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 March 31, 2017

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
1-6196	PIEDMONT NATURAL GAS COMPANY, INC. (a North Carolina corporation) 4720 Piedmont Row Drive Charlotte, North Carolina 28210 704-364-3120 56-0556998

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 ¨	Piedmont Natural Gas Company, Inc. (Piedmont)	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 ¨	Piedmont	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 ¨	Emerging Growth Company ¨
Duke Energy Carolinas	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨	Emerging Growth Company ¨
Progress Energy	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨	Emerging Growth Company ¨
Duke Energy Progress	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨	Emerging Growth Company ¨
Duke Energy Florida	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨	Emerging Growth Company ¨
Duke Energy Ohio	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨	Emerging Growth Company ¨
Duke Energy Indiana	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨	Emerging Growth Company ¨
Piedmont	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filerx	Smaller reporting company ¨	Emerging Growth Company ¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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	Piedmont	Yes ¨	Nox

Number of shares of Common stock outstanding at March 31, 2017:

Registrant	Description	Shares
Duke Energy	Common stock, $0.001 par value	699,883,528

This combined Form 10-Q is filed separately by eight registrants: Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont (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, Duke Energy Indiana and Piedmont 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
	Piedmont Natural Gas Company, Inc. Financial Statements	35
	Combined Notes to Condensed Consolidated Financial Statements
	Note 1 – Organization and Basis of Presentation	39
	Note 2 – Acquisitions and Dispositions	43
	Note 3 – Business Segments	45
	Note 4 – Regulatory Matters	47
	Note 5 – Commitments and Contingencies	53
	Note 6 – Debt and Credit Facilities	59
	Note 7 – Goodwill and Intangible Assets	60
	Note 8 – Related Party Transactions	61
	Note 9 – Derivatives and Hedging	62
	Note 10 – Investments in Debt and Equity Securities	67
	Note 11 – Fair Value Measurements	73
	Note 12 – Variable Interest Entities	81
	Note 13 – Common Stock	85
	Note 14 – Stock-Based Compensation	86
	Note 15 – Employee Benefit Plans	86
	Note 16 – Income Taxes	89
	Note 17 – Subsequent Events	89
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	90
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	117
Item 4.	Controls and Procedures	117
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	119
Item 1A.	Risk Factors	119
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	119
Item 6.	Exhibits	120
	Signatures	123

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;

◦ 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 private 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 and natural gas markets and continued industry consolidation;

◦ 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, including extreme weather associated with climate change;

◦ 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 ability to complete necessary or desirable pipeline expansion or infrastructure projects in our natural gas business;

◦ Operational interruptions to our gas distribution and transmission activities;

◦ The availability of adequate interstate pipeline transportation capacity and natural gas supply;

◦ 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, including the financial stability of third party service providers;

◦ The timing and extent of changes in commodity prices and interest 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;

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

◦ 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 the 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;

◦ Substantial revision to the U.S. tax code, such as changes to the corporate tax rate or material change in the deductibility of interest;

◦ The impact of potential goodwill impairments;

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

◦ The ability to successfully integrate the natural gas businesses following the acquisition of Piedmont Natural Gas Company, Inc. and realize anticipated benefits.

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
	March 31,
(in millions, except per-share amounts)	2017		2016
Operating Revenues
Regulated electric	$	4,913	$	5,053
Regulated natural gas	646		169
Nonregulated electric and other	170		155
Total operating revenues	5,729		5,377
Operating Expenses
Fuel used in electric generation and purchased power	1,449		1,588
Cost of natural gas	258		49
Operation, maintenance and other	1,433		1,416
Depreciation and amortization	859		793
Property and other taxes	304		295
Impairment charges	—		3
Total operating expenses	4,303		4,144
Gains on Sales of Other Assets and Other, net	11		7
Operating Income	1,437		1,240
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	29		8
Other income and expenses, net	86		70
Total other income and expenses	115		78
Interest Expense	491		489
Income From Continuing Operations Before Income Taxes	1,061		829
Income Tax Expense from Continuing Operations	344		252
Income From Continuing Operations	717		577
Income From Discontinued Operations, net of tax	—		122
Net Income	717		699
Less: Net Income Attributable to Noncontrolling Interests	1		5
Net Income Attributable to Duke Energy Corporation	$	716	$	694
Earnings Per Share – Basic and Diluted
Income from continuing operations attributable to Duke Energy Corporation common stockholders
Basic	$	1.02	$	0.83
Diluted	$	1.02	$	0.83
Income from discontinued operations attributable to Duke Energy Corporation common stockholders
Basic	$	—	$	0.18
Diluted	$	—	$	0.18
Net income attributable to Duke Energy Corporation common stockholders
Basic	$	1.02	$	1.01
Diluted	$	1.02	$	1.01
Weighted average shares outstanding
Basic	700		689
Diluted	700		689

See Notes to Condensed Consolidated Financial Statements

6

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017		2016
Net Income	$	717	$	699
Other Comprehensive Income, net of tax
Foreign currency translation adjustments	—		49
Pension and OPEB adjustments	1		—
Net unrealized gains (losses) on cash flow hedges	2		(14		)
Reclassification into earnings from cash flow hedges	1		2
Unrealized gains on available-for-sale securities	4		4
Other Comprehensive Income, net of tax	8		41
Comprehensive Income	725		740
Less: Comprehensive Income Attributable to Noncontrolling Interests	1		6
Comprehensive Income Attributable to Duke Energy Corporation	$	724	$	734

See Notes to Condensed Consolidated Financial Statements

7

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2017			December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	878		$	392
Receivables (net of allowance for doubtful accounts of $13 at 2017 and $14 at 2016)	623			751
Receivables of VIEs (net of allowance for doubtful accounts of $57 at 2017 and $54 at 2016)	1,682			1,893
Inventory	3,366			3,522
Regulatory assets (includes $53 at 2017 and $50 at 2016 related to VIEs)	1,031			1,023
Other	425			458
Total current assets	8,005			8,039
Property, Plant and Equipment
Cost	123,301			121,397
Accumulated depreciation and amortization	(40,293		)	(39,406		)
Generation facilities to be retired, net	508			529
Net property, plant and equipment	83,516			82,520
Other Noncurrent Assets
Goodwill	19,425			19,425
Regulatory assets (includes $1,131 at 2017 and $1,142 at 2016 related to VIEs)	12,838			12,878
Nuclear decommissioning trust funds	6,448			6,205
Investments in equity method unconsolidated affiliates	1,122			925
Other	2,754			2,769
Total other noncurrent assets	42,587			42,202
Total Assets	$	134,108		$	132,761
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	2,203		$	2,994
Notes payable and commercial paper	3,558			2,487
Taxes accrued	363			384
Interest accrued	526			503
Current maturities of long-term debt (includes $281 at 2017 and $260 at 2016 related to VIEs)	1,977			2,319
Asset retirement obligations	404			411
Regulatory liabilities	340			409
Other	1,570			2,044
Total current liabilities	10,941			11,551
Long-Term Debt (includes $4,108 at 2017 and $3,587 at 2016 related to VIEs)	47,021			45,576
Other Noncurrent Liabilities
Deferred income taxes	14,443			14,155
Asset retirement obligations	10,186			10,200
Regulatory liabilities	6,972			6,881
Accrued pension and other post-retirement benefit costs	1,115			1,111
Investment tax credits	537			493
Other	1,707			1,753
Total other noncurrent liabilities	34,960			34,593
Commitments and Contingencies
Equity
Common stock, $0.001 par value, 2 billion shares authorized; 700 million shares outstanding at 2017 and 2016	1			1
Additional paid-in capital	38,742			38,741
Retained earnings	2,521			2,384
Accumulated other comprehensive loss	(85		)	(93		)
Total Duke Energy Corporation stockholders' equity	41,179			41,033
Noncontrolling interests	7			8
Total equity	41,186			41,041
Total Liabilities and Equity	$	134,108		$	132,761

See Notes to Condensed Consolidated Financial Statements

8

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	717		$	699
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	991			931
Equity component of AFUDC	(62		)	(42		)
Gains on sales of other assets	(11		)	(9		)
Impairment charges	—			3
Deferred income taxes	342			181
Equity in earnings of unconsolidated affiliates	(29		)	(8		)
Accrued pension and other post-retirement benefit costs	6			4
Payments for asset retirement obligations	(134		)	(112		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(38		)	102
Receivables	343			139
Inventory	155			89
Other current assets	16			13
Increase (decrease) in
Accounts payable	(463		)	(210		)
Taxes accrued	(28		)	40
Other current liabilities	(478		)	(81		)
Other assets	(40		)	45
Other liabilities	2			(102		)
Net cash provided by operating activities	1,289			1,682
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,160		)	(1,645		)
Contributions to equity method investments	(175		)	(59		)
Purchases of available-for-sale securities	(1,386		)	(1,347		)
Proceeds from sales and maturities of available-for-sale securities	1,405			1,362
Change in restricted cash	(34		)	(32		)
Other	(49		)	(37		)
Net cash used in investing activities	(2,399		)	(1,758		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	1,563			1,140
Issuance of common stock related to employee benefit plans	—			7
Payments for the redemption of long-term debt	(408		)	(389		)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	25			—
Payments for the redemption of short-term debt with original maturities greater than 90 days	(7		)	(92		)
Notes payable and commercial paper	1,045			(66		)
Change in bank overdrafts	5			—
Dividends paid	(600		)	(570		)
Other	(27		)	(33		)
Net cash provided by (used in) financing activities	1,596			(3		)
Changes in cash and cash equivalents associated with assets held for sale	—			30
Net increase (decrease) in cash and cash equivalents	486			(49		)
Cash and cash equivalents at beginning of period	392			383
Cash and cash equivalents at end of period	$	878		$	334
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	575		$	576

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			(Losses) Gains						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, 2015	688	$	1	$	37,968	$	2,564		$	(692	)	$	(50	)	$	(3	)	$	(61	)	$	39,727		$	44		$	39,771
Net income	—	—		—		694			—			—			—			—			694			5			699
Other comprehensive income (loss)	—	—		—		—			48			(12		)	4			—			40			1			41
Common stock issuances, including dividend reinvestment and employee benefits	1	—		1		—			—			—			—			—			1			—			1
Common stock dividends	—	—		—		(570		)	—			—			—			—			(570		)	—			(570		)
Distributions to noncontrolling interest in subsidiaries	—	—		—		—			—			—			—			—			—			(1		)	(1		)
Balance at March 31, 2016	689	$	1	$	37,969	$	2,688		$	(644	)	$	(62	)	$	1		$	(61	)	$	39,892		$	49		$	39,941
Balance at December 31, 2016	700	$	1	$	38,741	$	2,384		$	—		$	(20	)	$	(1	)	$	(72	)	$	41,033		$	8		$	41,041
Net income	—	—		—		716			—			—			—			—			716			1			717
Other comprehensive income	—	—		—		—			—			3			4			1			8			—			8
Common stock issuances, including dividend reinvestment and employee benefits	—	—		1		—			—			—			—			—			1			—			1
Common stock dividends	—	—		—		(600		)	—			—			—			—			(600		)	—			(600		)
Distributions to noncontrolling interest in subsidiaries	—	—		—		—			—			—			—			—			—			(2		)	(2		)
Other(a)	—	—		—		21			—			—			—			—			21			—			21
Balance at March 31, 2017	700	$	1	$	38,742	$	2,521		$	—		$	(17	)	$	3		$	(71	)	$	41,179		$	7		$	41,186

(a) Cumulative-effect adjustment due to implementation of a new accounting standard related to stock-based compensation and the associated income taxes. See Note 1 for more information.

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
	March 31,
(in millions)	2017		2016
Operating Revenues	$	1,716	$	1,740
Operating Expenses
Fuel used in electric generation and purchased power	428		421
Operation, maintenance and other	482		512
Depreciation and amortization	254		259
Property and other taxes	68		67
Total operating expenses	1,232		1,259
Operating Income	484		481
Other Income and Expenses, net	37		37
Interest Expense	103		107
Income Before Income Taxes	418		411
Income Tax Expense	148		140
Net Income	$	270	$	271
Other Comprehensive Income, net of tax
Reclassification into earnings from cash flow hedges	—		1
Comprehensive Income	$	270	$	272

See Notes to Condensed Consolidated Financial Statements

11

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2017			December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	11		$	14
Receivables (net of allowance for doubtful accounts of $2 at 2017 and 2016)	166			160
Receivables of VIEs (net of allowance for doubtful accounts of $7 at 2017 and 2016)	563			645
Receivables from affiliated companies	109			163
Notes receivable from affiliated companies	—			66
Inventory	1,051			1,055
Regulatory assets	233			238
Other	65			37
Total current assets	2,198			2,378
Property, Plant and Equipment
Cost	41,600			41,127
Accumulated depreciation and amortization	(14,649		)	(14,365		)
Net property, plant and equipment	26,951			26,762
Other Noncurrent Assets
Regulatory assets	3,098			3,159
Nuclear decommissioning trust funds	3,406			3,273
Other	926			943
Total other noncurrent assets	7,430			7,375
Total Assets	$	36,579		$	36,515
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	602		$	833
Accounts payable to affiliated companies	250			247
Notes payable to affiliated companies	337			—
Taxes accrued	90			143
Interest accrued	134			102
Current maturities of long-term debt	404			116
Asset retirement obligations	224			222
Regulatory liabilities	118			161
Other	345			468
Total current liabilities	2,504			2,292
Long-Term Debt	8,787			9,187
Long-Term Debt Payable to Affiliated Companies	300			300
Other Noncurrent Liabilities
Deferred income taxes	6,668			6,544
Asset retirement obligations	3,658			3,673
Regulatory liabilities	2,860			2,840
Accrued pension and other post-retirement benefit costs	103			97
Investment tax credits	237			203
Other	595			607
Total other noncurrent liabilities	14,121			13,964
Commitments and Contingencies
Equity
Member's equity	10,876			10,781
Accumulated other comprehensive loss	(9		)	(9		)
Total equity	10,867			10,772
Total Liabilities and Equity	$	36,579		$	36,515

See Notes to Condensed Consolidated Financial Statements

12

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	270		$	271
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	339			330
Equity component of AFUDC	(30		)	(23		)
Deferred income taxes	162			145
Accrued pension and other post-retirement benefit costs	—			1
Payments for asset retirement obligations	(65		)	(52		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3			3
Receivables	66			2
Receivables from affiliated companies	54			33
Inventory	4			40
Other current assets	(26		)	102
Increase (decrease) in
Accounts payable	(131		)	(165		)
Accounts payable to affiliated companies	3			21
Taxes accrued	(53		)	52
Other current liabilities	(125		)	21
Other assets	(3		)	26
Other liabilities	(2		)	(26		)
Net cash provided by operating activities	466			781
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(563		)	(459		)
Purchases of available-for-sale securities	(722		)	(785		)
Proceeds from sales and maturities of available-for-sale securities	722			785
Notes receivable from affiliated companies	66			(691		)
Other	(20		)	(18		)
Net cash used in investing activities	(517		)	(1,168		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			992
Payments for the redemption of long-term debt	(113		)	(1		)
Notes payable to affiliated companies	337			—
Distributions to parent	(175		)	(600		)
Other	(1		)	—
Net cash provided by financing activities	48			391
Net (decrease) increase in cash and cash equivalents	(3		)	4
Cash and cash equivalents at beginning of period	14			13
Cash and cash equivalents at end of period	$	11		$	17
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	164		$	179

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 Losses on
	Member's			Cash Flow			Total
(in millions)	Equity			Hedges			Equity
Balance at December 31, 2015	$	11,617		$	(11	)	$	11,606
Net income	271			—			271
Other comprehensive income	—			1			1
Distributions to parent	(600		)	—			(600		)
Balance at March 31, 2016	$	11,288		$	(10	)	$	11,278
Balance at December 31, 2016	$	10,781		$	(9	)	$	10,772
Net income	270			—			270
Distributions to parent	(175		)	—			(175		)
Balance at March 31, 2017	$	10,876		$	(9	)	$	10,867

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
	March 31,
(in millions)	2017		2016
Operating Revenues	$	2,179	$	2,332
Operating Expenses
Fuel used in electric generation and purchased power	726		860
Operation, maintenance and other	544		592
Depreciation and amortization	313		290
Property and other taxes	117		119
Impairment charges	—		2
Total operating expenses	1,700		1,863
Gains on Sales of Other Assets and Other, net	8		6
Operating Income	487		475
Other Income and Expenses, net	24		20
Interest Expense	206		160
Income Before Income Taxes	305		335
Income Tax Expense	104		123
Net Income	201		212
Less: Net Income Attributable to Noncontrolling Interests	2		3
Net Income Attributable to Parent	$	199	$	209
Net Income	$	201	$	212
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	1		1
Reclassification into earnings from cash flow hedges	1		1
Unrealized gains on available-for-sale securities	1		1
Other Comprehensive Income, net of tax	3		3
Comprehensive Income	204		215
Less: Comprehensive Income Attributable to Noncontrolling Interests	2		3
Comprehensive Income Attributable to Parent	$	202	$	212

See Notes to Condensed Consolidated Financial Statements

15

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2017			December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	38		$	46
Receivables (net of allowance for doubtful accounts of $3 at 2017 and $6 at 2016)	80			114
Receivables of VIEs (net of allowance for doubtful accounts of $7 at 2017 and 2016)	612			692
Receivables from affiliated companies	2			106
Notes receivable from affiliated companies	184			80
Inventory	1,652			1,717
Regulatory assets (includes $53 at 2017 and $50 at 2016 related to VIEs)	447			401
Other	252			148
Total current assets	3,267			3,304
Property, Plant and Equipment
Cost	45,902			44,864
Accumulated depreciation and amortization	(15,618		)	(15,212		)
Generation facilities to be retired, net	508			529
Net property, plant and equipment	30,792			30,181
Other Noncurrent Assets
Goodwill	3,655			3,655
Regulatory assets (includes $1,131 at 2017 and $1,142 at 2016 related to VIEs)	5,815			5,722
Nuclear decommissioning trust funds	3,041			2,932
Other	851			856
Total other noncurrent assets	13,362			13,165
Total Assets	$	47,421		$	46,650
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	678		$	1,003
Accounts payable to affiliated companies	316			348
Notes payable to affiliated companies	866			729
Taxes accrued	96			83
Interest accrued	224			201
Current maturities of long-term debt (includes $55 at 2017 and $62 at 2016 related to VIEs)	521			778
Asset retirement obligations	180			189
Regulatory liabilities	157			189
Other	627			745
Total current liabilities	3,665			4,265
Long-Term Debt (includes $1,713 at 2017 and $1,741 at 2016 related to VIEs)	16,454			15,590
Long-Term Debt Payable to Affiliated Companies	1,173			1,173
Other Noncurrent Liabilities
Deferred income taxes	5,484			5,246
Asset retirement obligations	5,289			5,286
Regulatory liabilities	2,472			2,395
Accrued pension and other post-retirement benefit costs	540			547
Other	332			341
Total other noncurrent liabilities	14,117			13,815
Commitments and Contingencies
Equity
Common stock, $0.01 par value, 100 shares authorized and outstanding at 2017 and 2016	—			—
Additional paid-in capital	8,094			8,094
Retained earnings	3,963			3,764
Accumulated other comprehensive loss	(35		)	(38		)
Total Progress Energy, Inc. stockholders' equity	12,022			11,820
Noncontrolling interests	(10		)	(13		)
Total equity	12,012			11,807
Total Liabilities and Equity	$	47,421		$	46,650

See Notes to Condensed Consolidated Financial Statements

16

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	201		$	212
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	365			342
Equity component of AFUDC	(24		)	(14		)
Gains on sales of other assets	(9		)	(7		)
Impairment charges	—			2
Deferred income taxes	220			182
Accrued pension and other post-retirement benefit costs	(3		)	(6		)
Payments for asset retirement obligations	(60		)	(54		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(2		)	6
Receivables	115			70
Receivables from affiliated companies	100			295
Inventory	65			3
Other current assets	(173		)	(76		)
Increase (decrease) in
Accounts payable	(228		)	9
Accounts payable to affiliated companies	(32		)	(55		)
Taxes accrued	12			42
Other current liabilities	(121		)	(64		)
Other assets	(53		)	(46		)
Other liabilities	(14		)	(7		)
Net cash provided by operating activities	359			834
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,011		)	(750		)
Purchases of available-for-sale securities	(629		)	(533		)
Proceeds from sales and maturities of available-for-sale securities	635			548
Proceeds from insurance	4			43
Notes receivable from affiliated companies	(104		)	—
Change in restricted cash	5			—
Other	(4		)	(15		)
Net cash used in investing activities	(1,104		)	(707		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	892			53
Payments for the redemption of long-term debt	(288		)	(310		)
Notes payable to affiliated companies	137			128
Distributions to noncontrolling interests	(1		)	(1		)
Other	(3		)	—
Net cash provided by (used in) financing activities	737			(130		)
Net decrease in cash and cash equivalents	(8		)	(3		)
Cash and cash equivalents at beginning of period	46			44
Cash and cash equivalents at end of period	$	38		$	41
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	219		$	228

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 (Losses)			Net Unrealized					Total Progress
	Additional				Gains on			Gains on		Pension and			Energy, Inc.
	Paid-in		Retained		Cash Flow			Available-for-		OPEB			Stockholders'		Noncontrolling			Total
(in millions)	Capital		Earnings		Hedges			Sale Securities		Adjustments			Equity		Interests			Equity
Balance at December 31, 2015	$	8,092	$	4,831	$	(31	)	$	—	$	(17	)	$	12,875	$	(22	)	$	12,853
Net income	—		209		—			—		—			209		3			212
Other comprehensive income	—		—		1			1		1			3		—			3
Distributions to noncontrolling interests	—		—		—			—		—			—		(1		)	(1		)
Balance at March 31, 2016	$	8,092	$	5,040	$	(30	)	$	1	$	(16	)	$	13,087	$	(20	)	$	13,067
Balance at December 31, 2016	$	8,094	$	3,764	$	(23	)	$	1	$	(16	)	$	11,820	$	(13	)	$	11,807
Net income	—		199		—			—		—			199		2			201
Other comprehensive income	—		—		1			1		1			3		—			3
Other	—		—		—			—		—			—		1			1
Balance at March 31, 2017	$	8,094	$	3,963	$	(22	)	$	2	$	(15	)	$	12,022	$	(10	)	$	12,012

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
	March 31,
(in millions)	2017		2016
Operating Revenues	$	1,219	$	1,307
Operating Expenses
Fuel used in electric generation and purchased power	364		448
Operation, maintenance and other	350		386
Depreciation and amortization	181		175
Property and other taxes	40		41
Total operating expenses	935		1,050
Gains on Sales of Other Assets and Other, net	2		1
Operating Income	286		258
Other Income and Expenses, net	19		17
Interest Expense	82		63
Income Before Income Taxes	223		212
Income Tax Expense	76		75
Net Income and Comprehensive Income	$	147	$	137

See Notes to Condensed Consolidated Financial Statements

19

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2017			December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	11		$	11
Receivables (net of allowance for doubtful accounts of $1 at 2017 and $4 at 2016)	28			51
Receivables of VIEs (net of allowance for doubtful accounts of $5 at 2017 and 2016)	364			404
Receivables from affiliated companies	6			5
Notes receivable from affiliated companies	—			165
Inventory	1,053			1,076
Regulatory assets	187			188
Other	102			57
Total current assets	1,751			1,957
Property, Plant and Equipment
Cost	28,769			28,419
Accumulated depreciation and amortization	(10,716		)	(10,561		)
Generation facilities to be retired, net	508			529
Net property, plant and equipment	18,561			18,387
Other Noncurrent Assets
Regulatory assets	3,338			3,243
Nuclear decommissioning trust funds	2,315			2,217
Other	535			525
Total other noncurrent assets	6,188			5,985
Total Assets	$	26,500		$	26,329
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	317		$	589
Accounts payable to affiliated companies	244			227
Notes payable to affiliated companies	502			—
Taxes accrued	35			104
Interest accrued	90			102
Current maturities of long-term debt	202			452
Asset retirement obligations	180			189
Regulatory liabilities	149			158
Other	294			365
Total current liabilities	2,013			2,186
Long-Term Debt	6,409			6,409
Long-Term Debt Payable to Affiliated Companies	150			150
Other Noncurrent Liabilities
Deferred income taxes	3,453			3,323
Asset retirement obligations	4,516			4,508
Regulatory liabilities	2,012			1,946
Accrued pension and other post-retirement benefit costs	247			252
Investment tax credits	146			146
Other	49			51
Total other noncurrent liabilities	10,423			10,226
Commitments and Contingencies
Equity
Member's Equity	7,505			7,358
Total Liabilities and Equity	$	26,500		$	26,329

See Notes to Condensed Consolidated Financial Statements

20

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	147		$	137
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	228			223
Equity component of AFUDC	(13		)	(10		)
Gains on sales of other assets	(3		)	(2		)
Deferred income taxes	120			100
Accrued pension and other post-retirement benefit costs	(5		)	(8		)
Payments for asset retirement obligations	(47		)	(42		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(2		)	(1		)
Receivables	65			18
Receivables from affiliated companies	(1		)	10
Inventory	23			15
Other current assets	(60		)	83
Increase (decrease) in
Accounts payable	(192		)	(16		)
Accounts payable to affiliated companies	17			(14		)
Taxes accrued	(68		)	18
Other current liabilities	(81		)	(39		)
Other assets	(44		)	(17		)
Other liabilities	(10		)	(4		)
Net cash provided by operating activities	74			451
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(474		)	(379		)
Purchases of available-for-sale securities	(476		)	(390		)
Proceeds from sales and maturities of available-for-sale securities	470			384
Notes receivable from affiliated companies	165			—
Other	(9		)	(13		)
Net cash used in investing activities	(324		)	(398		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			53
Payments for the redemption of long-term debt	(250		)	(8		)
Notes payable to affiliated companies	502			(101		)
Other	(2		)	(1		)
Net cash provided by (used in) financing activities	250			(57		)
Net decrease in cash and cash equivalents	—			(4		)
Cash and cash equivalents at beginning of period	11			15
Cash and cash equivalents at end of period	$	11		$	11
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	66		$	55

See Notes to Condensed Consolidated Financial Statements

21

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Member's
(in millions)	Equity
Balance at December 31, 2015	$	7,059
Net income	137
Balance at March 31, 2016	$	7,196
Balance at December 31, 2016	$	7,358
Net income	147
Balance at March 31, 2017	$	7,505

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
	March 31,
(in millions)	2017		2016
Operating Revenues	$	959	$	1,024
Operating Expenses
Fuel used in electric generation and purchased power	362		412
Operation, maintenance and other	191		205
Depreciation and amortization	132		114
Property and other taxes	77		78
Impairment charges	1		2
Total operating expenses	763		811
Operating Income	196		213
Other Income and Expenses, net	16		5
Interest Expense	70		41
Income Before Income Taxes	142		177
Income Tax Expense	52		67
Net Income	$	90	$	110
Other Comprehensive Income, net of tax
Unrealized gains on available-for-sale securities	1		1
Comprehensive Income	$	91	$	111

See Notes to Condensed Consolidated Financial Statements

23

PART I

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2017			December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	7		$	16
Receivables (net of allowance for doubtful accounts of $2 at 2017 and 2016)	50			61
Receivables of VIEs (net of allowance for doubtful accounts of $2 at 2017 and 2016)	248			288
Receivables from affiliated companies	2			5
Notes receivable from affiliated companies	293			—
Inventory	599			641
Regulatory assets (includes $53 at 2017 and $50 at 2016 related to VIEs)	260			213
Other (includes $14 at 2017 and $53 at 2016 related to VIEs)	104			125
Total current assets	1,563			1,349
Property, Plant and Equipment
Cost	17,122			16,434
Accumulated depreciation and amortization	(4,894		)	(4,644		)
Net property, plant and equipment	12,228			11,790
Other Noncurrent Assets
Regulatory assets (includes $1,131 at 2017 and $1,142 at 2016 related to VIEs)	2,476			2,480
Nuclear decommissioning trust funds	726			715
Other	268			278
Total other noncurrent assets	3,470			3,473
Total Assets	$	17,261		$	16,612
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	361		$	413
Accounts payable to affiliated companies	77			125
Notes payable to affiliated companies	—			297
Taxes accrued	62			33
Interest accrued	76			49
Current maturities of long-term debt (includes $55 at 2017 and $62 at 2016 related to VIEs)	319			326
Regulatory liabilities	7			31
Other	309			352
Total current liabilities	1,211			1,626
Long-Term Debt (includes $1,414 at 2017 and $1,442 at 2016 related to VIEs)	6,662			5,799
Other Noncurrent Liabilities
Deferred income taxes	2,800			2,694
Asset retirement obligations	773			778
Regulatory liabilities	459			448
Accrued pension and other post-retirement benefit costs	261			262
Other	104			105
Total other noncurrent liabilities	4,397			4,287
Commitments and Contingencies
Equity
Member's equity	4,989			4,899
Accumulated other comprehensive income	2			1
Total equity	4,991			4,900
Total Liabilities and Equity	$	17,261		$	16,612

See Notes to Condensed Consolidated Financial Statements

24

PART I

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	90		$	110
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	134			116
Equity component of AFUDC	(11		)	(4		)
Impairment charges	1			2
Deferred income taxes	100			83
Accrued pension and other post-retirement benefit costs	1			1
Payments for asset retirement obligations	(14		)	(12		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	—			7
Receivables	51			52
Receivables from affiliated companies	(1		)	14
Inventory	42			(12		)
Other current assets	(33		)	(44		)
Increase (decrease) in
Accounts payable	(35		)	25
Accounts payable to affiliated companies	(48		)	(40		)
Taxes accrued	29			(70		)
Other current liabilities	(47		)	(14		)
Other assets	(13		)	(30		)
Other liabilities	(5		)	(6		)
Net cash provided by operating activities	241			178
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(538		)	(370		)
Purchases of available-for-sale securities	(153		)	(143		)
Proceeds from sales and maturities of available-for-sale securities	165			164
Proceeds from insurance	4			43
Notes receivable from affiliated companies	(293		)	—
Other	9			(1		)
Net cash used in investing activities	(806		)	(307		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	892			—
Payments for the redemption of long-term debt	(38		)	(2		)
Notes payable to affiliated companies	(297		)	135
Other	(1		)	—
Net cash provided by financing activities	556			133
Net (decrease) increase in cash and cash equivalents	(9		)	4
Cash and cash equivalents at beginning of period	16			8
Cash and cash equivalents at end of period	$	7		$	12
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	153		$	173

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
	Member's		Available-for-Sale		Total
(in millions)	Equity		Securities		Equity
Balance at December 31, 2015	$	5,121	$	—	$	5,121
Net income	110		—		110
Other comprehensive income	—		1		1
Balance at March 31, 2016	$	5,231	$	1	$	5,232
Balance at December 31, 2016	$	4,899	$	1	$	4,900
Net income	90		—		90
Other comprehensive income	—		1		1
Balance at March 31, 2017	$	4,989	$	2	$	4,991

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
	March 31,
(in millions)	2017		2016
Operating Revenues
Regulated electric	$	337	$	340
Regulated natural gas	170		170
Nonregulated electric and other	11		6
Total operating revenues	518		516
Operating Expenses
Fuel used in electric generation and purchased power – regulated	97		111
Fuel used in electric generation and purchased power – nonregulated	15		10
Cost of natural gas	54		49
Operation, maintenance and other	130		119
Depreciation and amortization	67		61
Property and other taxes	72		71
Total operating expenses	435		421
Gains on Sales of Other Assets and Other, net	—		1
Operating Income	83		96
Other Income and Expenses, net	4		2
Interest Expense	22		20
Income From Continuing Operations Before Income Taxes	65		78
Income Tax Expense From Continuing Operations	23		21
Income From Continuing Operations	42		57
Income From Discontinued Operations, net of tax	—		2
Net Income and Comprehensive Income	$	42	$	59

