sold	$	429	$	425	$	961	$	1,069	$	623	$	637	$	1,258	$	1,353
Loss recognized on sale	2		2		5		5		2		2		5		5
Cash flows
Cash proceeds from receivables sold	427		467		964		1,107		612		660		1,255		1,382
Collection fees received	—		1		—		1		1		1		1		1
Return received on retained interests	—		1		1		2		1		1		2		3

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 the prior month-end LIBOR plus a fixed rate of 1.00 percent.

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Common Stock

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

Common Stock

COMMON STOCK

Basic Earnings Per Share (EPS) is computed by dividing net income attributable to Duke Energy common stockholders, adjusted for distributed and undistributed earnings allocated to participating securities, by the weighted average number of common stock outstanding during the period. Diluted EPS is computed by dividing net income attributable to Duke Energy common stockholders, as adjusted for distributed and undistributed earnings allocated to participating securities, by the diluted weighted average number of common stock 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 and the Equity Forwards, were exercised or settled. Duke Energy’s participating securities are restricted stock units that are entitled to dividends declared on Duke Energy common stock 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 stock outstanding to the diluted weighted average number of common shares outstanding.

	Three Months Ended June 30,				Six Months Ended June 30,
(in millions, except per-share amounts)	2016		2015		2016		2015
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	508	$	600	$	1,199	$	1,372
Weighted average shares outstanding – basic	689		692		689		700
Equity Forwards	1		—		—		—
Weighted average shares outstanding – diluted	690		692		689		700
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	0.74	$	0.87	$	1.74	$	1.96
Diluted	$	0.74	$	0.87	$	1.74	$	1.96
Potentially dilutive items excluded from the calculation(a)	2		2		2		2
Dividends declared per common share	$	0.825	$	0.795	$	1.65	$	1.59

(a) Performance stock awards were not included in the dilutive securities calculation because the performance measures related to the awards had not been met.

Equity Forwards

In March 2016, Duke Energy marketed an equity offering of 10.6 million shares of common stock. In lieu of issuing equity at the time of the offering, Duke Energy entered into Equity Forwards with Barclays. No amounts have or will be recorded in Duke Energy’s Condensed Consolidated Financial Statements with respect to the equity offering until settlements of the Equity Forwards occur. The Equity Forwards require Duke Energy to, at its election prior to June 30, 2017, either physically settle the transactions by issuing the total of 10.6 million of its common stock to Barclays in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $69.84 per share) or Duke Energy can net settle the transactions in whole or in part through the delivery or receipt of cash or shares. If Duke Energy had elected to net share settle the contract as of June 30, 2016, Duke Energy would have been required to deliver 2.1 million shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreements. The net proceeds received upon settlement are expected to be used to finance a portion of the acquisition of Piedmont.

Until settlement of the Equity Forwards, earnings per share dilution resulting from the agreements will be determined under the treasury stock method.

Accelerated Stock Repurchase Program

On April 6, 2015, Duke Energy entered into agreements with each of Goldman, Sachs & Co. and JPMorgan Chase Bank, National Association (the Dealers) to repurchase a total of $1.5 billion of Duke Energy common stock under an accelerated stock repurchase program (the ASR). Duke Energy made payments of $750 million to each of the Dealers and was delivered 16.6 million shares, with a total fair value of $1.275 billion, which represented approximately 85 percent of the total number of shares of Duke Energy common stock expected to be repurchased under the ASR. The company recorded the $1.5 billion payment as a reduction to common stock as of April 6, 2015. In June 2015, the Dealers delivered 3.2 million additional shares to Duke Energy to complete the ASR. Approximately 19.8 million shares, in total, were delivered to Duke Energy and retired under the ASR at an average price of $75.75 per share. The final number of shares repurchased was based upon the average of the daily volume weighted average stock prices of Duke Energy’s common stock during the term of the program, less a discount.

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Stock-Based Compensation

6 Months Ended

Jun. 30, 2016

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Stock-Based Compensation

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.

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Restricted stock unit awards	$	10	$	11	$	17	$	20
Performance awards	5		8		10		13
Pretax stock-based compensation cost	$	15	$	19	$	27	$	33
Tax benefit associated with stock-based compensation expense	$	5	$	7	$	9	$	12
Stock-based compensation costs capitalized	1		1		2		2

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Employee Benefit Plans

6 Months Ended

Jun. 30, 2016

Compensation and Retirement Disclosure [Abstract]

Employee Benefit Plans

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 equal to a percentage of current eligible earnings based on age or the combination of age and 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 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. The qualified and non-qualified, non-contributory defined benefit plans are closed to new and rehired non-union and certain unionized employees.

Duke Energy’s policy is to fund amounts on an actuarial basis to provide assets sufficient to meet benefit payments to be paid to plan participants. The following table includes information related to the Duke Energy Registrants’ contributions to its U.S. qualified defined benefit pension plans. Duke Energy did not make any contributions to its U.S. qualified defined benefit pension plans during the six months ended June 30, 2016.

Six Months Ended June 30, 2015

Duke

Duke

Duke

Duke

Duke

Duke

Energy

Progress

Energy

Energy

Energy

Energy

(in millions)

Energy

Carolinas

Energy

Progress

Florida

Ohio

Indiana

Contributions

$

132

$

42

$

42

$

21

$

21

$

1

$

9

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 costs 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 costs for employees of Duke Energy’s shared services affiliate that provides support to the Subsidiary Registrants. These allocated amounts are included in the governance and shared service costs discussed in Note 8. Duke Energy uses a December 31 measurement date for its defined benefit retirement plan assets and obligations.

QUALIFIED PENSION PLANS

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

	Three Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	37		$	12		$	10		$	6		$	5		$	1		$	2
Interest cost on projected benefit obligation	83			22			27			13			14			5			7
Expected return on plan assets	(129		)	(36		)	(42		)	(20		)	(21		)	(7		)	(11		)
Amortization of actuarial loss	33			8			13			5			7			1			3
Amortization of prior service credit	(4		)	(2		)	(1		)	(1		)	—			—			—
Other	1			—			—			1			—			—			—
Net periodic pension costs	$	21		$	4		$	7		$	4		$	5		$	—		$	1

	Three Months Ended June 30, 2015
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	39		$	12		$	11		$	6		$	5		$	1		$	2
Interest cost on projected benefit obligation	81			20			26			12			13			4			7
Expected return on plan assets	(129		)	(33		)	(41		)	(21		)	(22		)	(7		)	(11		)
Amortization of actuarial loss	44			10			17			9			8			3			4
Amortization of prior service credit	(3		)	(2		)	(1		)	(1		)	(1		)	—			—
Other	2			—			—			1			1			—			—
Net periodic pension costs	$	34		$	7		$	12		$	6		$	4		$	1		$	2

	Six Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	73		$	24		$	21		$	12		$	10		$	2		$	4
Interest cost on projected benefit obligation	166			43			53			25			28			10			14
Expected return on plan assets	(258		)	(71		)	(84		)	(41		)	(42		)	(14		)	(21		)
Amortization of actuarial loss	66			16			27			11			14			2			6
Amortization of prior service credit	(8		)	(4		)	(2		)	(1		)	—			—			—
Other	4			1			1			1			—			—			—
Net periodic pension costs	$	43		$	9		$	16		$	7		$	10		$	—		$	3

	Six Months Ended June 30, 2015
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	79		$	25		$	22		$	12		$	10		$	2		$	5
Interest cost on projected benefit obligation	163			41			52			24			27			9			14
Expected return on plan assets	(258		)	(69		)	(84		)	(41		)	(44		)	(13		)	(21		)
Amortization of actuarial loss	87			20			34			17			16			5			7
Amortization of prior service credit	(7		)	(4		)	(2		)	(1		)	(1		)	—			—
Other	4			1			1			1			1			—			—
Net periodic pension costs	$	68		$	14		$	23		$	12		$	9		$	3		$	5

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, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	3		1		1		1		1
Amortization of actuarial loss	2		—		—		—		—
Net periodic pension costs	$	6	$	1	$	1	$	1	$	1

	Three Months Ended June 30, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	3		—		1		1		1
Amortization of actuarial loss	1		—		1		—		—
Net periodic pension costs	$	5	$	—	$	2	$	1	$	1

	Six Months Ended June 30, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	7		1		2		1		1
Amortization of actuarial loss	4		—		1		—		—
Net periodic pension costs	$	12	$	1	$	3	$	1	$	1

	Six Months Ended June 30, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	1	$	—	$	—
Interest cost on projected benefit obligation	7		1		2		1		1
Amortization of actuarial loss	3		—		1		—		1
Net periodic pension costs	$	11	$	1	$	4	$	1	$	2

OTHER POST-RETIREMENT BENEFIT PLANS

Duke Energy provides, and the Subsidiary Registrants participate in, some health care and life insurance benefits for retired employees on a contributory and non-contributory basis. Employees are eligible for these benefits if they have met age and service requirements at retirement, as set forth in the plans. The health care benefits include medical, dental, vision, and prescription drug coverage and are subject to certain limitations, such as deductibles and co-payments.

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

	Three Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	1		$	—		$	—		$	—		$	—		$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			3			2			1			1			1
Expected return on plan assets	(4		)	(2		)	—			—			—			—			(1		)
Amortization of actuarial loss (gain)	2			(1		)	6			3			3			(1		)	—
Amortization of prior service credit	(36		)	(3		)	(25		)	(17		)	(9		)	—			—
Net periodic other post-retirement benefit costs	$	(28	)	$	(4	)	$	(16	)	$	(12	)	$	(5	)	$	—		$	—

	Three Months Ended June 30, 2015
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Service cost	$	1		$	1		$	1		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			3			2			1			1		2
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—
Amortization of actuarial loss (gain)	7			(1		)	7			4			2			—		(1		)
Amortization of prior service credit	(35		)	(3		)	(25		)	(16		)	(7		)	—		—
Net periodic other post-retirement benefit costs	$	(21	)	$	(3	)	$	(14	)	$	(10	)	$	(4	)	$	1	$	1

	Six Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	2		$	—		$	—		$	—		$	—		$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	17			4			7			4			3			1			2
Expected return on plan assets	(7		)	(4		)	—			—			—			—			(1		)
Amortization of actuarial loss (gain)	3			(2		)	11			6			5			(1		)	(1		)
Amortization of prior service credit	(71		)	(6		)	(51		)	(34		)	(18		)	—			—
Net periodic other post-retirement benefit costs	$	(56	)	$	(8	)	$	(33	)	$	(24	)	$	(10	)	$	—		$	—

	Six Months Ended June 30, 2015
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Service cost	$	3		$	1		$	1		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	18			4			7			4			3			1		2
Expected return on plan assets	(6		)	(4		)	—			—			—			—		—
Amortization of actuarial loss (gain)	13			(1		)	14			9			5			—		(1		)
Amortization of prior service credit	(70		)	(7		)	(51		)	(33		)	(16		)	—		—
Net periodic other post-retirement benefit costs	$	(42	)	$	(7	)	$	(29	)	$	(20	)	$	(8	)	$	1	$	1

EMPLOYEE SAVINGS PLAN

Duke Energy sponsors, and the Subsidiary Registrants participate in, an employee savings plan that covers 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 of up to 6 percent of eligible pay per pay period. Dividends on Duke Energy shares held by the savings plan are charged to retained earnings when declared and shares held in the plan are considered outstanding in the calculation of basic and diluted earnings per share.

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, subject to a three-year vesting requirement, is provided to the employee’s savings plan account.

The following table presents employer contributions made by Duke Energy and expensed by the Subsidiary Registrants.

			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Three Months Ended June 30,
2016	$	39	$	13	$	12	$	8	$	4	$	1	$	2
2015	37		13		12		8		3		1		2
Six Months Ended June 30,
2016	$	91	$	31	$	27	$	19	$	8	$	2	$	4
2015	86		29		26		19		7		2		4

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Income Taxes

6 Months Ended

Jun. 30, 2016

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

TAXES ON FOREIGN EARNINGS

As of December 31, 2015, Duke Energy's intention was to indefinitely reinvest foreign earnings of International Energy earned after December 31, 2014. In February 2016, Duke Energy announced it had initiated a process to divest the International Energy business segment, excluding the investment in NMC. Accordingly, Duke Energy no longer intends to indefinitely reinvest the undistributed earnings of International Energy. The Company recorded U.S. income taxes of approximately $4 million and $16 million for the three and six months ended June 30, 2016, respectively, related to such earnings and will prospectively provide U.S. income taxes on future foreign earnings.

This change in the Company's intent, combined with the extension of bonus depreciation by Congress in late 2015, allows Duke Energy to more efficiently utilize foreign tax credits and reduce U.S. deferred tax liabilities associated with historic unremitted foreign earnings by approximately $95 million for the six months ended June 30, 2016.

EFFECTIVE TAX RATES

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
Duke Energy	31.8	%	35.6	%	27.2	%	33.6	%
Duke Energy Carolinas	35.1	%	36.6	%	34.6	%	36.2	%
Progress Energy	36.0	%	39.2	%	36.3	%	37.1	%
Duke Energy Progress	35.5	%	40.6	%	35.4	%	36.0	%
Duke Energy Florida	37.6	%	38.7	%	37.7	%	38.6	%
Duke Energy Ohio	34.3	%	35.0	%	29.2	%	36.8	%
Duke Energy Indiana	36.1	%	36.4	%	33.1	%	36.5	%

The decrease in the effective tax rate for Duke Energy for the three and six months ended June 30, 2016, is driven by lower income taxes on foreign earnings due to a more efficient utilization of foreign tax credits, as described above, and favorable impacts of finalizing federal tax audits. Refer to "Taxes on Foreign Earnings" above for additional information.

The decrease in the effective tax rate for Duke Energy Carolinas for the three and six months ended June 30, 2016, is primarily due to a favorable state resolution related to prior-year tax returns and favorable impacts of finalizing tax audits.

The decrease in the effective tax rate for Progress Energy for the three months ended June 30, 2016, is primarily due to a change in tax levelization.

The decrease in the effective tax rate for Duke Energy Progress for the three months ended June 30, 2016, is primarily due to a change in tax levelization.

The decrease in the effective tax rate for Duke Energy Florida for the three months ended June 30, 2016, is primarily due to an increase in AFUDC equity.

The decrease in the effective tax rate for Duke Energy Ohio for the six months ended June 30, 2016, is primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.

The decrease in the effective tax rate for Duke Energy Indiana for the six months ended June 30, 2016, is primarily due to a favorable prior-period adjustment for depreciation and other property, plant and equipment.

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Subsequent Events

6 Months Ended

Jun. 30, 2016

Subsequent Events [Abstract]

Subsequent Events

SUBSEQUENT EVENTS

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

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Organization and Basis of Presentation (Policy)

6 Months Ended

Jun. 30, 2016

Policy Text Block [Line Items]

Nature of Operations and Basis of Consolidation

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, LLC (Duke Energy Progress); Duke Energy Florida, LLC (Duke Energy Florida); Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, LLC (Duke Energy Indiana, formerly Duke Energy Indiana, Inc.). 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 (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 primarily engaged in the transmission and distribution of electricity in portions of Ohio and Kentucky, the generation and sale of electricity in portions of Kentucky, and the transportation and sale of natural gas in portions of Ohio and Kentucky. Duke Energy Ohio conducts competitive auctions for retail electricity supply in Ohio whereby the energy price is recovered from retail customers and recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Operations in Kentucky are conducted through its wholly owned subsidiary, Duke Energy Kentucky, Inc. (Duke Energy Kentucky). References herein to Duke Energy Ohio collectively 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. On April 2, 2015, Duke Energy completed the sale of its nonregulated Midwest generation business, which sold power into wholesale energy markets, to a subsidiary of Dynegy Inc. (Dynegy). See Note 2 for additional information. Substantially all of Duke Energy Ohio’s operations that remain after the sale qualify for regulatory accounting.

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 FERC. Substantially all of Duke Energy Indiana’s operations qualify for regulatory accounting. On January 1, 2016, Duke Energy Indiana, an Indiana corporation, converted into an Indiana limited liability company.

Basis of Accounting

BASIS OF PRESENTATION

Duke Energy completed the sale of Duke Energy Ohio's nonregulated Midwest generation business and Duke Energy Retail Sales (collectively, the Disposal Group), a retail sales business owned by Duke Energy, to Dynegy on April 2, 2015. The results of operations of these businesses prior to the date of sale have been classified as Discontinued Operations on the Condensed Consolidated Statements of Operations. Duke Energy has elected to present cash flows of discontinued operations combined with cash flows of continuing operations. Unless otherwise noted, the notes to these Condensed Consolidated Financial Statements exclude amounts related to discontinued operations. See Note 2 for additional information.

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. Since 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, 2015.

The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to Combined Notes to Condensed Consolidated Financial Statements. However, none of the registrants make any representations as to information related solely to Duke Energy or the subsidiaries of Duke Energy other than itself.

These Condensed Consolidated Financial Statements, in the opinion of the respective companies’ management, reflect all normal recurring adjustments 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.

Use of Estimates

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

Unbilled Revenue

UNBILLED REVENUE

Revenues on sales of electricity and natural gas are recognized when service is provided or the product is delivered. 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, customer mix, average price in effect for customer classes, timing of rendering customer bills and meter reading schedules.

Excise Taxes

EXCISE TAXES

Certain excise taxes levied by state or local governments are required to be paid even if not collected from the customer. These taxes are recognized on a gross basis. Otherwise, excise taxes are accounted for net.

Excise taxes accounted for on a gross basis as both operating revenues and property and other taxes on the Condensed Consolidated Statements of Operations were as follows.

New Accounting Standards

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2016 and 2015 had no material impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. The following accounting standard was adopted by the Duke Energy Registrants during 2015.

Balance Sheet Presentation of Debt Issuance Costs. In April and August of 2015, the Financial Accounting Standards Board (FASB) issued revised accounting guidance for the presentation of debt issuance costs. The core principle of this revised accounting guidance is that debt issuance costs are not assets, but adjustments to the carrying cost of debt. For Duke Energy, this revised accounting guidance was adopted retrospectively.

The implementation of this accounting standard resulted in a reduction of Other within Regulatory Assets and Deferred Debits and in Long-Term Debt of $192 million and $170 million on the Condensed Consolidated Balance Sheets as of June 30, 2016, and December 31, 2015, respectively.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of June 30, 2016.

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. The amendments in this update also require disclosure of sufficient information to allow users to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.

For Duke Energy, the revised accounting guidance is effective for interim and annual periods beginning January 1, 2018. The guidance can be applied retrospectively to all prior reporting periods presented or retrospectively with a cumulative effect as of the initial date of application. Duke Energy is currently evaluating the requirements. The ultimate impact of the new standard has not yet been determined.

Leases. In February 2016, the FASB issued revised accounting guidance for leases. The core principle of this guidance is that a lessee should recognize the assets and liabilities that arise from leases on the balance sheet.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2019, although it can be early adopted. The guidance is applied using a modified retrospective approach. Duke Energy is currently evaluating the requirements. Other than an expected increase in assets and liabilities, the ultimate impact of the new standard has not yet been determined.

Stock-Based Compensation and Income Taxes. In March 2016, the FASB issued revised accounting guidance for stock-based compensation and the associated income taxes. This standard changes certain aspects of accounting for stock-based payment awards to employees including the accounting for income taxes, statutory tax withholding requirements, as well as the classification on the Condensed Consolidated Statements of Cash Flows. This guidance will be applied prospectively, retrospectively, or using a modified retrospective transition method depending on the item changed.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2017, although it can be early adopted. Duke Energy is currently evaluating the requirements. The primary change expected is an increase in the volatility of income tax expense.

Duke Energy Ohio [Member]

Policy Text Block [Line Items]

Unbilled Revenue

Additionally, Duke Energy Ohio and Duke Energy Indiana sell nearly all of their retail accounts receivable to an affiliate, Cinergy Receivables Company, LLC (CRC), on a revolving basis. These transfers of receivables are accounted for as sales and include receivables for unbilled revenues. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 12 for further information. These receivables for unbilled revenues are shown in the table below.

Duke Energy Indiana [Member]

Policy Text Block [Line Items]

Unbilled Revenue

Additionally, Duke Energy Ohio and Duke Energy Indiana sell nearly all of their retail accounts receivable to an affiliate, Cinergy Receivables Company, LLC (CRC), on a revolving basis. These transfers of receivables are accounted for as sales and include receivables for unbilled revenues. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 12 for further information. These receivables for unbilled revenues are shown in the table below.

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Organization and Basis of Presentation (Tables)

6 Months Ended

Jun. 30, 2016

Organization And Basis Of Presentation [Line Items]

Schedule of Excise Taxes

Excise taxes accounted for on a gross basis as both operating revenues and property and other taxes on the Condensed Consolidated Statements of Operations were as follows.