See Notes to Condensed Consolidated Financial Statements

27

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2017			December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	13		$	13
Receivables (net of allowance for doubtful accounts of $2 at 2017 and 2016)	63			71
Receivables from affiliated companies	88			129
Notes receivable from affiliated companies	179			94
Inventory	118			137
Regulatory assets	21			37
Other	34			37
Total current assets	516			518
Property, Plant and Equipment
Cost	8,236			8,126
Accumulated depreciation and amortization	(2,611		)	(2,579		)
Net property, plant and equipment	5,625			5,547
Other Noncurrent Assets
Goodwill	920			920
Regulatory assets	525			520
Other	23			23
Total other noncurrent assets	1,468			1,463
Total Assets	$	7,609		$	7,528
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	252		$	282
Accounts payable to affiliated companies	64			63
Notes payable to affiliated companies	8			16
Taxes accrued	127			178
Interest accrued	33			19
Current maturities of long-term debt	1			1
Regulatory liabilities	21			21
Other	83			91
Total current liabilities	589			671
Long-Term Debt	1,951			1,858
Long-Term Debt Payable to Affiliated Companies	25			25
Other Noncurrent Liabilities
Deferred income taxes	1,472			1,443
Asset retirement obligations	76			77
Regulatory liabilities	236			236
Accrued pension and other post-retirement benefit costs	56			56
Other	166			166
Total other noncurrent liabilities	2,006			1,978
Commitments and Contingencies
Equity
Common stock, $8.50 par value, 120,000,000 shares authorized; 89,663,086 shares outstanding at 2017 and 2016	762			762
Additional paid-in capital	2,695			2,695
Accumulated deficit	(419		)	(461		)
Total equity	3,038			2,996
Total Liabilities and Equity	$	7,609		$	7,528

See Notes to Condensed Consolidated Financial Statements

28

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	42		$	59
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	68			62
Equity component of AFUDC	(2		)	(1		)
Gains on sales of other assets	—			(1		)
Deferred income taxes	30			11
Accrued pension and other post-retirement benefit costs	1			1
Payments for asset retirement obligations	(2		)	(1		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	1			2
Receivables	7			(18		)
Receivables from affiliated companies	41			(9		)
Inventory	19			1
Other current assets	9			78
Increase (decrease) in
Accounts payable	(10		)	(1		)
Accounts payable to affiliated companies	1			—
Taxes accrued	(52		)	(31		)
Other current liabilities	9			14
Other assets	(6		)	(2		)
Other liabilities	(3		)	—
Net cash provided by operating activities	153			164
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(143		)	(85		)
Notes receivable from affiliated companies	(85		)	(19		)
Other	(8		)	(4		)
Net cash used in investing activities	(236		)	(108		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	93			95
Payments for the redemption of long-term debt	(1		)	(51		)
Notes payable to affiliated companies	(8		)	(95		)
Other	(1		)	—
Net cash provided by (used in) financing activities	83			(51		)
Net increase in cash and cash equivalents	—			5
Cash and cash equivalents at beginning of period	13			14
Cash and cash equivalents at end of period	$	13		$	19
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	57		$	31

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, 2015	$	762	$	2,720	$	(698	)	$	2,784
Net income	—		—		59			59
Balance at March 31, 2016	$	762	$	2,720	$	(639	)	$	2,843
Balance at December 31, 2016	$	762	$	2,695	$	(461	)	$	2,996
Net income	—		—		42			42
Balance at March 31, 2017	$	762	$	2,695	$	(419	)	$	3,038

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
	March 31,
(in millions)	2017		2016
Operating Revenues	$	758	$	714
Operating Expenses
Fuel used in electric generation and purchased power	251		228
Operation, maintenance and other	174		162
Depreciation and amortization	125		125
Property and other taxes	22		23
Total operating expenses	572		538
Operating Income	186		176
Other Income and Expenses, net	8		4
Interest Expense	44		44
Income Before Income Taxes	150		136
Income Tax Expense	59		41
Net Income	$	91	$	95
Other Comprehensive Loss, net of tax
Reclassification into earnings from cash flow hedges	—		(1		)
Comprehensive Income	$	91	$	94

See Notes to Condensed Consolidated Financial Statements

31

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2017			December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	15		$	17
Receivables (net of allowance for doubtful accounts of $1 at 2017 and 2016)	72			105
Receivables from affiliated companies	88			114
Notes receivable from affiliated companies	199			86
Inventory	478			504
Regulatory assets	156			149
Other	35			45
Total current assets	1,043			1,020
Property, Plant and Equipment
Cost	14,411			14,241
Accumulated depreciation and amortization	(4,426		)	(4,317		)
Net property, plant and equipment	9,985			9,924
Other Noncurrent Assets
Regulatory assets	1,066			1,073
Other	156			147
Total other noncurrent assets	1,222			1,220
Total Assets	$	12,250		$	12,164
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	210		$	263
Accounts payable to affiliated companies	75			74
Taxes accrued	72			31
Interest accrued	52			61
Current maturities of long-term debt	3			3
Regulatory liabilities	44			40
Other	75			93
Total current liabilities	531			565
Long-Term Debt	3,631			3,633
Long-Term Debt Payable to Affiliated Companies	150			150
Other Noncurrent Liabilities
Deferred income taxes	1,921			1,900
Asset retirement obligations	867			866
Regulatory liabilities	743			748
Accrued pension and other post-retirement benefit costs	77			71
Investment tax credits	148			137
Other	24			27
Total other noncurrent liabilities	3,780			3,749
Commitments and Contingencies
Equity
Member's Equity	4,158			4,067
Total Liabilities and Equity	$	12,250		$	12,164

See Notes to Condensed Consolidated Financial Statements

32

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	91		$	95
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	126			127
Equity component of AFUDC	(6		)	(3		)
Deferred income taxes	37			(16		)
Accrued pension and other post-retirement benefit costs	1			2
Payments for asset retirement obligations	(7		)	(5		)
(Increase) decrease in
Receivables	44			16
Receivables from affiliated companies	26			7
Inventory	26			45
Other current assets	(2		)	(19		)
Increase (decrease) in
Accounts payable	(32		)	(44		)
Accounts payable to affiliated companies	1			(22		)
Taxes accrued	41			30
Other current liabilities	(15		)	(18		)
Other assets	(11		)	(4		)
Other liabilities	(3		)	(11		)
Net cash provided by operating activities	317			180
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(189		)	(151		)
Purchases of available-for-sale securities	(4		)	(5		)
Proceeds from sales and maturities of available-for-sale securities	2			4
Notes receivable from affiliated companies	(113		)	(19		)
Other	(12		)	(1		)
Net cash used in investing activities	(316		)	(172		)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt	(2		)	—
Other	(1		)	—
Net cash used in financing activities	(3		)	—
Net (decrease) increase in cash and cash equivalents	(2		)	8
Cash and cash equivalents at beginning of period	17			9
Cash and cash equivalents at end of period	$	15		$	17
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	84		$	42

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, 2015	$	1		$	1,384		$	2,450		$	—	$	1		$	3,836
Net income	—			—			—			95		—			95
Other comprehensive loss	—			—			—			—		(1		)	(1		)
Transfer to Member's Equity	(1		)	(1,384		)	(2,450		)	3,835		—			—
Balance at March 31, 2016	$	—		$	—		$	—		$	3,930	$	—		$	3,930
Balance at December 31, 2016	$	—		$	—		$	—		$	4,067	$	—		$	4,067
Net income	—			—			—			91		—			91
Balance at March 31, 2017	$	—		$	—		$	—		$	4,158	$	—		$	4,158

See Notes to Condensed Consolidated Financial Statements

34

PART I

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
	2017		2016
Operating Revenues
Regulated natural gas	$	498	$	481
Nonregulated natural gas and other	2		2
Total operating revenues	500		483
Operating Expenses
Cost of natural gas	205		197
Operation, maintenance and other	77		74
Depreciation and amortization	35		34
Property and other taxes	13		11
Total operating expenses	330		316
Operating Income	170		167
Equity in Earnings of Unconsolidated Affiliates	3		16
Interest Expense	20		17
Income Before Income Taxes	153		166
Income Tax Expense	58		63
Net Income and Comprehensive Income	$	95	$	103

See Notes to Condensed Consolidated Financial Statements

35

PART I

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2017			December 31, 2016
ASSETS
Current Assets
Cash and cash equivalents	$	15		$	25
Receivables (net of allowance for doubtful accounts of $5 at 2017 and $3 at 2016)	193			232
Receivables from affiliated companies	7			7
Inventory	29			66
Regulatory assets	98			124
Other	21			21
Total current assets	363			475
Property, Plant and Equipment
Cost	6,297			6,174
Accumulated depreciation and amortization	(1,390		)	(1,360		)
Net property, plant and equipment	4,907			4,814
Other Noncurrent Assets
Goodwill	49			49
Regulatory assets	350			373
Investments in equity method unconsolidated affiliates	225			212
Other	19			21
Total other noncurrent assets	643			655
Total Assets	$	5,913		$	5,944
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	104		$	155
Accounts payable to affiliated companies	3			8
Notes payable and commercial paper	—			330
Notes payable to affiliated companies	261			—
Taxes accrued	69			67
Interest accrued	27			33
Current maturities of long-term debt	35			35
Other	70			102
Total current liabilities	569			730
Long-Term Debt	1,786			1,786
Other Noncurrent Liabilities
Deferred income taxes	981			931
Asset retirement obligations	14			14
Regulatory liabilities	613			608
Accrued pension and other post-retirement benefit costs	14			14
Other	169			189
Total other noncurrent liabilities	1,791			1,756
Commitments and Contingencies
Equity
Common stock, no par value: 100 shares authorized and outstanding at 2017 and 2016	860			860
Retained earnings	907			812
Total equity	1,767			1,672
Total Liabilities and Equity	$	5,913		$	5,944

See Notes to Condensed Consolidated Financial Statements

36

PART I

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2017			2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	95		$	103
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	37			37
Deferred income taxes	50			68
Equity in earnings from unconsolidated affiliates	(3		)	(16		)
Accrued pension and other post-retirement benefit costs	3			1
Payments for asset retirement obligations	—			(1		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(41		)	—
Receivables	40			(14		)
Inventory	37			49
Other current assets	24			20
Increase (decrease) in
Accounts payable	(31		)	(21		)
Accounts payable to affiliated companies	(5		)	—
Taxes accrued	2			3
Other current liabilities	(17		)	(9		)
Other assets	25			23
Other liabilities	(1		)	(20		)
Net cash provided by operating activities	215			223
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(141		)	(132		)
Contributions to equity method investments	(12		)	(9		)
Other	(3		)	(1		)
Net cash used in investing activities	(156		)	(142		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of common stock	—			7
Notes payable and commercial paper	(330		)	(80		)
Notes payable to affiliated companies	261			—
Dividends paid	—			(27		)
Net cash used in financing activities	(69		)	(100		)
Net decrease in cash and cash equivalents	(10		)	(19		)
Cash and cash equivalents at beginning of period	25			33
Cash and cash equivalents at end of period	$	15		$	14
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	24		$	43

See Notes to Condensed Consolidated Financial Statements

37

PART I

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

						Accumulated
						Other
						Comprehensive
						Income
						Net Loss on
						Hedging Activities
	Common		Retained			of Unconsolidated			Total
(in millions)	Stock		Earnings			Affiliates			Equity
Balance at December 31, 2015	$	728	$	731		$	(1	)	$	1,458
Net income	—		103			—			103
Common stock issuances, including dividend reinvestments and employee benefits	7		—			—			7
Common stock dividends	—		(27		)	—			(27		)
Balance at March 31, 2016	$	735	$	807		$	(1	)	$	1,541
Balance at December 31, 2016	$	860	$	812		$	—		$	1,672
Net income	—		95			—			95
Balance at March 31, 2017	$	860	$	907		$	—		$	1,767

See Notes to Condensed Consolidated Financial Statements

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 – PIEDMONT NATURAL GAS COMPANY, INC.

Combined Notes to Condensed Consolidated Financial Statements – (Unaudited)

Index to Combined Notes to Condensed Consolidated Financial Statements

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

Applicable Notes

Registrant

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

17

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

•

•

•

•

•

•

•

•

•

•

•

•

•

Piedmont Natural Gas Company, Inc.

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Tables within the notes may not sum across due to (i) Progress Energy's consolidation of Duke Energy Progress, Duke Energy Florida and other subsidiaries that are not registrants, (ii) subsidiaries that are not registrants but included in the consolidated Duke Energy balances and (iii) the Piedmont registrant not included in the consolidated Duke Energy results for the three months ended March 31, 2016, as Piedmont results were not consolidated by Duke Energy until after the acquisition date of October 3, 2016.

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.) primarily through its direct and indirect subsidiaries. Certain Duke Energy subsidiaries are also subsidiary registrants, including 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), Duke Energy Indiana, LLC (Duke Energy Indiana) and Piedmont Natural Gas Company, Inc. (Piedmont). When discussing Duke Energy’s consolidated financial information, it necessarily includes the results of its separate subsidiary registrants (collectively referred to as the Subsidiary Registrants), which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants.

On October 3, 2016, Duke Energy completed the acquisition of Piedmont. Piedmont's results of operations and cash flows are included in the accompanying condensed consolidated financial statements of Duke Energy for the three months ended March 31, 2017, but not for the three months ended March 31, 2016, as Piedmont's earnings and cash flows are only included in Duke Energy's consolidated results subsequent to the acquisition date. See Note 2 for additional information regarding the acquisition.

In December 2016, Duke Energy completed an exit of the Latin American market to focus on its domestic regulated business, which was further bolstered by the acquisition of Piedmont. The sale of the International Energy business segment, excluding an equity method investment in National Methanol Company (NMC), was completed through two transactions including a sale of assets in Brazil to China Three Gorges (Luxembourg) Energy S.à.r.l. (China Three Gorges) and a sale of Duke Energy's remaining Latin American assets in Peru, Chile, Ecuador, Guatemala, El Salvador and Argentina to ISQ Enerlam Aggregator, L.P. and Enerlam (UK) Holding Ltd. (I Squared Capital) (collectively, the International Disposal Group). See Note 2 for additional information on the sale of International Energy.

The results of operations of the International Disposal Group 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 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. Substantially all of the Subsidiary Registrants' operations qualify for regulatory accounting.

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.

Progress Energy is a public utility holding company headquartered in Raleigh, North Carolina, subject to regulation by FERC. Progress Energy conducts operations through its wholly owned subsidiaries, Duke Energy Progress and Duke Energy Florida.

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.

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.

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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.

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.

Piedmont is a regulated public utility primarily engaged in the distribution of natural gas in portions of North Carolina, South Carolina and Tennessee. Piedmont is also invested in joint venture, energy-related businesses, including regulated interstate natural gas transportation and storage and intrastate natural gas transportation businesses. Piedmont is subject to the regulatory provisions of the NCUC, PSCSC, Tennessee Public Utility Commission (formerly the Tennessee Regulatory Authority) (TPUC) and FERC.

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles (GAAP) in the U.S. for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all information and notes required by GAAP in the U.S. for annual financial statements. 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, 2016, and the Consolidated Financial Statements and Notes in the Piedmont Annual Report on Form 10-K for the year ended October 31, 2016.

Effective November 1, 2016, Piedmont's fiscal year-end was changed from October 31 to December 31, the year-end of Duke Energy. A transition report was filed on Form 10-Q (Form 10-QT) as of December 31, 2016, for the transition period from November 1, 2016 to December 31, 2016.

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 and natural gas 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, meter reading schedules, and the impact of weather normalization or margin decoupling mechanisms.

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

(in millions)	March 31, 2017		December 31, 2016
Duke Energy	$	724	$	831
Duke Energy Carolinas	296		313
Progress Energy	151		161
Duke Energy Progress	84		102
Duke Energy Florida	67		59
Duke Energy Ohio	2		2
Duke Energy Indiana	27		32
Piedmont	38		77

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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)	March 31, 2017		December 31, 2016
Duke Energy Ohio	$	69	$	97
Duke Energy Indiana	106		123

AMOUNTS ATTRIBUTABLE TO CONTROLLING INTERESTS

Duke Energy's amount of Income from Discontinued Operations, net of tax presented on the Condensed Consolidated Statements of Operations for the three months ended March 31, 2016, includes amounts attributable to noncontrolling interest. The following table presents Net Income Attributable to Duke Energy Corporation for continuing operations and discontinued operations.

	Three Months Ended
(in millions)	March 31, 2016
Income from Continuing Operations	$	577
Income from Continuing Operations Attributable to Noncontrolling Interests	3
Income from Continuing Operations Attributable to Duke Energy Corporation	$	574
Income from Discontinued Operations, net of tax	$	122
Income from Discontinued Operations Attributable to Noncontrolling Interests, net of tax	2
Income from Discontinued Operations Attributable to Duke Energy Corporation, net of tax	$	120
Net Income	$	699
Net Income Attributable to Noncontrolling Interests	5
Net Income Attributable to Duke Energy Corporation	$	694

INVENTORY

Inventory is used for operations and is recorded primarily using the average cost method. Inventory related to regulated operations is valued at historical cost. Inventory related to nonregulated operations is valued at the lower of cost or market. Materials and supplies are recorded as inventory when purchased and subsequently charged to expense or capitalized to property, plant and equipment when installed. Inventory, including excess or obsolete inventory, is written-down to the lower of cost or market value. Once inventory has been written-down, it creates a new cost basis for the inventory that is not subsequently written-up. Provisions for inventory write-offs were not material for the three months ended March 31, 2017 and December 31, 2016. The components of inventory are presented in the tables below.

	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Materials and supplies	$	2,328	$	766	$	1,122	$	780	$	341	$	85	$	315	$	2
Coal	724		248		297		162		135		17		161		—
Natural gas, oil and other fuel	314		37		233		111		123		16		2		27
Total inventory	$	3,366	$	1,051	$	1,652	$	1,053	$	599	$	118	$	478	$	29

	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Materials and supplies	$	2,374	$	767	$	1,167	$	813	$	354	$	84	$	312	$	1
Coal	774		251		314		148		166		19		190		—
Natural gas, oil and other fuel	374		37		236		115		121		34		2		65
Total inventory	$	3,522	$	1,055	$	1,717	$	1,076	$	641	$	137	$	504	$	66

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.

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 March 31,
(in millions)	2017		2016
Duke Energy	$	91	$	91
Duke Energy Carolinas	9		8
Progress Energy	46		47
Duke Energy Progress	5		5
Duke Energy Florida	41		42
Duke Energy Ohio	28		28
Duke Energy Indiana	7		8
Piedmont	1		1

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2017 and 2016 had no material impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. While immaterial, adoption of the following accounting standard had the most significant impact on the Duke Energy results of operations, cash flows and financial position for the three months ended March 31, 2017.

Stock-Based Compensation and Income Taxes. In March 2017, Duke Energy adopted Financial Accounting Standards Board (FASB) guidance, which revised the accounting for stock-based compensation and the associated income taxes. The adopted guidance changes certain aspects of accounting for stock-based payment awards to employees including the accounting for income taxes and classification on the Condensed Consolidated Statements of Cash Flows. The primary impact to Duke Energy as a result of implementing this guidance was a cumulative-effect adjustment to retained earnings for tax benefits not previously recognized and higher income tax expense for the three months ended March 31, 2017. See the Duke Energy Condensed Consolidated Statements of Changes in Equity and Note 16 for further information.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of March 31, 2017.

Retirement Benefits. In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic costs related to benefit plans. Current GAAP permits the aggregation of all the components of net periodic costs on the income statement and does not require the disclosure of the location of net periodic costs on the Condensed Consolidated Statement of Operations. Under the amended guidance, the service cost component of net periodic costs must be included within Operating income within the same line as other compensation expenses. All other components of net periodic costs must be outside of Operating income. In addition, the updated guidance permits only the service cost component of net periodic costs to be capitalized to Inventory or Property, Plant and Equipment. This represents a change from current GAAP, which permits all components of net periodic costs to be capitalized. The guidance allows for a practical expedient that permits a company to use amounts disclosed in prior-period financial statements as the estimation basis for applying the retrospective presentation requirements.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2018. These amendments should be applied retrospectively for the presentation of the various components of net periodic costs and prospectively for the change in eligible costs to be capitalized. Duke Energy currently presents all of the components of net periodic costs that are not capitalized within Operation, maintenance and other on the Condensed Consolidated Statement of Operations. Under this updated guidance, Duke Energy will retrospectively move all the components of net periodic costs except for the service cost component to below Operating income. However, Duke Energy will continue to present the service cost component not capitalized within Operation, maintenance and other as this line item includes other compensation expense. Duke Energy is currently evaluating the financial statement impact, if any, of adopting this standard and whether or not the practical expedient will be utilized.

Goodwill Impairment. In January 2017, the FASB issued revised guidance for subsequent measurement of goodwill. Under the guidance, a company will recognize an impairment to goodwill for the amount by which a reporting unit's carrying value exceeds the reporting unit's fair value, not to exceed the amount of goodwill allocated to that reporting unit. For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2020. However, Duke Energy expects to early adopt this guidance on a prospective basis for the next interim or annual goodwill impairment test. Duke Energy does not expect adopting this guidance will have a material impact to its results of operations or financial position.

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.

42

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Most of Duke Energy’s revenue is expected to be in scope of the new guidance. The majority of our sales, including energy provided to residential customers, are from tariff offerings that provide natural gas or electricity without a defined contractual term (‘at-will’). For such arrangements, Duke Energy expects that the revenue from contracts with customers will be equivalent to the electricity or natural gas supplied and billed in that period (including estimated billings). As such, Duke Energy does not expect that there will be a significant shift in the timing or pattern of revenue recognition for such sales. The evaluation of other revenue streams is ongoing, including long-term contracts with industrial customers and long-term purchase power agreements (PPA).

Duke Energy continues to evaluate what information would be most useful for users of the financial statements, including information already provided in disclosures outside of the financial statement footnotes. These additional disclosures could include the disaggregation of revenues by geographic location, type of service, customer class or by duration of contract (‘at-will’ versus contracted revenue). Revenues from contracts with customers, revenue recognized under regulated operations accounting and revenue from lease accounting will also be disclosed.

Duke Energy intends to use the modified retrospective method of adoption effective January 1, 2018. This method results in a cumulative-effect adjustment that will be recorded to retained earnings as of January 1, 2018, as if the standard had always been in effect. Disclosures for 2018 will include a comparison to what would have been reported for 2018 under the current revenue recognition rules in order to assist financial statement users in understanding how revenue recognition has changed as a result of this standard and to facilitate comparability with prior year reported results, which are not restated under the modified retrospective approach.

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 financial statement impact of adopting this standard. Other than an expected increase in assets and liabilities, the ultimate impact of the new standard has not yet been determined. Significant system enhancements may be required to facilitate the identification, tracking and reporting of potential leases based upon requirements of the new lease standard.

Statement of Cash Flows. In November 2016, the FASB issued revised accounting guidance to reduce diversity in practice for the presentation and classification of restricted cash on the statement of cash flows. Under the updated guidance, restricted cash and restricted cash equivalents will be included within beginning-of-period and end-of-period cash and cash equivalents on the statement of cash flows.

For Duke Energy, this guidance is effective for the interim and annual periods beginning January 1, 2018, although it can be early adopted. The guidance will be applied using a retrospective transition method to each period presented. Upon adoption by Duke Energy, the revised guidance will result in a change to the amount of cash and cash equivalents and restricted cash explained when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Prior to adoption, the Duke Energy Registrants reflect changes in restricted cash within Cash Flows from Investing Activities on the Condensed Consolidated Statement of Cash Flows.

Financial Instruments Classification and Measurement. In January 2016, the FASB issued revised accounting guidance for the classification and measurement of financial instruments. Changes in the fair value of all equity securities will be required to be recorded in net income. Current GAAP allows some changes in fair value for available-for-sale equity securities to be recorded in Accumulated other comprehensive income (AOCI). Additional disclosures will be required to present separately the financial assets and financial liabilities by measurement category and form of financial asset. An entity's equity investments that are accounted for under the equity method of accounting are not included within the scope of the new guidance.

For Duke Energy, the revised accounting guidance is effective for interim and annual periods beginning January 1, 2018, by recording a cumulative-effect adjustment to retained earnings as of January 1, 2018. This guidance is expected to have minimal impact on the Duke Energy Registrant's Condensed Consolidated Statements of Operations and Comprehensive Income as changes in the fair value of most of the Duke Energy Registrants' available-for-sale equity securities are deferred as regulatory assets or liabilities pursuant to accounting guidance for regulated operations.

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 3, 2016, Duke Energy acquired all outstanding common stock of Piedmont for a total cash purchase price of $5.0 billion and assumed Piedmont's existing long-term debt, which had a fair value of approximately $2.0 billion at the time of the acquisition. The acquisition provides a foundation for Duke Energy to establish a broader, long-term strategic natural gas infrastructure platform to complement its existing natural gas pipeline investments and regulated natural gas business in the Midwest. In connection with the closing of the acquisition, Piedmont became a wholly owned subsidiary of Duke Energy.

43

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Purchase Price Allocation

The purchase price allocation of the Piedmont acquisition is as follows:

(in millions)
Current assets	$	497
Property, plant and equipment, net	4,714
Goodwill	3,353
Other long-term assets	804
Total assets	9,368
Current liabilities, including current maturities of long-term debt	576
Long-term liabilities	1,790
Long-term debt	2,002
Total liabilities	4,368
Total purchase price	$	5,000

The fair value of Piedmont's assets and liabilities were determined based on significant estimates and assumptions that are judgmental in nature, including projected future cash flows (including timing), discount rates reflecting risk inherent in the future cash flows and market prices of long-term debt.

The majority of Piedmont’s operations are subject to the rate-setting authority of the NCUC, the PSCSC and the TPUC and are accounted for pursuant to accounting guidance for regulated operations. The rate-setting and cost recovery provisions currently in place for Piedmont’s regulated operations provide revenues derived from costs, including a return on investment of assets and liabilities included in rate base. Thus, the fair value of Piedmont's assets and liabilities subject to these rate-setting provisions approximates the pre-acquisition carrying value and does not reflect any net valuation adjustments.

The significant assets and liabilities for which valuation adjustments were reflected within the purchase price allocation include the acquired equity method investments and long-term debt. The difference between the fair value and the pre-acquisition carrying value of long-term debt for regulated operations was recorded as a regulatory asset.

The excess of the purchase price over the fair value of Piedmont's assets and liabilities on the acquisition date was recorded as goodwill. The goodwill reflects the value paid by Duke Energy primarily for establishing a broader, long-term strategic natural gas infrastructure platform, an improved risk profile and expected synergies resulting from the combined entities.

Under Securities and Exchange Commission (SEC) regulations, Duke Energy elected not to apply push down accounting to the stand-alone Piedmont financial statements.

Accounting Charges Related to the Acquisition

Duke Energy incurred pretax nonrecurring transaction and integration costs associated with the acquisition of $16 million and $101 million for the three months ended March 31, 2017 and 2016, respectively. The 2016 amount includes $100 million of Interest Expense, which was driven by $93 million of unrealized losses on forward-starting interest rate swaps related to the acquisition financing. See Note 9 for additional information on the swaps.

Pro Forma Financial Information

The following unaudited pro forma financial information reflects the combined results of operations of Duke Energy and Piedmont as if the merger had occurred as of January 1, 2016. The pro forma financial information excludes potential cost savings, intercompany revenues, Piedmont’s earnings from the equity method investment in SouthStar sold immediately prior to the merger, and after-tax nonrecurring transaction and integration costs incurred by Duke Energy and Piedmont of $63 million. See Note 3 for additional information on Piedmont's sale of SouthStar.

This information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of Duke Energy.

	Three Months Ended
(in millions)	March 31, 2016
Operating Revenues	$	5,840
Net Income Attributable to Duke Energy Corporation	832

44

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

DISPOSITIONS

Sale of International Energy

In December 2016, Duke Energy sold its International Energy businesses, excluding the equity method investment in NMC (the International Disposal Group), in two separate transactions. Duke Energy sold its Brazilian business to China Three Gorges for approximately $1.2 billion, including the assumption of debt, and its remaining Central and South American businesses to I Squared Capital in a deal also valued at approximately $1.2 billion, including the assumption of debt. The transactions generated cash proceeds of $1.9 billion, excluding transaction costs, which were primarily used to reduce Duke Energy holding company debt.

The following table presents the results of the International Disposal Group, which are included in Income from Discontinued Operations, net of tax in Duke Energy's Condensed Consolidated Statements of Operations. Interest expense directly associated with the International Disposal Group was allocated to discontinued operations. No interest from corporate level debt was allocated to discontinued operations.

	Three Months Ended
(in millions)	March 31, 2016
Operating Revenues	$	246
Fuel used in electric generation and purchased power	47
Cost of natural gas	11
Operation, maintenance and other	71
Depreciation and amortization	22
Property and other taxes	3
Other Income and Expenses, net	10
Interest Expense	22
Income before income taxes	80
Income tax benefit(a)	(39		)
Income from discontinued operations of the International Disposal Group	119
Income from discontinued operations of other businesses	3
Income from Discontinued Operations, net of tax	$	122

(a) Includes an income tax benefit of $95 million related to historical undistributed foreign earnings. See Note 16 for additional information.

Duke Energy has elected not to separately disclose discontinued operations on the Condensed Consolidated Statements of Cash Flows. The following table summarizes Duke Energy's cash flows from discontinued operations related to the International Disposal Group.

	Three Months Ended
(in millions)	March 31, 2016
Cash flows provided by (used in):
Operating activities	$	85
Investing activities	(9		)

Other Sale Related Matters

Duke Energy will provide certain transition services to China Three Gorges and I Squared Capital for a period not to extend beyond November 2017 and December 2017, respectively. Cash flows related to providing the transition services are not material. In addition, Duke Energy will reimburse China Three Gorges and I Squared Capital for all tax obligations arising from the period preceding consummation on the transactions, totaling approximately $78 million. Duke Energy has not recorded any other liabilities, contingent liabilities or indemnifications related to the International Disposal Group.

3. BUSINESS SEGMENTS

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. 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 includes intercompany revenues and expenses that are eliminated in the Condensed Consolidated Financial Statements. Products and services are sold between affiliate companies and reportable segments of Duke Energy at cost.

Duke Energy

Due to the Piedmont acquisition and the sale of International Energy in the fourth quarter of 2016, Duke Energy's segment structure has been realigned to include the following segments: Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables. Prior period information has been recast to conform to the current segment structure. See Note 2 for further information on the Piedmont and International Energy transactions.

45

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

The Electric Utilities and Infrastructure segment includes Duke Energy's regulated electric utilities in the Carolinas, Florida and the Midwest. The regulated electric utilities conduct operations through the Subsidiary Registrants that are substantially all regulated and, accordingly, qualify for regulatory accounting treatment. Electric Utilities and Infrastructure also includes Duke Energy's electric transmission infrastructure investments.

The Gas Utilities and Infrastructure segment includes Piedmont, Duke Energy's natural gas local distribution companies in Ohio and Kentucky, and Duke Energy's natural gas storage and mid-stream pipeline investments. Gas Utilities and Infrastructure's operations are substantially all regulated and, accordingly, qualify for regulatory accounting treatment.

Commercial Renewables is primarily comprised of nonregulated utility scale wind and solar generation assets located throughout the U.S.

The remainder 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). Other also includes Duke Energy's 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.

Business segment information is presented in the following tables. Segment assets presented exclude intercompany assets.

	Three Months Ended March 31, 2017
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	4,939	$	648	$	128	$	5,715	$	14		$	—		$	5,729
Intersegment revenues	8		22		—		30		19			(49		)	—
Total revenues	$	4,947	$	670	$	128	$	5,745	$	33		$	(49	)	$	5,729
Segment income (loss)	$	635	$	133	$	25	$	793	$	(77	)	$	—		$	716
Add back noncontrolling interests															1
Net income															$	717
Segment assets	$	115,766	$	10,866	$	4,400	$	131,032	$	2,898		$	178		$	134,108

	Three Months Ended March 31, 2016
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,081	$	169	$	114	$	5,364	$	13		$	—		$	5,377
Intersegment revenues	8		1		—		9		16			(25		)	—
Total revenues	$	5,089	$	170	$	114	$	5,373	$	29		$	(25	)	$	5,377
Segment income (loss)(a)	$	664	$	32	$	26	$	722	$	(148	)	$	—		$	574
Add back noncontrolling interests															3
Income from discontinued operations, net of tax															122
Net income															$	699

(a) Other includes $74 million of after-tax costs to achieve mergers, including losses on forward-starting interest rate swaps related to the Piedmont acquisition financing. See Note 9 for additional information.

Duke Energy Ohio

Duke Energy Ohio has two reportable operating segments, Electric Utilities and Infrastructure and Gas Utilities and Infrastructure.

Electric Utilities and Infrastructure transmits and distributes electricity in portions of Ohio and generates, distributes and sells electricity in portions of Kentucky. Gas Utilities and Infrastructure transports and sells natural gas in portions of Ohio and northern Kentucky. It conducts operations primarily through Duke Energy Ohio and its wholly owned subsidiary, Duke Energy Kentucky.

46

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Other is primarily comprised of governance costs allocated by its parent, Duke Energy, and revenues and expenses related to Duke Energy Ohio's contractual arrangement to buy power from the Ohio Valley Electric Corporation's (OVEC) power plants. See Note 8 for additional information on related party transactions.

	Three Months Ended March 31, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Consolidated
Total revenues	$	337	$	170	$	507	$	11		$	—		$	518
Segment income (loss)/Net Income	24		26		50		(8		)	—			42
Segment assets	4,856		2,696		7,552		71			(14		)	7,609

	Three Months Ended March 31, 2016
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Consolidated
Total revenues	$	340	$	170	$	510	$	6		$	—		$	516
Segment income (loss)	$	36	$	31	$	67	$	(9	)	$	(1	)	$	57
Income from discontinued operations, net of tax													2
Net income													$	59

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

Piedmont has one reportable segment, Gas Utilities and Infrastructure, which transports and sells natural gas. The remainder of Piedmont's operations is classified as Other. While not considered a reportable segment, Other primarily consists of certain unallocated corporate costs, including acquisition-related expenses, and Piedmont's equity method investment in SouthStar Energy Services, LLC (SouthStar) prior to its sale. Piedmont sold its 15 percent membership interest in SouthStar on October 3, 2016. Piedmont's income, net of tax, from SouthStar for the three months ended March 31, 2016 was $7 million.

The remaining Subsidiary Registrants each have one reportable operating segment, Electric Utilities and Infrastructure, which generates, transmits, distributes and sells electricity. The remainder of each company's operations is classified as Other. While not considered a reportable segment for any of these companies, Other consists of certain unallocated corporate costs. Other for Progress Energy also includes interest expense on corporate debt instruments of $55 million and $56 million for the three months ended March 31, 2017 and 2016, respectively. The following table summarizes the net loss of Other for each of these entities.

	Three Months Ended
	March 31,
(in millions)	2017			2016
Duke Energy Carolinas	$	(6	)	$	(17	)
Progress Energy	(43		)	(49		)
Duke Energy Progress	(3		)	(8		)
Duke Energy Florida	(2		)	(4		)
Duke Energy Indiana	(2		)	(2		)
Piedmont	(4		)	6

The assets at Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana are substantially all included within the Electric Utilities and Infrastructure segment at March 31, 2017. The assets at Piedmont are substantially all included within the Gas Utilities and Infrastructure segment at March 31, 2017.

4. REGULATORY MATTERS

RATE RELATED INFORMATION

The NCUC, PSCSC, FPSC, IURC, PUCO, TPUC and KPSC approve rates for retail electric and natural gas services within their states. The FERC approves rates for electric sales to wholesale customers served under cost-based rates (excluding Ohio and Indiana), as well as sales of transmission service. The FERC also regulates certification and siting of new interstate natural gas pipeline projects.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Duke Energy Carolinas and Duke Energy Progress

Ash Basin Closure Costs Deferral

On December 30, 2016, Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the NCUC seeking an accounting order authorizing deferral 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 North Carolina. Initial comments were received in March 2017, and reply comments were filed on April 19, 2017. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

Duke Energy Carolinas

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 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. On March 24, 2017, the South Carolina Supreme Court denied the request for review, thus concluding the matter.

William States Lee III Nuclear Station

In December 2007, Duke Energy Carolinas applied to the NRC for combined operating licenses (COLs) for two Westinghouse Electric Company (Westinghouse) AP1000 reactors for the proposed William States Lee III Nuclear Station to be located at a site in Cherokee County, South Carolina. The NCUC and PSCSC have concurred with the prudency of Duke Energy Carolinas decisions to incur certain project development and preconstruction costs through several separately issued orders, although full cost recovery is not guaranteed. In December 2016, the NRC issued a COL for each reactor. Duke Energy Carolinas is not required to build the nuclear reactors as a result of the COLs being issued.

On March 29, 2017, Westinghouse filed for voluntary Chapter 11 bankruptcy in the U.S. Bankruptcy Court for the Southern District of New York. Duke Energy Carolinas is monitoring the bankruptcy proceedings to assess the impact it will have on the future construction of nuclear plants.

Duke Energy Progress

Storm Cost Deferral Filing

On December 16, 2016, Duke Energy Progress filed a petition with the NCUC requesting an accounting order to defer certain costs incurred in connection with response to Hurricane Matthew and other significant storms in 2016. Duke Energy Progress proposed in the filing to true-up the total costs quarterly through August 2017. The current estimate of incremental operation and maintenance and capital costs is $116 million. On March 15, 2017, the Public Staff filed comments supporting deferral of a portion of Duke Energy Progress’ requested amount. Duke Energy Progress filed reply comments on April 12, 2017. Duke Energy Progress cannot predict the outcome of this matter.

Western Carolinas Modernization Plan

On November 4, 2015, Duke Energy Progress announced a Western Carolinas Modernization Plan, which included 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 plan also included upgrades to existing transmission lines and substations, installation of solar generation and 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.

On March 28, 2016, the NCUC issued an order approving a Certificate of Public Convenience and Necessity (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. On March 28, 2017, Duke Energy Progress filed an annual progress report for the construction of the combined-cycle plants with the NCUC, with an estimated cost of $893 million. Site preparation activities for the combined-cycle plants are underway and construction of these plants is scheduled to begin in fall 2017, with an expected in-service date in late 2019. Duke Energy Progress plans to file for future approvals related to the proposed solar generation and pilot battery storage project.

The carrying value of the 376-MW Asheville coal-fired plant, including associated ash basin closure costs, of $471 million and $492 million are included in Generation facilities to be retired, net on Duke Energy Progress' Condensed Consolidated Balance Sheet as of March 31, 2017 and December 31, 2016, respectively.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Duke Energy Florida

Hines Chiller Uprate Project

On February 2, 2017, 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 Energy Complex. The Uprate Project was placed into service in March 2017 at a cost of approximately $150 million. The retail revenue requirement is approximately $19 million. On March 28, 2017, the FPSC issued an order approving the revenue requirement which were included in base rates for the first billing cycle of April 2017.

Levy Nuclear Project

On July 28, 2008, Duke Energy Florida applied to the NRC for COLs for two Westinghouse AP1000 reactors at Levy. In 2008, the FPSC granted Duke Energy Florida’s petition for an affirmative Determination of Need and related orders requesting cost recovery under Florida’s nuclear cost-recovery rule, together with the associated facilities, including transmission lines and substation facilities. In October 2016, the NRC issued COLs for the proposed Levy Nuclear Plant Units 1 and 2. Duke Energy Florida is not required to build the nuclear reactors as a result of the COLs being issued.

On January 28, 2014, Duke Energy Florida terminated the Levy engineering, procurement and construction agreement (EPC). Duke Energy Florida may be required to pay for work performed under the EPC. Duke Energy Florida recorded an exit obligation in 2014 for the termination of the EPC. This liability was recorded within Other in Deferred Credits and Other Liabilities with an offset primarily to Regulatory assets on the Condensed Consolidated Balance Sheets. Duke Energy Florida is allowed to recover reasonable and prudent EPC cancellation costs from its retail customers. On May 1, 2017, Duke Energy Florida filed a request with the FPSC to recover approximately $82 million of Levy Nuclear Project costs from retail customers in 2018. A hearing is scheduled in August 2017. Duke Energy Florida cannot predict the outcome of this matter.

On March 29, 2017, Westinghouse filed for voluntary Chapter 11 bankruptcy in the U.S. Bankruptcy Court for the Southern District of New York. Duke Energy Florida is monitoring the bankruptcy proceedings to assess the impact it will have on the future construction of nuclear plants.

Duke Energy Ohio

Ohio Valley Electric Corporation

On March 31, 2017, Duke Energy Ohio filed for approval to adjust its existing price stabilization rider (Rider PSR) to pass through net costs related to its contractual entitlement to capacity and energy from the generating assets owned by OVEC. The PUCO approved Rider PSR, but set it at zero dollars in connection with the most recent electric security plan. The application seeks to adjust Rider PSR as of April 1, 2017. Duke Energy Ohio is seeking deferral authority for net costs incurred from April 1, 2017, until the new rates under Rider PSR are put into effect. See Note 12 for additional discussion of Duke Energy Ohio's ownership interest in OVEC. Duke Energy Ohio cannot predict the outcome of this proceeding.

East Bend Coal Ash Basin Filing

On December 2, 2016, Duke Energy Kentucky filed with the KPSC a request for a CPCN for construction projects necessary to close and repurpose an ash basin at the East Bend facility as a result of current and proposed U.S. Environmental Protection Agency (EPA) regulations. Duke Energy Kentucky estimated a total cost of approximately $93 million in the filing and expects in-service date in the fourth quarter of 2018. Duke Energy Kentucky expects the KPSC to issue an order in the second quarter of 2017.

Base Rate Case

Duke Energy Ohio filed with the PUCO an electric distribution base rate case application and supporting testimony in March 2017. Duke Energy Ohio has requested an estimated annual increase of approximately $15 million and a return on equity of 10.4 percent. The application also includes requests to continue certain current riders and establish new riders related to LED Outdoor Lighting Service and regulatory mandates. Duke Energy Ohio cannot predict the outcome of this matter.

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. On January 20, 2017, Duke Energy Ohio filed an amended application with the Ohio Power Siting Board for approval of one of two proposed routes. If approved, construction of the pipeline extension is expected to be completed before the 2019/2020 winter season. A public hearing is scheduled for June 15, 2017, and an adjudicatory hearing is scheduled to begin July 12, 2017. The proposed project involves the installation of a natural gas line and is estimated to cost between $86 million and $110 million, excluding AFUDC.

Advanced Metering Infrastructure

On April 25, 2016, Duke Energy Kentucky filed with the KPSC an application for approval of a CPCN for the construction of advanced metering infrastructure. Duke Energy Kentucky estimates the $49 million project, if approved, will take 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 to be replaced. Duke Energy Kentucky and the Kentucky Attorney General entered into a stipulation to settle matters related to the application. An evidentiary hearing on the application and stipulation was held on December 8, 2016. Duke Energy Kentucky cannot predict the outcome of this matter.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 proposed to replace certain natural gas service lines on an accelerated basis over a 10-year period. Duke Energy Ohio also proposed 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's current projected total capital and operations and maintenance expenditures under the ASRP are approximately $240 million. The filing also sought approval of a rider mechanism (Rider ASRP) to recover related expenditures. Duke Energy Ohio proposed to update Rider ASRP on an annual basis. Intervenors opposed the ASRP, primarily because they believe the program is neither required nor necessary under federal pipeline regulation. On October 26, 2016, the PUCO issued an order denying the proposed ASRP. The PUCO did, however, encourage Duke Energy Ohio to work with the PUCO Staff and intervenors. Duke Energy Ohio filed an application for rehearing of the PUCO decision. In December 2016, the PUCO granted the request for the purpose of further review. 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. 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 upon 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 January 6, 2016, Duke Energy Ohio and the PUCO Staff entered into a stipulation, pending the PUCO's approval, to resolve issues related to performance incentives and the PUCO Staff audit of 2013 costs, among other issues. In December 2015, based upon the stipulation, Duke Energy Ohio re-established approximately $20 million of the revenues that had been previously reversed. On October 26, 2016, the PUCO issued an order approving the stipulation without modification. Intervenors requested a rehearing of the PUCO decision. In December 2016, the PUCO granted a rehearing for the purpose of further review. 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 PUCO order also authorized Duke Energy Ohio to continue deferring MGP environmental investigation and remediation costs incurred subsequent to 2012 and to submit annual filings to adjust the MGP rider for future costs. Intervening parties appealed this decision to the Ohio Supreme Court and that appeal remains pending. Oral argument was heard on February 28, 2017. Incurred and projected investigation and remediation expenses at these MGP sites that have not been collected through the MGP rider are approximately $100 million and are recorded as Regulatory assets on Duke Energy Ohio's Condensed Consolidated Balance Sheet as of March 31, 2017. 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 $90 million at March 31, 2017, and December 31, 2016, recorded within Other in Current liabilities and Other in Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets. The retail portions of MTEP costs billed by MISO are recovered by Duke Energy Ohio through a non-bypassable rider. As of March 31, 2017, and December 31, 2016, Duke Energy Ohio had $71 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.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 EPA's 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, including AFUDC, under a federal mandate tracker that 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. On January 24, 2017, Duke Energy Indiana and various Intervenors filed a settlement agreement with the IURC. Terms of the settlement include recovery of 60 percent of the estimated CCR compliance construction project capital costs through existing rider mechanisms and deferral of 40 percent of these costs until Duke Energy Indiana's next general retail rate case. The deferred costs will earn a return based on Duke Energy Indiana's long-term debt rate of 4.73 percent until costs are included in retail rates, at which time the deferred costs will earn a full return. Costs are to be capped at $365 million, plus actual AFUDC. Costs above the cap may be recoverable in the next rate case. Terms of the settlement agreement also require Duke Energy Indiana to perform certain reporting and groundwater monitoring. The settlement is subject to approval by the IURC. An evidentiary hearing was held on February 23, 2017, and Duke Energy Indiana filed a proposed order with the IURC on March 30, 2017. Duke Energy Indiana cannot predict the outcome of this matter.

FERC Transmission Return on Equity Complaints

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 complaints, among other things, claim that the current base rate of return on equity earned by MISO transmission owners should be reduced to 8.67 percent. On January 5, 2015, the FERC issued an order accepting the MISO transmission owners' adder of 0.50 percent 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. On December 22, 2015, the presiding FERC ALJ in the first complaint issued an Initial Decision in which the base rate of return on equity was set at 10.32 percent. On September 28, 2016, the Initial Decision in the first complaint was affirmed by FERC, but is subject to rehearing requests. 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 Decision in the second complaint is pending FERC review. On April 14, 2017, the U.S. Court of Appeals for the District of Columbia Circuit, in Emera Maine v. FERC, reversed and remanded certain aspects of the methodology employed by FERC to establish rates of return on equity. This decision may affect the outcome of the complaints against Duke Energy Indiana. Duke Energy Indiana currently believes these matters will not have a material impact on its results of operations, cash flows and financial position.

Piedmont

North Carolina Integrity Management Rider Filings

In October 2016, Piedmont filed a petition with the NCUC under the integrity management rider (IMR) mechanism seeking authority to collect an additional $8 million in annual revenues, effective December 2016, based on the eligible capital investments closed to integrity and safety projects over the six-month period ending September 30, 2016. In November 2016, the NCUC approved the request.

On May 1, 2017, Piedmont filed a petition with the NCUC under the IMR mechanism to collect an additional $11.6 million in annual revenues, effective June 2017, based on the eligible capital investments closed to integrity and safety projects over the six-month period ending March 31, 2017.  A ruling from the NCUC is pending.

Tennessee IMR Filings

In November 2016, Piedmont filed an annual report with the TPUC under the IMR mechanism seeking authority to collect an additional $1.7 million in annual revenues effective January 2017, based on the capital investments in integrity and safety projects over the 12-month period ending October 31, 2016. The TPUC approved the request at a hearing on April 10, 2017.

OTHER REGULATORY MATTERS

Atlantic Coast Pipeline

On September 2, 2014, Duke Energy, Dominion Resources (Dominion), Piedmont and Southern Company Gas announced the formation of Atlantic Coast Pipeline, LLC (ACP) to build and own the proposed Atlantic Coast Pipeline (ACP pipeline), an approximately 600-mile interstate natural gas pipeline running from West Virginia to North Carolina. The ACP pipeline is designed to meet the needs identified in RFPs by Duke Energy Carolinas, Duke Energy Progress and Piedmont. The ACP pipeline development costs are estimated between $5.0 billion to $5.5 billion. Dominion will build and operate the ACP pipeline and holds a leading ownership percentage in ACP of 48 percent. Duke Energy owns a 47 percent interest through its Gas Utilities and Infrastructure segment. Southern Company Gas maintains a 5 percent interest. See Note 12 for additional information related to Duke Energy's ownership interest.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Duke Energy Carolinas, Duke Energy Progress and Piedmont, among others, will be customers of the pipeline. Purchases will be made under several 20-year supply contracts, subject to state regulatory approval. On September 18, 2015, ACP filed an application with the FERC requesting a CPCN authorizing ACP to construct the pipeline. ACP executed a construction agreement in September 2016. ACP also requested approval of an open access tariff and the precedent agreements it entered into with future pipeline customers. In December 2016, FERC issued a draft Environmental Impact Statement (EIS) indicating that the proposed pipeline would not cause significant harm to the environment or protected populations. The draft EIS comment period ended in April 2017, and ACP is working to resolve items identified through the comment process. The final EIS is expected in summer 2017. FERC approval of the application is expected within 90 days of the issuance of the final EIS. Construction is projected to begin in the second-half of 2017, with a targeted in-service date in the second half of 2019.

Sabal Trail Transmission, LLC Pipeline

On May 4, 2015, Duke Energy acquired a 7.5 percent ownership interest in Sabal Trail Transmission, LLC (Sabal Trail) from Spectra Energy Partners, LP, a master limited partnership, formed by Enbridge Inc. (formerly Spectra Energy Corp.). Spectra Energy Partners, LP holds a 50 percent ownership interest in Sabal Trail and NextEra Energy has a 42.5 percent ownership interest. Sabal Trail is a joint venture that is constructing a 515-mile natural gas pipeline (Sabal Trail pipeline) to transport natural gas to Florida. Total estimated project costs are approximately $3.2 billion. The Sabal Trail pipeline will traverse Alabama, Georgia and Florida. 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 pipeline. On September 7, 2016, FERC denied the intervenors' rehearing requests. On September 21, 2016, intervenors filed an appeal of FERC's CPCN orders to the U.S. Court of Appeals for the District of Columbia Circuit. Oral argument on the appeal was held on April 18, 2017, and a decision is expected in the summer of 2017. The Sabal Trail pipeline has received other required regulatory approvals and construction began in the summer of 2016, with an expected in-service date in mid-2017. See Note 12 for additional information related to Duke Energy's ownership interest.

Constitution Pipeline

Duke Energy owns a 24 percent ownership interest in Constitution Pipeline Company, LLC (Constitution). Constitution is a natural gas pipeline project slated to transport natural gas supplies from the Marcellus supply region in northern Pennsylvania to major northeastern markets. The pipeline will be constructed and operated by Williams Partners L.P., which has a 41 percent ownership share. The remaining interest is held by Cabot Oil and Gas Corporation and WGL Holdings, Inc.

On April 22, 2016, the New York State Department of Environmental Conservation (NYSDEC) denied Constitution’s application for a necessary water quality certification for the New York portion of the Constitution pipeline. Constitution filed legal actions in the U.S. District Court for the Northern District of New York and in the U.S. Court of Appeals for the Second Circuit (U.S. Court of Appeals) challenging the legality and appropriateness of the NYSDEC’s decision. Both courts granted Constitution's motions to expedite the schedules for the legal actions. On November 16, 2016, oral arguments were heard in the U.S. Court of Appeals. On March 16, 2017, the U.S. District Court for the Northern District of New York dismissed without prejudice Constitution’s claim that New York State permits were preempted by the federal permitting process. The ruling on oral arguments made in the U.S. Court of Appeals regarding NYSDEC's denial of the water quality certification is currently expected in mid-2017.

Constitution remains steadfastly committed to pursuing the project and intends to pursue all available options to challenge the NYSDEC's decision. In light of the denial of the certification, Constitution revised its target in-service date of the project to be as early as the second half of 2018, assuming that the challenge process is satisfactorily and promptly concluded.

In July 2016, Constitution requested, and the FERC approved, an extension of the construction period and in-service deadline of the project to December 2018. Also in July, the FERC denied the New York Attorney General's (NYAG) complaint and request for a stay of the certificate order authorizing the project on the grounds that Constitution had improperly cut trees along the proposed route. The FERC found the complaint procedurally deficient and that there was no justification for a stay; it did find the filing constituted a valid request for investigation and thus referred the matter to FERC staff for further examination as may be appropriate. On November 22, 2016, the FERC denied the NYAG's request for reconsideration of this order.

Since April 2016, with the actions of the NYSDEC, Constitution stopped construction and discontinued capitalization of future development costs until the project's uncertainty is resolved. As a result, Duke Energy evaluated the investment in the Constitution project for other-than-temporary impairments (OTTIs). At this time, no OTTI has been determined and therefore no impairment charge to reduce the carrying value of the investment has been recorded. However, to the extent that the legal and regulatory proceedings have unfavorable outcomes, or if Constitution concludes that the project is not viable or does not go forward as legal and regulatory actions progress, the conclusions with respect to OTTIs could change and may require that an impairment charge of up to the recorded investment in the project, net of any cash and working capital returned, be recorded. Duke Energy will continue to monitor and update the OTTI analysis as required. Different assumptions could affect the timing and amount of any charge recorded in a period.

Pending the outcome of the matters described above, and when construction proceeds, Duke Energy remains committed to fund an amount in proportion to its ownership interest for the development and construction of the new pipeline. Duke Energy's total anticipated contributions are approximately $229 million.

See Note 12 for additional information related to ownership interest and carrying value of the investment.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 North Carolina, Florida and Indiana earlier than their current estimated useful lives primarily because facilities do not have the requisite emission control equipment 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. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2017, and exclude capitalized asset retirement costs.

		Remaining Net
	Capacity	Book Value
	(in MW)	(in millions)
Duke Energy Carolinas
Allen Steam Station Units 1-3(a)	585	$	167
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2(b)	873	117
Duke Energy Indiana
Gallagher Units 2 and 4(c)	280	135
Total Duke Energy	1,738	$	419

(a) Duke Energy Carolinas will retire Allen Steam Station Units 1 through 3 by December 31, 2024, as part of the resolution of a lawsuit involving alleged New Source Review violations.

(b) Duke Energy Florida will likely retire these coal units by 2018 to comply with environmental regulations.

(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 settlement of Edwardsport IGCC matters.

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

5. COMMITMENTS AND CONTINGENCIES

ENVIRONMENTAL

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

Remediation Activities

In addition to asset retirement obligations (AROs) 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 at all sites. 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.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets.

	Three Months Ended March 31, 2017
				Duke					Duke		Duke			Duke			Duke
	Duke			Energy		Progress			Energy		Energy			Energy			Energy
(in millions)	Energy			Carolinas		Energy			Progress		Florida			Ohio			Indiana			Piedmont
Balance at beginning of period	$	98		$	10	$	18		$	3	$	14		$	59		$	10		$	1
Provisions/adjustments	6			1		—			—		1			4			(1		)	1
Cash reductions	(6		)	—		(1		)	—		(1		)	(4		)	—			—
Balance at end of period	$	98		$	11	$	17		$	3	$	14		$	59		$	9		$	2

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Balance at beginning of period	$	94		$	10		$	17		$	3		$	14		$	54	$	12	$	1
Provisions/adjustments	10			2			1			—			1			—		6		—
Cash reductions	(3		)	(1		)	(2		)	(1		)	(1		)	—		—		—
Balance at end of period	$	101		$	11		$	16		$	2		$	14		$	54	$	18	$	1

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	$	71
Duke Energy Carolinas	22
Duke Energy Ohio	36
Duke Energy Indiana	7
Piedmont	2

North Carolina and South Carolina Ash Basins

In February 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. 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 future state or federal civil enforcement proceedings, future regulatory directives, natural resources damages, future claims or litigation and long-term environmental impact costs, cannot be reasonably estimated at this time.

The North Carolina Department of Environmental Quality (NCDEQ) 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 ash release, Duke Energy Carolinas and Duke Energy Progress have been served with a higher level of NOVs, including assessed penalties for violations at L.V. Sutton Combined Cycle Plant (Sutton) and Dan River Steam Station. Duke Energy Carolinas and Duke Energy Progress cannot predict whether the NCDEQ will assess future penalties related to existing unresolved NOVs and if such penalties would be material. See "NCDEQ Notices of Violation" section below for additional discussion.

LITIGATION

Duke Energy

Duke Energy no longer has exposure to litigation matters related to the International Energy Disposal Group as a result of the divestiture of the business in December 2016. See Note 2 for additional information related to the sale of International 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 (collectively, the Duke Energy Defendants). Duke Energy is named as a nominal defendant.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 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 December 14, 2016, the Delaware Chancery Court entered an order dismissing the Amended Complaint. Plaintiffs filed an appeal to the Delaware Supreme Court on January 9, 2017. The parties have completed briefing in the case and a date for oral argument has not been set.

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 appointed 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. On March 30, 2017, the court granted Defendants’ Motion to Dismiss on the claims relating to coal ash environmental issues and political contributions. A notice of appeal has not been filed. As discussed below, an agreement-in-principle has been reached to settle the merger related claims in the Bresalier Complaint, and those claims were also dismissed subject to that agreement.

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 (Merger Chancery Litigation). The lawsuit names as defendants the 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.

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 have reached an agreement-in-principle to settle the Merger Chancery Litigation, conditioned on dismissal as well, of the Tansey v. Rogers, et al case and the merger related claims in the Bresalier Complaint discussed above, for a total of $27 million. The entire settlement amount is to be funded by insurance. The settlement amount, less court-approved attorney fees, will be payable to Duke Energy. Settlement documents have been submitted to the court for approval and a hearing has been set for July 13, 2017.

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 in a consolidated federal court proceeding in Nevada. Each of these lawsuits contained 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 sought 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. The proposed settlement of the class action lawsuits was submitted to the Court and preliminarily approved on January 26, 2017. The Court will consider final approval of the class settlement following notice to the class members. The settlement amounts are not material to Duke Energy.

Duke Energy Carolinas and Duke Energy Progress

Coal Ash Insurance Coverage Litigation

In March 2017, Duke Energy Carolinas and Duke Energy Progress filed a civil action in North Carolina Superior Court against various insurance providers. The lawsuit seeks payment for coal ash related liabilities covered by third-party liability insurance policies. The insurance policies were issued between 1971 and 1986 and provide third-party liability insurance for property damage. The civil action seeks damages for breach of contract and indemnification for costs arising from the North Carolina Coal Ash Management Act of 2014, as amended, (Coal Ash Act) and the EPA CCR rule at 15 coal-fired plants in North Carolina and South Carolina. Duke Energy Carolinas and Duke Energy Progress 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. The 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.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

On August 16, 2013, the 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.

The court issued orders in 2016 granting Motions' for Partial Summary Judgment for seven of the 14 North Carolina plants named in the enforcement actions. The litigation is concluded for these seven plants. Litigation continues for the remaining seven plants. In response to a motion for partial summary judgment on the groundwater claims filed by the environmental groups, on October 17, 2016, Duke Energy Carolinas and Duke Energy Progress filed a cross-motion for partial summary judgment on the groundwater claims. On February 13, 2017, the court issued an order denying both the environmental groups' motion for partial summary judgment and Duke Energy Carolinas and Duke Energy Progress' cross-motion for partial summary judgment. On March 15, 2017, Duke Energy Carolinas and Duke Energy Progress filed a Notice of Appeal to challenge the trial court’s denial of their cross-motion for partial summary judgment. The parties were unable to reach an agreement at mediation on April 18, 2017.

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

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. On August 19, 2016, Duke Energy Progress filed a Motion to Dismiss. On April 26, 2017, the court entered an order dismissing four of the claims in the federal citizen suit. Two claims relating to alleged violations of National Pollutant Discharge Elimination System permit provisions survived the motion to dismiss, and Duke Energy Progress’ response is due on May 10, 2017.

On March 16, 2017, the Roanoke River Basin Association served Duke Energy Progress with a 60-day notice of intent to bring suit pursuant to the citizen suit provision of the CWA for alleged violations of effluent standards and limitations at the Roxboro Plant.

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

Five previously filed cases involving the Riverbend, Cape Fear, H.F. Lee, Sutton and Buck plants were dismissed or settled in 2016.

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 the NCDEQ advising them not to drink water from the private wells on their land tested by the 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 basins, 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.

Duke Energy Carolinas and Duke Energy Progress have received formal demand letters from residents near Duke Energy Carolinas' and Duke Energy Progress' coal ash basins. The residents claim damages for nuisance and diminution in property value, among other things. The parties held three days of mediation discussions that ended at impasse. On January 6, 2017, Duke Energy Carolinas and Duke Energy Progress received the plaintiffs' notice of their intent to file suits should the matter not settle. The NCDEQ preliminarily approved Duke Energy’s permanent water solution plans on January 13, 2017, and as a result shortly thereafter, Duke Energy issued a press release, providing additional details regarding the homeowner compensation package. This package consists of three components: (i) a $5,000 goodwill payment to each eligible well owner to support the transition to a new water supply, (ii) where a public water supply is available and selected by the eligible well owner, a stipend to cover 25 years of water bills and (iii) the Property Value Protection Plan. The Property Value Protection Plan is a program offered by Duke Energy designed to guarantee eligible plant neighbors the fair market value of their residential property should they decide to sell their property during the time that the plan is offered. Duke Energy received a letter from Plaintiffs' counsel indicating their intent to file suit on February 2, 2017, should a settlement not be reached by that date. Plaintiff’s counsel did not file suit upon the expiration of the tolling agreement on February 2, 2017, and no suit has been filed to date. Duke Energy Carolinas and Duke Energy Progress have recognized reserves of $18 million and $4 million, respectively.

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.

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 March 31, 2017, there were 111 asserted claims for non-malignant cases with the cumulative relief sought of up to $29 million, and 58 asserted claims for malignant cases with the cumulative relief sought of up to $16 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 $506 million at March 31, 2017 and $512 million at December 31, 2016. These reserves are classified in Other within Other Noncurrent 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 2036, 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 2036 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 $814 million in excess of the self-insured retention. Receivables for insurance recoveries were $587 million at March 31, 2017 and December 31, 2016. These amounts are classified in Other within Other Noncurrent 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. On September 21, 2016, the Court granted the motions to dismiss with prejudice. Plaintiffs filed a motion for reconsideration, which was denied. On January 4, 2017, plaintiffs filed a notice of appeal. Plaintiffs filed an appellate brief on March 16, 2017, and Duke Energy Florida filed responses on April 17, 2017. Duke Energy Florida cannot predict the outcome of this appeal.

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 an 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.

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. On July 11, 2016, Duke Energy Florida and Westinghouse filed separate Motions for Summary Judgment. On September 29, 2016, the court issued its ruling on the parties' respective Motions for Summary Judgment, ruling in favor of Westinghouse on a $30 million termination fee claim and dismissing Duke Energy Florida's $54 million refund claim, but stating that Duke Energy Florida could use the refund claim to offset any damages for termination costs. Westinghouse's claim for termination costs was unaffected by this ruling and continued to trial. At trial, Westinghouse reduced its claim for termination costs from $482 million to $424 million. Following a trial on the matter, the court issued its final order in December 2016 denying Westinghouse’s claim for termination costs and re-affirming its earlier ruling in favor of Westinghouse on the $30 million termination fee and Duke Energy Florida’s refund claim. Judgment was entered against Duke Energy Florida in the amount of approximately $34 million, which includes prejudgment interest. Westinghouse has appealed the trial court's order and Duke Energy Florida has cross-appealed.

It is not possible to predict the ultimate outcome of the appeal of the trial court's order. 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.

On March 29, 2017, Westinghouse filed Chapter 11 bankruptcy in the Southern District of New York, which could delay the timing of the appeal. Additional impacts, if any, of this bankruptcy filing on the resolution of the pending appeal and cross-appeal are unknown at this time.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

MGP Cost Recovery Action

On December 30, 2011, Duke Energy Florida filed a lawsuit against FirstEnergy Corp. (FirstEnergy) to recover investigation and remediation costs incurred by Duke Energy Florida in connection with the restoration of two former MGP sites in Florida. Duke Energy Florida alleged that FirstEnergy, as the successor to Associated Gas & Electric Co., owes past and future contribution and response costs of up to $43 million for the investigation and remediation of MGP sites. On December 6, 2016, the trial court entered judgment against Duke Energy Florida in the case. In January 2017, Duke Energy Florida appealed the decision to the U.S. Court of Appeals for the 6th Circuit. Duke Energy Florida cannot predict the outcome of this appeal.