	Three Months Ended June 30,				Six Months Ended June 30,
(in millions)	2016		2015		2016		2015
Duke Energy	$	87	$	97	$	178	$	197
Duke Energy Carolinas	7		9		15		18
Progress Energy	50		57		96		106
Duke Energy Progress	4		4		9		8
Duke Energy Florida	46		53		87		98
Duke Energy Ohio	22		23		51		55
Duke Energy Indiana	8		8		16		18

Unbilled Revenues [Member]

Organization And Basis Of Presentation [Line Items]

Schedule Of Unbilled Revenues With Restricted Receivables

Unbilled revenues, which are included within Receivables and Receivables of variable interest entities (VIEs) on the Condensed Consolidated Balance Sheets, are presented in the following table.

(in millions)	June 30, 2016		December 31, 2015
Duke Energy	$	840	$	748
Duke Energy Carolinas	330		283
Progress Energy	209		172
Duke Energy Progress	104		102
Duke Energy Florida	105		70
Duke Energy Ohio	2		3
Duke Energy Indiana	38		31

Duke Energy Ohio [Member] | Unbilled Revenues [Member]

Organization And Basis Of Presentation [Line Items]

Schedule Of Unbilled Revenues With Restricted Receivables

These receivables for unbilled revenues are shown in the table below.

(in millions)	June 30, 2016		December 31, 2015
Duke Energy Ohio	$	70	$	71
Duke Energy Indiana	109		97

Duke Energy Indiana [Member] | Unbilled Revenues [Member]

Organization And Basis Of Presentation [Line Items]

Schedule Of Unbilled Revenues With Restricted Receivables

These receivables for unbilled revenues are shown in the table below.

(in millions)	June 30, 2016		December 31, 2015
Duke Energy Ohio	$	70	$	71
Duke Energy Indiana	109		97

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Acquisitions and Dispositions (Tables)

6 Months Ended

Jun. 30, 2016

Business Combinations [Abstract]

Income Statement Disclosures

The following table presents the results of discontinued operations for the three and six months ended June 30, 2015.

	Three Months Ended						Six Months Ended
	June 30, 2015						June 30, 2015
				Duke						Duke
	Duke			Energy			Duke			Energy
(in millions)	Energy			Ohio			Energy			Ohio
Operating Revenues	$	—		$	—		$	543		$	412
Gain (Loss) on disposition	6			—			(37		)	(44		)
(Loss) Income before income taxes(a)	$	(80	)	$	(88	)	$	67		$	52
Income tax (benefit) expense	(21		)	(23		)	30			27
(Loss) Income from discontinued operations of the Disposal Group	(59		)	(65		)	37			25
Other, net of tax(b)	2			—			(3		)	—
(Loss) Income from Discontinued Operations, net of tax	$	(57	)	$	(65	)	$	34		$	25

(a) The (Loss) Income before income taxes includes the pretax impact of a $71 million and $81 million charge for the agreement in principle reached in a lawsuit related to the Disposal Group for the three and six months ended June 30, 2015, respectively. Refer to Note 5 for further information related to the lawsuit.

(b) Relates to discontinued operations of businesses not related to the Disposal Group and includes indemnifications provided for certain legal, tax and environmental matters, and foreign currency translation adjustments.

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Business Segments (Tables)

6 Months Ended

Jun. 30, 2016

Segment Reporting Information [Line Items]

Business Segment Data

The following table provides the amount of Other net expense.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
(in millions)	2016			2015			2016			2015
Duke Energy Carolinas	$	(17	)	$	(10	)	$	(34	)	$	(18	)
Progress Energy(a)	(45		)	(42		)	(94		)	(84		)
Duke Energy Progress	(8		)	(4		)	(16		)	(8		)
Duke Energy Florida	(5		)	(3		)	(9		)	(6		)
Duke Energy Ohio	(10		)	(6		)	(19		)	(8		)
Duke Energy Indiana	(5		)	(2		)	(7		)	(4		)

(a) Other for Progress Energy also includes interest expense on corporate debt instruments of $55 million and $111 million for the three and six months endedJune 30, 2016, respectively, and $59 million and $119 million for the three and six months endedJune 30, 2015, respectively.

	Three Months Ended June 30, 2016
								Total
	Regulated		International			Commercial		Reportable
(in millions)	Utilities		Energy			Portfolio		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,090	$	270		$	112	$	5,472	$	12		$	—		$	5,484
Intersegment revenues	9		—			—		9		17			(26		)	—
Total revenues	$	5,099	$	270		$	112	$	5,481	$	29		$	(26	)	$	5,484
Segment income (loss)(a)(b)	$	718	$	(102	)	$	14	$	630	$	(120	)	$	—		$	510
Add back noncontrolling interests																3
Loss from discontinued operations, net of tax																(1		)
Net income																$	512
Segment assets	$	112,754	$	3,131		$	4,329	$	120,214	$	2,260		$	180		$	122,654

(a) Other includes after-tax charges for costs to achieve mergers of $69 million, primarily due to unrealized losses on forward-starting interest rate swaps related to the Piedmont acquisition, and cost savings initiatives of $15 million primarily due to severance costs. See Notes 2 and 9 for additional information related to the forward-starting interest rate swaps.

(b) International Energy includes an after-tax impairment charge of $145 million. See Note 2 for additional information.

	Three Months Ended June 30, 2015
								Total
	Regulated		International		Commercial			Reportable
(in millions)	Utilities		Energy		Portfolio			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,211	$	287	$	75		$	5,573	$	16		$	—		$	5,589
Intersegment revenues	9		—		—			9		18			(27		)	—
Total revenues	$	5,220	$	287	$	75		$	5,582	$	34		$	(27	)	$	5,589
Segment income (loss)(a)(b)	$	632	$	52	$	(30	)	$	654	$	(51	)	$	(3	)	$	600
Add back noncontrolling interests																4
Loss from discontinued operations, net of tax(c)																(57		)
Net income																$	547

(a)    Other includes after-tax costs to achieve the Progress Energy merger of $14 million.

(b) Commercial Portfolio includes state tax expense of $41 million, resulting from changes to state apportionment factors due to the sale of the Disposal Group, that does not qualify for discontinued operations. Refer to Note 2 for further information related to the sale.

(c) Includes the after-tax impact of $46 million for the agreement in principle reached in a lawsuit related to the Disposal Group. Refer to Note 5 for further information related to the lawsuit.

	Six Months Ended June 30, 2016
							Total
	Regulated		International		Commercial		Reportable
(in millions)	Utilities		Energy		Portfolio		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	10,340	$	516	$	227	$	11,083	$	23		$	—		$	11,106
Intersegment revenues	18		—		—		9		35			(53		)	—
Total revenues	$	10,358	$	516	$	227	$	11,092	$	58		$	(53	)	$	11,106
Segment income (loss)(a)(b)	$	1,413	$	21	$	41	$	1,475	$	(274	)	$	—		$	1,201
Add back noncontrolling interests															8
Income from discontinued operations, net of tax															2
Net income															$	1,211

(a) Other includes after-tax charges for costs to achieve mergers of $143 million, primarily due to unrealized losses on forward-starting interest rate swaps related to the Piedmont acquisition, and cost savings initiatives of $27 million primarily due to severance costs. See Notes 2 and 9 for additional information related to the forward-starting interest rate swaps.

(b) International Energy includes an after-tax impairment charge of $145 million. See Note 2 for additional information.

	Six Months Ended June 30, 2015
								Total
	Regulated		International		Commercial			Reportable
(in millions)	Utilities		Energy		Portfolio			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	10,924	$	560	$	148		$	11,632	$	22		$	—		$	11,654
Intersegment revenues	19		—		—			19		39			(58		)	—
Total revenues	$	10,943	$	560	$	148		$	11,651	$	61		$	(58	)	$	11,654
Segment income (loss)(a)(b)	$	1,406	$	88	$	(23	)	$	1,471	$	(94	)	$	(4	)	$	1,373
Add back noncontrolling interests																7
Income from discontinued operations, net of tax(c)																34
Net income																$	1,414

(a)    Other includes after-tax costs to achieve the Progress Energy merger of $27 million.

(b) Commercial Portfolio includes state tax expense of $41 million, resulting from changes to state apportionment factors due to the sale of the Disposal Group, that does not qualify for discontinued operations. Refer to Note 2 for further information related to the sale.

(c) Includes after-tax impact of $53 million for the agreement in principle reached in a lawsuit related to the Disposal Group. Refer to Note 5 for further information related to the lawsuit.

XML

Regulatory Matters (Tables)

6 Months Ended

Jun. 30, 2016

Public Utilities, General Disclosures [Line Items]

Schedule of Potential Plant Retirements

The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement due to a lack of requisite environmental control equipment. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of June 30, 2016.

		Remaining Net
	Capacity	Book Value(a)
	(in MW)	(in millions)
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2	873	126
Duke Energy Indiana
Wabash River Unit 6(b)	318	34
Gallagher Units 2 and 4(c)	280	135
Total Duke Energy	1,471	295

(a) Remaining net book value amounts exclude any capitalized asset retirement costs.

(b) In April 2016, Wabash River 6 terminated coal burning operations and is targeted for retirement by the end of 2016. The total net book value of $93 million for the retail portion of Wabash River Unit 6 and the retail portion of capitalized asset retirement costs for Wabash River Units 2 through 6 is classified as Generation facilities to be retired, net on Duke Energy Indiana's Condensed Consolidated Balance Sheet at June 30, 2016.

(c) Duke Energy Indiana committed to either retire or stop burning coal at Gallagher Units 2 and 4 by December 31, 2022, as part of the proposed settlement of Edwardsport IGCC matters.

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Commitments and Contingencies (Table)

6 Months Ended

Jun. 30, 2016

Valuation and Qualifying Accounts Disclosure [Line Items]

Schedule of Additional Possible Losses in Excess of Recorded Environmental Reserves

Additional losses in excess of recorded reserves that could be incurred for the stages of investigation, remediation and monitoring for environmental sites that have been evaluated at this time are not material except as presented in the table below.

(in millions)
Duke Energy	$	75
Duke Energy Carolinas	22
Duke Energy Ohio	42
Duke Energy Indiana	7

Schedule of Loss Contingencies

The table below presents recorded reserves based on management’s best estimate of probable loss for legal matters, excluding asbestos related reserves and the exit obligation discussed above related to the termination of an EPC contract. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Accounts payable and Other within Current Liabilities. The reasonably possible range of loss in excess of recorded reserves is not material, other than as described above.

(in millions)	June 30, 2016		December 31, 2015
Reserves for Legal Matters
Duke Energy	$	110	$	166
Duke Energy Carolinas	14		11
Progress Energy	52		54
Duke Energy Progress	6		6
Duke Energy Florida	30		31
Duke Energy Ohio	4		80

Reserve for Environmental Costs [Member]

Valuation and Qualifying Accounts Disclosure [Line Items]

Schedule of Loss Contingencies

The following tables contain 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, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Balance at beginning of period	$	97		$	10		$	17		$	3		$	14		$	54		$	12
Provisions/adjustments	28			3			4			1			3			1			21
Cash reductions	(7		)	(2		)	(4		)	(1		)	(3		)	(1		)	(1		)
Balance at end of period	$	118		$	11		$	17		$	3		$	14		$	54		$	32

	Six Months Ended June 30, 2015
				Duke					Duke			Duke			Duke			Duke
	Duke			Energy		Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas		Energy			Progress			Florida			Ohio			Indiana
Balance at beginning of period	$	97		$	10	$	17		$	5		$	12		$	54		$	10
Provisions/adjustments	5			—		2			—			2			1			3
Cash reductions	(4		)	—		(2		)	(1		)	(1		)	(1		)	(1		)
Balance at end of period	$	98		$	10	$	17		$	4		$	13		$	54		$	12

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Debt and Credit Facilities (Tables)

6 Months Ended

Jun. 30, 2016

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments [Table Text Block]

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

				Six Months Ended
				June 30, 2016
						Duke		Duke		Duke		Duke		Duke
	Maturity	Interest		Duke		Energy		Energy		Energy		Energy		Energy
Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Florida		Ohio		Indiana
Unsecured
April 2016(a)	April 2023	2.875	%	$	350	$	350	$	—	$	—	$	—	$	—
First Mortgage Bonds
March 2016(b)	March 2023	2.500	%	500		—		500		—		—		—
March 2016(b)	March 2046	3.875	%	500		—		500		—		—		—
May 2016(c)	May 2046	3.750	%	500		—		—		—		—		500
June 2016(b)	June 2046	3.700	%	250		—		—		—		250		—
Secured Debt
June 2016(d)	March 2020	1.196	%	183		—		—		183		—		—
June 2016(d)	September 2022	1.731	%	150		—		—		150		—		—
June 2016(d)	September 2029	2.538	%	436		—		—		436		—		—
June 2016(d)	March 2033	2.858	%	250		—		—		250		—		—
June 2016(d)	September 2036	3.112	%	275		—		—		275		—		—
Total issuances				$	3,394	$	350	$	1,000	$	1,294	$	250	$	500

(a) Proceeds were used to pay down outstanding commercial paper and for general corporate purposes.

(b) Proceeds were used to fund capital expenditures for ongoing construction, capital maintenance and for general corporate purposes.

(c) Proceeds were used to repay $325 million of unsecured debt due June 2016, $150 million of first mortgage bonds due July 2016 and for general corporate purposes.

(d) Proceeds from the nuclear asset recovery bonds issued by DEFPF, a bankruptcy remote subsidiary of Duke Energy Florida, were used to acquire nuclear asset-recovery property from its parent, Duke Energy Florida. The nuclear asset-recovery bonds are payable only from and secured by the nuclear asset-recovery property. DEFPF is consolidated for financial reporting purposes; however, the nuclear asset-recovery bonds do not constitute a debt, liability or other legal obligation of, or interest in, Duke Energy Florida or any of its affiliates other than DEFPF. The assets of DEFPF, including the nuclear asset-recovery property, are not available to pay creditors of Duke Energy Florida or any of its affiliates. Duke Energy Florida used the proceeds from the sale to repay short-term borrowings under the intercompany money pool borrowing arrangement and make an equity distribution of $649 million to the ultimate parent, Duke Energy (Parent), which repaid short-term borrowings. The nuclear asset-recovery bonds are sequential pay amortizing bonds. The maturity date above represents the scheduled final maturity date for the bonds. See Notes 4 and 12 for additional information.

Schedule Of 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		June 30, 2016
Unsecured Debt
Duke Energy (Parent)	November 2016	2.150	%	$	500
Duke Energy (Parent)	April 2017	1.009	%	400
Duke Energy	May 2017	15.530	%	56
Secured Debt
Duke Energy	June 2017	2.075	%	45
First Mortgage Bonds
Duke Energy Indiana	July 2016	0.979	%	150
Duke Energy Carolinas	December 2016	1.750	%	350
Duke Energy Progress	March 2017	0.880	%	250
Tax-exempt Bonds
Duke Energy Carolinas	February 2017	3.600	%	77
Duke Energy Ohio(a)	August 2027	1.280	%	50
Duke Energy Indiana(b)	May 2035	1.092	%	44
Other(c)				420
Current maturities of long-term debt				$	2,342

(a) Represents Duke Energy Kentucky's bonds with a mandatory put in December 2016.

(b) The bonds have a mandatory put in December 2016.

(c) Includes capital lease obligations, amortizing debt and small bullet maturities.

Schedule Of Line Of Credit Facilities

Duke Energy has a Master Credit Facility with a capacity of $7.5 billion through January 2020. The Duke Energy Registrants, excluding Progress Energy (Parent), have borrowing capacity under the Master Credit Facility up to a specified sublimit 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. Duke Energy Carolinas and Duke Energy Progress are also required to each maintain $250 million of available capacity under the Master Credit Facility as security to meet obligations under plea agreements reached with the U.S. Department of Justice in 2015 related to violations at North Carolina facilities with ash basins. The table below includes the current borrowing sublimits and available capacity under the Master Credit Facility.

	June 30, 2016
				Duke			Duke			Duke			Duke			Duke			Duke
	Duke			Energy			Energy			Energy			Energy			Energy			Energy
(in millions)	Energy			(Parent)			Carolinas			Progress			Florida			Ohio			Indiana
Facility size(a)	$	7,500		$	3,475		$	800		$	1,000		$	1,200		$	425		$	600
Reduction to backstop issuances
Commercial paper(b)	(1,673		)	(992		)	(300		)	(159		)	(47		)	(25		)	(150		)
Outstanding letters of credit	(77		)	(70		)	(4		)	(2		)	(1		)	—			—
Tax-exempt bonds	(116		)	—			(35		)	—			—			—			(81		)
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—
Available capacity	$	5,134		$	2,413		$	211		$	589		$	1,152		$	400		$	369

(a) Represents the sublimit of each borrower.

(b) Duke Energy issued $625 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana. The balances are classified as Long-Term Debt Payable to Affiliated Companies in the Condensed Consolidated Balance Sheets.

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Goodwill and Intangible Assets (Tables)

6 Months Ended

Jun. 30, 2016

Goodwill [Line Items]

Goodwill By Reportable Operating Segment

The following table presents goodwill by reportable operating segment for Duke Energy.

Duke Energy

	Regulated		International		Commercial
(in millions)	Utilities		Energy		Portfolio		Total
Goodwill at December 31, 2015	$	15,950	$	271	$	122	$	16,343
Foreign exchange changes	—		14		—		14
Goodwill at June 30, 2016	$	15,950	$	285	$	122	$	16,357

XML

Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2016

Duke Energy Carolinas [Member]

Related Party Transaction [Line Items]

Schedule of Related Party Transactions, Other Revenue and Expense

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,
(in millions)	2016		2015		2016		2015
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	202	$	416	$	421
Indemnification coverages(b)	5		6		11		12
JDA revenue(c)	2		14		11		40
JDA expense(c)	50		38		91		95
Progress Energy
Corporate governance and shared service expenses(a)	$	160	$	172	$	334	$	339
Indemnification coverages(b)	9		9		17		19
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	89	$	93	$	189	$	194
Indemnification coverages(b)	4		4		7		8
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	79	$	145	$	145
Indemnification coverages(b)	5		5		10		11
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	87	$	103	$	172	$	188
Indemnification coverages(b)	1		1		2		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	89	$	83	$	183	$	172
Indemnification coverages(b)	2		2		4		4

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, 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) Duke Energy Carolinas and Duke Energy Progress participate in a JDA which 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.

Intercompany Income Tax Receivable/Payable

The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana
June 30, 2016
Intercompany income tax receivable	$	10	$	90	$	—	$	—	$	15	$	6
Intercompany income tax payable	—		—		11		48		—		—
December 31, 2015
Intercompany income tax receivable	$	122	$	120	$	104	$	—	$	54	$	—
Intercompany income tax payable	—		—		—		96		—		47

Progress Energy [Member]

Related Party Transaction [Line Items]

Schedule of Related Party Transactions, Other Revenue and Expense

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,
(in millions)	2016		2015		2016		2015
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	202	$	416	$	421
Indemnification coverages(b)	5		6		11		12
JDA revenue(c)	2		14		11		40
JDA expense(c)	50		38		91		95
Progress Energy
Corporate governance and shared service expenses(a)	$	160	$	172	$	334	$	339
Indemnification coverages(b)	9		9		17		19
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	89	$	93	$	189	$	194
Indemnification coverages(b)	4		4		7		8
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	79	$	145	$	145
Indemnification coverages(b)	5		5		10		11
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	87	$	103	$	172	$	188
Indemnification coverages(b)	1		1		2		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	89	$	83	$	183	$	172
Indemnification coverages(b)	2		2		4		4

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, 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) Duke Energy Carolinas and Duke Energy Progress participate in a JDA which 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.

Intercompany Income Tax Receivable/Payable

The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana
June 30, 2016
Intercompany income tax receivable	$	10	$	90	$	—	$	—	$	15	$	6
Intercompany income tax payable	—		—		11		48		—		—
December 31, 2015
Intercompany income tax receivable	$	122	$	120	$	104	$	—	$	54	$	—
Intercompany income tax payable	—		—		—		96		—		47

Duke Energy Progress [Member]

Related Party Transaction [Line Items]

Schedule of Related Party Transactions, Other Revenue and Expense

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,
(in millions)	2016		2015		2016		2015
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	202	$	416	$	421
Indemnification coverages(b)	5		6		11		12
JDA revenue(c)	2		14		11		40
JDA expense(c)	50		38		91		95
Progress Energy
Corporate governance and shared service expenses(a)	$	160	$	172	$	334	$	339
Indemnification coverages(b)	9		9		17		19
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	89	$	93	$	189	$	194
Indemnification coverages(b)	4		4		7		8
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	79	$	145	$	145
Indemnification coverages(b)	5		5		10		11
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	87	$	103	$	172	$	188
Indemnification coverages(b)	1		1		2		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	89	$	83	$	183	$	172
Indemnification coverages(b)	2		2		4		4

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, 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) Duke Energy Carolinas and Duke Energy Progress participate in a JDA which 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.