Duke Energy Indiana

Benton County Wind Farm Dispute

On December 16, 2013, Benton County Wind Farm LLC (BCWF) filed a lawsuit against Duke Energy Indiana seeking damages for past generation losses totaling approximately $16 million alleging Duke Energy Indiana violated its obligations under a 2006 PPA by refusing to offer electricity to the market at negative prices. Damage claims continue to increase during times that BCWF is not dispatched. Under 2013 revised MISO market rules, Duke Energy Indiana is required to make a price offer to MISO for the power it proposes to sell into MISO markets and MISO determines whether BCWF is dispatched. Because market prices would have been negative due to increased market participation, Duke Energy Indiana determined it would not bid at negative prices in order to balance customer needs against BCWF's need to run. BCWF contends Duke Energy Indiana must bid at the lowest negative price to ensure dispatch, while Duke Energy Indiana contends it is not obligated to bid at any particular price, that it cannot ensure dispatch with any bid and that is has reasonably balanced the parties' interests. On July 6, 2015, the U.S. District Court for the Southern District of Indiana entered judgment against BCWF on all claims. BCWF appealed the decision and on December 9, 2016, the appeals court ruled in favor of BCWF. The matter has been remanded to a lower court to determine damages. A settlement conference is scheduled on May 31, 2017. Duke Energy Indiana cannot predict the outcome of this matter. Ultimate resolution of this matter could have a material effect on the results of operations, financial position or cash flows of Duke Energy Indiana. However, appropriate regulatory recovery will be pursued for the retail portion of any costs incurred in connection with such resolution.

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 Other Noncurrent 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)	March 31, 2017		December 31, 2016
Reserves for Legal Matters
Duke Energy	$	91	$	98
Duke Energy Carolinas	23		23
Progress Energy	57		59
Duke Energy Progress	13		14
Duke Energy Florida	27		28
Duke Energy Ohio	4		4
Piedmont	2		2

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 or natural gas, 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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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC – PIEDMONT NATURAL GAS COMPANY, INC.

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

6. DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

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

				Three Months Ended March 31, 2017
						Duke		Duke
	Maturity	Interest		Duke		Energy		Energy
Issuance Date	Date	Rate		Energy		Florida		Ohio
Secured Debt
February 2017(a)	June 2034	4.120	%	$	587	$	—	$	—
First Mortgage Bonds
January 2017(b)	January 2020	1.850	%	250		250		—
January 2017(b)	January 2027	3.200	%	650		650		—
March 2017(c)	June 2046	3.700	%	100		—		100
Total issuances				$	1,587	$	900	$	100

(a) Portfolio financing of four Texas and Oklahoma wind facilities. Secured by substantially all of the assets of these wind facilities and nonrecourse to Duke Energy. Proceeds were used to reimburse Duke Energy for a portion of previously funded construction expenditures.

(b) Debt issued to fund capital expenditures for ongoing construction and capital maintenance, to repay at maturity a $250 million aggregate principal amount of bonds due September 2017 and for general corporate purposes.

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

In April 2017, Duke Energy (Parent) issued $420 million of unsecured notes with a fixed interest rate of 3.364 percent and maturity date of April 2025. The net proceeds were used to refinance $400 million of unsecured debt at maturity and to repay outstanding commercial paper.

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		March 31, 2017
Unsecured Debt
Duke Energy (Parent)	August 2017	1.625	%	$	700
Piedmont	September 2017	8.510	%	35
Secured Debt
Duke Energy	June 2017	2.605	%	45
Duke Energy	June 2017	2.455	%	34
First Mortgage Bonds
Duke Energy Florida	September 2017	5.800	%	250
Duke Energy Progress	November 2017	1.252	%	200
Duke Energy Carolinas	January 2018	5.250	%	400
Other(a)				313
Current maturities of long-term debt				$	1,977

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

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DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC – PIEDMONT NATURAL GAS COMPANY, INC.

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

AVAILABLE CREDIT FACILITIES

Master Credit Facility

In March 2017, Duke Energy amended its Master Credit Facility to increase its capacity from $7.5 billion to $8 billion, and to extend the termination date of the facility from January 30, 2020, to March 16, 2022. The amendment also added Piedmont as a borrower within the Master Credit Facility. Piedmont's separate $850 million credit facility was terminated in connection with the amendment. With the amendment, 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.

	March 31, 2017
				Duke			Duke			Duke			Duke			Duke			Duke
	Duke			Energy			Energy			Energy			Energy			Energy			Energy
(in millions)	Energy			(Parent)			Carolinas			Progress			Florida			Ohio			Indiana			Piedmont
Facility size(a)	$	8,000		$	3,400		$	1,100		$	1,000		$	950		$	450		$	600		$	500
Reduction to backstop issuances
Commercial paper(b)	(3,134		)	(1,822		)	(469		)	(402		)	—			(30		)	(150		)	(261		)
Outstanding letters of credit	(71		)	(62		)	(4		)	(2		)	(1		)	—			—			(2		)
Tax-exempt bonds	(81		)	—			—			—			—			—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—			—
Available capacity	$	4,214		$	1,516		$	377		$	346		$	949		$	420		$	369		$	237

(a) Represents the sublimit of each borrower. Certain sublimits were reallocated in May 2017 to provide additional liquidity to certain borrowers in light of near-term funding needs.

(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.

7. GOODWILL AND INTANGIBLE ASSETS

GOODWILL

Duke Energy

The following table presents the goodwill by reportable operating segment on Duke Energy's Condensed Consolidated Balance Sheets at March 31, 2017 and December 31, 2016.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables		Total
Goodwill	$	17,379	$	1,924	$	122	$	19,425

Duke Energy Ohio

Duke Energy Ohio's Goodwill balance of $920 million, allocated $596 million to Electric Utilities and Infrastructure and $324 million to Gas Utilities and Infrastructure, is presented net of accumulated impairment charges of $216 million on the Condensed Consolidated Balance Sheets at March 31, 2017 and December 31, 2016.

Progress Energy

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

Piedmont

Piedmont's Goodwill is included in the Gas Utilities and Infrastructure operating segment and there are no accumulated impairment charges. Effective November 1, 2016, Piedmont's fiscal year was changed from October 31 to December 31. Effective with this change, Piedmont changed the date of their annual impairment testing of goodwill from October 31 to August 31 to align with the other Duke Energy Registrants.

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

61

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 the year ended December 31, 2016 for more information regarding money pool. The net impact of these transactions was not material for the three months ended March 31, 2017 and 2016, 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.

Equity Method Investments

Piedmont has related party transactions as a customer of its equity method investments in natural gas storage and transportation facilities. Below are expenses for the three months ended March 31, 2017 and 2016, which are included in Operating Expenses – Cost of natural gas on Piedmont's Condensed Consolidated Statement of Operations and Comprehensive Income.

		Three Months Ended March 31,
(in millions)	Type of expense	2017		2016
Cardinal	Transportation Costs	$	2	$	2
Pine Needle	Gas Storage Costs	2		3
Hardy Storage	Gas Storage Costs	2		2
Total		$	6	$	7

In association with these transactions, Piedmont has accounts payable to its equity method investments of $2 million at March 31, 2017, and December 31, 2016. These amounts are included in Accounts payable on the Condensed Consolidated Balance Sheets.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

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. Piedmont enters into gas supply contracts to provide diversification, reliability and gas cost benefits to their customers. 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.

62

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 impacts 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 AOCI for the three months ended March 31, 2017, were not material. Duke Energy's interest rate derivatives designated as hedges include interest rate swaps used to hedge existing debt within the Commercial Renewables business.

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 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 March 31, 2016, Duke Energy entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure related to the Piedmont acquisition financing. The swaps did not qualify for hedge accounting and were marked-to-market, with any gains or losses included within earnings. For the three months ended March 31, 2016, unrealized losses on the swaps of $93 million were included within Interest Expense on Duke Energy's Condensed Consolidated Statements of Operations. The swaps were unwound in August 2016 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 as of March 31, 2017 and December 31, 2016.

			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	750	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	927		400		500		250		250		27
Total notional amount	$	1,677	$	400	$	500	$	250	$	250	$	27

(a)    Duke Energy includes amounts related to consolidated VIEs of $750 million as of March 31, 2017 and December 31, 2016.

COMMODITY PRICE RISK

The Duke Energy Registrants are exposed to the impact of changes in the prices of electricity purchased and sold in bulk power markets and coal and natural gas purchases, including Piedmont's gas supply contracts. Exposure to commodity price risk is influenced by a number of factors including the term of contracts, the liquidity of markets and delivery locations. For the Subsidiary Registrants, bulk power electricity and coal and natural gas purchases flow through fuel adjustment clauses, formula based contracts or other cost sharing mechanisms. Differences between the costs included in rates and the incurred costs, including undesignated derivative contracts, are largely deferred as regulatory assets or regulatory liabilities. Piedmont policies allow for the use of financial instruments to hedge commodity price risks. The strategy and objective of these hedging programs are to use the financial instruments to reduce gas costs volatility for customers.

Volumes

The tables below include 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.

	March 31, 2017
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	184	—	—	—	—	184	—
Natural gas (millions of dekatherms)	817	85	228	105	123	—	504

	December 31, 2016
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	147	—	—	—	—	147	—
Natural gas (millions of dekatherms)	890	91	269	118	151	1	529

63

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	58	$	16	$	30	$	19	$	11	$	—	$	9	$	2
Noncurrent	5		1		2		1		1		1		—		—
Total Derivative Assets – Commodity Contracts	$	63	$	17	$	32	$	20	$	12	$	1	$	9	$	2
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	18	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	2		—		2		—		2		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	20	$	—	$	2	$	—	$	2	$	—	$	—	$	—
Total Derivative Assets	$	83	$	17	$	34	$	20	$	14	$	1	$	9	$	2

Derivative Liabilities	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	32	$	—	$	17	$	1	$	17	$	—	$	—	$	14
Noncurrent	145		4		11		4		1		—		—		131
Total Derivative Liabilities – Commodity Contracts	$	177	$	4	$	28	$	5	$	18	$	—	$	—	$	145
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	8	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	9		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		—		—		—		1		—		—
Noncurrent	21		10		6		5		1		4		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	39	$	10	$	6	$	5	$	1	$	5	$	—	$	—
Total Derivative Liabilities	$	216	$	14	$	34	$	10	$	19	$	5	$	—	$	145

64

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Derivative Assets	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	108	$	23	$	61	$	35	$	26	$	4	$	16	$	3
Noncurrent	32		10		21		10		11		1		—		—
Total Derivative Assets – Commodity Contracts	$	140	$	33	$	82	$	45	$	37	$	5	$	16	$	3
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	19	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	3		—		3		1		2		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	22	$	—	$	3	$	1	$	2	$	—	$	—	$	—
Total Derivative Assets	$	162	$	33	$	85	$	46	$	39	$	5	$	16	$	3

Derivative Liabilities	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	43	$	—	$	12	$	—	$	12	$	—	$	2	$	35
Noncurrent	166		1		7		1		—		—		—		152
Total Derivative Liabilities – Commodity Contracts	$	209	$	1	$	19	$	1	$	12	$	—	$	2	$	187
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	8	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	8		—		—		—		—		—		—		—
Not Designated as Hedging Instruments															—
Current	1		—		—		—		—		1		—		—
Noncurrent	26		15		6		6		—		5		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	43	$	15	$	6	$	6	$	—	$	6	$	—	$	—
Total Derivative Liabilities	$	252	$	16	$	25	$	7	$	12	$	6	$	2	$	187

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.

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Derivative Assets	March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	60		$	16		$	32		$	19		$	13		$	—	$	9	$	2
Gross amounts offset	(7		)	—			(7		)	(1		)	(6		)	—		—		—
Net amounts presented in Current Assets: Other	$	53		$	16		$	25		$	18		$	7		$	—	$	9	$	2
Noncurrent
Gross amounts recognized	$	23		$	1		$	2		$	1		$	1		$	1	$	—	$	—
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	21		$	—		$	1		$	—		$	1		$	1	$	—	$	—

Derivative Liabilities	March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	41		$	—		$	17		$	1		$	17		$	1	$	—	$	14
Gross amounts offset	(7		)	—			(7		)	(1		)	(6		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	34		$	—		$	10		$	—		$	11		$	1	$	—	$	14
Noncurrent
Gross amounts recognized	$	175		$	14		$	17		$	9		$	2		$	4	$	—	$	131
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	173		$	13		$	16		$	8		$	2		$	4	$	—	$	131

Derivative Assets	December 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	111		$	23		$	64		$	36		$	28		$	4	$	16	$	3
Gross amounts offset	(11		)	—			(11		)	—			(11		)	—		—		—
Net amounts presented in Current Assets: Other	$	100		$	23		$	53		$	36		$	17		$	4	$	16	$	3
Noncurrent
Gross amounts recognized	$	51		$	10		$	21		$	10		$	11		$	1	$	—	$	—
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	49		$	9		$	20		$	9		$	11		$	1	$	—	$	—

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Derivative Liabilities	December 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	52		$	—		$	12		$	—		$	12		$	1	$	2	$	35
Gross amounts offset	(11		)	—			(11		)	—			(11		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	41		$	—		$	1		$	—		$	1		$	1	$	2	$	35
Noncurrent
Gross amounts recognized	$	200		$	16		$	13		$	7		$	—		$	5	$	—	$	152
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	198		$	15		$	12		$	6		$	—		$	5	$	—	$	152

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, Duke Energy Indiana and Piedmont were not material.

	March 31, 2017
			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	$	40	$	14	$	25	$	9	$	17
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	40		14		25		9		17

	December 31, 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	$	34	$	16	$	18	$	6	$	12
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	34		16		18		6		12

The Duke Energy Registrants have elected to offset cash collateral and fair values of derivatives. For amounts to be netted, the derivative and cash collateral must be executed with the same counterparty under the same master netting arrangement.

10.INVESTMENTS IN DEBT AND EQUITY SECURITIES

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

TRADING SECURITIES

Piedmont's investments in debt and equity securities held in rabbi trusts associated with certain deferred compensation plans are classified as trading securities. The fair value of these investments was $5 million as of March 31, 2017 and December 31, 2016.

AVAILABLE-FOR-SALE SECURITIES

All other investments in debt and equity securities are classified 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.

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 OTTIs 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.

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 OTTI exists, the unrealized credit loss is included in earnings. There were no material credit losses as of March 31, 2017 and December 31, 2016.

DUKE ENERGY

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	114	$	—	$	—	$	111
Equity securities	2,250		32		4,284		2,092		54		4,106
Corporate debt securities	10		5		576		10		8		528
Municipal bonds	3		6		336		3		10		331
U.S. government bonds	10		8		949		10		8		984
Other debt securities	—		3		132		—		3		124
Total NDTF	$	2,273	$	54	$	6,391	$	2,115	$	83	$	6,184
Other Investments
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	25
Equity securities	44		—		106		38		—		104
Corporate debt securities	1		—		60		1		1		66
Municipal bonds	2		1		84		2		1		82
U.S. government bonds	—		—		43		—		1		51
Other debt securities	—		2		42		—		2		42
Total Other Investments(b)	$	47	$	3	$	353	$	41	$	5	$	370
Total Investments	$	2,320	$	57	$	6,744	$	2,156	$	88	$	6,554

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	82
Due after one through five years	640
Due after five through 10 years	514
Due after 10 years	986
Total	$	2,222

68

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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
	March 31,
(in millions)	2017		2016
Realized gains	$	93	$	54
Realized losses	62		50

DUKE ENERGY CAROLINAS

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	20	$	—	$	—	$	18
Equity securities	1,229		15		2,366		1,157		28		2,245
Corporate debt securities	5		4		388		5		6		354
Municipal bonds	1		1		67		1		2		67
U.S. government bonds	3		5		431		2		5		458
Other debt securities	—		3		120		—		3		116
Total NDTF	$	1,238	$	28	$	3,392	$	1,165	$	44	$	3,258
Other Investments
Other debt securities	$	—	$	1	$	3	$	—	$	1	$	3
Total Other Investments(b)	$	—	$	1	$	3	$	—	$	1	$	3
Total Investments	$	1,238	$	29	$	3,395	$	1,165	$	45	$	3,261

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	2
Due after one through five years	221
Due after five through 10 years	269
Due after 10 years	517
Total	$	1,009

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
	March 31,
(in millions)	2017		2016
Realized gains	$	66	$	34
Realized losses	40		37

69

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

PROGRESS ENERGY

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	94	$	—	$	—	$	93
Equity securities	1,021		17		1,918		935		26		1,861
Corporate debt securities	5		1		188		5		2		174
Municipal bonds	2		5		269		2		8		264
U.S. government bonds	7		3		518		8		3		526
Other debt securities	—		—		12		—		—		8
Total NDTF	$	1,035	$	26	$	2,999	$	950	$	39	$	2,926
Other Investments
Cash and cash equivalents	$	—	$	—	$	12	$	—	$	—	$	21
Municipal bonds	2		—		46		2		—		44
Total Other Investments(b)	$	2	$	—	$	58	$	2	$	—	$	65
Total Investments	$	1,037	$	26	$	3,057	$	952	$	39	$	2,991

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	72
Due after one through five years	355
Due after five through 10 years	189
Due after 10 years	417
Total	$	1,033

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
	March 31,
(in millions)	2017		2016
Realized gains	$	27	$	19
Realized losses	21		13

70

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

DUKE ENERGY PROGRESS

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	43	$	—	$	—	$	45
Equity securities	772		13		1,541		704		21		1,505
Corporate debt securities	4		1		131		4		1		120
Municipal bonds	2		5		268		2		8		263
U.S. government bonds	5		2		284		5		2		275
Other debt securities	—		—		7		—		—		5
Total NDTF	$	783	$	21	$	2,274	$	715	$	32	$	2,213
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	1
Total Other Investments(b)	$	—	$	—	$	1	$	—	$	—	$	1
Total Investments	$	783	$	21	$	2,275	$	715	$	32	$	2,214

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	17
Due after one through five years	215
Due after five through 10 years	142
Due after 10 years	316
Total	$	690

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
	March 31,
(in millions)	2017		2016
Realized gains	$	24	$	15
Realized losses	19		11

71

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

DUKE ENERGY FLORIDA

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	51	$	—	$	—	$	48
Equity securities	249		4		377		231		5		356
Corporate debt securities	1		—		57		1		1		54
Municipal bonds	—		—		1		—		—		1
U.S. government bonds	2		1		234		3		1		251
Other debt securities	—		—		5		—		—		3
Total NDTF(b)	$	252	$	5	$	725	$	235	$	7	$	713
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	4
Municipal bonds	2		—		46		2		—		44
Total Other Investments(c)	$	2	$	—	$	47	$	2	$	—	$	48
Total Investments	$	254	$	5	$	772	$	237	$	7	$	761

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) During the three months endedMarch 31, 2017, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing commissioning activity of the Crystal River Unit 3 nuclear plant.

(c) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	55
Due after one through five years	140
Due after five through 10 years	47
Due after 10 years	101
Total	$	343

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
	March 31,
(in millions)	2017		2016
Realized gains	$	3	$	4
Realized losses	2		2

72

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

DUKE ENERGY INDIANA

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
Other Investments
Equity securities	$	38	$	—	$	84	$	33	$	—	$	79
Corporate debt securities	—		—		2		—		—		2
Municipal bonds	—		1		28		—		1		28
U.S. government bonds	—		—		1		—		—		1
Total Other Investments(b)	$	38	$	1	$	115	$	33	$	1	$	110
Total Investments	$	38	$	1	$	115	$	33	$	1	$	110

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	2
Due after one through five years	15
Due after five through 10 years	9
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 months ended March 31, 2017 and 2016.

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 that 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.

73

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 months endedMarch 31, 2017 and 2016.

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 New York Stock Exchange (NYSE) and Nasdaq Stock Market. 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, including Piedmont's gas supply contracts, are primarily valued using internally developed discounted cash flow models that incorporate forward price, adjustments for liquidity (bid-ask spread) and credit or non-performance risk (after reflecting credit enhancements such as collateral), and are discounted to present value. Pricing inputs are derived from published exchange transaction prices and other observable data sources. In the absence of an active market, the last available price may be used. If forward price curves are not observable for the full term of the contract and the unobservable period had more than an insignificant impact on the valuation, the commodity derivative is classified as Level 3. In isolation, increases (decreases) in natural gas forward prices result in favorable (unfavorable) fair value adjustments for gas purchase contracts; and increases (decreases) in electricity forward prices result in unfavorable (favorable) fair value adjustments for electricity sales contracts. Duke Energy regularly evaluates and validates pricing inputs used to estimate the fair value of gas commodity contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.

Interest rate derivatives

Most over-the-counter interest rate contract derivatives are valued using financial models that 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.

Other fair value considerations

See Note 2 related to the acquisition of Piedmont in 2016. See Note 11 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2016 for a discussion of the valuation of goodwill and intangible assets.

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3			Not categorized
Nuclear decommissioning trust fund equity securities	$	4,284		$	4,207	$	—		$	—		$	77
Nuclear decommissioning trust fund debt securities	2,107			602		1,505			—			—
Other trading and available-for-sale equity securities	110			110		—			—			—
Other trading and available-for-sale debt securities	248			61		182			5			—
Derivative assets	83			2		71			10			—
Total assets	6,832			4,982		1,758			15			77
Derivative liabilities	(216		)	—		(71		)	(145		)	—
Net assets (liabilities)	$	6,616		$	4,982	$	1,687		$	(130	)	$	77

74

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

	December 31, 2016
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not categorized
Nuclear decommissioning trust fund equity securities	$	4,106		$	4,029		$	—		$	—		$	77
Nuclear decommissioning trust fund debt securities	2,078			632			1,446			—			—
Other trading and available-for-sale equity securities	104			104			—			—			—
Other trading and available-for-sale debt securities	266			75			186			5			—
Derivative assets	162			5			136			21			—
Total assets	6,716			4,845			1,768			26			77
Derivative liabilities	(252		)	(2		)	(63		)	(187		)	—
Net assets (liabilities)	$	6,464		$	4,843		$	1,705		$	(161	)	$	77

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

	Three Months Ended March 31, 2017
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	5	$	(166	)	$	(161	)
Purchases, sales, issuances and settlements:
Settlements	—		(9		)	(9		)
Total amount included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		40			40
Balance at end of period	$	5	$	(135	)	$	(130	)

	Three Months Ended March 31, 2016
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	5		$	10		$	15
Purchases, sales, issuances and settlements:
Sales	(1		)	—			(1		)
Settlements	—			(7		)	(7		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—			(1		)	(1		)
Balance at end of period	$	4		$	2		$	6

75

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,366		$	2,289	$	—		$	—	$	77
Nuclear decommissioning trust fund debt securities	1,026			146		880			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	17			—		17			—		—
Total assets	3,412			2,435		897			3		77
Derivative liabilities	(14		)	—		(14		)	—		—
Net assets	$	3,398		$	2,435	$	883		$	3	$	77

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,245		$	2,168	$	—		$	—	$	77
Nuclear decommissioning trust fund debt securities	1,013			178		835			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	33			—		33			—		—
Total assets	3,294			2,346		868			3		77
Derivative liabilities	(16		)	—		(16		)	—		—
Net assets	$	3,278		$	2,346	$	852		$	3	$	77

There was no change to the Level 3 balance during the three months ended March 31, 2017 and March 31, 2016.

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,918		$	1,918	$	—
Nuclear decommissioning trust fund debt securities	1,081			456		625
Other available-for-sale debt securities	58			12		46
Derivative assets	34			—		34
Total assets	3,091			2,386		705
Derivative liabilities	(34		)	—		(34		)
Net assets	$	3,057		$	2,386	$	671

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,861		$	1,861	$	—
Nuclear decommissioning trust fund debt securities	1,065			454		611
Other available-for-sale debt securities	65			21		44
Derivative assets	85			—		85
Total assets	3,076			2,336		740
Derivative liabilities	(25		)	—		(25		)
Net assets	$	3,051		$	2,336	$	715

76

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,541		$	1,541	$	—
Nuclear decommissioning trust fund debt securities and other	733			221		512
Other available-for-sale debt securities and other	1			1		—
Derivative assets	20			—		20
Total assets	2,295			1,763		532
Derivative liabilities	(10		)	—		(10		)
Net assets	$	2,285		$	1,763	$	522

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,505		$	1,505	$	—
Nuclear decommissioning trust fund debt securities and other	708			207		501
Other available-for-sale debt securities and other	1			1		—
Derivative assets	46			—		46
Total assets	2,260			1,713		547
Derivative liabilities	(7		)	—		(7		)
Net assets	$	2,253		$	1,713	$	540

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	377		$	377	$	—
Nuclear decommissioning trust fund debt securities and other	348			235		113
Other available-for-sale debt securities and other	47			1		46
Derivative assets	14			—		14
Total assets	786			613		173
Derivative liabilities	(19		)	—		(19		)
Net assets	$	767		$	613	$	154

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	356		$	356	$	—
Nuclear decommissioning trust fund debt securities and other	357			247		110
Other available-for-sale debt securities and other	48			4		44
Derivative assets	39			—		39
Total assets	800			607		193
Derivative liabilities	(12		)	—		(12		)
Net assets	$	788		$	607	$	181

77

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	1		$	—	$	—		$	1
Derivative liabilities	(5		)	—		(5		)	—
Net (liabilities) assets	$	(4	)	$	—	$	(5	)	$	1

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	5		$	—	$	—		$	5
Derivative liabilities	(6		)	—		(6		)	—
Net (liabilities) assets	$	(1	)	$	—	$	(6	)	$	5

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	5		$	3
Purchases, sales, issuances and settlements:
Settlements	(1		)	(2		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(3		)	(1		)
Balance at end of period	$	1		$	—

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.

	March 31, 2017
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Other available-for-sale equity securities	$	84	$	84	$	—	$	—
Other available-for-sale debt securities and other	31		—		31		—
Derivative assets	9		—		—		9
Net assets	$	124	$	84	$	31	$	9

	December 31, 2016
(in millions)	Total Fair Value			Level 1			Level 2		Level 3
Other available-for-sale equity securities	$	79		$	79		$	—	$	—
Other available-for-sale debt securities and other	31			—			31		—
Derivative assets	16			—			—		16
Total assets	126			79			31		16
Derivative liabilities	(2		)	(2		)	—		—
Net assets	$	124		$	77		$	31	$	16

78

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	16		$	7
Purchases, sales, issuances and settlements:
Settlements	(7		)	(5		)
Balance at end of period	$	9		$	2

PIEDMONT

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. See Note 10 for additional information related to investments.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 3
Other trading equity securities	4			4		—
Other trading debt securities	1			1		—
Derivative assets	2			2		—
Total assets	7			7		—
Derivative liabilities	(145		)	—		(145		)
Net (liabilities) assets	$	(138	)	$	7	$	(145	)

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 3
Other trading equity securities	$	4		$	4	$	—
Other trading debt securities	1			1		—
Derivative assets	3			3		—
Total assets	8			8		—
Derivative liabilities	(187		)	—		(187		)
Net (liabilities) assets	$	(179	)	$	8	$	(187	)

79

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	(187	)	$	(149	)
Total gains and settlements	42			23
Balance at end of period	$	(145	)	$	(126	)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

	March 31, 2017
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
Financial Transmission Rights (FTRs)	$	1		RTO auction pricing	FTR price – per megawatt-hour (MWh)	$	0.23		-	$	2.02
Duke Energy Indiana
FTRs	9			RTO auction pricing	FTR price – per MWh	(1.08		)	-	5.33
Piedmont
Natural gas contracts	(145		)	Discounted cash flow	Forward natural gas curves – price per million British thermal unit (MMBtu)	2.08			-	3.57
Duke Energy
Total Level 3 derivatives	$	(135	)

	December 31, 2016
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
FTRs	$	5		RTO auction pricing	FTR price – per MWh	$	0.77		-	$	3.52
Duke Energy Indiana
FTRs	16			RTO auction pricing	FTR price – per MWh	(0.83		)	-	9.32
Piedmont
Natural gas contracts	(187		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	2.31			-	4.18
Duke Energy
Total Level 3 derivatives	$	(166	)

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.

	March 31, 2017				December 31, 2016
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy	$	48,998	$	50,480	$	47,895	$	49,161
Duke Energy Carolinas	9,491		10,405		9,603		10,494
Progress Energy	18,148		19,742		17,541		19,107
Duke Energy Progress	6,761		7,103		7,011		7,357
Duke Energy Florida	6,981		7,596		6,125		6,728
Duke Energy Ohio	1,977		2,122		1,884		2,020
Duke Energy Indiana	3,784		4,292		3,786		4,260
Piedmont	1,821		1,954		1,821		1,933

80

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

At both March 31, 2017 and December 31, 2016, fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper, and nonrecourse 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 three months ended March 31, 2017 and the year ended December 31, 2016, 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, natural gas 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.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
(in millions)	CRC		DERF		DEPR		DEFR
Expiration date	December 2018		December 2018		February 2019		April 2019
Credit facility amount	$	325	$	425	$	300	$	225
Amounts borrowed at March 31, 2017	325		425		300		225
Amounts borrowed at December 31, 2016	325		425		300		225

81

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

Nuclear Asset-Recovery Bonds – DEFPF

Duke Energy Florida Project Finance, LLC (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 Note 4.

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)	March 31, 2017		December 31, 2016
Receivables of VIEs	$	4	$	6
Current Assets: Regulatory assets	53		50
Current Assets: Other	14		53
Other Noncurrent Assets: Regulatory assets	1,131		1,142
Current Liabilities: Other	3		17
Current maturities of long-term debt	55		62
Long-Term Debt	1,189		1,217

Commercial Renewables

Certain of Duke Energy’s renewable energy facilities are VIEs due to Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. Assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders. The activities that most significantly impact the economic performance of these renewable energy facilities were decisions associated with siting, negotiating PPAs, 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)	March 31, 2017			December 31, 2016
Current Assets: Other	$	336		$	223
Property, plant and equipment, cost	3,671			3,419
Accumulated depreciation and amortization	(448		)	(453		)
Current maturities of long-term debt	227			198
Long-Term Debt	1,645			1,097
Deferred income taxes	321			275
Other Noncurrent Liabilities: Other	251			252

82

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

NON-CONSOLIDATED VIEs

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

	March 31, 2017
	Duke Energy										Duke		Duke
	Pipeline			Commercial		Other					Energy		Energy
(in millions)	Investments			Renewables		VIEs		Total			Ohio		Indiana		Piedmont
Receivables from affiliated companies	$	—		$	—	$	—	$	—		$	53	$	69	$	—
Investments in equity method unconsolidated affiliates	673			173		92		938			—		—		152
Other noncurrent assets	12			—		—		12			—		—		—
Total assets	$	685		$	173	$	92	$	950		$	53	$	69	$	152
Taxes accrued(a)	23			—		—		23			—		—		(1		)
Other current liabilities	—			—		2		2			—		—		—
Deferred income taxes(a)	(7		)	—		—		(7		)	—		—		4
Other noncurrent liabilities	—			—		13		13			—		—		—
Total liabilities	$	16		$	—	$	15	$	31		$	—	$	—	$	3
Net assets	$	669		$	173	$	77	$	919		$	53	$	69	$	149

(a) Taxes accrued and Deferred income taxes are netted by jurisdiction on a consolidated basis on the Condensed Consolidated Balance Sheets.

	December 31, 2016
	Duke Energy								Duke		Duke
	Pipeline		Commercial		Other				Energy		Energy
(in millions)	Investments		Renewables		VIEs		Total		Ohio		Indiana		Piedmont
Receivables from affiliated companies	$	—	$	—	$	—	$	—	$	82	$	101	$	—
Investments in equity method unconsolidated affiliates	487		174		90		751		—		—		139
Other noncurrent assets	12		—		—		12		—		—		—
Total assets	$	499	$	174	$	90	$	763	$	82	$	101	$	139
Other current liabilities	—		—		3		3		—		—		—
Other noncurrent liabilities	—		—		13		13		—		—		4
Total liabilities	$	—	$	—	$	16	$	16	$	—	$	—	4
Net assets	$	499	$	174	$	74	$	747	$	82	$	101	$	135

The Duke Energy Registrants are not aware of any situations where the maximum exposure to loss significantly exceeds the carrying values shown above except for the power purchase agreement with OVEC, which is discussed below, and various guarantees, some of which are reflected in the table above as Other noncurrent liabilities. For more information on various guarantees, refer to Note 5.

Pipeline Investments

Duke Energy has investments in various joint ventures with pipeline projects currently under construction. These entities are considered VIEs due to having insufficient equity to finance their own activities without subordinated financial support. Duke Energy does not have the power to direct the activities that most significantly impact the economic performance, the obligation to absorb losses or the right to receive benefits of these VIEs and therefore does not consolidate these entities.

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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

The table below presents the ownership interest and investment balances in these joint ventures.

	Duke Energy						Piedmont
			Investment Amount (in millions)						Investment Amount (in millions)
	Ownership		March 31,		December 31,		Ownership		March 31,		December 31,
Entity Name	Interest		2017		2016		Interest(a)		2017		2016
ACP	47	%	$	403	$	265	7	%	$	59	$	46
Sabal Trail	7.5	%	188		140
Constitution(b)	24	%	82		82		24	%	93		93
Total			$	673	$	487			$	152	$	139

(a) On April 1, 2017, Piedmont transferred its ownership interests in ACP and Constitution to a wholly owned subsidiary of Duke Energy at Piedmont's book value.

(b) Duke Energy's investment amount includes purchase accounting adjustments not recorded at the Piedmont registrant.

Commercial Renewables

Duke Energy has investments in various renewable energy project entities. Some of these entities are VIEs due to Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. 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 VIEs

Duke Energy holds a 50 percent equity interest in Duke-American Transmission Company, LLC (DATC). DATC is considered a VIE due to having insufficient equity to finance their own activities without subordinated financial support. The activities that most significantly impact DATC's economic performance are 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, American Transmission Company, LLC, therefore Duke Energy does not consolidate DATC.

Duke Energy holds a 50 percent equity interest in Pioneer Transmission, LLC (Pioneer). Pioneer is considered a VIE due to having insufficient equity to finance their own activities without subordinated financial support. The activities that most significantly impact Pioneer's economic performance are decisions related to the 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, American Electric Power, therefore Duke Energy does not consolidate Pioneer.

OVEC

Duke Energy Ohio’s 9 percent ownership interest in OVEC is considered a non-consolidated VIE due to having insufficient equity to finance their activities without subordinated financial support. As a counterparty to an inter-company power agreement (ICPA), Duke Energy Ohio has a contractual arrangement to receive entitlements to capacity and energy from OVEC’s power plants through June 2040 commensurate with its power participation ratio, which is equivalent to Duke Energy Ohio's ownership interest. Costs, including fuel, operating expenses, fixed costs, debt amortization, and interest expense are allocated to counterparties to the ICPA based on their power participation ratio. The value of the ICPA is subject to variability due to fluctuation in power prices and changes in OVEC's cost of business, including costs associated with its 2,256 MW of coal-fired generation capacity. Deterioration in the credit quality, or bankruptcy of one or more parties to the ICPA could increase the costs of OVEC. In addition, certain proposed environmental rulemaking could result in future increased cost allocations.

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 OTTI has occurred.

Key assumptions used in estimating fair value are detailed in the following table.

	Duke Energy Ohio				Duke Energy Indiana
	2017		2016		2017		2016
Anticipated credit loss ratio	0.5	%	0.5	%	0.3	%	0.3	%
Discount rate	1.8	%	1.5	%	1.8	%	1.5	%
Receivable turnover rate	13.4	%	13.3	%	10.7	%	10.6	%

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Receivables sold	$	238	$	267	$	277	$	306
Less: Retained interests	53		82		69		101
Net receivables sold	$	185	$	185	$	208	$	205

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

	Duke Energy Ohio				Duke Energy Indiana
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(in millions)	2017		2016		2017		2016
Sales
Receivables sold	$	533	$	532	$	664	$	635
Loss recognized on sale	2		3		3		3
Cash flows
Cash proceeds from receivables sold	$	559	$	537	$	693	$	643
Return received on retained interests	1		1		2		1

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 shares 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 shares outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as stock options and equity forward sale agreements, 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 shares outstanding to the diluted weighted average number of common shares outstanding.

	Three Months Ended March 31,
(in millions, except per share amounts)	2017		2016
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	715	$	574
Weighted average shares outstanding – basic	700		689
Weighted average shares outstanding – diluted	700		689
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	1.02	$	0.83
Diluted	$	1.02	$	0.83
Potentially dilutive items excluded from the calculation(a)	2		2
Dividends declared per common share	$	0.855	$	0.825

(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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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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 forward sale agreements with Barclays (the Equity Forwards). The Equity Forwards required Duke Energy to either physically settle the transactions by issuing 10.6 million shares, or net settle in whole or in part through the delivery or receipt of cash or shares. As of March 31, 2016, share dilution resulting from the agreements was determined under the treasury stock method.

Duke Energy physically settled the Equity Forwards in full in October 2016 following the close of the Piedmont acquisition. See Note 2 for additional information related to the Piedmont acquisition.

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
	March 31,
(in millions)	2017		2016
Restricted stock unit awards	$	8	$	7
Performance awards	7		5
Pretax stock-based compensation cost	$	15	$	12
Tax benefit associated with stock-based compensation expense	$	5	$	4
Stock-based compensation costs capitalized	1		1

Prior to Duke Energy acquiring Piedmont, Piedmont had an incentive compensation plan for eligible officers and other participants. Piedmont's total stock-based compensation costs were approximately $2 million for the three months ended March 31, 2016.

15. EMPLOYEE BENEFIT PLANS

DEFINED BENEFIT RETIREMENT PLANS

Duke Energy maintains, and the Subsidiary Registrants participate in, qualified and non-qualified, non-contributory defined benefit retirement plans. Duke Energy’s policy is to fund amounts on an actuarial basis to provide assets sufficient to meet benefit payments to be paid to plan participants. Duke Energy did not make any contributions to its U.S. qualified defined benefit pension plans during the three months ended March 31, 2017 and 2016.

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

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC – PIEDMONT NATURAL GAS COMPANY, INC.

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

QUALIFIED PENSION PLANS

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

	Three Months Ended March 31, 2017
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	40		$	12		$	12		$	6		$	5		$	1		$	2		$	3
Interest cost on projected benefit obligation	82			20			25			12			13			5			7			3
Expected return on plan assets	(136		)	(35		)	(43		)	(21		)	(21		)	(7		)	(11		)	(6		)
Amortization of actuarial loss	36			8			14			6			7			1			3			3
Amortization of prior service credit	(6		)	(2		)	(1		)	—			—			—			—			(1		)
Other	2			—			1			—			—			—			—			—
Net periodic pension costs	$	18		$	3		$	8		$	3		$	4		$	—		$	1		$	2

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	36		$	12		$	11		$	6		$	5		$	1		$	2		$	3
Interest cost on projected benefit obligation	83			21			26			12			14			5			7			2
Expected return on plan assets	(129		)	(35		)	(42		)	(21		)	(21		)	(7		)	(10		)	(6		)
Amortization of actuarial loss	33			8			14			6			7			1			3			2
Amortization of prior service credit	(4		)	(2		)	(1		)	—			—			—			—			—
Other	3			1			1			—			—			—			—			—
Net periodic pension costs	$	22		$	5		$	9		$	3		$	5		$	—		$	2		$	1

NON-QUALIFIED PENSION PLANS

Net periodic costs for non-qualified pension plans were not material for the three months ended March 31, 2017 and 2016.

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.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

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

	Three Months Ended March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Service cost	$	1		$	—		$	—		$	—		$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			4			2			2			—		—		—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—		—
Amortization of actuarial loss (gain)	2			(1		)	5			3			2			—		—		—
Amortization of prior service credit	(29		)	(2		)	(21		)	(14		)	(8		)	—		—		—
Net periodic other post-retirement benefit	$	(20	)	$	(3	)	$	(12	)	$	(9	)	$	(4	)	$	—	$	—	$	—

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana			Piedmont
Service cost	$	1		$	—		$	—		$	—		$	—		$	—	$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	8			2			4			2			2			—		1			—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—			—
Amortization of actuarial loss (gain)	1			(1		)	5			3			2			—		(1		)	—
Amortization of prior service credit	(35		)	(3		)	(26		)	(17		)	(9		)	—		—			—
Net periodic other post-retirement benefit	$	(28	)	$	(4	)	$	(17	)	$	(12	)	$	(5	)	$	—	$	—		$	—

DEFINED CONTRIBUTION RETIREMENT PLANS

EMPLOYEE SAVINGS PLAN

Duke Energy sponsors, and the Subsidiary Registrants participate in, employee savings plans that cover substantially all U.S. employees.

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		Piedmont
Three Months Ended March 31,
2017	$	65	$	22	$	18	$	13	$	5	$	1	$	3	$	2
2016	52		18		15		11		4		1		2		2

MONEY PURCHASE PENSION PLAN

Duke Energy provides, and Piedmont participates in, the Money Purchase Pension (MPP) plan, which is a defined contribution pension plan that allows employees to direct investments and assume risk of investment returns. In January 2017, a $2 million contribution was made to the MPP plan.

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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 – PIEDMONT NATURAL GAS COMPANY, INC.

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

16. INCOME TAXES

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
	March 31,
	2017		2016
Duke Energy	32.4	%	30.4	%
Duke Energy Carolinas	35.4	%	34.1	%
Progress Energy	34.1	%	36.7	%
Duke Energy Progress	34.1	%	35.4	%
Duke Energy Florida	36.6	%	37.9	%
Duke Energy Ohio	35.4	%	26.9	%
Duke Energy Indiana	39.3	%	30.2	%
Piedmont	37.9	%	38.0	%

The increase in the effective tax rate (ETR) for Duke Energy for the three months ended March 31, 2017, is primarily due to lower investment tax credits due to lower solar investments in the current year, the inclusion of Piedmont's earnings at a higher ETR, and a tax charge related to the implementation of a new accounting standard related to stock compensation; partially offset by higher production tax credits related to wind projects placed in service. See Note 1 for additional information on the new accounting standard.

The increase in the ETR for Duke Energy Carolinas for the three months ended March 31, 2017, is primarily due to a favorable state resolution booked in 2016 related to prior year tax returns.

The decrease in the ETR for Progress Energy for the three months ended March 31, 2017, is primarily due to higher AFUDC equity and the amortization of excess North Carolina deferred tax.

The decrease in the ETR for Duke Energy Progress for the three months ended March 31, 2017, is primarily due to the amortization of excess North Carolina deferred tax.

The decrease in the ETR for Duke Energy Florida for the three months ended March 31, 2017, is primarily due to higher AFUDC equity.

The increase in the ETR for Duke Energy Ohio for the three months ended March 31, 2017, is primarily due to an immaterial out of period adjustment in the prior year related to deferred tax balances associated with property, plant and equipment.

The increase in the ETR for Duke Energy Indiana for the three months ended March 31, 2017, is primarily due to an immaterial out of period adjustment in the prior year related to deferred tax balances associated with property, plant and equipment.

TAXES ON FOREIGN EARNINGS

As of December 31, 2015, Duke Energy's intention was to indefinitely reinvest any future undistributed foreign earnings earned after December 31, 2014. In February 2016, Duke Energy announced it had initiated a process to divest the International Disposal Group and, accordingly, no longer intended to indefinitely reinvest post-2014 undistributed foreign earnings. This change in the company's intent, combined with the extension of bonus depreciation by Congress in late 2015, allowed Duke Energy to more efficiently utilize foreign tax credits and reduce U.S. deferred tax liabilities associated with historical unremitted foreign earnings by approximately $95 million for the three months endedMarch 31, 2016. Due to the classification of the International Disposal Group as discontinued operations, income tax amounts related to the International Disposal Group's foreign earnings are presented within Income from Discontinued Operations, net of tax on the Condensed Consolidated Statements of Operations. See Note 2 for additional information related to the sale of the International Disposal Group.

17. SUBSEQUENT EVENTS

For information on additional subsequent events related to regulatory matters, commitments and contingencies, debt and credit facilities, and variable interest entities see Notes 4, 5, 6 and 12, respectively.

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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), Duke Energy Indiana, LLC (Duke Energy Indiana) and Piedmont Natural Gas Company, Inc. (Piedmont) (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, Duke Energy Indiana and Piedmont. 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. Piedmont's results of operations are included in Duke Energy's results for the three months ended March 31, 2017, but not for the three months endedMarch 31, 2016, as Piedmont's earnings are only included in Duke Energy's consolidated results subsequent to the acquisition date. See below for additional information regarding the acquisition.

Management’s Discussion and Analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes for the three months ended March 31, 2017, and with Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2016, Piedmont's Annual Report on Form 10-K for the year ended October 31, 2016, and the transition report filed by Piedmont on Form 10-Q (Form 10-QT) as of December 31, 2016, for the transition period from November 1, 2016 to December 31, 2016.

Executive Overview

Acquisition of Piedmont Natural Gas

On October 3, 2016, Duke Energy completed the acquisition of Piedmont for a total cash purchase price of $5.0 billion and assumed Piedmont's existing long-term debt, which had a fair value of approximately $2.0 billion at the time of the acquisition. The acquisition provides a foundation for Duke Energy to establish a broader, long-term strategic natural gas infrastructure platform to complement its existing natural gas pipeline investments and regulated natural gas business in the Midwest.

Duke Energy incurred pretax nonrecurring transaction and integration costs associated with the acquisition of $16 million and $101 million for the three months ended March 31, 2017 and 2016, respectively. The 2016 amount includes $100 million of Interest Expense, which was driven by unrealized losses on forward-starting interest rate swaps related to the acquisition financing. Duke Energy expects to incur system integration and other acquisition-related transition costs, primarily through 2018, that are necessary to achieve certain anticipated cost savings, efficiencies and other benefits. See Note 2 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions," for additional information regarding the transaction.

Sale of International Energy

In December 2016, Duke Energy sold its Latin American generation businesses (International Disposal Group) in two separate transactions for a combined enterprise value of $2.4 billion. Duke Energy sold its Brazilian business to China Three Gorges for approximately $1.2 billion, including the assumption of debt, and its remaining Central and South American businesses to I Squared Capital in a deal also valued at approximately $1.2 billion, including the assumption of debt. The transactions generated cash proceeds of $1.9 billion, excluding transaction costs, which were primarily used to reduce Duke Energy holding company debt. Existing favorable tax attributes resulted in no immediate U.S. federal-level cash tax impacts.

Due to the transactions, results of the International Disposal Group are classified as discontinued operations. See Note 2 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions" for additional information.

Results of Operations

Non-GAAP Measures

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. 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. 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 may not be comparable to similarly titled measures used by other companies because other companies may not calculate the measures in the same manner.

Duke Energy management evaluates financial performance in part based on non-GAAP financial measures, including adjusted earnings and adjusted diluted EPS. Adjusted earnings and adjusted diluted EPS represent income from continuing operations attributable to Duke Energy, adjusted for the dollar and per share impact of special items. As discussed below, special items represent certain charges and credits, which management believes are not indicative of Duke Energy's ongoing performance.

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Management believes the presentation of adjusted earnings and adjusted diluted EPS provides useful information to investors, as it provides them with 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 financial results to the Duke Energy Board of Directors, employees, stockholders, analysts and investors. 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 (GAAP Reported Earnings) and Diluted EPS Attributable to Duke Energy Corporation common stockholders (GAAP Reported EPS), respectively.

Special items included in the periods presented include the following items, which management believes do not reflect ongoing costs:

• Costs to Achieve Mergers represent charges that result from strategic acquisitions.

• Cost Savings Initiatives represents severance charges related to company-wide initiatives, excluding merger integration, to standardize processes and systems, leverage technology and workforce optimization.

Adjusted earnings also include operating results of the International Disposal Group, which have been classified as discontinued operations. Management believes inclusion of the operating results of the Disposal Group within adjusted earnings and adjusted diluted EPS results in a better reflection of Duke Energy's financial performance during the period.

Reconciliation of GAAP Reported Amounts to Adjusted Amounts

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

	Three Months Ended March 31,
	2017				2016
(in millions, except per-share amounts)	Earnings		EPS		Earnings			EPS
GAAP Reported Earnings/GAAP Reported EPS	$	716	$	1.02	$	694		$	1.01
Adjustments to Reported:
Costs to Achieve Mergers(a)	10		0.02		74			0.11
Cost Savings Initiatives(b)	—		—		12			0.02
Discontinued Operations(c)	—		—		(3		)	(0.01		)
Adjusted Earnings/Adjusted Diluted EPS	$	726	$	1.04	$	777		$	1.13

(a) Net of tax of $6 million in 2017 and $46 million in 2016.

(b) Net of tax of $8 million in 2016.

(c) The 2016 amount represents GAAP reported Income from Discontinued Operations, less the International Disposal Group operating results, which are included in adjusted earnings.

Three Months Ended March 31, 2017 as compared to March 31, 2016

GAAP Reported EPS was $1.02 for the first quarter of 2017 compared to $1.01 for the first quarter of 2016. The increase in GAAP Reported EPS was driven by the inclusion of Piedmont's earnings, lower costs to achieve mergers including losses in the prior year on forward-starting interest rate swaps related to the Piedmont acquisition financing, as well as lower operations and maintenance expense at Electric Utilities and Infrastructure; partially offset by warm winter weather in the current year and the absence of the International Disposal Group's earnings.

As discussed above, management also evaluates financial performance based on adjusted diluted EPS. Duke Energy’s first quarter 2017 adjusted diluted EPS was $1.04 compared to $1.13 for the first quarter of 2016.

The decrease in adjusted earnings for the three months endedMarch 31, 2017, compared to the same period in 2016, was primarily due to:

• The prior year operating results of the International Disposal Group, which was sold in December 2016. The 2016 operating results included a benefit from the revaluation of deferred income taxes. See Note 16 to the Condensed Consolidated Financial Statements, "Income Taxes," for additional information; and

• Lower regulated electric revenues due to warm winter weather in the current year.

Partially offset by:

• Piedmont's earnings contribution, net of financing costs, due to the acquisition on October 3, 2016;

• Lower operations and maintenance expense at Electric Utilities and Infrastructure due to ongoing cost efficiency efforts and significant storm costs in the prior year; and

• Higher regulated electric revenues from increased pricing and riders driven by new rates in DEP South Carolina, base rate adjustments in Florida, and energy efficiency rider revenues in North Carolina, as well as growth in retail volumes.

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SEGMENT RESULTS

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.

Due to the Piedmont acquisition and the sale of International Energy in the fourth quarter of 2016, Duke Energy's segment structure has been realigned to include the following segments: Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables. The remainder of Duke Energy’s operations is presented as Other. Prior period information has been recast to conform to the current segment structure. See Note 2 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions," for further information on the Piedmont acquisition and International Energy sale and Note 3, “Business Segments,” for additional information on Duke Energy’s segments.

Electric Utilities and Infrastructure

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues	$	4,947	$	5,089	$	(142	)
Operating Expenses
Fuel used in electric generation and purchased power	1,454		1,577		(123		)
Operation, maintenance and other	1,271		1,298		(27		)
Depreciation and amortization	737		709		28
Property and other taxes	261		262		(1		)
Impairment charges	—		2		(2		)
Total operating expenses	3,723		3,848		(125		)
Gains on Sales of Other Assets and Other, net	3		1		2
Operating Income	1,227		1,242		(15		)
Other Income and Expenses	79		63		16
Interest Expense	315		270		45
Income Before Income Taxes	991		1,035		(44		)
Income Tax Expense	356		371		(15		)
Segment Income	$	635	$	664	$	(29	)
Duke Energy Carolinas Gigawatt-hours (GWh) sales	20,781		21,625		(844		)
Duke Energy Progress GWh sales	15,637		17,149		(1,512		)
Duke Energy Florida GWh sales	8,305		8,456		(151		)
Duke Energy Ohio GWh sales	6,059		6,107		(48		)
Duke Energy Indiana GWh sales	8,208		9,394		(1,186		)
Total Electric Utilities and Infrastructure GWh sales	58,990		62,731		(3,741		)
Net proportional Megawatt (MW) capacity in operation	48,964		50,111		(1,147		)

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Electric Utilities and Infrastructure’s results were impacted by warm winter weather and increased depreciation and amortization expense, partially offset by increased rider revenues and lower operations and maintenance expense. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• a $159 million decrease in retail sales, net of fuel revenues, due to warm winter weather in the current year; and

• a $108 million decrease in fuel revenues driven by lower sales volumes.

Partially offset by:

• a $108 million increase in rider revenues related to energy efficiency programs, Duke Energy Florida's nuclear asset securitization revenues, and Duke Energy Indiana's clean coal equipment, as well as increased retail pricing due to the Duke Energy Progress South Carolina rate case and Duke Energy Florida's base rate adjustment for the Osprey acquisition; and

• an $11 million increase in weather-normal sales volumes to retail customers in the current year.

Operating Expenses. The variance was driven primarily by:

• a $123 million decrease in fuel expense, including purchased power, primarily due to lower sales volumes and lower coal prices, partially offset by higher natural gas prices; and

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• a $27 million decrease in operations and maintenance expense primarily due to lower storm restoration costs and decreased labor costs, partially offset by higher environmental costs.

Partially offset by:

• a $28 million increase in depreciation and amortization expense primarily due to additional plant in service.

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

Interest Expense. The increase was primarily due to higher debt outstanding in the current year.

Income Tax Expense. The variance was primarily due to a decrease in pretax income. The effective tax rates for both the three months ended March 31, 2017 and 2016 were 35.9 percent.

Matters Impacting Future Electric Utilities and Infrastructure Results

An order from regulatory authorities disallowing recovery of costs related to closure of ash impoundments could have an adverse impact on Electric Utilities and Infrastructure's 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, 2016, "Asset Retirement Obligations," for additional information.

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 former North Carolina governor on July 14, 2016. Electric Utilities and Infrastructure's estimated asset retirement obligations (AROs) 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 and corrective action measures are developed and approved for each site, the closure work progresses and the closure method scope and remedial methods are determined, the complexity of work and the amount of coal combustion material could be different than originally estimated and, therefore, could materially impact Electric Utilities and Infrastructure's financial position. See Note 9 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2016, "Asset Retirement Obligations," for additional information.

Duke Energy is a party to multiple lawsuits and could be subject to fines and other penalties related to operations at certain North Carolina facilities with ash basins. The outcome of these lawsuits and potential fines and penalties could have an adverse impact on Electric Utilities and Infrastructure's financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

In the fourth quarter of 2016, Hurricane Matthew caused historic flooding, extensive damage and widespread power outages within the Duke Energy Progress service territory. Duke Energy Progress filed a petition with the North Carolina Utilities Commission (NCUC) requesting an accounting order to defer incremental operation and maintenance and capital costs incurred in response to Hurricane Matthew and other significant 2016 storms. Current estimated incremental costs are approximately $116 million. The NCUC has not ruled on the petition. A final order from the NCUC that disallows the deferral and future recovery of all or a significant portion of the incremental storm restoration costs incurred could result in an adverse impact on Electric Utilities and Infrastructure'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 Carolinas and Duke Energy Progress intend to file rate cases in North Carolina in 2017 to recover costs of complying with CCR regulations and the Coal Ash Act, as well as costs of capital investments in generation, transmission and distribution systems and any increase in expenditures subsequent to previous rate cases. Duke Energy Progress has filed notice with the NCUC that it intends to file a general rate case on or about June 1, 2017. In March 2017, Duke Energy Ohio filed an electric distribution base rate case application and supporting testimony. Electric Utilities and Infrastructure's earnings could be adversely impacted if these rate cases are delayed or denied by the NCUC or PUCO.

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Gas Utilities and Infrastructure

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues	$	670	$	170	$	500
Operating Expenses
Cost of natural gas	258		49		209
Operation, maintenance and other	105		32		73
Depreciation and amortization	57		20		37
Property and other taxes	30		18		12
Total operating expenses	450		119		331
Operating Income	220		51		169
Other Income and Expenses	18		3		15
Interest Expense	26		7		19
Income Before Income Taxes	212		47		165
Income Tax Expense	79		15		64
Segment Income	$	133	$	32	$	101
Piedmont LDC throughput (dekatherms) (a)	133,276,787		—		133,276,787
Duke Energy Midwest LDC throughput (MCF)	30,830,999		34,741,520		(3,910,521		)

(a)     Includes throughput subsequent to Duke Energy's acquisition of Piedmont on October 3, 2016.

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Gas Utilities and Infrastructure’s higher results were almost entirely due to the inclusion of Piedmont's earnings in the current year as a result of Duke Energy's acquisition of Piedmont on October 3, 2016. Piedmont's earnings included in Gas Utilities and Infrastructure's results were $99 million for the three months ended March 31, 2017. All variances are related to the inclusion of Piedmont's results of operations, except for the following:

Other Income and Expenses. The variance was driven primarily by higher earnings from Duke Energy's mid-stream gas pipeline investments that were owned prior to the Piedmont acquisition.

Matters Impacting Future Gas Utilities and Infrastructure Results

Gas Utilities and Infrastructure has a 24 percent ownership interest in Constitution Pipeline Company, LLC (Constitution), a natural gas pipeline project slated to transport natural gas supplies to major northeastern markets. On April 22, 2016, the New York State Department of Environmental Conservation denied Constitution’s application for a necessary water quality certification for the New York portion of the Constitution pipeline. Constitution has stopped construction and discontinued capitalization of future development costs until the project's uncertainty is resolved. To the extent the legal and regulatory proceedings have unfavorable outcomes, or if Constitution concludes that the project is not viable or does not go forward, an impairment charge of up to the recorded investment in the project, net of any cash and working capital returned, may be recorded. With the project on hold, funding of project costs has ceased until resolution of legal actions. Duke Energy is contractually obligated to provide funding of required operating costs, including the ownership percentage of legal expenses to obtain the necessary permitting for the project and project costs incurred prior to the denial of the water permit. If the legal actions result in an outcome where the project is abandoned, Constitution is obligated under various contracts to pay breakage fees that Gas Utilities and Infrastructure would be obligated to fund up to the ownership percentage, or potentially up to $10 million.

In 2013, the PUCO issued an order (PUCO order) approving Duke Energy Ohio’s recovery of costs incurred between 2008 and 2012 for environmental investigation and remediation of two former MGP sites. At March 31, 2017, Duke Energy Ohio had recorded in Regulatory assets on the Condensed Consolidated Balance Sheet approximately $100 million of estimated MGP remediation costs not yet recovered through the MGP rider mechanism. Intervenors have appealed to the Ohio Supreme Court the PUCO order authorizing recovery of these amounts. That appeal remains pending. Duke Energy Ohio cannot predict the outcome of the appeal before the Ohio Supreme Court or future action by the PUCO. If Duke Energy Ohio is not able to recover these remediation costs in rates, the costs could have an adverse impact on Gas Utilities and Infrastructure's 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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Commercial Renewables

	Three Months Ended March 31,
(in millions)	2017			2016			Variance
Operating Revenues	$	128		$	114		$	14
Operating Expenses
Operation, maintenance and other	77			73			4
Depreciation and amortization	39			30			9
Property and other taxes	9			6			3
Total operating expenses	125			109			16
Gains on Sales of Other Assets and Other, net	2			1			1
Operating Income	5			6			(1		)
Other Income and Expenses	(1		)	(2		)	1
Interest Expense	19			11			8
Loss Before Income Taxes	(15		)	(7		)	(8		)
Income Tax Benefit	(39		)	(33		)	(6		)
Less: Loss Attributable to Noncontrolling Interests	(1		)	—			(1		)
Segment Income	$	25		$	26		$	(1	)
Renewable plant production, GWh	2,285			2,060			225
Net proportional MW capacity in operation	2,907			1,963			944

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Commercial Renewables' results were impacted by higher financing costs and new renewables projects placed in service.

Operating Revenues and Operating Expenses. The increases were primarily due to new wind and solar generation placed in service.

Interest Expense. The variance was driven primarily by new wind project financings and less capitalized interest.

Income Tax Benefit.The variance was primarily due to an increase in pretax losses and higher production tax credits (PTCs) related to wind projects placed in service, partially offset by lower investment tax credits (ITCs) due to lower solar investments in the current year.

Matters Impacting Future Commercial Renewables Results

Changes or variability in assumptions used in calculating the fair value of the Commercial Renewables reporting units for goodwill testing purposes including but not limited to, legislative actions related to tax credit extensions, long-term growth rates and discount rates, could significantly impact the estimated fair value of the Commercial Renewables reporting units. In the event of a significant decline in the estimated fair value of the Commercial Renewables reporting units, goodwill impairment charges could be recorded. The carrying value of goodwill within Commercial Renewables was approximately $122 million at March 31, 2017.

Persistently low market pricing for wind resources, primarily in the Energy Reliability Council of Texas West market, and the future expiration of tax incentives including ITCs and PTCs could result in adverse impacts to the future results of Commercial Renewables.

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Other

	Three Months Ended March 31,
(in millions)	2017			2016			Variance
Operating Revenues	$	33		$	29		$	4
Operating Expenses
Fuel used in electric generation and purchased power	15			11			4
Operation, maintenance and other	8			36			(28		)
Depreciation and amortization	26			34			(8		)
Property and other taxes	3			9			(6		)
Impairment charges	—			2			(2		)
Total operating expenses	52			92			(40		)
Gains on Sales of Other Assets and Other, net	5			5			—
Operating Loss	(14		)	(58		)	44
Other Income and Expenses	21			17			4
Interest Expense	134			205			(71		)
Loss Before Income Taxes	(127		)	(246		)	119
Income Tax Benefit	(52		)	(101		)	49
Less: Income Attributable to Noncontrolling Interests	2			3			(1		)
Net Expense	$	(77	)	$	(148	)	$	71

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Other's lower net expense was driven by lower interest expense related to the Piedmont acquisition financing, decreased severance accruals and decreased charitable donations. The following is a detailed discussion of the variance drivers by line item.

Operating Expenses. The variance was primarily due to a decrease in severance accruals and a decrease in donations to the Duke Energy Foundation. The Duke Energy Foundation is a nonprofit organization funded by Duke Energy shareholders that makes charitable contributions to selected nonprofits and government subdivisions.

Other Income and Expenses. The increase was primarily driven by higher earnings from NMC due to higher commodity prices.

Interest Expense. The decrease was primarily due to Piedmont acquisition financing costs in the prior year, including $93 million of unrealized losses on forward-starting interest rate swaps. 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 a decrease in pretax losses. The effective tax rates for the three months ended March 31, 2017 and 2016 were 40.9 percent and 41.1 percent, respectively.

Matters Impacting Future Other Results

Included in Other is Duke Energy Ohio's 9 percent ownership interest in OVEC, which owns 2,256 MW of coal-fired generation capacity. As a counterparty to an inter-company power agreement (ICPA), Duke Energy Ohio has a contractual arrangement to receive entitlements to capacity and energy from OVEC’s power plants through June 2040 commensurate with its power participation ratio, which is equivalent to Duke Energy Ohio's ownership interest. Costs, including fuel, operating expenses, fixed costs, debt amortization, and interest expense, are allocated to counterparties to the ICPA, including Duke Energy Ohio, based on their power participation ratio. The value of the ICPA is subject to variability due to fluctuations in power prices and changes in OVEC’s costs of business. Deterioration in the credit quality or bankruptcy of one or more parties to the ICPA could increase the costs of OVEC. In addition, certain proposed environmental rulemaking costs could result in future increased cost allocations.

The retired Beckjord generating station (Beckjord), a nonregulated 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, the costs could have an adverse impact on Other's financial position, results of operations and cash flows.

Earnings from an equity method investment in NMC reflect sales of methanol and methyl tertiary butyl ether (MTBE), which generate margins that are directionally correlated with Brent crude oil prices. Weakness in the market price of Brent crude oil and related commodities may result in a decline in earnings. Duke Energy's economic ownership interest will decrease from 25 percent to 17.5 percent upon successful startup of NMC's polyacetal production facility, which is expected to occur in the second quarter of 2017.

U.S. federal tax reform has become an important priority of the current Congress and Administration. Any substantial revision to the U.S. tax code, including a loss of the ability to deduct interest expense, could adversely impact Duke Energy's future earnings, cash flows or financial position.

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INCOME FROM DISCONTINUED OPERATIONS, NET OF TAX

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Discontinued Operations, Net of Tax. The variance was driven by 2016 earnings from the International Disposal Group, which was sold in December 2016. See Note 2 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions," for additional information.

DUKE ENERGY CAROLINAS

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the three months ended March 31, 2017 and 2016 and the Annual Report on Form 10-K for the year ended December 31, 2016.

Results of Operations

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues	$	1,716	$	1,740	$	(24	)
Operating Expenses
Fuel used in electric generation and purchased power	428		421		7
Operation, maintenance and other	482		512		(30		)
Depreciation and amortization	254		259		(5		)
Property and other taxes	68		67		1
Total operating expenses	1,232		1,259		(27		)
Operating Income	484		481		3
Other Income and Expenses	37		37		—
Interest Expense	103		107		(4		)
Income Before Income Taxes	418		411		7
Income Tax Expense	148		140		8
Net Income	$	270	$	271	$	(1	)

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.

Increase (Decrease) over prior year	2017
Residential sales	(9.4	)%
General service sales	(2.1	)%
Industrial sales	(0.3	)%
Wholesale power sales	1.8	%
Joint dispatch sales	69.2	%
Total sales	(3.9	)%
Average number of customers	1.4	%

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Operating Revenues.The variance was driven primarily by:

• an $84 million decrease in retail sales, net of fuel revenues, due to warm winter weather in the current year.