Intercompany Income Tax Receivable/Payable

The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana
June 30, 2016
Intercompany income tax receivable	$	10	$	90	$	—	$	—	$	15	$	6
Intercompany income tax payable	—		—		11		48		—		—
December 31, 2015
Intercompany income tax receivable	$	122	$	120	$	104	$	—	$	54	$	—
Intercompany income tax payable	—		—		—		96		—		47

Duke Energy Florida [Member]

Related Party Transaction [Line Items]

Schedule of Related Party Transactions, Other Revenue and Expense

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,
(in millions)	2016		2015		2016		2015
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	202	$	416	$	421
Indemnification coverages(b)	5		6		11		12
JDA revenue(c)	2		14		11		40
JDA expense(c)	50		38		91		95
Progress Energy
Corporate governance and shared service expenses(a)	$	160	$	172	$	334	$	339
Indemnification coverages(b)	9		9		17		19
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	89	$	93	$	189	$	194
Indemnification coverages(b)	4		4		7		8
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	79	$	145	$	145
Indemnification coverages(b)	5		5		10		11
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	87	$	103	$	172	$	188
Indemnification coverages(b)	1		1		2		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	89	$	83	$	183	$	172
Indemnification coverages(b)	2		2		4		4

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, 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) Duke Energy Carolinas and Duke Energy Progress participate in a JDA which 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.

Intercompany Income Tax Receivable/Payable

The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana
June 30, 2016
Intercompany income tax receivable	$	10	$	90	$	—	$	—	$	15	$	6
Intercompany income tax payable	—		—		11		48		—		—
December 31, 2015
Intercompany income tax receivable	$	122	$	120	$	104	$	—	$	54	$	—
Intercompany income tax payable	—		—		—		96		—		47

Duke Energy Ohio [Member]

Related Party Transaction [Line Items]

Schedule of Related Party Transactions, Other Revenue and Expense

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,
(in millions)	2016		2015		2016		2015
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	202	$	416	$	421
Indemnification coverages(b)	5		6		11		12
JDA revenue(c)	2		14		11		40
JDA expense(c)	50		38		91		95
Progress Energy
Corporate governance and shared service expenses(a)	$	160	$	172	$	334	$	339
Indemnification coverages(b)	9		9		17		19
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	89	$	93	$	189	$	194
Indemnification coverages(b)	4		4		7		8
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	79	$	145	$	145
Indemnification coverages(b)	5		5		10		11
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	87	$	103	$	172	$	188
Indemnification coverages(b)	1		1		2		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	89	$	83	$	183	$	172
Indemnification coverages(b)	2		2		4		4

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, 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) Duke Energy Carolinas and Duke Energy Progress participate in a JDA which 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.

Intercompany Income Tax Receivable/Payable

The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana
June 30, 2016
Intercompany income tax receivable	$	10	$	90	$	—	$	—	$	15	$	6
Intercompany income tax payable	—		—		11		48		—		—
December 31, 2015
Intercompany income tax receivable	$	122	$	120	$	104	$	—	$	54	$	—
Intercompany income tax payable	—		—		—		96		—		47

Duke Energy Indiana [Member]

Related Party Transaction [Line Items]

Schedule of Related Party Transactions, Other Revenue and Expense

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,
(in millions)	2016		2015		2016		2015
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	202	$	416	$	421
Indemnification coverages(b)	5		6		11		12
JDA revenue(c)	2		14		11		40
JDA expense(c)	50		38		91		95
Progress Energy
Corporate governance and shared service expenses(a)	$	160	$	172	$	334	$	339
Indemnification coverages(b)	9		9		17		19
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	89	$	93	$	189	$	194
Indemnification coverages(b)	4		4		7		8
JDA revenue(c)	50		38		91		95
JDA expense(c)	2		14		11		40
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	79	$	145	$	145
Indemnification coverages(b)	5		5		10		11
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	87	$	103	$	172	$	188
Indemnification coverages(b)	1		1		2		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	89	$	83	$	183	$	172
Indemnification coverages(b)	2		2		4		4

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources and employee benefits, information technology, 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) Duke Energy Carolinas and Duke Energy Progress participate in a JDA which 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.

Intercompany Income Tax Receivable/Payable

The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana
June 30, 2016
Intercompany income tax receivable	$	10	$	90	$	—	$	—	$	15	$	6
Intercompany income tax payable	—		—		11		48		—		—
December 31, 2015
Intercompany income tax receivable	$	122	$	120	$	104	$	—	$	54	$	—
Intercompany income tax payable	—		—		—		96		—		47

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Derivatives and Hedging (Tables)

6 Months Ended

Jun. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Notional Amounts of Outstanding Derivative Positions

The tables below show volumes of outstanding commodity derivatives. Amounts disclosed represent the absolute value of notional volumes of commodity contracts excluding NPNS. 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, 2016
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana
Electricity (gigawatt-hours)	7	—	—	—	—	—	7
Natural gas (millions of decatherms)	418	80	338	124	214	—	—

	December 31, 2015
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana
Electricity (gigawatt-hours)	70	—	—	—	—	34	36
Natural gas (millions of decatherms)	398	66	332	117	215	—	—

The following table shows notional amounts of outstanding derivatives related to interest rate risk.

	June 30, 2016
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	663	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	2,327		400		500		250		250		27
Total notional amount	$	2,990	$	400	$	500	$	250	$	250	$	27

	December 31, 2015
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	700	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,827		400		500		250		250		27
Total notional amount	$	2,527	$	400	$	500	$	250	$	250	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $463 million at June 30, 2016 and $497 million at December 31, 2015.

Location And Fair Value Of Derivatives Recognized in the Condensed Consolidated Balance Sheets

The following tables show the fair value and balance sheet location of derivative instruments. 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.

Derivative Assets	June 30, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	64	$	8	$	20	$	8	$	12	$	5	$	31
Noncurrent	28		10		18		10		8		—		—
Total Derivative Assets – Commodity Contracts	$	92	$	18	$	38	$	18	$	20	$	5	$	31
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	$	3	$	—	$	3	$	1	$	2	$	—	$	—
Noncurrent	13		—		13		6		7		—		—
Total Derivative Assets – Interest Rate Contracts	$	16	$	—	$	16	$	7	$	9	$	—	$	—
Total Derivative Assets	$	108	$	18	$	54	$	25	$	29	$	5	$	31

Derivative Liabilities	June 30, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	84	$	7	$	77	$	18	$	59	$	—	$	1
Noncurrent	23		—		23		—		17		—		—
Total Derivative Liabilities – Commodity Contracts	$	107	$	7	$	100	$	18	$	76	$	—	$	1
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	9	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	52		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current(a)	170		—		—		—		—		1		—
Noncurrent	90		82		—		—		—		7		—
Total Derivative Liabilities – Interest Rate Contracts	$	321	$	82	$	—	$	—	$	—	$	8	$	—
Total Derivative Liabilities	$	428	$	89	$	100	$	18	$	76	$	8	$	1

(a) Duke Energy amount includes $168 million related to forward-starting interest rate swaps associated with the Piedmont acquisition.

Derivative Assets	December 31, 2015
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	12	$	—	$	1	$	—	$	1	$	3	$	7
Noncurrent	4		—		4		—		4		—		—
Total Derivative Assets – Commodity Contracts	$	16	$	—	$	5	$	—	$	5	$	3	$	7
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	4	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	6		—		6		2		2		—		—
Total Derivative Assets – Interest Rate Contracts	$	10	$	—	$	6	$	2	$	2	$	—	$	—
Total Derivative Assets	$	26	$	—	$	11	$	2	$	7	$	3	$	7

Derivative Liabilities	December 31, 2015
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	256	$	32	$	222	$	77	$	145	$	—	$	—
Noncurrent	100		8		92		16		71		—		—
Total Derivative Liabilities – Commodity Contracts	$	356	$	40	$	314	$	93	$	216	$	—	$	—
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	11	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	33		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	4		—		3		—		—		1		—
Noncurrent	15		5		5		5		—		6		—
Total Derivative Liabilities – Interest Rate Contracts	$	63	$	5	$	8	$	5	$	—	$	7	$	—
Total Derivative Liabilities	$	419	$	45	$	322	$	98	$	216	$	7	$	—

Offsetting Assets

Derivative Assets	December 31, 2015
				Duke					Duke		Duke			Duke		Duke
	Duke			Energy		Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas		Energy			Progress		Florida			Ohio		Indiana
Current
Gross amounts recognized	$	18		$	—	$	7		$	2	$	3		$	3	$	7
Gross amounts offset	(3		)	—		(2		)	—		(2		)	—		—
Net amounts presented in Current Assets: Other	$	15		$	—	$	5		$	2	$	1		$	3	$	7
Noncurrent
Gross amounts recognized	$	8		$	—	$	4		$	—	$	4		$	—	$	—
Gross amounts offset	(4		)	—		(4		)	—		(4		)	—		—
Net amounts presented in Investments and Other Assets: Other	$	4		$	—	$	—		$	—	$	—		$	—	$	—

The following tables present the line items on the Condensed Consolidated Balance Sheets where derivatives are reported. Substantially all of Duke Energy's outstanding derivative contracts are subject to enforceable master netting arrangements. The Gross amounts offset in the tables below show the effect of these netting arrangements on financial position, and include collateral posted to offset the net position. The amounts shown are 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.

Derivative Assets	June 30, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	67		$	8		$	23		$	9		$	14		$	5	$	31
Gross amounts offset	(15		)	(3		)	(13		)	(6		)	(7		)	—		—
Net amounts presented in Current Assets: Other	$	52		$	5		$	10		$	3		$	7		$	5	$	31
Noncurrent
Gross amounts recognized	$	41		$	10		$	31		$	16		$	15		$	—	$	—
Gross amounts offset	(5		)	—			(5		)	—			(4		)	—		—
Net amounts presented in Investments and Other Assets: Other	$	36		$	10		$	26		$	16		$	11		$	—	$	—

Offsetting Liabilities

Derivative Liabilities	December 31, 2015
				Duke					Duke			Duke			Duke		Duke
	Duke			Energy		Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas		Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	271		$	32	$	225		$	77		$	145		$	1	$	—
Gross amounts offset	(22		)	—		(21		)	(1		)	(20		)	—		—
Net amounts presented in Current Liabilities: Other	$	249		$	32	$	204		$	76		$	125		$	1	$	—
Noncurrent
Gross amounts recognized	$	148		$	13	$	97		$	21		$	71		$	6	$	—
Gross amounts offset	(16		)	—		(15		)	—			(15		)	—		—
Net amounts presented in Deferred Credits and Other Liabilities: Other	$	132		$	13	$	82		$	21		$	56		$	6	$	—

Derivative Liabilities	June 30, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Current
Gross amounts recognized	$	263		$	7		$	77		$	18		$	59		$	1	$	1
Gross amounts offset	(15		)	(3		)	(13		)	(6		)	(7		)	—		—
Net amounts presented in Current Liabilities: Other	$	248		$	4		$	64		$	12		$	52		$	1	$	1
Noncurrent
Gross amounts recognized	$	165		$	82		$	23		$	—		$	17		$	7	$	—
Gross amounts offset	(5		)	—			(5		)	—			(4		)	—		—
Net amounts presented in Deferred Credits and Other Liabilities: Other	$	160		$	82		$	18		$	—		$	13		$	7	$	—

Derivative Contracts with Contingent Credit Features

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 Ohio and Duke Energy Indiana were not material.

	June 30, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Aggregate fair value of derivatives in a net liability position	$	348	$	89	$	90	$	18	$	72
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	348		89		90		18		72

	December 31, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Aggregate fair value of derivatives in a net liability position	$	334	$	45	$	290	$	93	$	194
Fair value of collateral already posted	30		—		30		—		30
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	304		45		260		93		164

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 arrangement. Amounts disclosed below represent the receivables related to the right to reclaim cash collateral under master netting arrangements. All receivables presented below were offset against net derivative positions on the Condensed Consolidated Balance Sheets.

	June 30, 2016		December 31, 2015
(in millions)	Receivables		Receivables
Duke Energy	$	—	$	30
Progress Energy	—		30
Duke Energy Florida	—		30

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Investments in Debt and Equity Securities (Tables)

6 Months Ended

Jun. 30, 2016

Schedule of Available-for-sale Securities [Line Items]

Available-for-sale Securities

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	189	$	—	$	—	$	179
Equity securities	1,869		78		3,834		1,823		58		3,590
Corporate debt securities	22		1		480		7		8		432
Municipal bonds	12		1		307		5		1		185
U.S. government bonds	38		—		1,038		11		5		1,254
Other debt securities	1		3		144		—		4		177
Total NDTF	$	1,942	$	83	$	5,992	$	1,846	$	76	$	5,817
Other Investments
Cash and cash equivalents	$	—	$	—	$	27	$	—	$	—	$	29
Equity securities	34		1		98		32		1		95
Corporate debt securities	2		1		97		1		3		92
Municipal bonds	6		1		80		3		1		74
U.S. government bonds	2		—		47		—		—		45
Other debt securities	—		1		57		—		2		62
Total Other Investments(a)	$	44	$	4	$	406	$	36	$	7	$	397
Total Investments	$	1,986	$	87	$	6,398	$	1,882	$	83	$	6,214

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

(b) Substantially all these amounts are considered other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	88
Due after one through five years	660
Due after five through 10 years	511
Due after 10 years	991
Total	$	2,250

Schedule of Realized Gain (Loss)

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	64	$	28	$	118	$	130
Realized losses	42		17		92		31

Duke Energy Carolinas [Member]

Schedule of Available-for-sale Securities [Line Items]

Available-for-sale Securities

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	66	$	—	$	—	$	34
Equity securities	1,045		44		2,128		1,021		27		2,094
Corporate debt securities	13		1		309		3		5		292
Municipal bonds	2		—		42		1		—		33
U.S. government bonds	16		—		482		3		3		438
Other debt securities	1		3		136		—		4		147
Total NDTF	$	1,077	$	48	$	3,163	$	1,028	$	39	$	3,038
Other Investments
Other debt securities	$	—	$	1	$	3	$	—	$	1	$	3
Total Other Investments(a)	$	—	$	1	$	3	$	—	$	1	$	3
Total Investments	$	1,077	$	49	$	3,166	$	1,028	$	40	$	3,041

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	6
Due after one through five years	198
Due after five through 10 years	235
Due after 10 years	533
Total	$	972

Schedule of Realized Gain (Loss)

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	33	$	17	$	67	$	107
Realized losses	19		11		56		23

Progress Energy [Member]

Schedule of Available-for-sale Securities [Line Items]

Available-for-sale Securities

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	123	$	—	$	—	$	145
Equity securities	824		34		1,706		802		31		1,496
Corporate debt securities	9		—		171		4		3		140
Municipal bonds	10		1		265		4		1		152
U.S. government bonds	22		—		556		8		2		816
Other debt securities	—		—		8		—		—		30
Total NDTF	$	865	$	35	$	2,829	$	818	$	37	$	2,779
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	18
Municipal bonds	4		—		47		3		—		45
Total Other Investments(a)	$	4	$	—	$	68	$	3	$	—	$	63
Total Investments	$	869	$	35	$	2,897	$	821	$	37	$	2,842

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	65
Due after one through five years	375
Due after five through 10 years	200
Due after 10 years	407
Total	$	1,047

Schedule of Realized Gain (Loss)

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	31	$	9	$	50	$	21
Realized losses	23		5		36		6

Duke Energy Progress [Member]

Schedule of Available-for-sale Securities [Line Items]

Available-for-sale Securities

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	58	$	—	$	—	$	110
Equity securities	614		28		1,379		596		25		1,178
Corporate debt securities	7		—		118		3		2		96
Municipal bonds	10		1		265		4		1		150
U.S. government bonds	14		—		281		6		2		486
Other debt securities	—		—		5		—		—		18
Total NDTF	$	645	$	29	$	2,106	$	609	$	30	$	2,038
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	1
Total Other Investments(a)	$	—	$	—	$	1	$	—	$	—	$	1
Total Investments	$	645	$	29	$	2,107	$	609	$	30	$	2,039

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	14
Due after one through five years	191
Due after five through 10 years	154
Due after 10 years	310
Total	$	669

Schedule of Realized Gain (Loss)

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	27	$	8	$	42	$	17
Realized losses	20		4		31		5

Duke Energy Florida [Member]

Schedule of Available-for-sale Securities [Line Items]

Available-for-sale Securities

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	65	$	—	$	—	$	35
Equity securities	210		6		327		206		6		318
Corporate debt securities	2		—		53		1		1		44
Municipal bonds	—		—		—		—		—		2
U.S. government bonds	8		—		275		2		—		330
Other debt securities	—		—		3		—		—		12
Total NDTF	$	220	$	6	$	723	$	209	$	7	$	741
Other Investments
Cash and cash equivalents	$	—	$	—	$	4	$	—	$	—	$	6
Municipal bonds	4		—		47		3		—		45
Total Other Investments(a)	$	4	$	—	$	51	$	3	$	—	$	51
Total Investments	$	224	$	6	$	774	$	212	$	7	$	792

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	51
Due after one through five years	184
Due after five through 10 years	46
Due after 10 years	97
Total	$	378

Schedule of Realized Gain (Loss)

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				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Realized gains	$	4	$	1	$	8	$	4
Realized losses	3		1		5		1

Duke Energy Indiana [Member]

Schedule of Available-for-sale Securities [Line Items]

Available-for-sale Securities

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

	June 30, 2016						December 31, 2015
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(b)		Value		Gains		Losses(b)		Value
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	2
Equity securities	28		—		73		27		—		71
Corporate debt securities	—		—		2		—		—		2
Municipal bonds	1		1		29		—		1		26
Total Other Investments(a)	$	29	$	1	$	104	$	27	$	1	$	101
Total Investments	$	29	$	1	$	104	$	27	$	1	$	101

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

(b) Substantially all these amounts represent other-than-temporary impairments on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	June 30, 2016
Due in one year or less	$	2
Due after one through five years	16
Due after five through 10 years	8
Due after 10 years	5
Total	$	31

XML

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Line Items]

Fair Value Measurement Amounts For Assets And Liabilities

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, 2016
(in millions)	Total Fair Value			Level 1			Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	3,834		$	3,666		$	1		$	—	$	167
Nuclear decommissioning trust fund debt securities	2,158			744			1,414			—		—
Other available-for-sale equity securities	98			98			—			—		—
Other available-for-sale debt securities	308			74			230			4		—
Derivative assets	108			2			72			34		—
Total assets	6,506			4,584			1,717			38		167
Derivative liabilities	(428		)	(1		)	(427		)	—		—
Net assets	$	6,078		$	4,583		$	1,290		$	38	$	167

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	3,590		$	3,418	$	—		$	—	$	172
Nuclear decommissioning trust fund debt securities	2,227			672		1,555			—		—
Other available-for-sale equity securities	95			95		—			—		—
Other available-for-sale debt securities	302			75		222			5		—
Derivative assets	26			—		16			10		—
Total assets	6,240			4,260		1,793			15		172
Derivative liabilities	(419		)	—		(419		)	—		—
Net assets	$	5,821		$	4,260	$	1,374		$	15	$	172

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements. Amounts included in earnings for derivatives are primarily included in Operating Revenues. There was no change to the Level 3 balance during the three months endedJune 30, 2015.

	Three Months Ended June 30, 2016
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	4	$	2		$	6
Purchases, sales, issuances and settlements:
Purchases	—		34			34
Settlements	—		(6		)	(6		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		4			4
Balance at end of period	$	4	$	34		$	38

	Six Months Ended June 30, 2016
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	5		$	10		$	15
Purchases, sales, issuances and settlements:
Purchases	—			34			34
Sales	(1		)	—			(1		)
Settlements	—			(13		)	(13		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—			3			3
Balance at end of period	$	4		$	34		$	38

	Six Months Ended June 30, 2015
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	5	$	(1	)	$	4
Total pretax realized or unrealized gains included in earnings	—		18			18
Purchases, sales, issuances and settlements:
Purchases	—		24			24
Settlements	—		(22		)	(22		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		4			4
Balance at end of period	$	5	$	23		$	28

Quantitative Information Table - Level 3

The following table includes quantitative information about the Duke Energy Registrants' derivatives classified as Level 3. As of June 30, 2016 and December 31, 2015, all Level 3 derivatives were financial transmission rights (FTRs).

	June 30, 2016
	Fair Value of FTRs
	(in millions)		Valuation Technique	Unobservable Input	Range
Duke Energy	$	34	RTO auction pricing	FTR price – per Megawatt-Hour (MWh)	$	(1.64	)	-	$	8.64
Duke Energy Ohio	5		RTO auction pricing	FTR price – per MWh	0.36			-	2.47
Duke Energy Indiana	29		RTO auction pricing	FTR price – per MWh	(1.64		)	-	8.64

	December 31, 2015
	Fair Value of FTRs
	(in millions)		Valuation Technique	Unobservable Input	Range
Duke Energy	$	10	RTO auction pricing	FTR price – per MWh	$	(0.74	)	-	$	7.29
Duke Energy Ohio	3		RTO auction pricing	FTR price – per MWh	0.67			-	2.53
Duke Energy Indiana	7		RTO auction pricing	FTR price – per MWh	(0.74		)	-	7.29

Schedule Of Long Term Debt Fair Value [Table Text Block]

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, 2016				December 31, 2015
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy	$	42,273	$	47,953	$	39,569	$	42,537
Duke Energy Carolinas	9,360		10,874		8,367		9,156
Progress Energy	15,486		16,715		14,464		15,856
Duke Energy Progress	6,565		7,344		6,518		6,757
Duke Energy Florida	5,540		5,226		4,266		4,908
Duke Energy Ohio	1,887		2,134		1,598		1,724
Duke Energy Indiana	3,937		4,717		3,768		4,219

Duke Energy Carolinas [Member]

Fair Value Disclosures [Line Items]

Fair Value Measurement Amounts For Assets And Liabilities

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,128		$	1,960	$	1		$	—	$	167
Nuclear decommissioning trust fund debt securities	1,035			245		790			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	18			—		18			—		—
Total assets	3,184			2,205		809			3		167
Derivative liabilities	(89		)	—		(89		)	—		—
Net assets	$	3,095		$	2,205	$	720		$	3	$	167

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,094		$	1,922	$	—		$	—	$	172
Nuclear decommissioning trust fund debt securities	944			246		698			—		—
Other available-for-sale debt securities	3			—		—			3		—
Total assets	3,041			2,168		698			3		172
Derivative liabilities	(45		)	—		(45		)	—		—
Net assets	$	2,996		$	2,168	$	653		$	3	$	172

Progress Energy [Member]

Fair Value Disclosures [Line Items]

Fair Value Measurement Amounts For Assets And Liabilities

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,706		$	1,706	$	—
Nuclear decommissioning trust fund debt securities	1,123			499		624
Other available-for-sale debt securities	68			21		47
Derivative assets	54			—		54
Total assets	2,951			2,226		725
Derivative liabilities	(100		)	—		(100		)
Net assets	$	2,851		$	2,226	$	625

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,496		$	1,496	$	—
Nuclear decommissioning trust fund debt securities	1,283			426		857
Other available-for-sale debt securities	63			18		45
Derivative assets	11			—		11
Total assets	2,853			1,940		913
Derivative liabilities	(322		)	—		(322		)
Net assets	$	2,531		$	1,940	$	591

Duke Energy Progress [Member]

Fair Value Disclosures [Line Items]

Fair Value Measurement Amounts For Assets And Liabilities

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,379		$	1,379	$	—
Nuclear decommissioning trust fund debt securities and other	727			228		499
Other available-for-sale debt securities and other	1			1		—
Derivative assets	25			—		25
Total assets	2,132			1,608		524
Derivative liabilities	(18		)	—		(18		)
Net assets	$	2,114		$	1,608	$	506

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,178		$	1,178	$	—
Nuclear decommissioning trust fund debt securities and other	860			141		719
Other available-for-sale debt securities and other	1			1		—
Derivative assets	2			—		2
Total assets	2,041			1,320		721
Derivative liabilities	(98		)	—		(98		)
Net assets	$	1,943		$	1,320	$	623

Duke Energy Florida [Member]

Fair Value Disclosures [Line Items]

Fair Value Measurement Amounts For Assets And Liabilities

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, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	327		$	327	$	—
Nuclear decommissioning trust fund debt securities and other	396			271		125
Other available-for-sale debt securities and other	51			4		47
Derivative assets	29			—		29
Total assets	803			602		201
Derivative liabilities	(76		)	—		(76		)
Net assets	$	727		$	602	$	125

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	318		$	318	$	—
Nuclear decommissioning trust fund debt securities and other	423			285		138
Other available-for-sale debt securities and other	51			6		45
Derivative assets	7			—		7
Total assets	799			609		190
Derivative liabilities	(216		)	—		(216		)
Net assets (liabilities)	$	583		$	609	$	(26	)

Duke Energy Ohio [Member]

Fair Value Disclosures [Line Items]

Fair Value Measurement Amounts For Assets And Liabilities

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 are disclosed in Note 9.

	June 30, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	5		$	—	$	—		$	5
Derivative liabilities	(8		)	—		(8		)	—
Net (liabilities) assets	$	(3	)	$	—	$	(8	)	$	5

	December 31, 2015
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	3		$	—	$	—		$	3
Derivative liabilities	(7		)	—		(7		)	—
Net (liabilities) assets	$	(4	)	$	—	$	(7	)	$	3

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs

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

	Derivatives (net)
	Three Months Ended June 30,
(in millions)	2016		2015
Balance at beginning of period	$	—	$	7
Total pretax realized or unrealized gains included in earnings	—		(4		)
Purchases, sales, issuances and settlements:
Purchases	5		—
Sales	—		5
Settlements	—		(3		)
Balance at end of period	$	5	$	5

	Derivatives (net)
	Six Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	3		$	(18	)
Total pretax realized or unrealized gains included in earnings	—			21
Purchases, sales, issuances and settlements:
Purchases	5			—
Sales	—			5
Settlements	(2		)	(3		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(1		)	—
Balance at end of period	$	5		$	5

Duke Energy Indiana [Member]

Fair Value Disclosures [Line Items]

Fair Value Measurement Amounts For Assets And Liabilities

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, 2016
(in millions)	Total Fair Value			Level 1			Level 2		Level 3
Other available-for-sale equity securities	$	73		$	73		$	—	$	—
Other available-for-sale debt securities and other	31			—			31		—
Derivative assets	31			2			—		29
Total assets	135			75			31		29
Derivative liabilities	(1		)	(1		)	—		—
Net assets	$	134		$	74		$	31	$	29

	December 31, 2015
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Other available-for-sale equity securities	$	71	$	71	$	—	$	—
Other available-for-sale debt securities and other	30		2		28		—
Derivative assets	7		—		—		7
Net assets	$	108	$	73	$	28	$	7

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs

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

	Derivatives (net)
	Three Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	2		$	3
Purchases, sales, issuances and settlements:
Purchases	29			18
Settlements	(6		)	(10		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4			6
Balance at end of period	$	29		$	17

	Derivatives (net)
	Six Months Ended June 30,
(in millions)	2016			2015
Balance at beginning of period	$	7		$	14
Purchases, sales, issuances and settlements:
Purchases	29			18
Settlements	(11		)	(19		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4			4
Balance at end of period	$	29		$	17

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Variable Interest Entities (Tables)

6 Months Ended

Jun. 30, 2016

Variable Interest Entity, Primary Beneficiary [Member]

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

The following table summarizes the amounts and expiration dates of the credit facilities described above. Amounts borrowed under the credit facilities are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
	CRC		DERF		DEPR		DEFR
Expiration date	December 2018		December 2018		February 2019		April 2019
Credit facility amount (in millions)	$	325	$	425	$	300	$	225
Amounts borrowed at June 30, 2016	325		425		300		225
Amounts borrowed at December 31, 2015	325		425		254		225

Variable Interest Entity, Not Primary Beneficiary [Member]

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

The following tables summarize the impact of non-consolidated VIEs on the Condensed Consolidated Balance Sheets.

	June 30, 2016
	Duke Energy						Duke		Duke
							Energy		Energy
(in millions)	Renewables		Other		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	39	$	58
Investments in equity method unconsolidated affiliates	222		252		474		—		—
Total assets	$	222	$	252	$	474	$	39	$	58
Other current liabilities	—		3		3		—		—
Deferred credits and other liabilities	—		13		13		—		—
Total liabilities	$	—	$	16	$	16	$	—	$	—
Net assets	$	222	$	236	$	458	$	39	$	58

	December 31, 2015
	Duke Energy						Duke		Duke
							Energy		Energy
(in millions)	Renewables		Other		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	47	$	60
Investments in equity method unconsolidated affiliates	235		152		387		—		—
Total assets	$	235	$	152	$	387	$	47	$	60
Other current liabilities	—		3		3		—		—
Deferred credits and other liabilities	—		14		14		—		—
Total liabilities	$	—	$	17	$	17	$	—	$	—
Net assets	$	235	$	135	$	370	$	47	$	60

Cinergy Receivables [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

Key assumptions used in estimating fair value are detailed in the following table.

	Duke Energy Ohio				Duke Energy Indiana
	2016		2015		2016		2015
Anticipated credit loss ratio	0.5	%	0.6	%	0.3	%	0.3	%
Discount rate	1.4	%	1.2	%	1.4	%	1.2	%
Receivable turnover rate	13.2	%	12.9	%	10.6	%	10.6	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	June 30, 2016		December 31, 2015		June 30, 2016		December 31, 2015
Receivables sold	$	208	$	233	$	279	$	260
Less: Retained interests	39		47		58		60
Net receivables sold	$	169	$	186	$	221	$	200

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

	Duke Energy Ohio								Duke Energy Indiana
	Three Months Ended				Six Months Ended				Three Months Ended				Six Months Ended
	June 30,				June 30,				June 30,				June 30,
(in millions)	2016		2015		2016		2015		2016		2015		2016		2015
Sales
Receivables sold	$	429	$	425	$	961	$	1,069	$	623	$	637	$	1,258	$	1,353
Loss recognized on sale	2		2		5		5		2		2		5		5
Cash flows
Cash proceeds from receivables sold	427		467		964		1,107		612		660		1,255		1,382
Collection fees received	—		1		—		1		1		1		1		1
Return received on retained interests	—		1		1		2		1		1		2		3

DEFPF [Member] | Variable Interest Entity, Primary Beneficiary [Member]

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

The following table summarizes the impact of DEFPF on Duke Energy Florida's Condensed Consolidated Balance Sheets.

(in millions)	June 30, 2016
Regulatory Assets: Current	$	34
Current Assets: Other	7
Regulatory Assets and Deferred Debits: Regulatory assets	1,194
Current maturities of long-term debt	35
Long-Term Debt	1,243

Renewables [Member] | Variable Interest Entity, Primary Beneficiary [Member]

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

The table below presents material balances reported on Duke Energy's Condensed Consolidated Balance Sheets related to renewables VIEs.

(in millions)	June 30, 2016			December 31, 2015
Current Assets: Other	$	223		$	138
Property, plant and equipment, cost	2,578			2,015
Accumulated depreciation and amortization	(376		)	(321		)
Current maturities of long-term debt	154			108
Long-Term Debt	866			968
Deferred Credits and Other Liabilities: Deferred income taxes	31			289
Deferred Credits and Other Liabilities: Other	277			33

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Common Stock (Tables)

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

Schedule Of Earnings Per Share

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

	Three Months Ended June 30,				Six Months Ended June 30,
(in millions, except per-share amounts)	2016		2015		2016		2015
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	508	$	600	$	1,199	$	1,372
Weighted average shares outstanding – basic	689		692		689		700
Equity Forwards	1		—		—		—
Weighted average shares outstanding – diluted	690		692		689		700
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	0.74	$	0.87	$	1.74	$	1.96
Diluted	$	0.74	$	0.87	$	1.74	$	1.96
Potentially dilutive items excluded from the calculation(a)	2		2		2		2
Dividends declared per common share	$	0.825	$	0.795	$	1.65	$	1.59

(a) Performance stock awards were not included in the dilutive securities calculation because the performance measures related to the awards had not been met.

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Stock-Based Compensation (Tables)

6 Months Ended

Jun. 30, 2016

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Schedule Of Stock-Based Compensation Expense

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
(in millions)	2016		2015		2016		2015
Restricted stock unit awards	$	10	$	11	$	17	$	20
Performance awards	5		8		10		13
Pretax stock-based compensation cost	$	15	$	19	$	27	$	33
Tax benefit associated with stock-based compensation expense	$	5	$	7	$	9	$	12
Stock-based compensation costs capitalized	1		1		2		2

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Employee Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2016

Defined Benefit Plan Disclosure [Line Items]

Employee Savings Plan Matching Contributions

The following table presents employer contributions made by Duke Energy and expensed by the Subsidiary Registrants.

			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana
Three Months Ended June 30,
2016	$	39	$	13	$	12	$	8	$	4	$	1	$	2
2015	37		13		12		8		3		1		2
Six Months Ended June 30,
2016	$	91	$	31	$	27	$	19	$	8	$	2	$	4
2015	86		29		26		19		7		2		4

Qualified Pension Plans [Member]

Defined Benefit Plan Disclosure [Line Items]

Plan Contributions by Employer

The following table includes information related to the Duke Energy Registrants’ contributions to its U.S. qualified defined benefit pension plans. Duke Energy did not make any contributions to its U.S. qualified defined benefit pension plans during the six months ended June 30, 2016.

Six Months Ended June 30, 2015

Duke

Duke

Duke

Duke

Duke

Duke

Energy

Progress

Energy

Energy

Energy

Energy

(in millions)

Energy

Carolinas

Energy

Progress

Florida

Ohio

Indiana

Contributions

$

132

$

42

$

42

$

21

$

21

$

1

$

9

Components of Net Periodic Pension Costs

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

	Three Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	37		$	12		$	10		$	6		$	5		$	1		$	2
Interest cost on projected benefit obligation	83			22			27			13			14			5			7
Expected return on plan assets	(129		)	(36		)	(42		)	(20		)	(21		)	(7		)	(11		)
Amortization of actuarial loss	33			8			13			5			7			1			3
Amortization of prior service credit	(4		)	(2		)	(1		)	(1		)	—			—			—
Other	1			—			—			1			—			—			—
Net periodic pension costs	$	21		$	4		$	7		$	4		$	5		$	—		$	1

	Three Months Ended June 30, 2015
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	39		$	12		$	11		$	6		$	5		$	1		$	2
Interest cost on projected benefit obligation	81			20			26			12			13			4			7
Expected return on plan assets	(129		)	(33		)	(41		)	(21		)	(22		)	(7		)	(11		)
Amortization of actuarial loss	44			10			17			9			8			3			4
Amortization of prior service credit	(3		)	(2		)	(1		)	(1		)	(1		)	—			—
Other	2			—			—			1			1			—			—
Net periodic pension costs	$	34		$	7		$	12		$	6		$	4		$	1		$	2

	Six Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	73		$	24		$	21		$	12		$	10		$	2		$	4
Interest cost on projected benefit obligation	166			43			53			25			28			10			14
Expected return on plan assets	(258		)	(71		)	(84		)	(41		)	(42		)	(14		)	(21		)
Amortization of actuarial loss	66			16			27			11			14			2			6
Amortization of prior service credit	(8		)	(4		)	(2		)	(1		)	—			—			—
Other	4			1			1			1			—			—			—
Net periodic pension costs	$	43		$	9		$	16		$	7		$	10		$	—		$	3

	Six Months Ended June 30, 2015
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	79		$	25		$	22		$	12		$	10		$	2		$	5
Interest cost on projected benefit obligation	163			41			52			24			27			9			14
Expected return on plan assets	(258		)	(69		)	(84		)	(41		)	(44		)	(13		)	(21		)
Amortization of actuarial loss	87			20			34			17			16			5			7
Amortization of prior service credit	(7		)	(4		)	(2		)	(1		)	(1		)	—			—
Other	4			1			1			1			1			—			—
Net periodic pension costs	$	68		$	14		$	23		$	12		$	9		$	3		$	5

Non-Qualified Pension Plan [Member]

Defined Benefit Plan Disclosure [Line Items]

Components of Net Periodic Pension Costs

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, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	3		1		1		1		1
Amortization of actuarial loss	2		—		—		—		—
Net periodic pension costs	$	6	$	1	$	1	$	1	$	1

	Three Months Ended June 30, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	3		—		1		1		1
Amortization of actuarial loss	1		—		1		—		—
Net periodic pension costs	$	5	$	—	$	2	$	1	$	1

	Six Months Ended June 30, 2016
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	—	$	—	$	—
Interest cost on projected benefit obligation	7		1		2		1		1
Amortization of actuarial loss	4		—		1		—		—
Net periodic pension costs	$	12	$	1	$	3	$	1	$	1

	Six Months Ended June 30, 2015
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Service cost	$	1	$	—	$	1	$	—	$	—
Interest cost on projected benefit obligation	7		1		2		1		1
Amortization of actuarial loss	3		—		1		—		1
Net periodic pension costs	$	11	$	1	$	4	$	1	$	2

Other Post-Retirement Benefit Plans [Member]

Defined Benefit Plan Disclosure [Line Items]

Components of Net Periodic Pension Costs

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

	Three Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	1		$	—		$	—		$	—		$	—		$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			3			2			1			1			1
Expected return on plan assets	(4		)	(2		)	—			—			—			—			(1		)
Amortization of actuarial loss (gain)	2			(1		)	6			3			3			(1		)	—
Amortization of prior service credit	(36		)	(3		)	(25		)	(17		)	(9		)	—			—
Net periodic other post-retirement benefit costs	$	(28	)	$	(4	)	$	(16	)	$	(12	)	$	(5	)	$	—		$	—

	Three Months Ended June 30, 2015
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Service cost	$	1		$	1		$	1		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			3			2			1			1		2
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—
Amortization of actuarial loss (gain)	7			(1		)	7			4			2			—		(1		)
Amortization of prior service credit	(35		)	(3		)	(25		)	(16		)	(7		)	—		—
Net periodic other post-retirement benefit costs	$	(21	)	$	(3	)	$	(14	)	$	(10	)	$	(4	)	$	1	$	1

	Six Months Ended June 30, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana
Service cost	$	2		$	—		$	—		$	—		$	—		$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	17			4			7			4			3			1			2
Expected return on plan assets	(7		)	(4		)	—			—			—			—			(1		)
Amortization of actuarial loss (gain)	3			(2		)	11			6			5			(1		)	(1		)
Amortization of prior service credit	(71		)	(6		)	(51		)	(34		)	(18		)	—			—
Net periodic other post-retirement benefit costs	$	(56	)	$	(8	)	$	(33	)	$	(24	)	$	(10	)	$	—		$	—

	Six Months Ended June 30, 2015
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana
Service cost	$	3		$	1		$	1		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	18			4			7			4			3			1		2
Expected return on plan assets	(6		)	(4		)	—			—			—			—		—
Amortization of actuarial loss (gain)	13			(1		)	14			9			5			—		(1		)
Amortization of prior service credit	(70		)	(7		)	(51		)	(33		)	(16		)	—		—
Net periodic other post-retirement benefit costs	$	(42	)	$	(7	)	$	(29	)	$	(20	)	$	(8	)	$	1	$	1

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2016

Income Tax Disclosure [Abstract]

Summary of Effective Tax Rates

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2016		2015		2016		2015
Duke Energy	31.8	%	35.6	%	27.2	%	33.6	%
Duke Energy Carolinas	35.1	%	36.6	%	34.6	%	36.2	%
Progress Energy	36.0	%	39.2	%	36.3	%	37.1	%
Duke Energy Progress	35.5	%	40.6	%	35.4	%	36.0	%
Duke Energy Florida	37.6	%	38.7	%	37.7	%	38.6	%
Duke Energy Ohio	34.3	%	35.0	%	29.2	%	36.8	%
Duke Energy Indiana	36.1	%	36.4	%	33.1	%	36.5	%

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Organization and Basis of Presentation Organization and Basis of Presentation (Narrative)(Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Accounting Changes and Error Corrections [Abstract]
New Accounting Pronouncement or Change in Accounting Principle, Effect of Adoption, Quantification	$ 192	$ 170

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Organization and Basis of Presentation (Schedule of Unbilled Revenues with Restricted Receivables) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	$ 840	$ 748
Duke Energy Carolinas [Member]
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	330	283
Progress Energy [Member]
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	209	172
Duke Energy Progress [Member]
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	104	102
Duke Energy Florida [Member]
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	105	70
Duke Energy Ohio [Member]
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	2	3
Duke Energy Indiana [Member]
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	38	31
Cinergy Receivables [Member] | Duke Energy Ohio [Member]
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	70	71
Cinergy Receivables [Member] | Duke Energy Indiana [Member]
Organization And Basis Of Presentation [Line Items]
Unbilled receivables	$ 109	$ 97

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Organization and Basis of Presentation (Schedule of Excise Taxes) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	$ 87	$ 97	$ 178	$ 197
Duke Energy Carolinas [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	7	9	15	18
Progress Energy [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	50	57	96	106
Duke Energy Progress [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	4	4	9	8
Duke Energy Florida [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	46	53	87	98
Duke Energy Ohio [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	22	23	51	55
Duke Energy Indiana [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	$ 8	$ 8	$ 16	$ 18