Partially offset by:

• a $31 million increase in rider revenues related to energy efficiency programs;

• a $23 million increase in fuel revenues due to changes in generation mix, partially offset by lower sales volumes; and

• a $5 million increase in weather-normal retail sales volumes, net of fuel revenues.

Operating Expenses. The variance was driven primarily by a $30 million decrease in operations and maintenance expense due to lower storm restoration costs and decreased labor costs, partially offset by higher energy efficiency program costs.

Income Tax Expense. The variance was primarily due to an increase in pretax income and a higher effective tax rate. The effective tax rates for the three months ended March 31, 2017 and 2016 were 35.4 percent and 34.1 percent, respectively. The increase in the effective tax rate was primarily due to a favorable state resolution booked in 2016 related to prior year tax returns.

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Matters Impacting Future Results

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 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, 2016, "Asset Retirement Obligations," for additional information.

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 former North Carolina governor on July 14, 2016. Duke Energy Carolinas' estimated AROs 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 and corrective action measures are developed and approved for each site, the closure work progresses, and the closure method scope and remedial action methods are determined, the complexity of work and the amount of coal combustion material could be different than originally estimated and, therefore, could materially impact Duke Energy Carolinas' financial position. See Note 9 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2016, "Asset Retirement Obligations," for additional information.

Duke Energy Carolinas 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 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 intends to file a rate case in North Carolina in 2017 to recover costs of complying with CCR regulations and the Coal Ash Act, as well as costs of capital investments in generation, transmission and distribution systems and any increase in expenditures subsequent to previous rate cases. Duke Energy Carolinas' earnings could be adversely impacted if the rate case is delayed or denied by the NCUC.

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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 three months ended March 31, 2017 and 2016 and the Annual Report on Form 10-K for the year ended December 31, 2016.

Results of Operations

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues	$	2,179	$	2,332	$	(153	)
Operating Expenses
Fuel used in electric generation and purchased power	726		860		(134		)
Operation, maintenance and other	544		592		(48		)
Depreciation and amortization	313		290		23
Property and other taxes	117		119		(2		)
Impairment charges	—		2		(2		)
Total operating expenses	1,700		1,863		(163		)
Gains on Sales of Other Assets and Other, net	8		6		2
Operating Income	487		475		12
Other Income and Expenses	24		20		4
Interest Expense	206		160		46
Income Before Income Taxes	305		335		(30		)
Income Tax Expense	104		123		(19		)
Net Income	201		212		(11		)
Less: Net Income Attributable to Noncontrolling Interests	2		3		(1		)
Net Income Attributable to Parent	$	199	$	209	$	(10	)

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Operating Revenues. The variance was driven primarily by:

• a $126 million decrease in fuel revenues driven by lower retail sales and changes in generation mix at Duke Energy Progress, as well as decreased demand and capacity rates to retail customers at Duke Energy Florida;

• a $67 million decrease in retail sales, net of fuel revenues, due to warm winter weather in the current year; and

• a $10 million decrease in wholesale power revenues primarily due to contracts that expired in the prior year at Duke Energy Florida, partially offset by higher peak demand at Duke Energy Progress.

Partially offset by:

• a $29 million increase in rider revenues related to energy efficiency programs at Duke Energy Progress, and nuclear asset securitization revenues beginning in July 2016 at Duke Energy Florida; and

• a $15 million increase in retail pricing due to the Duke Energy Progress South Carolina rate case and Duke Energy Florida's base rate adjustment for the Osprey acquisition.

Operating Expenses. The variance was driven primarily by:

• a $134 million decrease in fuel expense primarily due to lower retail sales and changes in generation mix at Duke Energy Progress, as well as lower deferred fuel costs and decreased purchased power at Duke Energy Florida; and

• a $48 million decrease in operations and maintenance expense due to lower storm restoration costs as well as decreased labor and plant outage costs.

Partially offset by:

• a $23 million increase in depreciation and amortization expense primarily due to additional plant in service and nuclear regulatory asset amortization.

Interest Expense. The variance was primarily due to higher debt outstanding.

Income Tax Expense. The variance was primarily due to a decrease in pretax income and a lower effective tax rate. The effective tax rates for the three months ended March 31, 2017 and 2016 were 34.1 percent and 36.7 percent, respectively. The decrease in the effective tax rate was primarily due to higher AFUDC equity and the amortization of excess North Carolina deferred tax.

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Matters Impacting Future Results

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 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, 2016, "Asset Retirement Obligations," for additional information.

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 former North Carolina governor on July 14, 2016. Progress Energy's estimated AROs 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 and corrective action measures are developed and approved for each site, the closure work progresses, and the closure method scope and remedial action methods are determined, the complexity of work and the amount of coal combustion material could be different than originally estimated and, therefore, could materially impact Progress Energy's financial position. See Note 9 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2016, "Asset Retirement Obligations," 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 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.

In the fourth quarter of 2016, Hurricane Matthew caused historic flooding, extensive damage and widespread power outages within the Duke Energy Progress service territory. Duke Energy Progress filed a petition with the NCUC requesting an accounting order to defer incremental operation and maintenance and capital costs incurred in response to Hurricane Matthew and other significant 2016 storms. Current estimated incremental costs are approximately $116 million. The NCUC has not ruled on the petition. A final order from the NCUC that disallows the deferral and future recovery of all or a significant portion of the incremental storm restoration costs incurred could result in an adverse impact on Progress Energy's financial position, results of operations and cash flows.

On May 2, 2017, Duke Energy Progress filed notice with the NCUC that it intends to file a general rate case on or about June 1, 2017. Duke Energy Progress will seek to recover costs of complying with CCR regulations and the Coal Ash Act, as well as costs of capital investments in generation, transmission and distribution systems and any increase in expenditures subsequent to previous rate cases. Progress Energy's earnings could be adversely impacted if the rate case is delayed or denied by the NCUC.

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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 three months ended March 31, 2017 and 2016 and the Annual Report on Form 10-K for the year ended December 31, 2016.

Results of Operations

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues	$	1,219	$	1,307	$	(88	)
Operating Expenses
Fuel used in electric generation and purchased power	364		448		(84		)
Operation, maintenance and other	350		386		(36		)
Depreciation and amortization	181		175		6
Property and other taxes	40		41		(1		)
Total operating expenses	935		1,050		(115		)
Gains on Sales of Other Assets and Other, net	2		1		1
Operating Income	286		258		28
Other Income and Expenses	19		17		2
Interest Expense	82		63		19
Income Before Income Taxes	223		212		11
Income Tax Expense	76		75		1
Net Income and Comprehensive Income	$	147	$	137	$	10

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.

Increase (Decrease) over prior period	2017
Residential sales	(7.3	)%
General service sales	(3.0	)%
Industrial sales	2.1	%
Wholesale power sales	(11.6	)%
Joint dispatch sales	(18.5	)%
Total sales	(8.8	)%
Average number of customers	1.3	%

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Operating Revenues. The variance was driven primarily by:

• a $76 million decrease in fuel revenues driven by lower retail sales and changes in generation mix; and

• a $40 million decrease in retail sales, net of fuel revenues, due to warm winter weather in the current year.

Partially offset by:

• a $13 million increase in rider revenues related to energy efficiency programs;

• a $9 million increase in retail pricing due to the Duke Energy Progress South Carolina rate case; and

• an $8 million increase in wholesale power revenues primarily due to higher peak demand.

Operating Expenses. The variance was driven primarily by:

• an $84 million decrease in fuel expense primarily due to lower retail sales and changes in generation mix; and

• a $36 million decrease in operations and maintenance expense primarily due to lower storm restoration costs.

Interest Expense. The variance was primarily due to higher debt outstanding, as well as interest charges on North Carolina fuel overcollections.

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 March 31, 2017 and 2016 were 34.1 percent and 35.4 percent, respectively. The decrease in the effective tax rate was primarily due to the amortization of excess North Carolina deferred tax.

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Matters Impacting Future Results

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 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, 2016, "Asset Retirement Obligations," for additional information.

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 former North Carolina governor on July 14, 2016. Duke Energy Progress' estimated AROs 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 and corrective action measures are developed and approved for each site, the closure work progresses, and the closure method scope and remedial action methods are determined, the complexity of work and the amount of coal combustion material could be different than originally estimated and, therefore, could materially impact Duke Energy Progress' financial position. See Note 9 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2016, "Asset Retirement Obligations," 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.

In the fourth quarter of 2016, Hurricane Matthew caused historic flooding, extensive damage and widespread power outages within the Duke Energy Progress service territory. Duke Energy Progress filed a petition with the NCUC requesting an accounting order to defer incremental operation and maintenance and capital costs incurred in response to Hurricane Matthew and other significant 2016 storms. Current estimated incremental costs are approximately $116 million. The NCUC has not ruled on the petition. A final order from the NCUC that disallows the deferral and future recovery of all or a significant portion of the incremental storm restoration costs incurred could result in an adverse impact on Duke Energy Progress' financial position, results of operations and cash flows.

On May 2, 2017, Duke Energy Progress filed notice with the NCUC that it intends to file a general rate case on or about June 1, 2017. Duke Energy Progress will seek to recover costs of complying with CCR regulations and the Coal Ash Act, as well as costs of capital investments in generation, transmission and distribution systems and any increase in expenditures subsequent to previous rate cases. Duke Energy Progress' earnings could be adversely impacted if the rate case is delayed or denied by the NCUC.

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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 three months ended March 31, 2017 and 2016 and the Annual Report on Form 10-K for the year ended December 31, 2016.

Results of Operations

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues	$	959	$	1,024	$	(65	)
Operating Expenses
Fuel used in electric generation and purchased power	362		412		(50		)
Operation, maintenance and other	191		205		(14		)
Depreciation and amortization	132		114		18
Property and other taxes	77		78		(1		)
Impairment charges	1		2		(1		)
Total operating expenses	763		811		(48		)
Operating Income	196		213		(17		)
Other Income and Expenses	16		5		11
Interest Expense	70		41		29
Income Before Income Taxes	142		177		(35		)
Income Tax Expense	52		67		(15		)
Net Income	$	90	$	110	$	(20	)

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	2017
Residential sales	(8.4	)%
General service sales	0.4	%
Industrial sales	0.4	%
Wholesale and other	5.1	%
Total sales	(1.8	)%
Average number of customers	1.4	%

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Operating Revenues. The variance was driven primarily by:

• a $50 million decrease in fuel and capacity revenues primarily due to decreased demand and capacity rates to retail customers;

• a $27 million decrease in retail sales, net of fuel revenues, due to warm winter weather in the current year; and

• an $18 million decrease in wholesale power revenues primarily driven by contracts that expired in the prior year.

Partially offset by:

• a $16 million increase in rider revenues primarily due to nuclear asset securitization revenues beginning in July 2016;

• an $11 million increase in weather-normal sales volumes to retail customers in the current year; and

• a $6 million increase in retail pricing due to the base rate adjustment for the Osprey acquisition.

Operating Expenses. The variance was driven primarily by:

• a $50 million decrease in fuel expense primarily due to lower deferred fuel costs and decreased purchased power, partially offset by higher generation costs; and

• a $14 million decrease in operations and maintenance expense primarily due to decreased labor costs and planned outage costs.

Partially offset by:

• an $18 million increase in depreciation and amortization expense primarily due to additional plant in service, as well as nuclear regulatory asset amortization.

Other Income and Expenses. The variance was driven by higher AFUDC equity return on the Citrus County Combined Cycle and Hines Energy Complex Chiller Uprate projects in the current year and gains on insurance policies.

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Interest Expense. The variance was primarily due to higher debt outstanding and lower debt returns, driven by the CR3 debt return recorded prior to the securitization of CR3 in June of 2016.

Income Tax Expense. The variance was primarily due to a decrease in pretax income and a decrease in effective tax rate. The effective tax rates for the three months ended March 31, 2017 and 2016 were 36.6 percent and 37.9 percent, respectively. The decrease in the effective tax rate was primarily due to higher AFUDC equity.

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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 three months ended March 31, 2017 and 2016 and the Annual Report on Form 10-K for the year ended December 31, 2016.

Results of Operations

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues
Regulated electric	$	337	$	340	$	(3	)
Regulated natural gas	170		170		—
Nonregulated electric and other	11		6		5
Total operating revenues	518		516		2
Operating Expenses
Fuel used in electric generation and purchased power – regulated	97		111		(14		)
Fuel used in electric generation and purchased power – nonregulated	15		10		5
Cost of natural gas	54		49		5
Operation, maintenance and other	130		119		11
Depreciation and amortization	67		61		6
Property and other taxes	72		71		1
Total operating expenses	435		421		14
Gains on Sales of Other Assets and Other, net	—		1		(1		)
Operating Income	83		96		(13		)
Other Income and Expenses	4		2		2
Interest Expense	22		20		2
Income from Continuing Operations Before Income Taxes	65		78		(13		)
Income Tax Expense from Continuing Operations	23		21		2
Income from Continuing Operations	42		57		(15		)
Income from Discontinued Operations, net of tax	—		2		(2		)
Net Income	$	42	$	59	$	(17	)

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.

Increase (Decrease) over prior year	2017
Residential sales	(2.9	)%
General service sales	(1.7	)%
Industrial sales	(0.2	)%
Wholesale power sales	153.2	%
Total sales	(0.8	)%
Average number of customers	0.8	%

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Operating Revenues. The variance was driven primarily by:

• an $8 million increase in PJM transmission revenues;

• a $6 million increase in rider revenues primarily due to energy efficiency programs and a rate increase for the distribution capital investment rider, partially offset by a decrease in the percentage of income payment plan rider due to a rate decrease: and

• a $5 million increase in other revenues related to Ohio Valley Electric Corporation (OVEC).

Partially offset by:

• an $11 million decrease in fuel revenues primarily due to lower electric fuel prices and sales volumes, partially offset by higher costs passed through to natural gas customers due to higher natural gas prices; and

• an $8 million decrease in electric retail sales, net of fuel revenues, due to warm winter weather in the current year.

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Operating Expenses. The variance was driven primarily by:

• an $11 million increase in operations and maintenance expense due to higher energy efficiency program costs, higher storm costs, and higher transmission and distribution operations costs; and

• a $6 million increase in depreciation and amortization expense due to additional plant in service.

Partially offset by:

• a $14 million decrease in fuel expense driven by lower sales volumes and lower electric fuel costs.

Income Tax Expense. The variance was primarily due to a decrease in pretax income, partially offset by a higher effective tax rate. The effective tax rate for the three months ended March 31, 2017 and 2016 were 35.4 percent and 26.9 percent, respectively. The increase in the effective tax rate was primarily due to an immaterial out of period adjustment in the prior year related to deferred tax balances associated with property, plant and equipment.

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 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, 2016, "Asset Retirement Obligations," for additional information.

Duke Energy Ohio’s nonregulated Beckjord station, 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.

In 2013, the PUCO issued an order (PUCO order) approving Duke Energy Ohio’s recovery of costs incurred between 2008 and 2012 for environmental investigation and remediation of two former MGP sites. At March 31, 2017, Duke Energy Ohio had recorded in Regulatory assets on the Condensed Consolidated Balance Sheet approximately $100 million of estimated MGP remediation costs not yet recovered through the MGP rider mechanism. Intervenors have appealed to the Ohio Supreme Court the PUCO order authorizing recovery of these amounts. That appeal remains pending. Duke Energy Ohio cannot predict the outcome of the appeal before the Ohio Supreme Court or future action by the PUCO. If Duke Energy Ohio is not able to recover these remediation costs in rates, the costs could have an adverse impact on Duke Energy Ohio'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 Ohio has a 9 percent ownership interest in OVEC, which owns 2,256 MW of coal-fired generation capacity. As a counterparty to an ICPA, Duke Energy Ohio has a contractual arrangement to receive entitlements to capacity and energy from OVEC’s power plants through June 2040 commensurate with its power participation ratio, which is equivalent to Duke Energy Ohio’s ownership interest. Costs, including fuel, operating expenses, fixed costs, debt amortization, and interest expense, are allocated to counterparties to the ICPA, including Duke Energy Ohio, based on their power participation ratio. The value of the ICPA is subject to variability due to fluctuations in power prices and changes in OVEC’s costs of business. Deterioration in the credit quality or bankruptcy of one or more parties to the ICPA could increase the costs of OVEC. In addition, certain proposed environmental rulemaking costs could result in future increased cost allocations.

On March 2, 2017, Duke Energy Ohio filed an electric distribution base rate application with the PUCO to address recovery of electric distribution system capital investments and any increase in expenditures subsequent to previous rate cases. The application also includes requests to continue certain current riders and establish new riders related to LED Outdoor Lighting Service and regulatory mandates. Duke Energy Ohio's earnings could be adversely impacted if the rate case and requested riders are delayed or denied by the PUCO. See Note 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

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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 three months ended March 31, 2017 and 2016 and the Annual Report on Form 10-K for the year ended December 31, 2016.

Results of Operations

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues	$	758	$	714	$	44
Operating Expenses
Fuel used in electric generation and purchased power	251		228		23
Operation, maintenance and other	174		162		12
Depreciation and amortization	125		125		—
Property and other taxes	22		23		(1		)
Total operating expenses	572		538		34
Operating Income	186		176		10
Other Income and Expenses	8		4		4
Interest Expense	44		44		—
Income Before Income Taxes	150		136		14
Income Tax Expense	59		41		18
Net Income	$	91	$	95	$	(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.

Increase (Decrease) over prior year	2017
Residential sales	(4.1	)%
General service sales	(1.3	)%
Industrial sales	—	%
Wholesale power sales	(42.7	)%
Total sales	(12.6	)%
Average number of customers	1.2	%

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Operating Revenues.The variance was driven primarily by:

• a $28 million increase in rider revenues related to Edwardsport IGCC and energy efficiency programs; and

• a $17 million increase in fuel revenues primarily due to higher purchased power costs passed through to customers and higher financial transmission right (FTR) revenues.

Operating Expenses.The variance was driven primarily by:

• a $23 million increase in fuel and purchased power expense, primarily due to higher purchased power volumes and prices, partially offset by lower fuel costs due to lower generation; and

• a $14 million increase in operations and maintenance expense due to growth in energy efficiency programs and higher expenses at Edwardsport IGCC.

Other Income and Expenses. The variance was primarily driven by higher AFUDC equity.

Income Tax Expense. The variance was primarily due to an increase in pretax income and a higher effective tax rate. The effective tax rates for the three months ended March 31, 2017 and 2016 were 39.3 percent and 30.2 percent, respectively. The increase in the effective tax rate was primarily due to an immaterial out of period adjustment in the prior year related to deferred tax balances associated with 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 AROs. 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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The IURC approved a settlement agreement between Duke Energy Indiana and multiple parties that resolves 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. Pursuant to the terms of this agreement, the agreement imposes a cost cap for retail recoverable operations and maintenance costs through 2017. An inability to manage operating 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.

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PIEDMONT

Management’s Discussion and Analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes for the three months ended March 31, 2017, Piedmont's Annual Report on Form 10-K for the year ended October 31, 2016, and the transition report filed on Form 10-Q (Form 10-QT) as of December 31, 2016, for the transition period from November 1, 2016 to December 31, 2016.

Results of Operations

	Three Months Ended March 31,
(in millions)	2017		2016		Variance
Operating Revenues
Regulated natural gas	$	498	$	481	17
Nonregulated natural gas and other	2		2		—
Total operating revenues	500		483		17
Operating Expenses
Cost of natural gas	205		197		8
Operation, maintenance and other	77		74		3
Depreciation and amortization	35		34		1
Property and other taxes	13		11		2
Total operating expenses	330		316		14
Operating Income	170		167		3
Equity in Earnings of Unconsolidated Affiliates	3		16		(13		)
Interest Expense	20		17		3
Income Before Income Taxes	153		166		(13		)
Income Tax Expense	58		63		(5		)
Net Income	$	95	$	103	$	(8	)

The following table shows the percent changes in dekatherms delivered and average number of customers. The percentages for all throughput deliveries represent billed and unbilled sales. Amounts are not weather-normalized.

Increase (Decrease) over prior year	2017
Residential deliveries	(23.2	)%
Commercial deliveries	(19.9	)%
Industrial deliveries	(7.1	)%
Power generation deliveries	(12.4	)%
For resale	(12.7	)%
Total throughput deliveries	(14.3	)%
Secondary market volumes	(1.7	)%
Average number of customers	1.5	%

Piedmont's throughput was 133,276,787 dekatherms and 155,446,586 dekatherms for the three months ended March 31, 2017 and 2016, respectively. Due to the margin decoupling mechanism in North Carolina and weather normalization adjustment (WNA) mechanisms in South Carolina and Tennessee, changes in throughput deliveries do not have a material impact on Piedmont's revenues or earnings. The margin decoupling mechanism adjusts for variations in residential and commercial use per customer, including those due to weather and conservation. The WNA mechanisms mostly offset the impact of weather on bills rendered, but do not ensure full recovery of approved margin during periods when winter weather is significantly warmer or colder than normal.

Three Months Ended March 31, 2017 as Compared to March 31, 2016

Operating Revenues.The variance was driven primarily by:

• a $13 million increase in revenues to residential and commercial customers, net of natural gas costs passed through to customers, primarily due to IMR rate adjustments and customer growth, partially offset by decreased volumes delivered due to warmer weather; and

• an $8 million increase due to higher natural gas costs passed through to customers, primarily due to higher natural gas prices.

Partially offset by:

• a $3 million decrease in secondary market activity primarily due to lower margin sales.

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Operating Expenses.The variance was driven by:

• An $8 million increase in costs of natural gas, primarily due to higher natural gas prices and decreased opportunity for capacity release transactions; and

• A $6 million increase in other operating expenses, primarily due to higher severance expense, increased property taxes and depreciation attributable to additional plant in service.

Equity in Earnings of Unconsolidated Affiliates. The variance was primarily due to equity earnings from the investment in SouthStar in the prior year. Piedmont sold its 15 percent membership interest in SouthStar on October 3, 2016.

Income Tax Expense. The variance was primarily due to a decrease in pretax income. The effective tax rates for the three months ended March 31, 2017 and 2016 were 37.9 percent and 38.0 percent, respectively.

Matters Impacting Future Results

On April 1, 2017, Piedmont transferred its ownership interests in Atlantic Coast Pipeline, LLC (ACP) and Constitution to a wholly owned subsidiary of Duke Energy at book value. As a result, Piedmont will not recognize equity earnings (or losses) from these investments in future periods.

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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 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, 2016, for a summary and detailed discussion of projected primary sources and uses of cash for 2017 to 2019.

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 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

In March 2017, Duke Energy amended its Master Credit Facility to increase its capacity from $7.5 billion to $8 billion, and to extend the termination date of the facility from January 30, 2020, to March 16, 2022. The amendment also added Piedmont as a borrower within the Master Credit Facility. Piedmont's separate $850 million credit facility was terminated in connection with the amendment. With the amendment, 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.

	March 31, 2017
				Duke			Duke			Duke			Duke			Duke			Duke
	Duke			Energy			Energy			Energy			Energy			Energy			Energy
(in millions)	Energy			(Parent)			Carolinas			Progress			Florida			Ohio			Indiana			Piedmont
Facility size(a)	$	8,000		$	3,400		$	1,100		$	1,000		$	950		$	450		$	600		$	500
Reduction to backstop issuances
Commercial paper(b)	(3,134		)	(1,822		)	(469		)	(402		)	—			(30		)	(150		)	(261		)
Outstanding letters of credit	(71		)	(62		)	(4		)	(2		)	(1		)	—			—			(2		)
Tax-exempt bonds	(81		)	—			—			—			—			—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—			—
Available capacity	$	4,214		$	1,516		$	377		$	346		$	949		$	420		$	369		$	237

(a) Represents the sublimit of each borrower. Certain sublimits were reallocated in May 2017 to provide additional liquidity to certain borrowers in light of near-term funding needs.

(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.

Shelf Registration

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

In January 2017, Duke Energy amended its Form S-3 to add Piedmont as a registrant and included in the amendment a prospectus for Piedmont under which it may issue debt securities in the same manner as other Duke Energy Registrants.

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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		March 31, 2017
Unsecured Debt
Duke Energy (Parent)	August 2017	1.625	%	700
Piedmont	September 2017	8.510	%	35
Secured Debt
Duke Energy	June 2017	2.605	%	45
Duke Energy	June 2017	2.455	%	34
First Mortgage Bonds
Duke Energy Florida	September 2017	5.800	%	250
Duke Energy Progress	November 2017	1.252	%	200
Duke Energy Carolinas	January 2018	5.250	%	400
Other(a)				313
Current maturities of long-term debt				$	1,977

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

CASH FLOWS FROM OPERATING ACTIVITIES

Cash flows from operations of Electric Utilities and Infrastructure and Gas Utilities and Infrastructure are primarily driven by sales of electricity and natural gas, respectively, and costs of operations. These cash flows from operations are relatively stable and comprise a substantial portion of Duke Energy’s operating cash flows. Weather conditions, working capital and commodity price fluctuations, and unanticipated expenses including unplanned plant outages, storms, legal costs and related settlements can affect the timing and level of cash flows from operations.

Duke Energy believes it has sufficient liquidity resources through the commercial paper markets, and ultimately the Master Credit Facility, to support these 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 Reports on Form 10-K for additional information).

Restrictive Debt Covenants

The Duke Energy Registrants’ debt and credit agreements contain various financial and other covenants. The Master Credit Facility contains a covenant requiring the debt-to-total capitalization ratio not to exceed 65 percent for all borrowers except Piedmont. The debt-to-total capitalization ratio for Piedmont is not to exceed 70 percent. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of March 31, 2017, 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 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 Moody’s Investors Service, Inc. (Moody’s) and Standard & Poor’s Rating Services (S&P). In April 2017, Fitch Ratings, Inc. (Fitch) withdrew credit ratings of the Subsidiary Registrants, with the exclusion of Piedmont who was not previously rated by Fitch, due to commercial reasons. Fitch will continue to provide credit ratings for Duke Energy Corporation.

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Cash Flow Information

The following table summarizes Duke Energy’s cash flows.

	Three Months Ended
	March 31,
(in millions)	2017			2016
Cash flows provided by (used in):
Operating activities	$	1,289		$	1,682
Investing activities	(2,399		)	(1,758		)
Financing activities	1,596			(3		)
Changes in cash and cash equivalents included in assets held for sale	—			30
Net increase (decrease) in cash and cash equivalents	486			(49		)
Cash and cash equivalents at beginning of period	392			383
Cash and cash equivalents at end of period	$	878		$	334

OPERATING CASH FLOWS

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

	Three Months Ended
	March 31,
(in millions)	2017			2016
Net income	$	717		$	699
Non-cash adjustments to net income	1,237			1,060
Payments for asset retirement obligations	(134		)	(112		)
Working capital	(531		)	35
Net cash provided by operating activities	$	1,289		$	1,682

The variance was primarily due to:

• a $566 million decrease in cash flows from working capital due to the absence of the International Disposal Group's operating cash flows, lower regulated electric revenues due to warmer winter weather in the current year and the timing of payment of accruals.

Partially offset by:

• a $195 million increase in net income after non-cash adjustments, primarily due to the additional earnings attributed to the Piedmont acquisition.

INVESTING CASH FLOWS

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

	Three Months Ended
	March 31,
(in millions)	2017			2016
Capital, investment and acquisition expenditures	$	(2,335	)	$	(1,704	)
Available for sale securities, net	19			15
Other investing items	(83		)	(69		)
Net cash used in investing activities	$	(2,399	)	$	(1,758	)

The variance was primarily due to:

• a $631 million increase in capital, investment and acquisition expenditures due to growth in regulated generation investments and natural gas infrastructure.

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PART I

FINANCING CASH FLOWS

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

	Three Months Ended
	March 31,
(in millions)	2017			2016
Issuances of long-term debt, net	$	1,155		$	751
Notes payable and commercial paper	1,063			(158		)
Dividends paid	(600		)	(570		)
Other financing items	(22		)	(26		)
Net cash provided by (used in) financing activities	$	1,596		$	(3	)

The variance was due to:

• a $1,221 million increase in net proceeds from issuances of notes payable and commercial paper primarily as a result of the repayment of commercial paper at the end of 2016 with proceeds from the sale of the international business; and

• a $404 million increase in proceeds from net issuances of long-term debt mainly due to the timing of issuances and redemptions of long-term debt.

Summary of Significant Debt Issuances

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

				Three Months Ended March 31, 2017
						Duke		Duke
	Maturity	Interest		Duke		Energy		Energy
Issuance Date	Date	Rate		Energy		Florida		Ohio
Secured Debt
February 2017(a)	June 2034	4.120	%	$	587	$	—	$	—
First Mortgage Bonds
January 2017(b)	January 2020	1.850	%	250		250		—
January 2017(b)	January 2027	3.200	%	650		650		—
March 2017(c)	June 2046	3.700	%	100		—		100
Total issuances				$	1,587	$	900	$	100

(a) Portfolio financing of four Texas and Oklahoma wind facilities. Secured by substantially all of the assets of these wind facilities and nonrecourse to Duke Energy. Proceeds were used to reimburse Duke Energy for a portion of previously funded construction expenditures.

(b) Debt issued to fund capital expenditures for ongoing construction and capital maintenance, to repay at maturity a $250 million aggregate principal amount of bonds due September 2017 and for general corporate purposes.

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

In April 2017, Duke Energy (Parent) issued $420 million of unsecured notes with a fixed interest rate of 3.364 percent and maturity date of April 2025. The net proceeds were used to refinance $400 million of unsecured debt at maturity and to repay outstanding commercial paper.

OTHER MATTERS

Environmental Regulations

The Duke Energy 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.

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PART I

Coal Combustion Residuals

In April 2015, the EPA published a rule to regulate the disposal of CCR from electric utilities as solid waste. The federal regulation classifies CCR as nonhazardous waste 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, protection and remedial procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. As a result of the EPA rule, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana recorded additional ARO amounts during 2015. Various industry and environmental parties have appealed the EPA's CCR rule in the U.S. Court of Appeals for the District of Columbia (D.C. Circuit Court). 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. A decision by the court on the remaining issues is expected in the third quarter of 2017. Duke Energy does not expect a material impact from the settlement or that it will result in additional ARO 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. 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, 2016.

Coal Ash Management Act of 2014

Asset retirement obligations recorded on the Duke Energy Carolinas and Duke Energy Progress Condensed Consolidated Balance Sheets at March 31, 2017, and December 31, 2016, include the legal obligation for closure of coal ash basins and the disposal of related ash as a result of the Coal Ash Act, the EPA CCR rule and other agreements. In January 2016, the NCDEQ published draft 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 impacts to surface water and to groundwater. The NCDEQ's draft proposed classifications categorized 12 basins at four sites as intermediate risk and four basins at three sites as low risk. The NCDEQ's draft proposed classifications also categorized nine basins at six sites 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, proposing to rank all originally proposed low risk and "low-to-intermediate" risk sites as intermediate.

On July 14, 2016, the former governor of North Carolina signed legislation, which amended the Coal Ash Act and required 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-risk 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-risk basins is required to be completed no later than August 1, 2028. Upon satisfactory completion of the dam improvement projects and installation of alternative drinking water sources by October 15, 2018, the legislation requires the NCDEQ to reclassify sites proposed as intermediate risk, excluding H.F. Lee, Cape Fear and Weatherspoon, as low risk. In January 2017, NCDEQ issued preliminary approval of Duke Energy's plans for the alternative water sources.

Additionally, the July 2016 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. On October 5, 2016, Duke Energy announced Buck Steam Station as a first location for one of the beneficiation projects. On December 13, 2016, Duke Energy announced H.F. Lee as the second location. Duke Energy intends to announce the third location by July 1, 2017.

Provisions of the Coal Ash Act prohibit cost recovery in customer rates for unlawful discharge of ash impoundment waters occurring after January 1, 2014. The Coal Ash Act leaves the decision on cost recovery determinations related to closure of ash impoundments to the normal ratemaking processes before utility regulatory commissions. Consistent with the requirements of the Coal Ash Act, Duke Energy has submitted comprehensive site assessments and groundwater corrective plans to NCDEQ and will submit to NCDEQ site-specific coal ash impoundment closure plans in advance of closure. These plans and all associated permits must be approved by NCDEQ before closure work can begin.

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, 2016.

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 when the courts will rule on the petitions. The Duke Energy Registrants cannot predict the outcome of these matters.