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Acquisitions and Dispositions (Narrative) (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016	Sep. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2016	Aug. 01, 2016	Feb. 22, 2016	Dec. 31, 2015
Significant Acquisitions and Disposals [Abstract]
Payments to acquire businesses				$ 29
Goodwill	$ 16,357		$ 16,357					$ 16,343
Asset Impairment Charges	195		198
Piedmont Natural Gas [Member]
Significant Acquisitions and Disposals [Abstract]
Forward starting interest rate swaps, notional	$ 1,400		$ 1,400
Shares offered	10.6		10.6
Bridge Facility	$ 4,900		$ 4,900
Bridge Facility, Remaining Borrowing Capacity	3,200		3,200
Acquirer Termination Fee	250		250
Acquiree Termination Fee	125		125
Duke Energy Progress [Member] | NCEMPA Generating Assets [Member]
Significant Acquisitions and Disposals [Abstract]
Payments to acquire businesses		$ 1,250
Acquisition adjustment, recorded within property, plant and equipment		$ 350
Duke Energy Ohio [Member]
Significant Acquisitions and Disposals [Abstract]
Goodwill	920		920					$ 920
Duke Energy Ohio [Member] | Midwest Generation Business [Member]
Significant Acquisitions and Disposals [Abstract]
Proceeds from sale of business				$ 2,800
International Energy [Member]
Significant Acquisitions and Disposals [Abstract]
Asset Impairment Charges			194
Segment Carrying Value	2,400		2,400
Currency Translation Adjustment	$ 589		$ 589
Term Loan Facility [Member]
Significant Acquisitions and Disposals [Abstract]
Bridge Facility							$ 1,000
Scenario, Forecast [Member] | Piedmont Natural Gas [Member]
Significant Acquisitions and Disposals [Abstract]
Payments to acquire businesses					$ 4,900
Long-term debt assumed					2,000
Goodwill					$ 3,500
Subsequent Event [Member] | Term Loan Facility [Member] | Piedmont Natural Gas [Member]
Significant Acquisitions and Disposals [Abstract]
Bridge Facility						$ 1,000

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Acquisitions and Dispositions (Assets Held For Sale) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Income From Discontinued Operations, net of tax	$ (1)	$ (57)	$ 2	$ 34
Duke Energy Ohio [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Income From Discontinued Operations, net of tax		(65)	$ 2	25
Midwest Generation Business [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Operating Revenues				543
Loss on disposition		6		(37)
Income before income taxes		(80)		67
Income tax expense		(21)		30
Income From Discontinued Operations, net of tax		(59)		37
Midwest Generation Business [Member] | Duke Energy Ohio [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Operating Revenues				412
Loss on disposition				(44)
Income before income taxes		(88)		52
Income tax expense		(23)		27
Income From Discontinued Operations, net of tax		(65)		25
Other Disposal Groups [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Income From Discontinued Operations, net of tax		2		(3)
Antitrust Lawsuit [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Litigation Settlement, Expense		71		81
Antitrust Lawsuit [Member] | Duke Energy Ohio [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Litigation Settlement, Expense		$ 71		$ 81

XML

Business Segments (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting Information [Line Items]
Revenue, Net	$ 5,484	$ 5,589	$ 11,106	$ 11,654
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	510	600	1,201	1,373
Duke Energy Ohio [Member]
Segment Reporting Information [Line Items]
Revenue, Net	428	405	944	991
Commercial Portfolio [Member]
Segment Reporting Information [Line Items]
Revenue, Net	112	75	227	148
Commercial Portfolio [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenue, Net	112	75	227	148
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	14	(30)	41	(23)
Commercial Portfolio [Member] | Duke Energy Ohio [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenue, Net				14
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent				9
International Energy [Member]
Segment Reporting Information [Line Items]
Revenue, Net	270	287	516	560
International Energy [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenue, Net	270	287	516	560
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	$ (102)	$ 52	$ 21	$ 88
National Methanol Company [Member] | International Energy [Member]
Segment Reporting Information [Line Items]
Equity Method Investment, Ownership Percentage	25.00%		25.00%

XML

Business Segments (Business Segment Data) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Operating revenues	$ 5,484	$ 5,589	$ 11,106	$ 11,654
Segment income	510	600	1,201	1,373
Add back noncontrolling interests	3	4	8	7
(Loss) Income From Discontinued Operations, net of tax	(1)	(57)	2	34
Net income (loss)	512	547	1,211	1,414
Segment assets	122,654		122,654		$ 121,156
Loss Contingency, Loss in Period		46		53
Regulated Utilities [Member]
Segment Reporting Information [Line Items]
Operating revenues	5,090	5,211	10,340	10,924
International Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	270	287	516	560
Asset Impairment Charges, net of tax	145		145
Commercial Portfolio [Member]
Segment Reporting Information [Line Items]
Operating revenues	112	75	227	148
Current State and Local Tax Expense (Benefit)		41		41
Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	12	16	23	22
Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	5,472	5,573	11,083	11,632
Operating Segments [Member] | Regulated Utilities [Member]
Segment Reporting Information [Line Items]
Operating revenues	5,099	5,220	10,358	10,943
Segment income	718	632	1,413	1,406
Segment assets	112,754		112,754
Operating Segments [Member] | International Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	270	287	516	560
Segment income	(102)	52	21	88
Segment assets	3,131		3,131
Operating Segments [Member] | Commercial Portfolio [Member]
Segment Reporting Information [Line Items]
Operating revenues	112	75	227	148
Segment income	14	(30)	41	(23)
Segment assets	4,329		4,329
Operating Segments [Member] | Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	5,481	5,582	11,092	11,651
Segment income	630	654	1,475	1,471
Segment assets	120,214		120,214
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	(26)	(27)	(53)	(58)
Segment income		(3)		(4)
Segment assets	180		180
Intersegment Eliminations [Member] | Regulated Utilities [Member]
Segment Reporting Information [Line Items]
Operating revenues	(9)	(9)	(18)	(19)
Intersegment Eliminations [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	(17)	(18)	(35)	(39)
Intersegment Eliminations [Member] | Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	(9)	(9)	(9)	(19)
Corporate, Non-Segment [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	29	34	58	61
Segment income	(120)	(51)	(274)	(94)
Segment assets	2,260		2,260
Costs to achieve merger	69	$ 14	143	$ 27
Cost Savings Initiative, Net of tax	$ 15		$ 27

XML

Business Segments (Schedule of Segment Reporting Information, by Segment) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting Information [Line Items]
Interest Expense	$ 500	$ 403	$ 1,011	$ 806
Segment income	510	600	1,201	1,373
Duke Energy Carolinas [Member]
Segment Reporting Information [Line Items]
Interest Expense	107	106	214	208
Duke Energy Carolinas [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(17)	(10)	(34)	(18)
Progress Energy [Member]
Segment Reporting Information [Line Items]
Interest Expense	160	166	320	334
Progress Energy [Member] | Other [Member]
Segment Reporting Information [Line Items]
Interest Expense	55	59	111	119
Segment income	(45)	(42)	(94)	(84)
Duke Energy Progress [Member]
Segment Reporting Information [Line Items]
Interest Expense	64	56	127	116
Duke Energy Progress [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(8)	(4)	(16)	(8)
Duke Energy Florida [Member]
Segment Reporting Information [Line Items]
Interest Expense	40	50	81	99
Duke Energy Florida [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(5)	(3)	(9)	(6)
Duke Energy Ohio [Member]
Segment Reporting Information [Line Items]
Interest Expense	21	18	41	38
Duke Energy Ohio [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(10)	(6)	(19)	(8)
Duke Energy Indiana [Member]
Segment Reporting Information [Line Items]
Interest Expense	47	43	91	88
Duke Energy Indiana [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	$ (5)	$ (2)	$ (7)	$ (4)

XML

Regulatory Matters (Narrative) (Details) $ in Millions	1 Months Ended	3 Months Ended			6 Months Ended		12 Months Ended
	Dec. 31, 2015 USD ($)	Mar. 31, 2017 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($) MW	Jun. 30, 2015 USD ($)	Dec. 31, 2015 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 11,373.0		$ 11,290.0		$ 11,290.0		$ 11,373.0
Electric Domestic Regulated Revenue			4,965.0	$ 5,090.0	10,018.0	$ 10,547.0
Payments to Acquire Businesses, Gross						29.0
Debt issuances			3,394.0		3,394.0
Property, Plant and Equipment, Net	75,709.0		77,329.0		$ 77,329.0		75,709.0
Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW					1,471
Property, Plant and Equipment, Net			$ 295.0		$ 295.0
Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			40.00%		40.00%
Atlantic Coast Pipeline (ACP) [Member] | Dominion Resources [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			45.00%		45.00%
Atlantic Coast Pipeline (ACP) [Member] | Piedmont Natural Gas [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			10.00%		10.00%
Sabal Trail Transmission Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			7.50%		7.50%
Sabal Trail Transmission Pipeline [Member] | Spectra Energy [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			59.50%		59.50%
Sabal Trail Transmission Pipeline [Member] | NextEra [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			33.00%		33.00%
Western Carolinas Modernization Plan [Member]
Public Utilities, General Disclosures [Line Items]
Approved Appeal Bond			$ 98.0		$ 98.0
Duke Energy Carolinas [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	2,766.0		2,856.0		2,856.0		2,766.0
Debt issuances			1,000.0		1,000.0
Property, Plant and Equipment, Net	25,877.0		26,405.0		$ 26,405.0		25,877.0
Duke Energy Carolinas [Member] | FERC Transmission Rates [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage amount by state commission					10.20%
Duke Energy Carolinas [Member] | FERC Complaint [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					8.49%
Duke Energy Carolinas [Member] | William States Lee Combined Cycle Facility [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost of new utility plant, including AFUDC			$ 600.0		$ 600.0
Duke Energy Carolinas [Member] | William States Lee Combined Cycle Facility [Member] | NCEMC [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			13.00%		13.00%
Progress Energy [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	5,435.0		$ 5,298.0		$ 5,298.0		5,435.0
Property, Plant and Equipment, Net	28,347.0		29,139.0		$ 29,139.0		28,347.0
Progress Energy [Member] | Crystal River Units 1 and 2 [Member] | Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW					873
Property, Plant and Equipment, Net			126.0		$ 126.0
Duke Energy Progress [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	2,710.0		2,744.0		2,744.0		2,710.0
Property, Plant and Equipment, Net	17,720.0		17,927.0		17,927.0		17,720.0
Duke Energy Progress [Member] | Western Carolinas Modernization Plan [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			1,100.0		$ 1,100.0
Duke Energy Progress [Member] | FERC Transmission Rates [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage amount by state commission					10.80%
Duke Energy Progress [Member] | FERC Complaint [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					8.49%
Duke Energy Progress [Member] | 2016 South Carolina Rate Case [Member] | PSCSC [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					10.75%
Public Utilities, Requested Rate Increase (Decrease), Percentage					14.50%
Public Utilities, Requested Rate Increase (Decrease), Amount					$ 79.0
Duke Energy Progress [Member] | Asheville Plant [Member] | Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW					376
Property, Plant and Equipment, Net	548.0		506.0		$ 506.0		548.0
Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	2,725.0		2,553.0		2,553.0		2,725.0
Debt issuances			1,294.0		1,294.0
Property, Plant and Equipment, Net	10,623.0		11,208.0		11,208.0		10,623.0
Duke Energy Florida [Member] | Hines Chiller Uprate Project [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			150.0		150.0
Duke Energy Florida [Member] | Hines Chiller Uprate Project Phase 1[Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount					16.0
Duke Energy Florida [Member] | Hines Chiller Uprate Project Phase 2 [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount					3.0
Duke Energy Florida [Member] | Osprey Energy Center Acquisition [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount					$ 48.0
Duke Energy Florida [Member] | Osprey Energy Center Acquisition [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Payments to Acquire Businesses, Gross		$ 166.0
Duke Energy Florida [Member] | Crystal River Units 1 and 2 [Member] | Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW					873
Property, Plant and Equipment, Net			126.0		$ 126.0
Duke Energy Florida [Member] | Crystal River Unit 3 [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Asset, Amortization Period					20 years
Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	497.0		472.0		$ 472.0		497.0
Electric Domestic Regulated Revenue			323.0	$ 299.0	663.0	$ 638.0
Debt issuances			250.0		250.0
Property, Plant and Equipment, Net	5,243.0		5,370.0		5,370.0		5,243.0
Duke Energy Ohio [Member] | Energy Efficiency and Peak Demand Reduction Program [Member] | PUCO [Member]
Public Utilities, General Disclosures [Line Items]
Electric Domestic Regulated Revenue	20.0
Duke Energy Ohio [Member] | Advanced Metering Infrastructure Project [Member]
Public Utilities, General Disclosures [Line Items]
Amount of Regulatory Costs Not yet Approved			10.0		10.0
Estimated capital cost			49.0		49.0
Duke Energy Ohio [Member] | Accelerated Natural Gas Service Line Replacement Rider [Member] | PUCO [Member]
Public Utilities, General Disclosures [Line Items]
Amount of Regulatory Costs Not yet Approved			320.0		320.0
Duke Energy Ohio [Member] | Regional Transmission Organization [Member]
Public Utilities, General Disclosures [Line Items]
Exit obligation	92.0		91.0		91.0		92.0
Regulatory Assets, Noncurrent	72.0		$ 72.0		$ 72.0		72.0
Duke Energy Ohio [Member] | RTO Realignment [Member]
Public Utilities, General Disclosures [Line Items]
Approved MVP Proposals			17		17
MISO estimate of Duke Energy Ohio's MVP obligation					$ 2,700.0
Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	716.0		$ 825.0		825.0		716.0
Debt issuances			500.0		500.0
Property, Plant and Equipment, Net	$ 9,523.0		9,551.0		9,551.0		9,523.0
Duke Energy Indiana [Member] | Coal Combustion Residual Plan [Member]
Public Utilities, General Disclosures [Line Items]
Amount of Regulatory Costs Not yet Approved			380.0		$ 380.0
Federal Mandate Costs Recovered Through Tracker Mechanism					80.00%
Federally Mandated Costs Recovered In Future Rate Case					20.00%
Duke Energy Indiana [Member] | FERC Transmission Rates [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage amount by state commission					12.38%
Duke Energy Indiana [Member] | FERC Transmission Rates [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage amount by state commission					0.50%
Duke Energy Indiana [Member] | FERC Complaint 1 [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					10.32%
Duke Energy Indiana [Member] | FERC Complaint 2 [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					8.67%
Duke Energy Indiana [Member] | FERC Complaint 2 [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					9.70%
Duke Energy Indiana [Member] | Grid Infrastructure Improvement Plan [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			1,900.0		$ 1,900.0
Duke Energy Indiana [Member] | Revised Grid Infrastructure Improvement Plan [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					10.00%
Estimated capital cost			1,800.0		$ 1,800.0
Public Utilities, Requested Rate Increase (Decrease), Amount					1,400.0
Duke Energy Indiana [Member] | Edwardsport Igcc Plant [Member] | IGCC Rider Proceeding [Member] | IURC [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount					87.5
Legal Fees					$ 5.5
Utilities Operating Expense, Other							$ 93.0
Regulatory Asset, Amortization Period					8 years
Regulatory Assets			175.0		$ 175.0
Minimum [Member] | Duke Energy Ohio [Member] | Natural Gas Pipeline Extension [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			100.0		100.0
Maximum [Member] | Duke Energy Carolinas [Member] | Advanced Metering Infrastructure Deferral [Member] | PSCSC [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			45.0		45.0
Maximum [Member] | Duke Energy Ohio [Member] | Natural Gas Pipeline Extension [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			150.0		150.0
DEFPF [Member] | Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			1,194.0		1,194.0
Debt issuances			1,294.0		1,294.0
DEFPF [Member] | Duke Energy Florida [Member] | Crystal River Unit 3 [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt					1,287.0
Debt issuances			$ 1,294.0		$ 1,294.0

XML

Regulatory Matters (Schedule of Net Carrying Value Of Facilities and Megawatt Capacity) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($) MW	Dec. 31, 2015 USD ($)
Public Utilities, General Disclosures [Line Items]
Remaining net book value (in millions)	$ 77,329	$ 75,709
Generation Facilities To Be Retired Net	$ 598	548
Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	1,471
Remaining net book value (in millions)	$ 295
Duke Energy Carolinas [Member]
Public Utilities, General Disclosures [Line Items]
Remaining net book value (in millions)	26,405	25,877
Progress Energy [Member]
Public Utilities, General Disclosures [Line Items]
Remaining net book value (in millions)	29,139	28,347
Generation Facilities To Be Retired Net	$ 506	548
Progress Energy [Member] | Generation Facilities To Be Retired [Member] | Crystal River Units 1 and 2 [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	873
Remaining net book value (in millions)	$ 126
Duke Energy Progress [Member]
Public Utilities, General Disclosures [Line Items]
Remaining net book value (in millions)	17,927	17,720
Generation Facilities To Be Retired Net	506	548
Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Remaining net book value (in millions)	$ 11,208	10,623
Duke Energy Florida [Member] | Generation Facilities To Be Retired [Member] | Crystal River Units 1 and 2 [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	873
Remaining net book value (in millions)	$ 126
Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Remaining net book value (in millions)	5,370	5,243
Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Remaining net book value (in millions)	9,551	$ 9,523
Generation Facilities To Be Retired Net	93
Duke Energy Indiana [Member] | Wabash River Unit 6 [Member]
Public Utilities, General Disclosures [Line Items]
Generation Facilities To Be Retired Net	$ 93
Duke Energy Indiana [Member] | Generation Facilities To Be Retired [Member] | Wabash River Unit 6 [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	318
Remaining net book value (in millions)	$ 34
Duke Energy Indiana [Member] | Generation Facilities To Be Retired [Member] | Gallagher Units 2 and 4 [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	280
Remaining net book value (in millions)	$ 135

XML

Commitments and Contingencies (Narrative) (Details) $ in Millions						1 Months Ended	3 Months Ended	6 Months Ended		12 Months Ended
	Feb. 08, 2016 USD ($)	Mar. 10, 2015 USD ($)	Feb. 02, 2014 T gal	Aug. 10, 2011	Aug. 09, 2011	Mar. 31, 2014 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($) plant Claims basin	Jun. 30, 2015 USD ($)	Dec. 31, 2015 USD ($)	Aug. 18, 2014 gal
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual								$ 110.0		$ 166.0
Charge for settlement agreement							$ 46.0		$ 53.0
Coal Ash Act Intermediate Ranking [Member]
Valuation and Qualifying Accounts [Abstract]
Number of Ash Basins | basin								12
Number of Plants with Ash Basins | plant								4
Coal Ash Act Low Ranking [Member]
Valuation and Qualifying Accounts [Abstract]
Number of Ash Basins | basin								4
Number of Plants with Ash Basins | plant								3
Coal Ash Act Low to Intermediate Ranking [Member]
Valuation and Qualifying Accounts [Abstract]
Number of Ash Basins | basin								9
Number of Plants with Ash Basins | plant								6
NCDEQ State Enforcement Actions [Member]
Valuation and Qualifying Accounts [Abstract]
Number of Plants with No Disputed Facts | plant								7
Number of Plants with Ash Basins | plant								14
Potential Groundwater Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Number of Plants with Ash Basins | plant								14
Brazil Expansion Lawsuit [Member]
Valuation and Qualifying Accounts [Abstract]
Obligation to expand installed generation capacity, percent				15.00%	15.00%
Antitrust Lawsuit [Member]
Valuation and Qualifying Accounts [Abstract]
Litigation Settlement, Expense							71.0		81.0
Duke Energy Carolinas [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual								$ 14.0		11.0
Duke Energy Carolinas [Member] | North Carolina Ash Basins [Member] | Dan River [Member]
Valuation and Qualifying Accounts [Abstract]
Civil Penalty Assessed	$ 6.8
Duke Energy Carolinas [Member] | Groundwater Violation [Member]
Valuation and Qualifying Accounts [Abstract]
Charge for settlement agreement								1.0
Duke Energy Carolinas [Member] | Asbestos Issue [Member]
Valuation and Qualifying Accounts [Abstract]
Asbestos-related injuries and damages reserves								515.0		536.0
Reinsurance retention policy, excess retention, amount reinsured								847.0
Probable insurance recoveries								$ 600.0		599.0
Duke Energy Carolinas [Member] | Asbestos Issue [Member] | Non Malignant Asbestos Claim [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency, pending claims, number | Claims								89
Asbestos-related injuries and damages reserves								$ 24.0
Duke Energy Carolinas [Member] | Asbestos Issue [Member] | Malignant Asbestos Claim [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency, pending claims, number | Claims								83
Asbestos-related injuries and damages reserves								$ 15.0
Duke Energy Carolinas [Member] | Minimum [Member] | North Carolina Ash Basins [Member] | Dan River [Member]
Valuation and Qualifying Accounts [Abstract]
Coal ash released, in tons | T			30,000
Basin water released, in gallons | gal			24,000,000
Duke Energy Carolinas [Member] | Maximum [Member] | North Carolina Ash Basins [Member] | Dan River [Member]
Valuation and Qualifying Accounts [Abstract]
Coal ash released, in tons | T			39,000
Basin water released, in gallons | gal			27,000,000
Progress Energy [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual								52.0		54.0
Duke Energy Progress [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual								6.0		6.0
Duke Energy Progress [Member] | North Carolina Ash Basins [Member] | L V Sutton Plant [Member]
Valuation and Qualifying Accounts [Abstract]
Civil Penalty Assessed		$ 25.0
Duke Energy Progress [Member] | Groundwater Violation [Member]
Valuation and Qualifying Accounts [Abstract]
Charge for settlement agreement								6.0
Duke Energy Progress [Member] | Groundwater Violation [Member] | L V Sutton Plant [Member]
Valuation and Qualifying Accounts [Abstract]
Civil Penalty Assessed		$ 25.0
Duke Energy Florida [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual								30.0		31.0
Duke Energy Florida [Member] | Westinghouse Electric Company Litigation [Member]
Valuation and Qualifying Accounts [Abstract]
Gain contingency, unrecorded amount								54.0
Loss contingency, damages sought, value						$ 510.0
Duke Energy Ohio [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual								$ 4.0		80.0
Duke Energy Ohio [Member] | W.C. Beckjord Station [Member]
Valuation and Qualifying Accounts [Abstract]
Gallons of Fuel Released | gal											9,000
Duke Energy Ohio [Member] | Antitrust Lawsuit [Member]
Valuation and Qualifying Accounts [Abstract]
Litigation Settlement Amount										$ 81.0
Litigation Settlement, Expense							$ 71.0		$ 81.0

XML

Commitments and Contingencies (Schedule of Environmental Loss Contingencies) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Environmental Matters Details [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	$ 75
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	97	$ 97
Provisions/adjustments	28	5
Cash reductions	(7)	(4)
Ending balance	118	98
Duke Energy Carolinas [Member]
Environmental Matters Details [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	22
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	10	10
Provisions/adjustments	3
Cash reductions	(2)
Ending balance	11	10
Progress Energy [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	17	17
Provisions/adjustments	4	2
Cash reductions	(4)	(2)
Ending balance	17	17
Duke Energy Progress [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	3	5
Provisions/adjustments	1
Cash reductions	(1)	(1)
Ending balance	3	4
Duke Energy Florida [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	14	12
Provisions/adjustments	3	2
Cash reductions	(3)	(1)
Ending balance	14	13
Duke Energy Ohio [Member]
Environmental Matters Details [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	42
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	54	54
Provisions/adjustments	1	1
Cash reductions	(1)	(1)
Ending balance	54	54
Duke Energy Indiana [Member]
Environmental Matters Details [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	7
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	12	10
Provisions/adjustments	21	3
Cash reductions	(1)	(1)
Ending balance	$ 32	$ 12

XML

Commitments and Contingencies (Schedule of Legal Reserves) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Loss Contingencies [Line Items]
Reserves for legal matters	$ 110	$ 166
Duke Energy Carolinas [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	14	11
Progress Energy [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	52	54
Duke Energy Progress [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	6	6
Duke Energy Florida [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	30	31
Duke Energy Ohio [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	$ 4	$ 80

XML

Debt and Credit Facilities Debt and Credit Facilities (Narrative) (Details) - USD ($) $ in Millions		3 Months Ended
	Feb. 22, 2016	Sep. 30, 2016	Jun. 30, 2016	Aug. 03, 2016	Aug. 01, 2016
Debt Instrument [Line Items]
Debt issuances			$ 3,394
Piedmont Natural Gas [Member]
Debt Instrument [Line Items]
Facility size			4,900
Available capacity			3,200
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size			7,500
Available capacity			5,134
February 2016 Term Loan Facility [Member]
Debt Instrument [Line Items]
Facility size	$ 1,000
Debt Instrument, Term	6 months
Amount outstanding at period end			100
February 2016 Term Loan Facility [Member] | Subsequent Event [Member] | Piedmont Natural Gas [Member]
Debt Instrument [Line Items]
Facility size					$ 1,000
August 2016 Term Loan Facility [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Facility size					1,500
Facility size at period end					100
Available capacity					1,400
Debt Instrument, Term		10 months
Expiration Period (in days)		90 days
August 2016 Term Loan Facility [Member] | Subsequent Event [Member] | Piedmont Natural Gas [Member]
Debt Instrument [Line Items]
Facility size					$ 1,000
Solar Facilities Financing [Member] | Subsequent Event [Member] | Secured Debt [Member]
Debt Instrument [Line Items]
Debt issuances				$ 333
Solar Facilities Financing [Member] | Subsequent Event [Member] | Secured Debt [Member] | 1.75% Secured Debt Maturing June 2034 [Member]
Debt Instrument [Line Items]
Debt issuances				$ 228
Interest rate				1.75%
Debt Instrument, Interest Rate, Increase (Decrease)		0.125%
Solar Facilities Financing [Member] | Subsequent Event [Member] | Secured Debt [Member] | 1.75% Secured Debt Maturing June 2020 [Member]
Debt Instrument [Line Items]
Debt issuances				$ 105
Interest rate				1.75%
Debt Instrument, Interest Rate, Increase (Decrease)		0.125%
Duke Energy Progress [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size			1,000
Available capacity			589
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Debt issuances			1,000
Duke Energy Carolinas [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size			800
Available capacity			211
USDOJ [Member] | Duke Energy Progress [Member] | North Carolina Ash Basins [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Minimum Master Credit Facility Balance Required			250
USDOJ [Member] | Duke Energy Carolinas [Member] | North Carolina Ash Basins [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Minimum Master Credit Facility Balance Required			$ 250
Swap [Member] | Solar Facilities Financing [Member] | Subsequent Event [Member] | Secured Debt [Member] | 1.75% Secured Debt Maturing June 2034 [Member]
Debt Instrument [Line Items]
Derivative, Fixed Interest Rate				1.81%
Swap [Member] | Solar Facilities Financing [Member] | Subsequent Event [Member] | Secured Debt [Member] | 1.75% Secured Debt Maturing June 2020 [Member]
Debt Instrument [Line Items]
Derivative, Fixed Interest Rate				1.38%

XML

Debt and Credit Facilities (Summary of Debt Issuances) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Jun. 30, 2015
Debt Instrument [Line Items]
Debt issuances		$ 3,394
Parent Company [Member]
Debt Instrument [Line Items]
Debt issuances		350
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Debt issuances		1,000
Distributions to parent		1,200	$ 100
Duke Energy Florida [Member]
Debt Instrument [Line Items]
Debt issuances		1,294
Distributions to parent		649
Duke Energy Ohio [Member]
Debt Instrument [Line Items]
Debt issuances		250
Duke Energy Indiana [Member]
Debt Instrument [Line Items]
Debt issuances		500
Distributions to parent		149
Unsecured Debt [Member] | April 2016 2.875% Unsecured Note Maturing April 2023 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 350
Interest rate		2.875%
Unsecured Debt [Member] | Parent Company [Member] | April 2016 2.875% Unsecured Note Maturing April 2023 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 350
Interest rate		2.875%
First Mortgage [Member] | March 2016 2.500% First Mortgage Bond Maturing March 2023 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500
Interest rate		2.50%
First Mortgage [Member] | March 2016 3.875% First Mortgage Bond Maturing March 2046 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500
Interest rate		3.875%
First Mortgage [Member] | May 2016 3.750% First Mortgage Bond Maturing May 2046 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500
Interest rate		3.75%
Repayments of Debt		$ 325
First Mortgage [Member] | June 2016 3.700% First Mortgage Bond Maturing June 2046 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 250
Interest rate		3.70%
First Mortgage [Member] | Duke Energy Carolinas [Member] | March 2016 2.500% First Mortgage Bond Maturing March 2023 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500
Interest rate		2.50%
First Mortgage [Member] | Duke Energy Carolinas [Member] | March 2016 3.875% First Mortgage Bond Maturing March 2046 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500
Interest rate		3.875%
First Mortgage [Member] | Duke Energy Ohio [Member] | June 2016 3.700% First Mortgage Bond Maturing June 2046 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 250
Interest rate		3.70%
First Mortgage [Member] | Duke Energy Indiana [Member] | May 2016 3.750% First Mortgage Bond Maturing May 2046 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500
Interest rate		3.75%
Repayments of Debt		$ 325
Secured Debt [Member] | June 2016 1.196% Secured Debt Maturing March 2020 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 183
Interest rate		1.196%
Secured Debt [Member] | June 2016 1.731% Secured Debt Maturing September 2022 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 150
Interest rate		1.731%
Secured Debt [Member] | June 2016 2.538% Secured Debt Maturing September 2029 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 436
Interest rate		2.538%
Secured Debt [Member] | June 2016 2.858% Secured Debt Maturing March 2033 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 250
Interest rate		2.858%
Secured Debt [Member] | June 2016 3.112% Secured Debt Maturing September 2036 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 275
Interest rate		3.112%
Secured Debt [Member] | Duke Energy Florida [Member] | June 2016 1.196% Secured Debt Maturing March 2020 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 183
Interest rate		1.196%
Distributions to parent		$ 649
Secured Debt [Member] | Duke Energy Florida [Member] | June 2016 1.731% Secured Debt Maturing September 2022 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 150
Interest rate		1.731%
Distributions to parent		$ 649
Secured Debt [Member] | Duke Energy Florida [Member] | June 2016 2.538% Secured Debt Maturing September 2029 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 436
Interest rate		2.538%
Distributions to parent		$ 649
Secured Debt [Member] | Duke Energy Florida [Member] | June 2016 2.858% Secured Debt Maturing March 2033 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 250
Interest rate		2.858%
Distributions to parent		$ 649
Secured Debt [Member] | Duke Energy Florida [Member] | June 2016 3.112% Secured Debt Maturing September 2036 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 275
Interest rate		3.112%
Distributions to parent		$ 649
Subsequent Event [Member] | First Mortgage [Member] | May 2016 3.750% First Mortgage Bond Maturing May 2046 [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 150
Subsequent Event [Member] | First Mortgage [Member] | Duke Energy Indiana [Member] | May 2016 3.750% First Mortgage Bond Maturing May 2046 [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 150

XML

Debt and Credit Facilities (Summary of Current Maturities of Long-term Debt)(Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 2,342	$ 2,074
Unsecured Debt [Member] | 15.530% Unsecured Debt Maturing May 2017 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 56
Interest rate	15.53%
Secured Debt [Member] | 2.075% Secured Debt Maturing June 2017 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 45
Interest rate	2.075%
Other Debt Obligations [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 420
Parent Company [Member] | Unsecured Debt [Member] | 2.150% Unsecured Debt Maturing November 2016 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 500
Interest rate	2.15%
Parent Company [Member] | Unsecured Debt [Member] | 1.009% Unsecured Debt Maturing April 2017 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 400
Interest rate	1.009%
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 468	356
Duke Energy Carolinas [Member] | First Mortgage Bonds [Member] | 1.750% First Mortgage Bonds Maturing December 2016 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 350
Interest rate	1.75%
Duke Energy Carolinas [Member] | Tax Exempt Bonds [Member] | 3.600% Tax-exempt Bonds Maturing February 2017[Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 77
Interest rate	3.60%
Duke Energy Progress [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 252	2
Duke Energy Progress [Member] | First Mortgage Bonds [Member] | 0.880% First Mortgage Bonds Maturing March 2017 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 250
Interest rate	0.88%
Duke Energy Florida [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 48	13
Duke Energy Ohio [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	54	106
Duke Energy Ohio [Member] | Tax Exempt Bonds [Member] | 1.280% Tax-exempt Bonds Maturing August 2027 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 50
Interest rate	1.28%
Duke Energy Indiana [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 221	$ 547
Duke Energy Indiana [Member] | First Mortgage Bonds [Member] | 0.979% First Mortgage Bonds Maturing July 2016 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 150
Interest rate	0.979%
Duke Energy Indiana [Member] | Tax Exempt Bonds [Member] | 1.092% Tax-exempt Bonds Maturing May 2035 [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 44
Interest rate	1.092%

XML

Debt and Credit Facilities (Schedule of Line of Credit Facilities) (Details) - Revolving Credit Facility [Member] $ in Millions	Jun. 30, 2016 USD ($)
Line of Credit Facility [Line Items]
Facility size	$ 7,500
Commercial paper	(1,673)
Outstanding letters of credit	(77)
Tax exempt bonds	(116)
Coal ash set-aside	(500)
Available capacity	5,134
Parent Company [Member]
Line of Credit Facility [Line Items]
Facility size	3,475
Commercial paper	(992)
Outstanding letters of credit	(70)
Available capacity	2,413
Duke Energy Carolinas [Member]
Line of Credit Facility [Line Items]
Facility size	800
Commercial paper	(300)
Outstanding letters of credit	(4)
Tax exempt bonds	(35)
Coal ash set-aside	(250)
Available capacity	211
Duke Energy Progress [Member]
Line of Credit Facility [Line Items]
Facility size	1,000
Commercial paper	(159)
Outstanding letters of credit	(2)
Coal ash set-aside	(250)
Available capacity	589
Duke Energy Florida [Member]
Line of Credit Facility [Line Items]
Facility size	1,200
Commercial paper	(47)
Outstanding letters of credit	(1)
Available capacity	1,152
Duke Energy Ohio [Member]
Line of Credit Facility [Line Items]
Facility size	425
Commercial paper	(25)
Available capacity	400
Duke Energy Indiana [Member]
Line of Credit Facility [Line Items]
Facility size	600
Commercial paper	(150)
Tax exempt bonds	(81)
Available capacity	369
Proceeds Loaned To Subsidiary Registrants [Member] | Parent Company [Member]
Line of Credit Facility [Line Items]
Commercial paper	$ (625)

XML

Goodwill and Intangible Assets (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Goodwill [Roll Forward]
Goodwill	$ 16,357	$ 16,343
Foreign exchange changes	14
Regulated Utilities [Member]
Goodwill [Roll Forward]
Goodwill	15,950	15,950
International [Member]
Goodwill [Roll Forward]
Goodwill	285	271
Foreign exchange changes	14
Commercial Portfolio [Member]
Goodwill [Roll Forward]
Goodwill	122	122
Duke Energy Ohio [Member]
Goodwill [Roll Forward]
Goodwill	920	920
Accumulated impairment charges	$ 216	$ 216

XML

Related Party Transactions (Other Revenue and Expense) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Duke Energy Carolinas [Member] | Corporate Governance And Shared Service Expenses [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 199	$ 202	$ 416	$ 421
Duke Energy Carolinas [Member] | Indemnification Coverages [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	5	6	11	12
Duke Energy Carolinas [Member] | Joint Dispatch Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	2	14	11	40
Related party transaction, expenses from transactions with related party	50	38	91	95
Progress Energy [Member] | Corporate Governance And Shared Service Expenses [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	160	172	334	339
Progress Energy [Member] | Indemnification Coverages [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	9	9	17	19
Progress Energy [Member] | Joint Dispatch Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	50	38	91	95
Related party transaction, expenses from transactions with related party	2	14	11	40
Duke Energy Progress [Member] | Corporate Governance And Shared Service Expenses [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	89	93	189	194
Duke Energy Progress [Member] | Indemnification Coverages [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	4	4	7	8
Duke Energy Progress [Member] | Joint Dispatch Agreement [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	50	38	91	95
Related party transaction, expenses from transactions with related party	2	14	11	40
Duke Energy Florida [Member] | Corporate Governance And Shared Service Expenses [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	71	79	145	145
Duke Energy Florida [Member] | Indemnification Coverages [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	5	5	10	11
Duke Energy Ohio [Member] | Corporate Governance And Shared Service Expenses [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	87	103	172	188
Duke Energy Ohio [Member] | Indemnification Coverages [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	1	1	2	4
Duke Energy Indiana [Member] | Corporate Governance And Shared Service Expenses [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	89	83	183	172
Duke Energy Indiana [Member] | Indemnification Coverages [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 2	$ 2	$ 4	$ 4

XML

Related Party Transactions (Narrative) (Details) - Duke Energy Ohio [Member] - USD ($) $ in Millions	Dec. 31, 2015	Apr. 01, 2015
Related Party Transaction [Line Items]
Intercompany loan payable	$ 103
DECAM [Member]
Related Party Transaction [Line Items]
Intercompany loan payable		$ 294

XML

Related Party Transactions Related Party Transactions (Intercompany Income Taxes) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Duke Energy Carolinas [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	$ 71	$ 107
Due to Related Parties, Current	173	229
Duke Energy Carolinas [Member] | Income Taxes [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	10	122
Progress Energy [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	11	375
Due to Related Parties, Current	232	311
Progress Energy [Member] | Income Taxes [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	90	120
Duke Energy Progress [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	9	16
Due to Related Parties, Current	134	190
Duke Energy Progress [Member] | Income Taxes [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current		104
Due to Related Parties, Current	11
Duke Energy Florida [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	3	84
Due to Related Parties, Current	100	116
Duke Energy Florida [Member] | Income Taxes [Member]
Income Tax Disclosure [Line Items]
Due to Related Parties, Current	48	96
Duke Energy Ohio [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	35	84
Due to Related Parties, Current	76	53
Duke Energy Ohio [Member] | Income Taxes [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	15	54
Duke Energy Indiana [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	60	71
Due to Related Parties, Current	87	83
Duke Energy Indiana [Member] | Income Taxes [Member]
Income Tax Disclosure [Line Items]
Due from Related Parties, Current	$ 6
Due to Related Parties, Current		$ 47

XML

Derivatives and Hedging (Notional Amounts of Derivative Instruments) (Details) Bcf in Millions, $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2016 USD ($)	Jun. 30, 2016 USD ($) GWh Bcf	Dec. 31, 2015 USD ($) GWh Bcf
Derivative [Line Items]
Undesignated Commodity Contracts Latest Expiration Year		2020
Commodity Contracts [Member] | Electricity [Member]
Derivative [Line Items]
Notional amount, energy measure, in gigawatt-hours | GWh		7	70
Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Bcf		418	398
Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 2,990	$ 2,990	$ 2,527
Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	663	663	700
Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	2,327	2,327	1,827
Variable Interest Entity, Primary Beneficiary [Member] | Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	463	463	$ 497
Piedmont Natural Gas [Member]
Derivative [Line Items]
Notional amount	1,400	1,400
Piedmont Natural Gas [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	1,400	1,400
Gain (Loss) on Interest Rate Derivative Instruments Not Designated as Hedging Instruments	75	$ 168
Duke Energy Carolinas [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Bcf		80	66
Duke Energy Carolinas [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	400	$ 400	$ 400
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	400	$ 400	$ 400
Progress Energy [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Bcf		338	332
Progress Energy [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	500	$ 500	$ 500
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	500	$ 500	$ 500
Duke Energy Progress [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Bcf		124	117
Duke Energy Progress [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	250	$ 250	$ 250
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	250	$ 250	$ 250
Duke Energy Florida [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Bcf		214	215
Duke Energy Florida [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	250	$ 250	$ 250
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	250	250	$ 250
Duke Energy Ohio [Member] | Commodity Contracts [Member] | Electricity [Member]
Derivative [Line Items]
Notional amount, energy measure, in gigawatt-hours | GWh			34
Duke Energy Ohio [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	27	27	$ 27
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 27	$ 27	$ 27
Duke Energy Indiana [Member] | Commodity Contracts [Member] | Electricity [Member]
Derivative [Line Items]
Notional amount, energy measure, in gigawatt-hours | GWh		7	36

XML

Derivatives and Hedging (Location and Fair Value Amounts of Derivatives Reflected in the Condensed Consolidated Balance Sheets) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	$ 108	$ 26
Location and fair value amounts of derivatives (Liability)	428	419
Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	67	18
Investments And Other Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	41	8
Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	263	271
Deferred Credits And Other Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	165	148
Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	92	16
Location and fair value amounts of derivatives (Liability)	107	356
Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	16	10
Location and fair value amounts of derivatives (Liability)	321	63
Designated As Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	9	11
Designated As Hedging Instrument [Member] | Interest Rate Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		4
Location and fair value amounts of derivatives (Liability)	52	33
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	64	12
Location and fair value amounts of derivatives (Liability)	84	256
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	28	4
Location and fair value amounts of derivatives (Liability)	23	100
Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	6
Location and fair value amounts of derivatives (Liability)	170	4
Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	13
Location and fair value amounts of derivatives (Liability)	90	15
Duke Energy Carolinas [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	18
Location and fair value amounts of derivatives (Liability)	89	45
Duke Energy Carolinas [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	8
Duke Energy Carolinas [Member] | Investments And Other Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	10
Duke Energy Carolinas [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	7	32
Duke Energy Carolinas [Member] | Deferred Credits And Other Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	82	13
Duke Energy Carolinas [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	18
Location and fair value amounts of derivatives (Liability)	7	40
Duke Energy Carolinas [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	82	5
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	8
Location and fair value amounts of derivatives (Liability)	7	32
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	10
Location and fair value amounts of derivatives (Liability)		8
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	82	5
Progress Energy [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	54	11
Location and fair value amounts of derivatives (Liability)	100	322
Progress Energy [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	23	7
Progress Energy [Member] | Investments And Other Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	31	4
Progress Energy [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	77	225
Progress Energy [Member] | Deferred Credits And Other Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	23	97
Progress Energy [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	38	5
Location and fair value amounts of derivatives (Liability)	100	314
Progress Energy [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	16	6
Location and fair value amounts of derivatives (Liability)		8
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	1
Location and fair value amounts of derivatives (Liability)	77	222
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	18	4
Location and fair value amounts of derivatives (Liability)	23	92
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	6
Location and fair value amounts of derivatives (Liability)		3
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	13
Location and fair value amounts of derivatives (Liability)		5
Duke Energy Progress [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	25	2
Location and fair value amounts of derivatives (Liability)	18	98
Duke Energy Progress [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	9	2
Duke Energy Progress [Member] | Investments And Other Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	16
Duke Energy Progress [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	18	77
Duke Energy Progress [Member] | Deferred Credits And Other Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		21
Duke Energy Progress [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	18
Location and fair value amounts of derivatives (Liability)	18	93
Duke Energy Progress [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	7	2
Location and fair value amounts of derivatives (Liability)		5
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	8
Location and fair value amounts of derivatives (Liability)	18	77
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	10
Location and fair value amounts of derivatives (Liability)		16
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	2
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	6
Location and fair value amounts of derivatives (Liability)		5
Duke Energy Florida [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	29	7
Location and fair value amounts of derivatives (Liability)	76	216
Duke Energy Florida [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	14	3
Duke Energy Florida [Member] | Investments And Other Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	15	4
Duke Energy Florida [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	59	145
Duke Energy Florida [Member] | Deferred Credits And Other Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	17	71
Duke Energy Florida [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	5
Location and fair value amounts of derivatives (Liability)	76	216
Duke Energy Florida [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	9	2
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	12	1
Location and fair value amounts of derivatives (Liability)	59	145
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	8	4
Location and fair value amounts of derivatives (Liability)	17	71
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	2
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	7
Duke Energy Ohio [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	5	3
Location and fair value amounts of derivatives (Liability)	8	7
Duke Energy Ohio [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	5	3
Duke Energy Ohio [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1	1
Duke Energy Ohio [Member] | Deferred Credits And Other Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	7	6
Duke Energy Ohio [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	5	3
Duke Energy Ohio [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	8	7
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	5	3
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1	1
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Noncurrent [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	7	6
Duke Energy Indiana [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	31	7
Location and fair value amounts of derivatives (Liability)	1
Duke Energy Indiana [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	31	7
Duke Energy Indiana [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1
Duke Energy Indiana [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	31	7
Location and fair value amounts of derivatives (Liability)	1
Duke Energy Indiana [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	31	$ 7
Location and fair value amounts of derivatives (Liability)	1
Piedmont Natural Gas [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	$ 168