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PART I

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. On April 13, 2017, the EPA administrator granted petitions from the Utility Water Act Group and U.S. Small Business Administration requesting reconsideration and an administrative stay of compliance dates in the ELG rule that have not yet passed pending judicial review, effective April 25, 2017. Briefing in the case was scheduled to conclude on July 5, 2017, however, on April 24, 2017, the Fifth Circuit Court of Appeals granted EPA's request to stay the pending litigation on the ELG rule until August 12, 2017. By the end of the stay period, EPA intends to inform the court of the portions of the rule, if any, that it will seek to have remanded to the agency for further rulemaking. The Duke Energy Registrants cannot predict the outcome of these matters.

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, CWA 316(b) and ELGs through December 31, 2021. The table excludes ash basin closure costs recorded in Asset retirement obligations on the Condensed Consolidated Balance Sheets. For more information related to AROs, see Note 9, “Asset Retirement Obligations” in Duke Energy’s Annual Report on Form 10‑K for the year ended December 31, 2016.

(in millions)	Estimated Cost
Duke Energy	$	1,235
Duke Energy Carolinas	530
Progress Energy	360
Duke Energy Progress	260
Duke Energy Florida	100
Duke Energy Ohio	125
Duke Energy Indiana	220

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 December 3, 2015, the EPA proposed a rule to lower the Cross-State Air Pollution Rule (CSAPR) Phase 2 state ozone season nitrogen oxide (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. On September 7, 2016, the EPA finalized the CSAPR Update Rule that reduces the CSAPR Phase 2 state ozone season NOX emission budgets for 22 eastern states, including Ohio, Kentucky and Indiana. In the final CSAPR Update Rule, the EPA removed Florida, South Carolina and North Carolina from the ozone season NOx program. Beginning in 2017, Duke Energy Registrants in these states will not be subject to any CSAPR ozone season NOx emission limitations. For the states that remain in the program, the reduced state ozone season NOx emission budgets took effect on May 1, 2017. In Kentucky and Indiana, where Duke Energy Registrants own and operate coal-fired electric generating units (EGUs) subject to the final rule requirements, potential near-term responses could include changing unit dispatch to run certain generating units less frequently and/or purchasing NOx allowances from the trading market. Longer term, upgrading the performance of existing NOx controls is an option. Numerous parties have filed petitions with the D.C. Circuit Court challenging various aspects of the CSAPR Update Rule. The court has yet to set a briefing schedule. Duke Energy Registrants cannot predict the outcome of these matters.

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 apply to plants that commenced construction after January 8, 2014. The EPA set an emissions standard for coal units of 1,400 pounds of CO₂ per gross MWh, 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 EGUs, 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.

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PART I

On March 28, 2017, President Trump signed an Executive Order directing EPA to review the rule and determine whether to suspend, revise or rescind it. On the same day, the Department of Justice (DOJ) filed a motion with the D.C. Circuit Court requesting that the court stay the litigation of the rule while it is reviewed by EPA. Subsequent to the DOJ motion, the D.C. Circuit Court canceled oral argument in the case, which had been scheduled for April 17, 2017. On April 28, 2017, the court ordered that the litigation be suspended for 60 days and directing parties to file supplemental briefs by May 15, 2017, addressing whether the rule should be remanded to EPA rather than be suspended. The rule remains in effect pending the outcome of litigation and EPA’s review. EPA has not announced a schedule for completing its review. The Duke Energy Registrants cannot predict the outcome of these matters, but do not expect the impacts of the current final standards will be material to Duke Energy's financial position, results of operations or cash flows.

Clean Power Plan

On October 23, 2015, the EPA published in the Federal Register the final Clean Power Plan (CPP) rule that regulates CO₂ emissions from existing fossil fuel-fired EGUs. The CPP established CO₂ emission rates and mass cap goals that apply to existing fossil fuel-fired EGUs. Petitions challenging the rule have been filed by several groups and on February 9, 2016, the Supreme Court issued a stay of the final CPP rule, halting implementation of the CPP until legal challenges are resolved. States in which the Duke Energy Registrants operate have suspended work on the CPP in response to the stay. Oral arguments before 10 of the 11 judges on D.C. Circuit Court were heard on September 27, 2016. The court has not issued its opinion in the case.

On March 28, 2017, President Trump signed an Executive Order directing EPA to review the CPP and determine whether to suspend, revise or rescind the rule. On the same day the DOJ filed a motion with the D.C. Circuit Court requesting that the court stay the litigation of the rule while it is reviewed by EPA. On April 28, 2017, the court issued an order to suspend the litigation for 60 days and directing parties to file supplemental briefs by May 15, 2017, addressing whether the rule should be remanded to the EPA rather than be suspended. Neither the Executive Order nor the court's order changes the current status of the CPP, which is under a legal hold by the U.S. Supreme Court. The EPA has not announced a schedule for completing its review. 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, 2016.

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, 2016.

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 months ended March 31, 2017, 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, 2016.

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 months ended March 31, 2017, 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, 2016.

Subsequent Events

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

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

During the three months ended March 31, 2017, there were no material changes to the Duke Energy Registrants' disclosures about market risk. For an in-depth discussion of the Duke Energy Registrants' market risks, see “Quantitative and Qualitative Disclosures about Market Risk” in Item 7 of the Annual Report on Form 10-K for the Duke Energy Registrants.

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) are recorded, processed, summarized and reported within the time periods specified by the SEC rules and forms.

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PART I

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 are 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 March 31, 2017, 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 March 31, 2017, and have concluded no change has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

118

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

For information regarding material legal proceedings, including regulatory and environmental matters, see Note 4, "Regulatory Matters," and Note 5, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements.

MTBE Litigation

On June 19, 2014, the Commonwealth of Pennsylvania filed suit against Duke Energy Merchants, LLC, an indirect wholly owned subsidiary of Duke Energy, among others, 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. The case is currently in the discovery phase.

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, 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 first quarter of 2017.

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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	Piedmont
4.1	Forty-fifth Supplemental Indenture, dated as of March 27, 2017, (incorporated by reference to Exhibit 4.1 to Registrant's Current Report on Form 8-K filed on March 27, 2017, File No. 1-01232).						X
*4.2	Fifteenth Supplemental Indenture, dated as of April 11, 2017.	X
10.1	Amendment No. 3 and Consent, dated as of March 16, 2017, among registrants, the Lenders party thereto, the Issuing Lenders party thereto, and Wells Fargo Bank, National Association, as Administrative Agent and Swingline Lender (incorporated by reference to Exhibit 10.1 to Registrants' Current Report on Form 8-K filed on March 17, 2017, File Nos. 1-32853, 1-04928, 1-03382, 1-03274, 1-01232, 1-03543, 1-06196).	X	X		X	X	X	X	X
*10.2**	Performance-Based Retention Award Agreement.	X
*10.3**	Performance Award Agreement.	X
*10.4**	Restricted Stock Unit Award Agreement.	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
*31.1.8	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

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PART II

*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
*31.2.8	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.								X
*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
*32.1.8	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

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PART II

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

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PART II

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.

		DUKE ENERGY CORPORATION DUKE ENERGY CAROLINAS, LLC PROGRESS ENERGY, INC. DUKE ENERGY PROGRESS, LLC DUKE ENERGY FLORIDA, LLC DUKE ENERGY OHIO, INC. DUKE ENERGY INDIANA, LLC PIEDMONT NATURAL GAS COMPANY, INC.
Date:	May 9, 2017	/s/ STEVEN K. YOUNG
		Steven K. Young Executive Vice President and Chief Financial Officer (Principal Financial Officer)
Date:	May 9, 2017	/s/ WILLIAM E. CURRENS JR.
		William E. Currens Jr. Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)

123

EX-4.2

Exhibit 4.2

DUKE ENERGY CORPORATION

TO

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.

Trustee

Fifteenth Supplemental Indenture

Dated as of April 11, 2017

$420,000,000 3.364% SENIOR NOTES DUE 2025

1

TABLE OF CONTENTS¹ 

ARTICLE I

3.364% SENIOR NOTES DUE 2025

Section 1.01.	Establishment	1
Section 1.02.	Definitions	2
Section 1.03.	Payment of Principal and Interest	2
Section 1.04.	Denominations	3
Section 1.05.	Global Securities	3
Section 1.06.	Redemption	4
Section 1.07.	Paying Agent	5
Section 1.08.	Legends	6

ARTICLE II

MISCELLANEOUS PROVISIONS

Section 2.01.	Recitals by the Corporation	6
Section 2.02.	Ratification and Incorporation of Original Indenture	6
Section 2.03.	Executed in Counterparts	6
Exhibit A – Form of 3.364% Senior Note Due 2025
Exhibit B – Certificate of Authentication
Exhibit C – Certificate of Transfer
Exhibit D – Schedule of Increases or Decreases in Global Security

1 This Table of Contents does not constitute part of the Indenture or have any bearing upon the interpretation of any of its terms and provisions.

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THIS FIFTEENTH SUPPLEMENTAL INDENTURE is made as of the 11th day of April, 2017, by and among DUKE ENERGY CORPORATION, a Delaware corporation, having its principal office at 550 South Tryon Street, Charlotte, North Carolina 28202-1803 (the “Corporation”), and The Bank of New York Mellon Trust Company, N.A. (formerly known as The Bank of New York Trust Company, N.A.), a national banking association, as Trustee (herein called the “Trustee”).

WITNESSETH:

WHEREAS, the Corporation has heretofore entered into an Indenture, dated as of June 3, 2008 (the “Original Indenture”), with The Bank of New York Mellon Trust Company, N.A., as Trustee;

WHEREAS, the Original Indenture is incorporated herein by this reference and the Original Indenture, as it may be amended and supplemented to the date hereof, including by this Fifteenth Supplemental Indenture, is herein called the “Indenture”;

WHEREAS, under the Indenture, a new series of Securities may at any time be established in accordance with the provisions of the Indenture and the terms of such series may be described by a supplemental indenture executed by the Corporation and the Trustee;

WHEREAS, the Corporation hereby proposes to create under the Indenture one additional series of Securities;

WHEREAS, additional Securities of other series hereafter established, except as may be limited in the Indenture as at the time supplemented and modified, may be issued from time to time pursuant to the Indenture as at the time supplemented and modified; and

WHEREAS, all conditions necessary to authorize the execution and delivery of this Fifteenth Supplemental Indenture and to make it a valid and binding obligation of the Corporation have been done or performed.

NOW, THEREFORE, in consideration of the agreements and obligations set forth herein and for other good and valuable consideration, the sufficiency of which is hereby acknowledged, the parties hereto hereby agree as follows:

ARTICLE I

3.364% SENIOR NOTES DUE 2025

Section 1.01. Establishment. There is hereby established a new series of Securities to be issued under the Indenture, to be designated as the Corporation’s 3.364% Senior Notes due 2025 (the “2025 Notes”).

There are to be authenticated and delivered initially $420,000,000 principal amount of the 2025 Notes, and no further 2025 Notes shall be authenticated and delivered except as provided by Section 304, 305, 306, 906 or 1106 of the Original Indenture and the last paragraph of Section 301 thereof. The 2025 Notes shall be issued in fully registered form without coupons.

The 2025 Notes shall be in substantially the form set out in Exhibit A hereto, and the form of the Trustee’s Certificate of Authentication for the 2025 Notes shall be in substantially the form set forth in Exhibit B hereto.

Each 2025 Note shall be dated the date of authentication thereof and shall bear interest from the date of original issuance thereof or from the most recent Interest Payment Date to which interest has been paid or duly provided for.

Section 1.02. Definitions. The following defined terms used in this Article I shall, unless the context otherwise requires, have the meanings specified below for purposes of the 2025 Notes. Capitalized terms used herein for which no definition is provided herein shall have the meanings set forth in the Original Indenture.

“Business Day” means any day other than a Saturday or Sunday that is neither a Legal Holiday nor a day on which banking institutions in New York, New York are authorized or required by law, regulation or executive order to close, or a day on which the Corporate Trust Office is closed for business.

“Interest Payment Date” means each April 15 and October 15 of each year, commencing on October 15, 2017.

“Legal Holiday” means any day that is a legal holiday in New York, New York.

“Original Issue Date” means April 11, 2017.

“Regular Record Date” means, with respect to each Interest Payment Date, the close of business on the 15th calendar day prior to such Interest Payment Date (whether or not a Business Day).

“Stated Maturity” means April 15, 2025.

Section 1.03. Payment of Principal and Interest. The principal of the 2025 Notes shall be due at Stated Maturity (unless earlier redeemed). The unpaid principal amount of the 2025 Notes shall bear interest at the rate of 3.364% per annum until paid or duly provided for, such interest to accrue from April 11, 2017 or from the most recent Interest Payment Date to which interest has been paid or duly provided for. Interest shall be paid semi-annually in arrears on each Interest Payment Date to the Person or Persons in whose name the 2025 Notes are registered on the Regular Record Date for such Interest Payment Date; provided that interest payable at the Stated Maturity or on a Redemption Date as provided herein shall be paid to the Person to whom principal is payable. Any such interest that is not so punctually paid or duly provided for shall forthwith cease to be payable to the Holders on such Regular Record Date and may either be paid to the Person or Persons in whose name the 2025 Notes are registered at the close of business on a Special Record Date for the payment of such defaulted interest to be fixed by the Trustee (“Special Record Date”), notice whereof shall be given to Holders of the 2025 Notes not less than ten (10) days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange, if any, on which the 2025 Notes may be listed, and upon such notice as may be required by any such exchange, all as more fully provided in the Original Indenture.

Payments of interest on the 2025 Notes shall include interest accrued to but excluding the respective Interest Payment Dates. Interest payments for the 2025 Notes shall be computed and paid on the basis of a 360-day year consisting of twelve 30-day months. In the event that any date on which interest is payable on the 2025 Notes is not a Business Day, then payment of the interest payable on such date shall be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay) with the same force and effect as if made on the date the payment was originally payable.

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Payment of principal of, premium, if any, and interest on the 2025 Notes shall be made in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts. Payments of principal of, premium, if any, and interest on 2025 Notes represented by a Global Security shall be made by wire transfer of immediately available funds to the Holder of such Global Security, provided that, in the case of payments of principal and premium, if any, such Global Security is first surrendered to the Paying Agent. If any of the 2025 Notes are no longer represented by a Global Security, (i) payments of principal, premium, if any, and interest due at the Stated Maturity or earlier redemption of such 2025 Notes shall be made at the office of the Paying Agent upon surrender of such 2025 Notes to the Paying Agent and (ii) payments of interest shall be made, at the option of the Corporation, subject to such surrender where applicable, by (A) check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or (B) wire transfer at such place and to such account at a banking institution in the United States as may be designated in writing to the Trustee at least sixteen (16) days prior to the date for payment by the Person entitled thereto.

Section 1.04. Denominations. The 2025 Notes shall be issued in denominations of $2,000 or any integral multiple of $1,000 in excess thereof.

Section 1.05. Global Securities. The 2025 Notes shall initially be issued in the form of one or more Global Securities registered in the name of the Depositary (which initially shall be The Depository Trust Company) or its nominee. The 2025 Notes will be initially issued pursuant to an exemption or exemptions from the registration requirements of the Securities Act of 1933, as amended (the “Securities Act”). Beneficial interests in the 2025 Notes offered and sold to “qualified institutional buyers” (as defined in Rule 144A under the Securities Act) in reliance upon Rule 144A under the Securities Act shall be represented by one or more separate Global Securities (each, a “Rule 144A Global Note”). Each Rule 144A Global Note shall bear the non-registration legend in substantially the form set forth in Exhibit A hereto (the “Rule 144A Legend”). Beneficial interests in the 2025 Notes offered and sold to purchasers outside of the United States pursuant to Regulation S under the Securities Act shall be represented by one or more separate Global Securities (each, a “Regulation S Global Note”) and shall bear the Regulation S legend in substantially the form set forth in Exhibit A hereto (the “Regulation S Legend”).

Except under the limited circumstances described below, 2025 Notes represented by such Global Security or Global Securities shall not be exchangeable for, and shall not otherwise be issuable as, 2025 Notes in definitive form. The Global Securities described in this Article I may not be transferred except by the Depositary to a nominee of the Depositary or by a nominee of the Depositary to the Depositary or another nominee of the Depositary or to a successor Depositary or its nominee. Nothing in the Indenture or the 2025 Notes shall be construed to require the Corporation to register any 2025 Note under the Securities Act, or to make any transfer of such 2025 Note in violation of applicable law.

A Global Security representing the 2025 Notes shall be exchangeable for 2025 Notes registered in the names of persons other than the Depositary or its nominee only if (i) the Depositary notifies the Corporation that it is unwilling or unable to continue as a Depositary for such Global Security and no successor Depositary shall have been appointed by the Corporation within 90 days of receipt by the Corporation of such notification, or if at any time the Depositary ceases to be a clearing agency registered under the Exchange Act at a time when the Depositary is required to be so registered to act as such Depositary and no successor Depositary shall have been appointed by the Corporation within 90 days after it becomes aware of such cessation, (ii) an Event of Default has occurred and is continuing with respect to the 2025 Notes and beneficial owners of a majority in aggregate principal amount of the 2025 Notes represented by Global Securities advise the Depositary to cease acting as Depositary, or (iii) the Corporation in its sole discretion, and subject to the procedures of the Depositary, determines that such Global Security shall be so exchangeable. Any Global Security that is exchangeable pursuant to the

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preceding sentence shall be exchangeable for 2025 Notes registered in such names as the Depositary shall direct.

A Rule 144A Global Note may not be transferred on the Security Register except in compliance with the restrictions on transfer contained in the Rule 144A Legend and upon receipt by the Security Registrar of a completed and executed Certificate of Transfer in the form contained in Exhibit C hereto. Prior to the expiration of 40 days beginning on and including the later of (i) the day on which the offering of the 2025 Notes commences and (ii) the original issue date of the 2025 Notes, a Regulation S Global Note may not be transferred on the Security Register except in compliance with the restrictions on transfer contained in the Regulation S Legend and upon receipt by the Security Registrar of a completed and executed Certificate of Transfer in the form contained in Exhibit C hereto.

Neither the Trustee or the Security Registrar shall have any obligation or duty to monitor, determine or inquire as to compliance with any restrictions on transfer imposed under the Indenture or under applicable law with respect to any transfer of any interest in any Global Security (including any transfers between or among Depositary participants, members or holders of any Global Security) other than, in connection with a registration of transfer of the 2025 Note on the Security Register, to require delivery of such certificates and other documentation or evidence as are expressly required by, and to do so if and when expressly required by, the terms of the Indenture, and to examine the same to determine substantial compliance as to form with the express requirements hereof. Transfers of beneficial interests between a Rule 144A Global Note and a Regulation S Global Note, and other transfers relating to beneficial interests in the Global Securities, shall be reflected by endorsements of the Trustee, as custodian for DTC, on the schedules attached to such Rule 144A Global Note and Regulation S Global Note. Neither the Corporation nor the Trustee shall have any liability for acts or omissions of any Depositary, for any Depositary records of beneficial interest, for any transactions between the Depositary, any participant member of the Depositary and/or beneficial owner of any interest in any 2025 Notes, or in respect of any transfers effected by the Depositary or by any participant member of the Depositary or any beneficial owner of any interest in any 2025 Notes held through any such participant member of the Depositary.

No service charge shall be made for any registration of transfer or exchange of the 2025 Notes, but the Corporation may require payment of a sum sufficient to cover any tax or other governmental charge that may be imposed in connection therewith.

Section 1.06. Redemption. At any time before February 15, 2025 (the “Par Call Date”), the 2025 Notes shall be redeemable, in whole or in part and from time to time, at the option of the Corporation, on any date (a “Redemption Date”), at a redemption price equal to the greater of (i) 100% of the principal amount of the 2025 Notes being redeemed and (ii) the sum of the present values of the remaining scheduled payments of principal and interest thereon that would be due if the 2025 Notes matured on the Par Call Date (exclusive of interest accrued to such Redemption Date) discounted to such Redemption Date on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate plus 20 basis points, plus, in either case, accrued and unpaid interest on the principal amount of the 2025 Notes being redeemed to, but excluding, such Redemption Date.

At any time on or after the Par Call Date, the 2025 Notes shall be redeemable, in whole or in part and from time to time, at the option of the Corporation, at a redemption price equal to 100% of the principal amount of the 2025 Notes being redeemed plus accrued and unpaid interest on the principal amount being redeemed to, but excluding, such Redemption Date.

For purposes of the first paragraph of this Section 1.06, the following terms have the following meanings:

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“Comparable Treasury Issue” means the United States Treasury security selected by the Quotation Agent as having an actual or interpolated maturity comparable to the remaining term of the 2025 Notes to be redeemed (assuming, for this purpose, that the 2025 Notes matured on the Par Call Date), that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such 2025 Notes.

“Comparable Treasury Price” means, with respect to any Redemption Date for the 2025 Notes, (1) the average of the Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest of such Reference Treasury Dealer Quotations, or (2) if fewer than three of such Reference Treasury Dealer Quotations are obtained, the average of all such Reference Treasury Dealer Quotations as determined by the Corporation.

“Quotation Agent” means a Reference Treasury Dealer appointed by the Corporation.

“Reference Treasury Dealer” means Morgan Stanley & Co. LLC, plus four other financial institutions appointed by the Corporation at the time of any redemption of the 2025 Notes, or their respective affiliates or successors, each of which is a primary U.S. Government securities dealer in the United States (a “Primary Treasury Dealer”); provided, however, that if any of the foregoing or their affiliates or successors shall cease to be a Primary Treasury Dealer, the Corporation will substitute therefor another Primary Treasury Dealer.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any Redemption Date for the 2025 Notes, the average, as determined by the Quotation Agent, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Quotation Agent by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third Business Day preceding such Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date for the 2025 Notes, the rate per annum equal to the semi-annual equivalent yield to maturity or interpolated maturity (on a day count basis) of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date. The Treasury Rate shall be calculated by the Corporation on the third Business Day preceding the Redemption Date.

The Corporation shall notify the Trustee of the redemption price with respect to any redemption of the 2025 Notes occurring before the Par Call Date promptly after the calculation thereof. The Trustee shall not be responsible for calculating said redemption price.

If less than all of the 2025 Notes are to be redeemed, the Trustee shall select the 2025 Notes or portions of 2025 Notes to be redeemed by such method as the Trustee shall deem fair and appropriate. The Trustee may select for redemption 2025 Notes and portions of 2025 Notes in amounts of $2,000 or any integral multiple of $1,000 in excess thereof. As long as the 2025 Notes are represented by Global Securities, beneficial interests in such Notes shall be selected for redemption by the Depositary in accordance with its standard procedures therefor.

The 2025 Notes shall not have a sinking fund.

Section 1.07. Paying Agent. The Trustee shall initially serve as Paying Agent with respect to the 2025 Notes, with the Place of Payment initially being the Corporate Trust Office.

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Section 1.08. Legends. Each 2025 Note, whether in a global form or in a definitive form, shall bear the Rule 144A Legend, or the Regulation S Legend, as applicable, in substantially the form set forth in Exhibit A hereto.

ARTICLE II

MISCELLANEOUS PROVISIONS

Section 2.01. Recitals by the Corporation. The recitals in this Fifteenth Supplemental Indenture are made by the Corporation only and not by the Trustee, and all of the provisions contained in the Original Indenture in respect of the rights, privileges, immunities, powers and duties of the Trustee shall be applicable in respect of the 2025 Notes and this Fifteenth Supplemental Indenture as fully and with like effect as if set forth herein in full.

Section 2.02. Ratification and Incorporation of Original Indenture. As supplemented hereby, the Original Indenture is in all respects ratified and confirmed, and the Original Indenture and this Fifteenth Supplemental Indenture shall be read, taken and construed as one and the same instrument.

Section 2.03. Executed in Counterparts. This Fifteenth Supplemental Indenture may be executed in several counterparts, each of which shall be deemed to be an original, and such counterparts shall together constitute but one and the same instrument.

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IN WITNESS WHEREOF, each party hereto has caused this instrument to be signed in its name and behalf by its duly authorized officer, all as of the day and year first above written.

Duke Energy Corporation

By: /s/ John L. Sullivan, III     

Name: John L. Sullivan, III

Title: Assistant Treasurer

The Bank of New York Mellon Trust Company, N .A., as Trustee

By:

Name:

Title:

[Signature Page to the Fifteenth Supplemental Indenture]

IN WITNESS WHEREOF, each party hereto has caused this instrument to be signed in its name and behalf by its duly authorized officer, all as of the day and year first above written.

Duke Energy Corporation

By:

Name: John L. Sullivan, III

Title:    Assistant Treasurer

The Bank of New York Mellon Trust Company,

By: /s/ Lawrence M. Kusch     

Name: Lawrence M. Kusch

Title:    Vice President

[Signature Page to the Fifteenth Supplemental Indenture]

EXHIBIT A

[DEPOSITARY LEGEND]

[UNLESS THIS SECURITY IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY (55 WATER STREET, NEW YORK, NEW YORK) TO THE CORPORATION OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE OR PAYMENT AND ANY SECURITY ISSUED IS REGISTERED IN THE NAME OF CEDE & CO. OR SUCH OTHER NAME AS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY AND ANY PAYMENT HEREON IS MADE TO CEDE & CO., ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY A PERSON IS WRONGFUL SINCE THE REGISTERED OWNER HEREOF, CEDE & CO., HAS AN INTEREST HEREIN.]

[RULE 144 A LEGEND]

[NEITHER THIS SECURITY NOR ANY BENEFICIAL INTEREST HEREIN HAS BEEN REGISTERED UNDER THE SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”). EACH HOLDER HEREOF, AND EACH OWNER OF A BENEFICIAL INTEREST HEREIN, BY PURCHASING THIS SECURITY, AGREES FOR THE BENEFIT OF DUKE ENERGY CORPORATION (THE “CORPORATION”) THAT THIS SECURITY MAY NOT BE RESOLD, PLEDGED OR OTHERWISE TRANSFERRED PRIOR TO THE DATE WHICH IS SIX MONTHS (IF ALL APPLICABLE CONDITIONS TO SUCH RESALE UNDER RULE 144 UNDER THE SECURITIES ACT (“RULE 144A”) (OR ANY SUCCESSOR PROVISION THEREOF) ARE SATISFIED) AFTER THE LATER OF THE ORIGINAL ISSUANCE DATE THEREOF, THE ISSUANCE DATE OF ANY SUBSEQUENT ISSUANCE OF ADDITIONAL SECURITIES OF THE SAME SERIES AND THE LAST DATE ON WHICH THE CORPORATION OR ANY AFFILIATE THEREOF WAS THE OWNER OF THIS SECURITY OR THE EXPIRATION OF SUCH SHORTER PERIOD AS MAY BE PRESCRIBED BY SUCH RULE 144 (OR SUCH SUCCESSOR PROVISION) PERMITTING RESALES OF THIS SECURITY WITHOUT ANY CONDITIONS (THE “RESALE RESTRICTION TERMINATION DATE”) OTHER THAN (A)(1) TO THE CORPORATION, (2) IN A TRANSACTION ENTITLED TO AN EXEMPTION FROM REGISTRATION PROVIDED BY RULE 144 UNDER THE SECURITIES ACT, (3) SO LONG AS THIS SECURITY IS ELIGIBLE FOR RESALE PURSUANT TO RULE 144A, TO A PERSON WHOM THE SELLER REASONABLY BELIEVES IS A QUALIFIED INSTITUTIONAL BUYER WITHIN THE MEANING OF RULE 144A PURCHASING FOR ITS OWN ACCOUNT OR FOR THE ACCOUNT OF A QUALIFIED INSTITUTIONAL BUYER TO WHOM NOTICE IS GIVEN THAT THE RESALE, PLEDGE OR OTHER TRANSFER IS BEING MADE IN RELIANCE ON RULE 144A (AS INDICATED BY THE BOX CHECKED BY THE TRANSFEROR ON THE CERTIFICATE OF TRANSFER ATTACHED TO THIS SECURITY), (4) IN AN OFFSHORE TRANSACTION IN ACCORDANCE WITH RULE 903 OR 904 OF REGULATION S UNDER THE SECURITIES ACT (AS INDICATED BY THE BOX CHECKED BY THE TRANSFEROR ON THE CERTIFICATE OF TRANSFER ATTACHED TO THIS SECURITY), (5) IN ACCORDANCE WITH ANOTHER APPLICABLE EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE SECURITIES ACT (AND BASED UPON AN OPINION OF COUNSEL ACCEPTABLE TO THE CORPORATION), OR (6) PURSUANT TO AN EFFECTIVE REGISTRATION STATEMENT UNDER THE SECURITIES ACT AND (B) IN EACH CASE IN ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF ANY STATE OF THE UNITED STATES. THE FOREGOING RESTRICTIONS ON RESALE WILL NOT APPLY SUBSEQUENT TO THE RESALE RESTRICTION TERMINATION DATE. THE HOLDER HEREOF, BY PURCHASING THIS SECURITY, REPRESENTS AND AGREES FOR THE BENEFIT OF THE CORPORATION THAT IT IS (i) A QUALIFIED INSTITUTIONAL BUYER WITHIN THE MEANING OF RULE 144A

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OR (ii) A NON-U.S. PERSON OUTSIDE THE UNITED STATES WITHIN THE MEANING OF, OR AN ACCOUNT SATISFYING THE REQUIREMENTS OF, PARAGRAPH (k)(2) OF RULE 902 UNDER REGULATION S UNDER THE SECURITIES ACT. THE HOLDER OF THIS SECURITY ACKNOWLEDGES THAT THE CORPORATION RESERVES THE RIGHT PRIOR TO ANY OFFER, SALE OR OTHER TRANSFER (1) PURSUANT TO CLAUSE (A)(2) PRIOR TO THE RESALE RESTRICTION TERMINATION DATE TO REQUIRE THE DELIVERY OF AN OPINION OF COUNSEL, CERTIFICATIONS OR OTHER INFORMATION SATISFACTORY TO THE CORPORATION AND (2) IN EACH OF THE FOREGOING CASES, TO REQUIRE THAT A CERTIFICATE AS TO COMPLIANCE WITH CERTAIN CONDITIONS TO TRANSFER IS COMPLETED AND DELIVERED BY THE TRANSFEROR TO THE CORPORATION.]

[REGULATION S LEGEND]

[THE SECURITIES COVERED HEREBY HAVE NOT BEEN REGISTERED UNDER THE U.S. SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), AND MAY NOT BE OFFERED OR SOLD WITHIN THE UNITED STATES OR TO, OR FOR THE ACCOUNT OR BENEFIT OF, U.S. PERSONS (I) AS PART OF THEIR DISTRIBUTION AT ANY TIME OR (II) OTHERWISE UNTIL 40 DAYS AFTER THE LATER OF THE DATE OF THE COMMENCEMENT OF THE OFFERING OF THE SECURITIES AND THE DATE OF ORIGINAL ISSUANCE OF THE SECURITIES, EXCEPT IN EITHER CASE IN ACCORDANCE WITH REGULATION S OR RULE 144A UNDER THE SECURITIES ACT OR ANY OTHER AVAILABLE EXEMPTION FROM REGISTRATION UNDER THE SECURITIES ACT. TERMS USED ABOVE HAVE THE MEANINGS GIVEN TO THEM BY REGULATION S.]

FORM OF

3.364% SENIOR NOTE DUE 2025

No.    Rule 144A CUSIP No. 26441C AU9

Regulation S CUSIP No. U2648M AB8

DUKE ENERGY CORPORATION

3.364% SENIOR NOTE DUE 2025

Principal Amount: $

Regular Record Date: Close of business on the 15th calendar day prior to the relevant Interest Payment Date (whether or not a Business Day)

Original Issue Date: April 11, 2017

Stated Maturity: April 15, 2025

Interest Payment Dates: Semi-annually on April 15 and October 15 of each year, commencing on October 15, 2017

Interest Rate: 3.364% per annum

Authorized Denomination: $2,000 or any integral multiple of $1,000 in excess thereof

Duke Energy Corporation, a Delaware corporation (the “Corporation”, which term includes any successor corporation under the Indenture referred to on the reverse hereof), for value received, hereby

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promises to pay to or registered assigns, the principal sum of DOLLARS ($) and to pay interest thereon from the Original Issue Date shown above, or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually in arrears on each Interest Payment Date as specified above, commencing on October 15, 2017 and on the Stated Maturity at the rate per annum shown above until the principal hereof is paid or made available for payment and at such rate on any overdue principal and on any overdue installment of interest. The interest so payable, and punctually paid or duly provided for, on any Interest Payment Date (other than an Interest Payment Date that is the Stated Maturity or a Redemption Date) will, as provided in the Indenture, be paid to the Person in whose name this 3.364% Senior Note due 2025 (this “Security”) is registered on the Regular Record Date as specified above next preceding such Interest Payment Date; provided that any interest payable at Stated Maturity or on a Redemption Date will be paid to the Person to whom principal is payable. Except as otherwise provided in the Indenture, any such interest not so punctually paid or duly provided for will forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Security is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice whereof shall be given to Holders of Securities of this series not less than 10 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange, if any, on which the Securities shall be listed, and upon such notice as may be required by any such exchange, all as more fully provided in the Indenture.