XML

Derivatives and Hedging (Schedule of Offsetting Assets and Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	$ 108	$ 26
Net amounts recognized on the Condensed Consolidated Balance Sheet	108	26
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	428	419
Net amounts recognized on the Condensed Consolidated Balance Sheet	428	419
Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	67	18
Gross amounts offset	(15)	(3)
Net amounts recognized on the Condensed Consolidated Balance Sheet	52	15
Investments And Other Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	41	8
Gross amounts offset	(5)	(4)
Net amounts recognized on the Condensed Consolidated Balance Sheet	36	4
Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	263	271
Gross amounts offset	(15)	(22)
Net amounts recognized on the Condensed Consolidated Balance Sheet	248	249
Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	165	148
Gross amounts offset	(5)	(16)
Net amounts recognized on the Condensed Consolidated Balance Sheet	160	132
Duke Energy Carolinas [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	18
Net amounts recognized on the Condensed Consolidated Balance Sheet	18
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	89	45
Net amounts recognized on the Condensed Consolidated Balance Sheet	89	45
Duke Energy Carolinas [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	8
Gross amounts offset	(3)
Net amounts recognized on the Condensed Consolidated Balance Sheet	5
Duke Energy Carolinas [Member] | Investments And Other Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	10
Net amounts recognized on the Condensed Consolidated Balance Sheet	10
Duke Energy Carolinas [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	7	32
Gross amounts offset	(3)
Net amounts recognized on the Condensed Consolidated Balance Sheet	4	32
Duke Energy Carolinas [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	82	13
Net amounts recognized on the Condensed Consolidated Balance Sheet	82	13
Progress Energy [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	54	11
Net amounts recognized on the Condensed Consolidated Balance Sheet	54	11
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	100	322
Net amounts recognized on the Condensed Consolidated Balance Sheet	100	322
Progress Energy [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	23	7
Gross amounts offset	(13)	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	10	5
Progress Energy [Member] | Investments And Other Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	31	4
Gross amounts offset	(5)	(4)
Net amounts recognized on the Condensed Consolidated Balance Sheet	26
Progress Energy [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	77	225
Gross amounts offset	(13)	(21)
Net amounts recognized on the Condensed Consolidated Balance Sheet	64	204
Progress Energy [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	23	97
Gross amounts offset	(5)	(15)
Net amounts recognized on the Condensed Consolidated Balance Sheet	18	82
Duke Energy Progress [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	25	2
Net amounts recognized on the Condensed Consolidated Balance Sheet	25	2
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	18	98
Net amounts recognized on the Condensed Consolidated Balance Sheet	18	98
Duke Energy Progress [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	9	2
Gross amounts offset	(6)
Net amounts recognized on the Condensed Consolidated Balance Sheet	3	2
Duke Energy Progress [Member] | Investments And Other Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	16
Net amounts recognized on the Condensed Consolidated Balance Sheet	16
Duke Energy Progress [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	18	77
Gross amounts offset	(6)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	12	76
Duke Energy Progress [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized		21
Net amounts recognized on the Condensed Consolidated Balance Sheet		21
Duke Energy Florida [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	29	7
Net amounts recognized on the Condensed Consolidated Balance Sheet	29	7
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	76	216
Net amounts recognized on the Condensed Consolidated Balance Sheet	76	216
Duke Energy Florida [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	14	3
Gross amounts offset	(7)	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	7	1
Duke Energy Florida [Member] | Investments And Other Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	15	4
Gross amounts offset	(4)	(4)
Net amounts recognized on the Condensed Consolidated Balance Sheet	11
Duke Energy Florida [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	59	145
Gross amounts offset	(7)	(20)
Net amounts recognized on the Condensed Consolidated Balance Sheet	52	125
Duke Energy Florida [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	17	71
Gross amounts offset	(4)	(15)
Net amounts recognized on the Condensed Consolidated Balance Sheet	13	56
Duke Energy Ohio [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	5	3
Net amounts recognized on the Condensed Consolidated Balance Sheet	5	3
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	8	7
Net amounts recognized on the Condensed Consolidated Balance Sheet	8	7
Duke Energy Ohio [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	5	3
Net amounts recognized on the Condensed Consolidated Balance Sheet	5	3
Duke Energy Ohio [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	1	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	1
Duke Energy Ohio [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	7	6
Net amounts recognized on the Condensed Consolidated Balance Sheet	7	6
Duke Energy Indiana [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	31	7
Net amounts recognized on the Condensed Consolidated Balance Sheet	31	7
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	(1)
Duke Energy Indiana [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	31	7
Net amounts recognized on the Condensed Consolidated Balance Sheet	31	$ 7
Duke Energy Indiana [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	$ 1

XML

Derivatives and Hedging (Derivative Instruments with Credit-Risk Related Contingent Features and Cash Collateral) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value amounts of derivative instruments in a net liability position	$ 348	$ 334
Fair value of collateral already posted		30
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	348	304
Information Regarding Cash Collateral Under Master Netting Arrangements
Amount of right to receive cash collateral, offset against derivative liability		30
Duke Energy Carolinas [Member]
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value amounts of derivative instruments in a net liability position	89	45
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	89	45
Progress Energy [Member]
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value amounts of derivative instruments in a net liability position	90	290
Fair value of collateral already posted		30
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	90	260
Information Regarding Cash Collateral Under Master Netting Arrangements
Amount of right to receive cash collateral, offset against derivative liability		30
Duke Energy Progress [Member]
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value amounts of derivative instruments in a net liability position	18	93
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	18	93
Duke Energy Florida [Member]
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value amounts of derivative instruments in a net liability position	72	194
Fair value of collateral already posted		30
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	$ 72	164
Information Regarding Cash Collateral Under Master Netting Arrangements
Amount of right to receive cash collateral, offset against derivative liability		$ 30

XML

Investments in Debt and Equity Securities (Available-For-Sale Investments) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	$ 1,986	$ 1,882
Gross Unrealized Holding Losses	87	83
Estimated Fair Value	6,398	6,214
Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,942	1,846
Gross Unrealized Holding Losses	83	76
Estimated Fair Value	5,992	5,817
Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	189	179
Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,869	1,823
Gross Unrealized Holding Losses	78	58
Estimated Fair Value	3,834	3,590
Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	22	7
Gross Unrealized Holding Losses	1	8
Estimated Fair Value	480	432
Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	12	5
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	307	185
Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	38	11
Gross Unrealized Holding Losses		5
Estimated Fair Value	1,038	1,254
Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1
Gross Unrealized Holding Losses	3	4
Estimated Fair Value	144	177
Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	44	36
Gross Unrealized Holding Losses	4	7
Estimated Fair Value	406	397
Other Classification [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	27	29
Other Classification [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	34	32
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	98	95
Other Classification [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	1
Gross Unrealized Holding Losses	1	3
Estimated Fair Value	97	92
Other Classification [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	6	3
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	80	74
Other Classification [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2
Estimated Fair Value	47	45
Other Classification [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Losses	1	2
Estimated Fair Value	57	62
Duke Energy Carolinas [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,077	1,028
Gross Unrealized Holding Losses	49	40
Estimated Fair Value	3,166	3,041
Duke Energy Carolinas [Member] | Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,077	1,028
Gross Unrealized Holding Losses	48	39
Estimated Fair Value	3,163	3,038
Duke Energy Carolinas [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	66	34
Duke Energy Carolinas [Member] | Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,045	1,021
Gross Unrealized Holding Losses	44	27
Estimated Fair Value	2,128	2,094
Duke Energy Carolinas [Member] | Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	13	3
Gross Unrealized Holding Losses	1	5
Estimated Fair Value	309	292
Duke Energy Carolinas [Member] | Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	1
Estimated Fair Value	42	33
Duke Energy Carolinas [Member] | Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	16	3
Gross Unrealized Holding Losses		3
Estimated Fair Value	482	438
Duke Energy Carolinas [Member] | Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1
Gross Unrealized Holding Losses	3	4
Estimated Fair Value	136	147
Duke Energy Carolinas [Member] | Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	3	3
Duke Energy Carolinas [Member] | Other Classification [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	3	3
Progress Energy [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	869	821
Gross Unrealized Holding Losses	35	37
Estimated Fair Value	2,897	2,842
Progress Energy [Member] | Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	865	818
Gross Unrealized Holding Losses	35	37
Estimated Fair Value	2,829	2,779
Progress Energy [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	123	145
Progress Energy [Member] | Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	824	802
Gross Unrealized Holding Losses	34	31
Estimated Fair Value	1,706	1,496
Progress Energy [Member] | Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	9	4
Gross Unrealized Holding Losses		3
Estimated Fair Value	171	140
Progress Energy [Member] | Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	10	4
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	265	152
Progress Energy [Member] | Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	22	8
Gross Unrealized Holding Losses		2
Estimated Fair Value	556	816
Progress Energy [Member] | Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	8	30
Progress Energy [Member] | Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	4	3
Estimated Fair Value	68	63
Progress Energy [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	21	18
Progress Energy [Member] | Other Classification [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	4	3
Estimated Fair Value	47	45
Duke Energy Progress [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	645	609
Gross Unrealized Holding Losses	29	30
Estimated Fair Value	2,107	2,039
Duke Energy Progress [Member] | Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	645	609
Gross Unrealized Holding Losses	29	30
Estimated Fair Value	2,106	2,038
Duke Energy Progress [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	58	110
Duke Energy Progress [Member] | Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	614	596
Gross Unrealized Holding Losses	28	25
Estimated Fair Value	1,379	1,178
Duke Energy Progress [Member] | Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	7	3
Gross Unrealized Holding Losses		2
Estimated Fair Value	118	96
Duke Energy Progress [Member] | Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	10	4
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	265	150
Duke Energy Progress [Member] | Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	14	6
Gross Unrealized Holding Losses		2
Estimated Fair Value	281	486
Duke Energy Progress [Member] | Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	5	18
Duke Energy Progress [Member] | Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	1	1
Duke Energy Progress [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	1	1
Duke Energy Florida [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	224	212
Gross Unrealized Holding Losses	6	7
Estimated Fair Value	774	792
Duke Energy Florida [Member] | Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	220	209
Gross Unrealized Holding Losses	6	7
Estimated Fair Value	723	741
Duke Energy Florida [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	65	35
Duke Energy Florida [Member] | Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	210	206
Gross Unrealized Holding Losses	6	6
Estimated Fair Value	327	318
Duke Energy Florida [Member] | Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	1
Gross Unrealized Holding Losses		1
Estimated Fair Value	53	44
Duke Energy Florida [Member] | Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value		2
Duke Energy Florida [Member] | Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	8	2
Estimated Fair Value	275	330
Duke Energy Florida [Member] | Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	3	12
Duke Energy Florida [Member] | Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	4	3
Estimated Fair Value	51	51
Duke Energy Florida [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	4	6
Duke Energy Florida [Member] | Other Classification [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	4	3
Estimated Fair Value	47	45
Duke Energy Indiana [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	29	27
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	104	101
Duke Energy Indiana [Member] | Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	29	27
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	104	101
Duke Energy Indiana [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value		2
Duke Energy Indiana [Member] | Other Classification [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	28	27
Estimated Fair Value	73	71
Duke Energy Indiana [Member] | Other Classification [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	2	2
Duke Energy Indiana [Member] | Other Classification [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	$ 29	$ 26

XML

Investments in Debt and Equity Securities (Maturities) (Details) $ in Millions	Jun. 30, 2016 USD ($)
Debt Instrument [Line Items]
Due in one year or less	$ 88
Due after one through five years	660
Due after five through 10 years	511
Due after 10 years	991
Total	2,250
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Due in one year or less	6
Due after one through five years	198
Due after five through 10 years	235
Due after 10 years	533
Total	972
Progress Energy [Member]
Debt Instrument [Line Items]
Due in one year or less	65
Due after one through five years	375
Due after five through 10 years	200
Due after 10 years	407
Total	1,047
Duke Energy Progress [Member]
Debt Instrument [Line Items]
Due in one year or less	14
Due after one through five years	191
Due after five through 10 years	154
Due after 10 years	310
Total	669
Duke Energy Florida [Member]
Debt Instrument [Line Items]
Due in one year or less	51
Due after one through five years	184
Due after five through 10 years	46
Due after 10 years	97
Total	378
Duke Energy Indiana [Member]
Debt Instrument [Line Items]
Due in one year or less	2
Due after one through five years	16
Due after five through 10 years	8
Due after 10 years	5
Total	$ 31

XML

Investments in Debt and Equity Securities (Realized Gains and Losses)(Details) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	$ 64	$ 28	$ 118	$ 130
Realized losses	42	17	92	31
Duke Energy Carolinas [Member]
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	33	17	67	107
Realized losses	19	11	56	23
Progress Energy [Member]
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	31	9	50	21
Realized losses	23	5	36	6
Duke Energy Progress [Member]
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	27	8	42	17
Realized losses	20	4	31	5
Duke Energy Florida [Member]
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	4	1	8	4
Realized losses	$ 3	$ 1	$ 5	$ 1

XML

Fair Value Measurements (Fair Value Measurement Amounts for Assets and Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	$ 108	$ 26
Total assets	6,506	6,240
Derivative liabilities	(428)	(419)
Net assets	6,078	5,821
Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	2
Total assets	4,584	4,260
Derivative liabilities	(1)
Net assets	4,583	4,260
Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	72	16
Total assets	1,717	1,793
Derivative liabilities	(427)	(419)
Net assets	1,290	1,374
Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	34	10
Total assets	38	15
Net assets	38	15
Fair Value, Inputs, Not Categorized [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	167	172
Net assets	167	172
Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	3,834	3,590
Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	3,666	3,418
Equity Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1
Equity Securities [Member] | Ndtf [Member] | Fair Value, Inputs, Not Categorized [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	167	172
Equity Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	98	95
Equity Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	98	95
Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	2,158	2,227
Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	744	672
Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,414	1,555
Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	308	302
Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	74	75
Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	230	222
Debt Securities [Member] | Other Classification [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	4	5
Duke Energy Carolinas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	18
Total assets	3,184	3,041
Derivative liabilities	(89)	(45)
Net assets	3,095	2,996
Duke Energy Carolinas [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	2,205	2,168
Net assets	2,205	2,168
Duke Energy Carolinas [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	18
Total assets	809	698
Derivative liabilities	(89)	(45)
Net assets	720	653
Duke Energy Carolinas [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	3	3
Net assets	3	3
Duke Energy Carolinas [Member] | Fair Value, Inputs, Not Categorized [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	167	172
Net assets	167	172
Duke Energy Carolinas [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	2,128	2,094
Duke Energy Carolinas [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,960	1,922
Duke Energy Carolinas [Member] | Equity Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1
Duke Energy Carolinas [Member] | Equity Securities [Member] | Ndtf [Member] | Fair Value, Inputs, Not Categorized [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	167	172
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,035	944
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	245	246
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	790	698
Duke Energy Carolinas [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	3	3
Duke Energy Carolinas [Member] | Debt Securities [Member] | Other Classification [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	3	3
Progress Energy [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	54	11
Total assets	2,951	2,853
Derivative liabilities	(100)	(322)
Net assets	2,851	2,531
Progress Energy [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	2,226	1,940
Net assets	2,226	1,940
Progress Energy [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	54	11
Total assets	725	913
Derivative liabilities	(100)	(322)
Net assets	625	591
Progress Energy [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,706	1,496
Progress Energy [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,706	1,496
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,123	1,283
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	499	426
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	624	857
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	68	63
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	21	18
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	47	45
Duke Energy Progress [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	25	2
Total assets	2,132	2,041
Derivative liabilities	(18)	(98)
Net assets	2,114	1,943
Duke Energy Progress [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	1,608	1,320
Net assets	1,608	1,320
Duke Energy Progress [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	25	2
Total assets	524	721
Derivative liabilities	(18)	(98)
Net assets	506	623
Duke Energy Progress [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,379	1,178
Duke Energy Progress [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,379	1,178
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	727	860
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	228	141
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	499	719
Duke Energy Progress [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1	1
Duke Energy Progress [Member] | Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1	1
Duke Energy Florida [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	29	7
Total assets	803	799
Derivative liabilities	(76)	(216)
Net assets	727	583
Duke Energy Florida [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	602	609
Net assets	602	609
Duke Energy Florida [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	29	7
Total assets	201	190
Derivative liabilities	(76)	(216)
Net assets	125	(26)
Duke Energy Florida [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	327	318
Duke Energy Florida [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	327	318
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	396	423
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	271	285
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	125	138
Duke Energy Florida [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	51	51
Duke Energy Florida [Member] | Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	4	6
Duke Energy Florida [Member] | Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	47	45
Duke Energy Ohio [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	5	3
Derivative liabilities	(8)	(7)
Net assets	(3)	(4)
Duke Energy Ohio [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative liabilities	(8)	(7)
Net assets	(8)	(7)
Duke Energy Ohio [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	5	3
Net assets	5	3
Duke Energy Indiana [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	31	7
Total assets	135
Derivative liabilities	1
Net assets	134	108
Duke Energy Indiana [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	2
Total assets	75
Derivative liabilities	1
Net assets	74	73
Duke Energy Indiana [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	31
Net assets	31	28
Duke Energy Indiana [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	29	7
Total assets	29
Net assets	29	7
Duke Energy Indiana [Member] | Equity Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	73	71
Duke Energy Indiana [Member] | Equity Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	73	71
Duke Energy Indiana [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	31	30
Duke Energy Indiana [Member] | Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments		2
Duke Energy Indiana [Member] | Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	$ 31	$ 28

XML

Fair Value Measurements (Reconciliation of Assets and Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Investments
Beginning balance	$ 6		$ 15	$ 4
Total pretax gains (losses) included in earnings				18
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	34		34	24
Sales			(1)
Settlements	(6)		(13)	(22)
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4		3	4
Ending balance	38	$ 28	38	28
Derivatives (net)
Beginning balance	2		10	(1)
Total pretax gains (losses) included in earnings				18
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases	34		34	24
Settlements	(6)		(13)	(22)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4		3	4
Ending balance	34	23	34	23
Investments [Member]
Investments
Beginning balance	4		5	5
Sales			(1)
Ending balance	4	5	4	5
Duke Energy Ohio [Member]
Derivatives (net)
Beginning balance		7	3	(18)
Total pretax gains (losses) included in earnings		(4)		21
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases	5		5
Sales		5		5
Settlements		(3)	(2)	(3)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities			(1)
Ending balance	5	5	5	5
Duke Energy Indiana [Member]
Derivatives (net)
Beginning balance	2	3	7	14
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases	29	18	29	18
Settlements	(6)	(10)	(11)	(19)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4	6	4	4
Ending balance	$ 29	$ 17	$ 29	$ 17

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Fair Value Measurements (Quantitative Level 3 Fair Value Disclosure) (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2016 USD ($) $ / MWh	Dec. 31, 2015 USD ($) $ / MWh	Mar. 31, 2016 USD ($)	Jun. 30, 2015 USD ($)	Mar. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Net derivative asset (liability) | $	$ 34	$ 10	$ 2	$ 23		$ (1)
Financial Transmission Rights [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Net derivative asset (liability) | $	$ 34	$ 10
Financial Transmission Rights [Member] | Minimum [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Fair Value Inputs Price Per Financial Transmission Rights | $ / MWh	(1.64)	(0.74)
Financial Transmission Rights [Member] | Maximum [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Fair Value Inputs Price Per Financial Transmission Rights | $ / MWh	8.64	7.29
Duke Energy Ohio [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Net derivative asset (liability) | $	$ 5	$ 3		5	$ 7	(18)
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Net derivative asset (liability) | $	$ 5	$ 3
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | Minimum [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Fair Value Inputs Price Per Financial Transmission Rights | $ / MWh	0.36	0.67
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | Maximum [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Fair Value Inputs Price Per Financial Transmission Rights | $ / MWh	2.47	2.53
Duke Energy Indiana [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Net derivative asset (liability) | $	$ 29	$ 7	$ 2	$ 17	$ 3	$ 14
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Net derivative asset (liability) | $	$ 29	$ 7
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | Minimum [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Fair Value Inputs Price Per Financial Transmission Rights | $ / MWh	(1.64)	(0.74)
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | Maximum [Member] | RTO Auction Pricing [Member]
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]
Fair Value Inputs Price Per Financial Transmission Rights | $ / MWh	8.64	7.29

XML

Fair Value Measurements (Additional Fair Value Disclosure) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 42,273	$ 39,569
Long-term debt, fair value	47,953	42,537
Duke Energy Carolinas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	9,360	8,367
Long-term debt, fair value	10,874	9,156
Progress Energy [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	15,486	14,464
Long-term debt, fair value	16,715	15,856
Duke Energy Progress [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	6,565	6,518
Long-term debt, fair value	7,344	6,757
Duke Energy Florida [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	5,540	4,266
Long-term debt, fair value	5,226	4,908
Duke Energy Ohio [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,887	1,598
Long-term debt, fair value	2,134	1,724
Duke Energy Indiana [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	3,937	3,768
Long-term debt, fair value	$ 4,717	$ 4,219

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Variable Interest Entities (Narrative) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	$ 3,394
Cinergy Receivables [Member]
Variable Interest Entities [Line Items]
Minimum equity balance required by Cinergy Receivables	3
Cinergy Receivables [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	$ 325
Percent of proceeds received as cash	75.00%
Percent of proceeds received as subordinated note	25.00%
Duke American Transmission Company [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	50.00%
Atlantic Coast Pipeline [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	40.00%
Sabal Trail Transmission Pipeline [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	7.50%
OVEC [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	9.00%
Duke Energy Carolinas [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	$ 1,000
Duke Energy Carolinas [Member] | DERF [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	425
Duke Energy Progress [Member] | DEPR [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	300
Duke Energy Florida [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	1,294
Duke Energy Florida [Member] | DEFR [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	225
Duke Energy Florida [Member] | DEFPF [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	1,294
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	$ 250
Duke Energy Ohio [Member] | Cinergy Receivables [Member]
Variable Interest Entities [Line Items]
Fixed interest rate added to LIBOR to compute variable rate	1.00%
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	$ 500
Duke Energy Indiana [Member] | Cinergy Receivables [Member]
Variable Interest Entities [Line Items]
Fixed interest rate added to LIBOR to compute variable rate	1.00%

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Variable Interest Entities (Schedule of Consolidated VIEs) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Cash and Cash Equivalents, at Carrying Value	$ 676	$ 857	$ 960	$ 2,036
Restricted receivables of VIEs	1,943	1,748
Regulatory Assets, Current	825	877
Other current assets	451	327
Regulatory Assets, Noncurrent	11,290	11,373
Investments and other assets	2,972	3,042
Property, plant and equipment, cost	115,143	112,826
Accumulated depreciation and amortization	(38,412)	(37,665)
Other deferred debits	30	43
Accounts payable	2,221	2,400
Current maturities of long-term debt	2,342	2,074
Other current liabilities	1,784	2,115
Long-Term Debt	39,931	37,495
Deferred income taxes	13,038	12,705
Asset retirement obligation	10,231	10,264
Other liabilities	1,730	1,706
Duke Energy Carolinas [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Cash and Cash Equivalents, at Carrying Value	16	13	28	13
Restricted receivables of VIEs	696	596
Regulatory Assets, Current	262	305
Other current assets	86	128
Regulatory Assets, Noncurrent	2,856	2,766
Investments and other assets	916	999
Property, plant and equipment, cost	40,285	39,398
Accumulated depreciation and amortization	(13,880)	(13,521)
Other deferred debits	3	4
Accounts payable	565	753
Current maturities of long-term debt	468	356
Other current liabilities	400	519
Long-Term Debt	8,592	7,711
Deferred income taxes	6,472	6,146
Asset retirement obligation	3,910	3,918
Other liabilities	645	621
Duke Energy Progress [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Cash and Cash Equivalents, at Carrying Value	8	15	13	9
Restricted receivables of VIEs	421	349
Regulatory Assets, Current	187	264
Other current assets	35	121
Regulatory Assets, Noncurrent	2,744	2,710
Investments and other assets	509	486
Property, plant and equipment, cost	27,771	27,313
Accumulated depreciation and amortization	(10,350)	(10,141)
Other deferred debits	2	3
Accounts payable	300	399
Current maturities of long-term debt	252	2
Other current liabilities	314	412
Long-Term Debt	6,163	6,366
Deferred income taxes	3,167	3,027
Asset retirement obligation	4,594	4,567
Other liabilities	23	45
Duke Energy Florida [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Cash and Cash Equivalents, at Carrying Value	8	8	$ 13	$ 8
Restricted receivables of VIEs	355	308
Regulatory Assets, Current	135	98
Other current assets	43	21
Regulatory Assets, Noncurrent	2,553	2,725
Investments and other assets	288	292
Property, plant and equipment, cost	15,938	15,343
Accumulated depreciation and amortization	(4,730)	(4,720)
Other deferred debits	3	2
Accounts payable	390	322
Current maturities of long-term debt	48	13
Other current liabilities	361	452
Long-Term Debt	5,492	4,253
Deferred income taxes	2,571	2,460
Asset retirement obligation	792	802
Other liabilities	103	146
DEFPF [Member] | Duke Energy Florida [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory Assets, Current	34
Other current assets	7
Regulatory Assets, Noncurrent	1,194
Current maturities of long-term debt	35
Long-Term Debt	1,243
DERF [Member] | Duke Energy Carolinas [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Long-Term Debt	425	425
DEPR [Member] | Duke Energy Progress [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Long-Term Debt	300	254
DEFR [Member] | Duke Energy Florida [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Long-Term Debt	225	225
Cinergy Receivables [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Long-Term Debt	325	325
Renewables [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Other current assets	223	138
Property, plant and equipment, cost	2,578	2,015
Accumulated depreciation and amortization	(376)	(321)
Current maturities of long-term debt	154	108
Long-Term Debt	866	968
Deferred income taxes	31	289
Other liabilities	$ 277	$ 33

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Variable Interest Entities (Schedule of Accounts Receivable Securitizations) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	$ 3,394
Long-Term Debt	39,931	$ 37,495
Duke Energy Carolinas [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	1,000
Long-Term Debt	8,592	7,711
Duke Energy Progress [Member]
Variable Interest Entities [Line Items]
Long-Term Debt	6,163	6,366
Duke Energy Florida [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	1,294
Long-Term Debt	$ 5,492	4,253
Cinergy Receivables [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Line of Credit Facility, Expiration Date	Dec. 01, 2018
Debt Instrument, Face Amount	$ 325
Long-Term Debt	$ 325	325
DERF [Member] | Duke Energy Carolinas [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Line of Credit Facility, Expiration Date	Dec. 01, 2018
Debt Instrument, Face Amount	$ 425
Long-Term Debt	$ 425	425
DEPR [Member] | Duke Energy Progress [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Line of Credit Facility, Expiration Date	Feb. 01, 2019
Debt Instrument, Face Amount	$ 300
Long-Term Debt	$ 300	254
DEFR [Member] | Duke Energy Florida [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Line of Credit Facility, Expiration Date	Apr. 01, 2019
Debt Instrument, Face Amount	$ 225
Long-Term Debt	$ 225	$ 225

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Variable Interest Entities (Schedule of Non-Consolidated VIEs) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	$ 613	$ 499
Investments and other assets	2,972	3,042
Other current liabilities	1,784	2,115
Deferred credits and other liabilities	32,869	32,490
Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies		0
Investments in equity method unconsolidated affiliates	474	387
Total assets	474	387
Other current liabilities	3	3
Deferred credits and other liabilities	13	14
Total liabilities	16	17
Net assets	458	370
Renewables [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies		0
Investments in equity method unconsolidated affiliates	222	235
Total assets	222	235
Net assets	222	235
Other VIEs [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies		0
Investments in equity method unconsolidated affiliates	252	152
Total assets	252	152
Other current liabilities	3	3
Deferred credits and other liabilities	13	14
Total liabilities	16	17
Net assets	236	135
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	35	84
Investments and other assets	16	20
Other current liabilities	82	153
Deferred credits and other liabilities	2,054	1,998
Duke Energy Ohio [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	39	47
Total assets	39	47
Net assets	39	47
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	60	71
Other current liabilities	101	97
Deferred credits and other liabilities	3,280	3,219
Duke Energy Indiana [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	58	60
Total assets	58	60
Net assets	$ 58	$ 60

XML

Variable Interest Entities (Fair Value Assumptions)(Details) - Cinergy Receivables [Member]	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Anticipated credit loss ratio	0.50%	0.60%
Discount rate	1.40%	1.20%
Receivable turnover rate	13.20%	12.90%
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Anticipated credit loss ratio	0.30%	0.30%
Discount rate	1.40%	1.20%
Receivable turnover rate	10.60%	10.60%

XML

Variable Interest Entities (Receivables Sold)(Details) - Cinergy Receivables [Member] - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables sold	$ 208	$ 233
Less: Retained interests	39	47
Net receivables sold	169	186
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables sold	279	260
Less: Retained interests	58	60
Net receivables sold	$ 221	$ 200

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Variable Interest Entities (Sales and Cash Flows)(Details) - Cinergy Receivables [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables sold	$ 429	$ 425	$ 961	$ 1,069
Loss recognized on sale	2	2	5	5
Cash proceeds from receivables sold	427	467	964	1,107
Collection fees received	0	1	0	1
Return received on retained interests	0	1	1	2
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables sold	623	637	1,258	1,353
Loss recognized on sale	2	2	5	5
Cash proceeds from receivables sold	612	660	1,255	1,382
Collection fees received	1	1	1	1
Return received on retained interests	$ 1	$ 1	$ 2	$ 3

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Common Stock (Earnings Per Share Data)(Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Common Stock [Line Items]
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	$ 510	$ 600	$ 1,201	$ 1,373
Average shares, basic	689	692	689	700
Average shares, diluted	690	692	689	700
EPS, basic (usd per share)	$ 0.74	$ 0.87	$ 1.74	$ 1.96
EPS, diluted (usd per share)	$ 0.74	$ 0.87	$ 1.74	$ 1.96
Common Class A [Member]
Common Stock [Line Items]
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	$ 508	$ 600	$ 1,199	$ 1,372
Average shares, basic	689	692	689	700
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements	1
Average shares, diluted	690	692	689	700
EPS, basic (usd per share)	$ 0.74	$ 0.87	$ 1.74	$ 1.96
EPS, diluted (usd per share)	$ 0.74	$ 0.87	$ 1.74	$ 1.96
Number of stock options and performance and unvested stock awards excluded from the dilutive securities calculation	2	2	2	2
Dividends declared per share (usd per share)	$ 0.825	$ 0.795	$ 1.65	$ 1.59

XML

Common Stock Common Stock (Accelerated Share Repurchase) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	1 Months Ended		3 Months Ended	6 Months Ended
	Jun. 30, 2015	Apr. 30, 2015	Jun. 30, 2015	Jun. 30, 2015	Apr. 06, 2015
Accelerated Share Repurchases [Line Items]
Stock Repurchase Program, Authorized Amount		$ 1,500
Payments for Repurchase of Common Stock		$ 1,500		$ 1,500
Delivered Shares from Dealers	3.2	16.6	19.8
Fair Market Value of Delivered Shares	$ 225	$ 1,275
Percentage of ASR common stock received					85.00%
Accelerated Share Repurchases, Final Price Paid Per Share			$ 75.75
Goldman Sachs [Member]
Accelerated Share Repurchases [Line Items]
Payments for Repurchase of Common Stock		750
JPMorgan Chase [Member]
Accelerated Share Repurchases [Line Items]
Payments for Repurchase of Common Stock		$ 750

XML

Common Stock Common Stock (Equity Securities Offering) (Details) - Piedmont Natural Gas [Member] shares in Millions	Jun. 30, 2016 $ / shares shares
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares offered	10.6
Then Forward Price | $ / shares	$ 69.84
Shares required to net settle	2.1

XML

Stock-Based Compensation (Schedule of Stock-Based Compensation Expense) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation expense	$ 15	$ 19	$ 27	$ 33
Tax benefit associated with stock-based compensation expense	5	7	9	12
Stock-based compensation costs capitalized	1	1	2	2
Restricted Stock Units Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation expense	10	11	17	20
Performance Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation expense	$ 5	$ 8	$ 10	$ 13

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Employee Benefit Plans (Narrative) (Details)	6 Months Ended
	Jun. 30, 2016
Defined Benefit Plan Disclosure [Line Items]
Matching contribution percentage	100.00%
Eligible pay percentage	6.00%
Additional savings plan account contribution percentage for employees not participating in defined pension plans	4.00%
Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Maximum years of participation	35 years

XML

Employee Benefit Plans Employee Benefit Plans (Plan Contributions) (Details) - Pension Plan [Member] $ in Millions	6 Months Ended
	Jun. 30, 2015 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	$ 132
Duke Energy Carolinas [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	42
Progress Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	42
Duke Energy Progress [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	21
Duke Energy Florida [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	21
Duke Energy Ohio [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	1
Duke Energy Indiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	$ 9

XML

Employee Benefit Plans (Components of Net Periodic Pension Costs) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Qualified Pension Plans [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	$ 37	$ 39	$ 73	$ 79
Interest cost on projected benefit obligation	83	81	166	163
Expected return on plan assets	(129)	(129)	(258)	(258)
Amortization of actuarial loss (gain)	33	44	66	87
Amortization of prior service cost (credit)	(4)	(3)	(8)	(7)
Other	1	2	4	4
Net periodic costs	21	34	43	68
Qualified Pension Plans [Member] | Duke Energy Carolinas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	12	12	24	25
Interest cost on projected benefit obligation	22	20	43	41
Expected return on plan assets	(36)	(33)	(71)	(69)
Amortization of actuarial loss (gain)	8	10	16	20
Amortization of prior service cost (credit)	(2)	(2)	(4)	(4)
Other			1	1
Net periodic costs	4	7	9	14
Qualified Pension Plans [Member] | Progress Energy [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	10	11	21	22
Interest cost on projected benefit obligation	27	26	53	52
Expected return on plan assets	(42)	(41)	(84)	(84)
Amortization of actuarial loss (gain)	13	17	27	34
Amortization of prior service cost (credit)	(1)	(1)	(2)	(2)
Other			1	1
Net periodic costs	7	12	16	23
Qualified Pension Plans [Member] | Duke Energy Progress [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	6	6	12	12
Interest cost on projected benefit obligation	13	12	25	24
Expected return on plan assets	(20)	(21)	(41)	(41)
Amortization of actuarial loss (gain)	5	9	11	17
Amortization of prior service cost (credit)	(1)	(1)	(1)	(1)
Other	1	1	1	1
Net periodic costs	4	6	7	12
Qualified Pension Plans [Member] | Duke Energy Florida [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	5	5	10	10
Interest cost on projected benefit obligation	14	13	28	27
Expected return on plan assets	(21)	(22)	(42)	(44)
Amortization of actuarial loss (gain)	7	8	14	16
Amortization of prior service cost (credit)		(1)		(1)
Other		1		1
Net periodic costs	5	4	10	9
Qualified Pension Plans [Member] | Duke Energy Ohio [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	1	1	2	2
Interest cost on projected benefit obligation	5	4	10	9
Expected return on plan assets	(7)	(7)	(14)	(13)
Amortization of actuarial loss (gain)	1	3	2	5
Net periodic costs		1		3
Qualified Pension Plans [Member] | Duke Energy Indiana [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	2	2	4	5
Interest cost on projected benefit obligation	7	7	14	14
Expected return on plan assets	(11)	(11)	(21)	(21)
Amortization of actuarial loss (gain)	3	4	6	7
Net periodic costs	1	2	3	5
Non-Qualified Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	1	1	1	1
Interest cost on projected benefit obligation	3	3	7	7
Amortization of actuarial loss (gain)	2	1	4	3
Net periodic costs	6	5	12	11
Non-Qualified Pension Plan [Member] | Duke Energy Carolinas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	1		1	1
Net periodic costs	1		1	1
Non-Qualified Pension Plan [Member] | Progress Energy [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost				1
Interest cost on projected benefit obligation	1	1	2	2
Amortization of actuarial loss (gain)		1	1	1
Net periodic costs	1	2	3	4
Non-Qualified Pension Plan [Member] | Duke Energy Progress [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	1	1	1	1
Net periodic costs	1	1	1	1
Non-Qualified Pension Plan [Member] | Duke Energy Florida [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	1	1	1	1
Amortization of actuarial loss (gain)				1
Net periodic costs	1	1	1	2
Other Post-Retirement Benefit Plans [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	1	1	2	3
Interest cost on projected benefit obligation	9	9	17	18
Expected return on plan assets	(4)	(3)	(7)	(6)
Amortization of actuarial loss (gain)	2	7	3	13
Amortization of prior service cost (credit)	(36)	(35)	(71)	(70)
Net periodic costs	(28)	(21)	(56)	(42)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Carolinas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost		1		1
Interest cost on projected benefit obligation	2	2	4	4
Expected return on plan assets	(2)	(2)	(4)	(4)
Amortization of actuarial loss (gain)	(1)	(1)	(2)	(1)
Amortization of prior service cost (credit)	(3)	(3)	(6)	(7)
Net periodic costs	(4)	(3)	(8)	(7)
Other Post-Retirement Benefit Plans [Member] | Progress Energy [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost		1		1
Interest cost on projected benefit obligation	3	3	7	7
Amortization of actuarial loss (gain)	6	7	11	14
Amortization of prior service cost (credit)	(25)	(25)	(51)	(51)
Net periodic costs	(16)	(14)	(33)	(29)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Progress [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	2	2	4	4
Amortization of actuarial loss (gain)	3	4	6	9
Amortization of prior service cost (credit)	(17)	(16)	(34)	(33)
Net periodic costs	(12)	(10)	(24)	(20)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Florida [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	1	1	3	3
Amortization of actuarial loss (gain)	3	2	5	5
Amortization of prior service cost (credit)	(9)	(7)	(18)	(16)
Net periodic costs	(5)	(4)	(10)	(8)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Ohio [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	1	1	1	1
Amortization of actuarial loss (gain)	(1)		(1)
Net periodic costs		1		1
Other Post-Retirement Benefit Plans [Member] | Duke Energy Indiana [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	1	2	2	2
Expected return on plan assets	$ (1)		(1)
Amortization of actuarial loss (gain)		(1)	$ (1)	(1)
Net periodic costs		$ 1		$ 1

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Employee Benefit Plans (Employee Savings Plans) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Employee Savings Plans [Abstract]
Employer contributions	$ 39	$ 37	$ 91	$ 86
Duke Energy Carolinas [Member]
Employee Savings Plans [Abstract]
Employer contributions	13	13	31	29
Progress Energy [Member]
Employee Savings Plans [Abstract]
Employer contributions	12	12	27	26
Duke Energy Progress [Member]
Employee Savings Plans [Abstract]
Employer contributions	8	8	19	19
Duke Energy Florida [Member]
Employee Savings Plans [Abstract]
Employer contributions	4	3	8	7
Duke Energy Ohio [Member]
Employee Savings Plans [Abstract]
Employer contributions	1	1	2	2
Duke Energy Indiana [Member]
Employee Savings Plans [Abstract]
Employer contributions	$ 2	$ 2	$ 4	$ 4

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Income Taxes Income Taxes (Taxes on Foreign Earnings) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016
Unremitted Earnings [Member] | International Energy [Member]
Income Tax Disclosure [Line Items]
U.S. Income Taxes on Foreign Earnings	$ 4	$ 16
Previously Remitted Earnings [Member]
Income Tax Disclosure [Line Items]
U.S. Income Taxes on Foreign Earnings		$ (95)

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Income Taxes (Effective Tax Rates) (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]
Effective tax rate	31.80%	35.60%	27.20%	33.60%
Duke Energy Carolinas [Member]
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]
Effective tax rate	35.10%	36.60%	34.60%	36.20%
Progress Energy [Member]
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]
Effective tax rate	36.00%	39.20%	36.30%	37.10%
Duke Energy Progress [Member]
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]
Effective tax rate	35.50%	40.60%	35.40%	36.00%
Duke Energy Florida [Member]
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]
Effective tax rate	37.60%	38.70%	37.70%	38.60%
Duke Energy Ohio [Member]
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]
Effective tax rate	34.30%	35.00%	29.20%	36.80%
Duke Energy Indiana [Member]
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]
Effective tax rate	36.10%	36.40%	33.10%	36.50%