Payments of interest on this Security will include interest accrued to but excluding the respective Interest Payment Dates. Interest payments for this Security shall be computed and paid on the basis of a 360-day year consisting of twelve 30-day months and will accrue from April 11, 2017 or from the most recent Interest Payment Date to which interest has been paid or duly provided for. In the event that any date on which interest is payable on this Security is not a Business Day, then payment of the interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay) with the same force and effect as if made on the date the payment was originally payable. “Business Day” means any day other than a Saturday or Sunday that is neither a Legal Holiday nor a day on which banking institutions in New York, New York are authorized or required by law, regulation or executive order to close, or a day on which the Corporate Trust Office is closed for business. “Legal Holiday” means any day that is a legal holiday in New York, New York.

Payment of principal of, premium, if any, and interest on the Securities of this series shall be made in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts. Payments of principal of, premium, if any, and interest on the Securities of this series represented by a Global Security shall be made by wire transfer of immediately available funds to the Holder of such Global Security, provided that, in the case of payments of principal and premium, if any, such Global Security is first surrendered to the Paying Agent. If any of the Securities of this series are no longer represented by a Global Security, (i) payments of principal, premium, if any, and interest due at the Stated Maturity or earlier redemption of such Securities shall be made at the office of the Paying Agent upon surrender of such Securities to the Paying Agent, and

(ii) payments of interest shall be made, at the option of the Corporation, subject to such surrender where applicable, by (A) check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or (B) wire transfer at such place and to such account at a banking institution in the United States as may be designated in writing to the Trustee at least sixteen (16) days prior to the date for payment by the Person entitled thereto.

At any time before February 15, 2025 (the “Par Call Date”), the Securities of this series shall be redeemable, in whole or in part and from time to time, at the option of the Corporation, on any date (a “Redemption Date”), at a redemption price equal to the greater of (i) 100% of the principal amount of the

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Securities of this series being redeemed and (ii) the sum of the present values of the remaining scheduled payments of principal and interest thereon that would be due if this Security matured on the Par Call Date (exclusive of interest accrued to such Redemption Date) discounted to such Redemption Date on a semi- annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate plus 20 basis points, plus, in either case, accrued and unpaid interest on the principal amount being redeemed to, but excluding, such Redemption Date.

At any time on or after the Par Call Date, the Securities of this series shall be redeemable, in whole or in part and from time to time, at the option of the Corporation, at a redemption price equal to 100% of the principal amount of the Securities of this series being redeemed plus accrued and unpaid interest on the principal amount being redeemed to, but excluding, such Redemption Date.

For purposes of the second preceding paragraph, the following terms have the following meanings:

“Comparable Treasury Issue” means the United States Treasury security selected by the Quotation Agent as having an actual or interpolated maturity comparable to the remaining term of the Securities of this series to be redeemed (assuming, for this purpose, that this Security matured on the Par Call Date), that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of such Securities of this series.

“Comparable Treasury Price” means, with respect to any Redemption Date for the Securities of this series, (1) the average of the Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest of such Reference Treasury Dealer Quotations, or (2) if fewer than three of such Reference Treasury Dealer Quotations are obtained, the average of all such Reference Treasury Dealer Quotations as determined by the Corporation.

“Quotation Agent” means a Reference Treasury Dealer appointed by the Corporation.

“Reference Treasury Dealer” means Morgan Stanley & Co. LLC, plus four other financial institutions appointed by the Corporation at the time of any redemption of the Securities of this series, or their respective affiliates or successors, each of which is a primary U.S. Government securities dealer in the United States (a “Primary Treasury Dealer”); provided, however, that if any of the foregoing or their affiliates or successors shall cease to be a Primary Treasury Dealer, the Corporation will substitute therefor another Primary Treasury Dealer.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any Redemption Date for the Securities of this series, the average, as determined by the Quotation Agent, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Quotation Agent by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third Business Day preceding such Redemption Date.

“Treasury Rate” means, with respect to any Redemption Date for the Securities of this series, the rate per annum equal to the semi-annual equivalent yield to maturity or interpolated maturity (on a day count basis) of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date. The Treasury Rate shall be calculated by the Corporation on the third Business Day preceding the Redemption Date.

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The Corporation shall notify the Trustee of the redemption price with respect to any redemption of the Securities of this series occurring before the Par Call Date promptly after the calculation thereof. The Trustee shall not be responsible for calculating said redemption price.

Notice of any redemption by the Corporation will be mailed (or, as long as the Securities of this series are represented by one or more Global Securities, transmitted in accordance with the Depositary’s standard procedures therefor) at least 30 days but not more than 60 days before any Redemption Date to each Holder of Securities of this series to be redeemed. If Notice of a redemption is provided and funds are deposited as required, interest will cease to accrue on and after the Redemption Date on the Securities of this series or portions of Securities of this series called for redemption. In the event that any Redemption Date is not a Business Day, the Corporation will pay the redemption price on the next Business Day without any interest or other payment in respect of any such delay. If less than all the Securities of this series are to be redeemed at the option of the Corporation, the Trustee shall select, in such manner as it shall deem fair and appropriate, the Securities of this series to be redeemed in whole or in part. The Trustee may select for redemption Securities of this series and portions of the Securities of this series in amounts of $2,000 or any integral multiple of $1,000 in excess thereof. As long as the Securities of this series are represented by Global Securities, beneficial interests in such Securities shall be selected for redemption by the Depositary in accordance with its standard procedures therefor.

In the event of redemption of this Security in part only, a new Security or Securities of this series and of like tenor for the unredeemed portion hereof will be issued in the name of the Holder hereof upon the surrender hereof.

The Securities of this series shall not have a sinking fund.

The Securities of this series shall constitute the direct unsecured and unsubordinated debt obligations of the Corporation and shall rank equally in priority with the Corporation’s existing and future unsecured and unsubordinated indebtedness.

REFERENCE IS HEREBY MADE TO THE FURTHER PROVISIONS OF THIS SECURITY SET FORTH ON THE REVERSE HEREOF, WHICH FURTHER PROVISIONS SHALL FOR ALL PURPOSES HAVE THE SAME EFFECT AS IF SET FORTH AT THIS PLACE.

Unless the certificate of authentication hereon has been executed by the Trustee by manual signature, this Security shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

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IN WITNESS WHEREOF, the Corporation has caused this instrument to be duly executed as of April11, 2017.

Duke Energy Corporation

By:

Name:

Title:

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

Dated: April 11, 2017	The Bank of New York Mellon Trust Company, N.A., as Trustee
By:
Authorized Signatory

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(Reverse Side of Security)

This 3.364% Senior Note due 2025 is one of a duly authorized issue of Securities of the Corporation (the “Securities”), issued and issuable in one or more series under an Indenture, dated as of June 3, 2008, as supplemented (the “Indenture”), between the Corporation and The Bank of New York Mellon Trust Company, N.A. (formerly known as The Bank of New York Trust Company, N.A.), as Trustee (the “Trustee,” which term includes any successor trustee under the Indenture), to which Indenture and all indentures supplemental thereto reference is hereby made for a statement of the respective rights, limitation of rights, duties and immunities thereunder of the Corporation, the Trustee and the Holders of the Securities issued thereunder and of the terms upon which said Securities are, and are to be, authenticated and delivered. This Security is one of the series designated on the face hereof as 3.364% Senior Notes due 2025 initially in the aggregate principal amount of $420,000,000. Capitalized terms used herein for which no definition is provided herein shall have the meanings set forth in the Indenture.

If an Event of Default with respect to the Securities of this series shall occur and be continuing, the principal of the Securities of this series may be declared due and payable in the manner, with the effect and subject to the conditions provided in the Indenture.

The Indenture permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Corporation and the rights of the Holders of the Securities of all series affected under the Indenture at any time by the Corporation and the Trustee with the consent of the Holders of not less than a majority in principal amount of the Outstanding Securities of all series affected thereby (voting as one class). The Indenture contains provisions permitting the Holders of not less than a majority in principal amount of the Outstanding Securities of all series with respect to which a default under the Indenture shall have occurred and be continuing (voting as one class), on behalf of the Holders of the Securities of all such series, to waive, with certain exceptions, such default under the Indenture and its consequences. The Indenture also permits the Holders of not less than a majority in principal amount of the Securities of each series at the time Outstanding, on behalf of the Holders of all Securities of such series, to waive compliance by the Corporation with certain provisions of the Indenture affecting such series. Any such consent or waiver by the Holder of this Security shall be conclusive and binding upon such Holder and upon all future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange hereof or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.

No reference herein to the Indenture and no provision of this Security or of the Indenture shall alter or impair the obligation of the Corporation, which is absolute and unconditional, to pay the principal of and interest on this Security at the times, place and rate, and in the coin or currency, herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Security is registrable in the Security Register, upon surrender of this Security for registration of transfer at the office or agency of the Corporation for such purpose, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Corporation and the Security Registrar and duly executed by, the Holder hereof or his attorney duly authorized in writing, together with the completed and executed Certificate of Transfer attached hereto, and thereupon one or more new Securities of this series, of authorized denominations and of like tenor and for the same aggregate principal amount, will be issued to the designated transferee or transferees. No service charge shall be made for any such registration of transfer or exchange, but the Corporation may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

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The Indenture contains provisions for defeasance at any time of the entire indebtedness of the Securities of this series and for covenant defeasance at any time of certain covenants in the Indenture upon compliance with certain conditions set forth in the Indenture.

Prior to due presentment of this Security for registration of transfer, the Corporation, the Trustee and any agent of the Corporation or the Trustee may treat the Person in whose name this Security is registered as the owner hereof for all purposes, whether or not this Security be overdue, and neither the Corporation, the Trustee nor any such agent shall be affected by notice to the contrary.

The Securities of this series are issuable only in registered form without coupons in denominations of $2,000 or any integral multiple of $1,000 in excess thereof. As provided in the Indenture and subject to the limitations therein set forth, Securities of this series are exchangeable for a like aggregate principal amount of Securities of this series of a different authorized denomination, as requested by the Holder surrendering the same upon surrender of the Security or Securities to be exchanged at the office or agency of the Corporation.

This Security shall be governed by, and construed in accordance with, the laws of the State of New York.

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ABBREVIATIONS

The following abbreviations, when used in the inscription on the face of this instrument, shall be construed as though they were written out in full according to applicable laws or regulations:

TEN COM — as tenants in common	UNIF GIFT MIN ACT - Custodian (Cust) (Minor)
TEN ENT — as tenants by the entireties
JT TEN — as joint tenants with rights of survivorship and not as tenants in common	under Uniform Gifts to Minors Act
(State)

Additional abbreviations may also be used though not on the above list.

FOR VALUE RECEIVED, the undersigned hereby sell(s) and transfer(s) unto (please insert Social Security or other identifying number of assignee)

PLEASE PRINT OR TYPEWRITE NAME AND ADDRESS, INCLUDING POSTAL ZIP CODE OF ASSIGNEE

the within Security and all rights thereunder, hereby irrevocably constituting and appointing    agent to transfer said Security on the books of the Corporation, with full power of substitution in the premises.

Dated:

NOTICE: The signature to this assignment must correspond with the name as written upon the face of the within instrument in every particular without alteration or enlargement, or any change whatever.

Signature

Guarantee:

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SIGNATURE GUARANTEE

Signatures must be guaranteed by an “eligible guarantor institution” meeting the requirements of the Security Registrar, which requirements include membership or participation in the Security Transfer Agent Medallion Program (“STAMP”) or such other “signature guarantee program” as may be determined by the Security Registrar in addition to, or in substitution for, STAMP, all in accordance with the Securities Exchange Act of 1934, as amended.

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EXHIBIT B

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

Dated:	The Bank of New York Mellon Trust Company, N.A., as Trustee
By:
Authorized Signatory

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EXHIBIT C

CERTIFICATE OF TRANSFER

Re:    DUKE ENERGY CORPORATION 3.364% SENIOR NOTE DUE 2025 (the “Securities”)

This Certificate relates to $principal amount of the Securities held in * book-entry

or *definitive form by(the “Transferor”).

The Transferor certifies that said beneficial interest in said Security is being resold, pledged or otherwise transferred as follows:*

1¨    to the Corporation; or

2¨     pursuant to an exemption from registration provided by Rule 144 under the Securities Act of 1933, as amended (the “Securities Act”); or

3¨     to a person whom the Transferor reasonably believes is a “qualified institutional buyer” within the meaning of Rule 144A under the Securities Act that purchases for its own account or for the account of a qualified institutional buyer to whom notice is given that the resale, pledge or other transfer is being made in reliance on Rule 144A under the Securities Act; or

4¨     pursuant to an offshore transaction in accordance with Rule 903 or 904 of Regulation S under the Securities Act; or

5¨     pursuant to another applicable exemption from the registration requirements of the Securities Act (and based upon an opinion of counsel acceptable to the Corporation); or

6¨    pursuant to an effective registration statement under the Securities Act.

Unless one of the boxes is checked, the Trustee may refuse to register any of the Securities evidenced by this certificate in the name of any person other than the registered holder thereof; provided, however, that if box (2) is checked, the Corporation or the Trustee, prior to registering any such transfer of the Notes, reserves the right to require the delivery of an opinion of counsel, certifications or other information satisfactory to the Corporation and the Trustee.

Dated:

NOTICE: The signature to this assignment must correspond with the name as written upon the face of the within instrument in every particular without alteration or enlargement, or any change whatever.

Signature

Guarantee:

* Fill in blank or check appropriate box, as applicable.

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SIGNATURE GUARANTEE

Signatures must be guaranteed by an “eligible guarantor institution” meeting the requirements of the Security Registrar, which requirements include membership or participation in the Security Transfer Agent Medallion Program (“STAMP”) or such other “signature guarantee program” as may be determined by the Security Registrar in addition to, or in substitution for, STAMP, all in accordance with the Securities Exchange Act of 1934, as amended.

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EXHIBIT D

SCHEDULE I TO GLOBAL SECURITY

The initial amount of the Global Securities evidenced by this certificate is $.

SCHEDULE OF INCREASES OR DECREASES IN GLOBAL SECURITY

The following increases or decreases in this Global Security have been made

Date Amount of increase in Principal Amount of this Global Security Amount of decrease in Principal Amount of this Global Security Principal Amount of this Global Security following each decrease or increase Signature of authorized signatory of Trustee or Securities Registrar

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EX-10.2

Exhibit 10.2

PERFORMANCE-BASED RETENTION AWARD AGREEMENT

This Performance-Based Retention Award Agreement (the "Agreement") has been made as of_______________, (the "Date of Grant") between Duke Energy Corporation, a Delaware corporation, with its principal offices in Charlotte, North Carolina (the "Corporation"), and _______________ (the "Grantee").

RECITALS

Under the Duke Energy Corporation 2015 Long-Term Incentive Plan, as it may, from time to time, be further amended (the "Plan"), the Compensation Committee of the Board of Directors of the Corporation (the "Committee"), or its delegate, has determined the form of this Agreement and selected the Grantee, as an Employee, to receive the award evidenced by this Agreement (the "Award") and the “Restricted Stock Units” and tandem Dividend Equivalents that are subject hereto. The applicable provisions of the Plan are incorporated in this Agreement by reference, including the definitions of terms contained in the Plan (unless such terms are otherwise defined herein).

AWARD

In accordance with the Plan, the Corporation has made this Award, effective as of the Date of Grant and upon the following terms and conditions:

Section 1.Number and Nature of Restricted Stock Units and Tandem Dividend Equivalents.  The number of Restricted Stock Units and the number of tandem Dividend Equivalents subject to this Award are each __________________________________. Each Restricted Stock Unit, upon becoming vested, represents a right to receive payment in the form of one (1) share of Common Stock. Each tandem Dividend Equivalent represents a right to receive a cash payment equivalent in amount to the aggregate cash dividends declared and paid on one (1) share of Common Stock for the period beginning on the Date of Grant and ending on the date the vested Restricted Stock Units are paid and before the Dividend Equivalent expires. Restricted Stock Units and Dividend Equivalents are used solely as units of measurement and are not shares of Common Stock, and the Grantee is not, and has no rights as, a shareholder of the Corporation by virtue of this Award.

Section 2.Vesting of Restricted Stock Units.  The Restricted Stock Units subject to this Award, and not previously forfeited, shall vest, as follows:

(a)If the Grantee remains continuously employed by the Corporation, including Subsidiaries, through the _________ anniversary of the Date of Grant (the "Vesting Date"), and if the Committee determines that the Performance Goal (as defined below) has been met during the period from _____________ to ______________ (the “Performance Period”), provided that such determination shall be made no later than _____________, the Restricted Stock Units shall become vested. If the Performance Goal is not met, the Restricted Stock Units shall be forfeited. The Performance Goal that shall apply to all Restricted Stock Units subject to this Award shall be based on the Committee’s determination, in its sole discretion, that the Corporation achieves a return on equity (“ROE”) equal to at least ____ during the Performance Period (the “Performance Goal”). The Committee shall calculate the Corporation’s ROE during the Performance Period using the following methodology: (i) the Corporation’s ROE during the Performance Period will equal the arithmetic average of the annual ROEs earned by the Corporation for ____________, (ii) the Corporation’s annual ROE will be calculated by dividing the Corporation’s adjusted net income by the Corporation’s average shareholders’ equity excluding goodwill, with the resulting ROE rounded to the nearest 0.05%. For this purpose, the Corporation’s “adjusted net income” will be determined pursuant to the methodology described in the ________________ with respect to EPS (including the adjustment provisions relating to targets and results), and the Corporation’s “average shareholders’ equity excluding goodwill” means, for any given year, the sum of the total shareholders’ equity of the Corporation less the goodwill balance on the Corporation’s balance sheet as of the first day of such year and as of the end of each year, divided by two. If the Committee determines that a merger, consolidation, liquidation, issuance of rights or warrants to purchase securities, recapitalization, reclassification, stock dividend, spin-off, split-off, stock split, reverse stock split or other distribution with respect to the shares of Common Stock, or any similar corporate transaction or event in respect of the Common Stock, the manner in which the Corporation conducts its business, changes in the law or regulations or regulatory structure, changes in accounting practice, other unusual or nonrecurring items or occurrences, or other events or circumstances, render the Performance Goal to be unsuitable, the Committee may, in its sole discretion, and without the consent of the Grantee or any other persons, modify the calculation of the Performance Goal, or the related level of achievement, in whole or in part, as the Committee deems equitable and appropriate to reflect such event; provided, however, that no such action may result in the loss of the otherwise available exemption of the Award under Section 162(m) of the Code. 

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(b)    If such employment terminates (i) as the result of Grantee’s death or (ii) as the result of Grantee’s permanent and total disability within the meaning of Code Section 22(e)(3), all Restricted Stock Units subject to this Award, which units have not previously been forfeited, immediately shall become fully vested, unless the Committee or its delegate, in its sole discretion, determines that Grantee is in violation of any obligation identified in Section 3, in which case any Restricted Stock Units not previously vested shall be forfeited.

(c)    100% of the Restricted Stock Units shall become vested, if, following the occurrence of a Change in Control and before the second anniversary of such occurrence, such employment is terminated involuntarily, and not for cause, by the Corporation, or employing Subsidiary, as determined by the Committee or its delegate in its sole discretion.

(d)    Unless the Grantee's right to receive payment of the Restricted Stock Units constitutes a "deferral of compensation" within the meaning of Section 409A of the Code, in the event that at a time when vesting would otherwise occur under Section 2(a) or 2(b) Grantee is on an employer-approved, personal leave of absence, then, unless prohibited by law, vesting shall be postponed and shall not occur unless and until Grantee returns to active service in accordance with the terms of the approved personal leave of absence and before January 14 of the calendar year immediately following the calendar year in which the leave commenced. In the event Grantee does not return to active service from such leave of absence prior to January 14 of the calendar year immediately following the calendar year in which the leave commenced, any Restricted Stock Units covered by this Award that were not vested as of the commencement of such leave shall be immediately forfeited (as if Grantee terminated employment for purposes of Section 4 hereof).

Section 3.     Restrictive Covenants. 

(a)  In consideration of the Award, Grantee agrees that during the period ending on the _______ anniversary of the Date of Grant ("Restricted Period"), Grantee shall not for any reason, directly or indirectly, without the prior written consent of the Corporation or its delegate: (i) become employed, engaged or involved with a competitor (defined below) of the Corporation or any Subsidiary in a position that involves: providing services that relate to or are similar in nature or purpose to the services performed by the Grantee for the Corporation or any Subsidiary at any time during his or her previous _______ years of employment with the Corporation or any Subsidiary; or, supervision, management, direction or advice regarding such services; either as principal, agent, manager, employee, partner, shareholder, director, officer or consultant (other than as a less-than three percent (3%) equity owner of any corporation traded on any national, international or regional stock exchange or in the over-the-counter market); or (ii) induce or attempt to induce any customer, client, supplier, employee, agent or independent contractor of the Corporation or any of the Subsidiaries to reduce, terminate, restrict or otherwise alter (to the Corporation’s detriment) its business relationship with the Corporation. 

(b)       The noncompetition obligations of clause (i) of the preceding sentence shall be effective only with respect to a “competitor” of the Corporation or any Subsidiary which is understood to mean any person or entity in competition with the Corporation or any Subsidiary, and more particularly those persons and entities in the businesses of:  production, transmission, distribution, or retail or wholesale marketing or selling of electricity; resale or arranging for the purchase or for the resale, brokering, marketing, or trading of electricity or derivatives thereof; energy management and the provision of energy solutions; development and operation of power generation facilities, and sales and marketing of electric power and natural gas, domestically and abroad; and any other business in which the Corporation, including Subsidiaries, is engaged at the termination of Grantee’s continuous employment by the Corporation, including Subsidiaries; and within the following geographical areas: (i) any country in the world (other than the United States) where the Corporation, including Subsidiaries, has at least $25 million in capital deployed as of termination of Grantee's continuous employment by Corporation, including through its Subsidiaries; (ii) the states of Colorado, Florida, Georgia, Illinois, Indiana, Kentucky, Michigan, Minnesota, Mississippi, New York, North Carolina, Ohio, Pennsylvania, South Carolina, Tennessee, Texas, Vermont, Wisconsin and Wyoming (iii) any other state in the United States where the Corporation including the Subsidiaries, has at least $25 million in capital deployed as of the termination of the Grantee’s employment with the Corporation or any Subsidiary. The Corporation and Grantee intend the above restrictions on competition in geographical areas to be entirely severable and independent, and any invalidity or enforceability of this provision with respect to any one or more of such restrictions, including geographical areas, shall not render this provision unenforceable as applied to any one or more of the other restrictions, including geographical areas. 

(c)        Grantee agrees not to: (i) disclose to any third party or otherwise misappropriate any confidential or proprietary information of the Corporation or of any Subsidiary (except as required by subpoena or other legal process, in which event the Grantee will give the Chief Legal Officer of the Corporation prompt notice of such subpoena or other legal process in order to permit the Corporation or any affected individual to seek appropriate protective orders); or, (ii) publish or provide any oral or written statements about the Corporation or any Subsidiary, any of the Corporation's or any Subsidiary's current or former officers, executives, directors, employees, agents or representatives that are false, disparaging or defamatory, or that disclose private or confidential information about their business or personal affairs. The obligations of this paragraph are in addition to, and do not replace, eliminate, or reduce in any way, all other contractual, statutory, or common law obligations Grantee may have to protect the Corporation’s confidential information and trade secrets and to avoid defamation or business disparagement.

(d)       Notwithstanding any other provision of Section 3, the Grantee remains free to report or otherwise communicate with the Nuclear Regulatory Commission, United States Department of Labor, Securities and Exchange Commission, or any other appropriate governmental agency concerning any nuclear safety, workplace safety or any public safety concern, any potential violations or any other matters within such agency’s regulatory responsibility without providing the notice described in Section 3(c), and the Grantee remains free to participate in any governmental proceeding or investigation without providing the notice described in Section 3(c).

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(e)       If any part of this Section is held to be unenforceable because of the duration, scope or geographical area covered, the Corporation and Grantee agree to modify such part, or that the court making such holding shall have the power to modify such part, to reduce its duration, scope or geographical area.

(f)        Nothing in Section 3 shall be construed to prohibit Grantee from being retained during the Restricted Period in a capacity as an attorney licensed to practice law, or to restrict Grantee from providing advice and counsel in such capacity, in any jurisdiction where such prohibition or restriction is contrary to law.  Notwithstanding any provisions of this Award to the contrary, Grantee may be entitled to immunity and protection from retaliation under the Defend Trade Secrets Act of 2016 for disclosing a trade secret under limited circumstances, as set forth in the Corporation’s Innovations – Inventions, Patents and Intellectual Properties Policy.

(g)       Grantee’s agreement to the restrictions provided for in this Agreement and the Corporation’s agreement to provide the Award are mutually dependent consideration. Therefore, notwithstanding any other provision to the contrary in this Agreement, if Grantee materially breaches any provision of this Section 3 or if the enforceability of any material restriction on Grantee provided for in this Agreement is challenged and found unenforceable by a court of law then the Corporation shall, at its election, have the right to (i) cancel the Award, (ii) recover from Grantee any shares of Common Stock, Dividend Equivalents or other cash paid under Award, or (iii) with respect to any shares of Common Stock paid under the Award that have been disposed of, require the Grantee to repay to the Corporation the fair market value of such shares of Common Stock on the date such shares were sold, transferred, or otherwise disposed of by Grantee.   This provision shall be construed as a return of consideration or ill-gotten gains due to the failure of Grantee’s promises under the Agreement, and not as a liquidated damages clause.  Nothing herein shall (i) reduce or eliminate the Corporation’s right to assert that the restrictions provided for in this agreement are fully enforceable as written, or as modified by a court pursuant to Section 3, or (ii) eliminate, reduce, or compromise the application of temporary or permanent injunctive relief as a fully appropriate and applicable remedy to enforce the restrictions provided for in Section 3 (inclusive of its subparts), in addition to recovery of damages or other remedies otherwise allowed by law.

Section 4.    Forfeiture. Any unvested Restricted Stock Unit subject to this Award shall be forfeited upon the termination of Grantee's continuous employment by the Corporation, including Subsidiaries, prior to the Vesting Date, except to the extent otherwise provided in Section 2. Any Dividend Equivalent subject to this Award shall expire at the time the Restricted Stock Unit with respect to which the Dividend Equivalent is in tandem (i) is vested and paid, or deferred, or (ii) is forfeited.

Section 5.Dividend Equivalent Payments.  Payments with respect to any Dividend Equivalent subject to this Award shall be paid in cash to the Grantee at the same time as the vested Restricted Stock Units as provided in Section 6. The Dividend Equivalent payment amount shall equal the aggregate cash dividends declared and paid with respect to one share of Common Stock for the period beginning on the Date of Grant and ending on the date the vested Restricted Stock Units are paid and before the Dividend Equivalent expires. However, should the timing of a particular payment under Section 6 to the Grantee in shares of Common Stock in conjunction with the timing of a particular cash dividend declared and paid on Common Stock be such that the Grantee receives such shares without the right to receive such dividend and the Grantee would not otherwise be entitled to payment under the expiring Dividend Equivalent with respect to such dividend, the Grantee, nevertheless, shall be entitled to such payment. Dividend Equivalent payments shall be subject to withholding for taxes. Any required income tax withholdings in respect of Dividend Equivalents attributable to Restricted Stock Units shall be satisfied by reducing the cash payment in respect of the required withholding amount, unless the Committee, or its delegate, in its discretion, requires Grantee to satisfy such tax obligation by other payment to the Corporation.    

Section 6.    Payment of Restricted Stock Units.  Payment of Restricted Stock Units subject to this Award shall be made to the Grantee as soon as practicable following the time such units become vested in accordance with Section 2 but in no event later than 60 days following such vesting, except to the extent deferred by Grantee in accordance with such procedures as the Committee, or its delegate, may prescribe from time to time or except to the extent required to avoid accelerated taxation and/or tax penalties under Section 409A of the Code. To the extent the Grantee's right to receive payment of the Restricted Stock Units constitutes a "deferral of compensation" within the meaning of Section 409A of the Code, then notwithstanding the first sentence of this Section 6, except in the event that the Grantee’s employment terminates as a result of death, payment of vested Restricted Stock Units subject to this Award shall be made to the Grantee within 60 days following the Vesting Date as provided in Section 2(a). Payment (or deferrals, as applicable) shall be subject to withholding for taxes. Payment shall be in the form of one (1) share of Common Stock for each full Restricted Stock Unit and any fractional Restricted Stock Unit shall be made in a cash amount equal in value to the shares of Common Stock that would otherwise be paid, valued at Fair Market Value on the date the respective Restricted Stock Units became vested, or if later, payable. Notwithstanding the foregoing, the number of shares of Common Stock that would otherwise be paid or deferred (valued at Fair Market Value on the date the respective Restricted Stock Unit became vested, or if later, payable) shall be reduced by the Committee, or its delegate, in its sole discretion, to fully satisfy tax withholding requirements, unless the Committee, or its delegate, in its discretion requires Grantee to satisfy such tax obligation by other payment to the Corporation. In the event that payment, after any such reduction in the number of shares of Common Stock to satisfy withholding for tax requirements, would be less than ten (10) shares of Common Stock, then, if so determined by the Committee, or its delegate, in its sole discretion, payment, instead of being made in shares of Common Stock, shall be made in a cash amount equal in value to the shares of Common Stock that would otherwise be paid, valued at Fair Market Value on the date the respective Restricted Stock Units became vested, or if later, payable.

Section 7.No Employment Rights. Nothing in this Agreement or in the Plan shall confer upon the Grantee the right to continued employment by the Corporation or any Subsidiary, or affect the right of the Corporation or any Subsidiary to terminate the employment or service of the Grantee at any time for any reason.

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Section 8.Nonalienation. The Restricted Stock Units and Dividend Equivalents subject to this Award are not assignable or transferable by the Grantee. Upon any attempt to transfer, assign, pledge, hypothecate, sell or otherwise dispose of any such Restricted Stock Unit or Dividend Equivalent, or of any right or privilege conferred hereby, or upon the levy of any attachment or similar process upon such Restricted Stock Unit or Dividend Equivalent, or upon such right or privilege, such Restricted Stock Unit or Dividend Equivalent or right or privilege, shall immediately become null and void.

Section 9.    Determinations.  Determinations by the Committee, or its delegate, shall be final and conclusive with respect to the interpretation of the Plan and this Agreement.

Section 10.    Governing Law.  The validity and construction of this Agreement shall be governed by the laws of the state of Delaware applicable to transactions taking place entirely within that state.

Section 11.Conflicts with Plan, Correction of Errors, Section 409A and Grantee’s Consent.  In the event that any provision of this Agreement conflicts in any way with a provision of the Plan, such Plan provision shall be controlling and the applicable provision of this Agreement shall be without force and effect to the extent necessary to cause such Plan provision to be controlling. In the event that, due to administrative error, this Agreement does not accurately reflect a Restricted Stock Unit Award properly granted to Grantee pursuant to the Plan, the Corporation, acting through its Executive Compensation and Benefits Department, reserves the right to cancel any erroneous document and, if appropriate, to replace the cancelled document with a corrected document. It is the intention of the Corporation and the Grantee that this Award not result in unfavorable tax consequences to Grantee under Code Section 409A. Accordingly, Grantee consents to such amendment of this Agreement as the Corporation may reasonably make in furtherance of such intention, and the Corporation shall promptly provide, or make available to, Grantee a copy of any such amendment.

To the extent applicable, it is intended that this Agreement comply with the provisions of Section 409A of the Code and that this Award not result in unfavorable tax consequences to Grantee under Section 409A of the Code. This Agreement will be administered and interpreted in a manner consistent with this intent, and any provision that would cause this Agreement to fail to satisfy Section 409A of the Code will have no force and effect until amended to comply therewith (which amendment may be retroactive to the extent permitted by Section 409A of the Code). The Corporation and the Grantee agree to work together in good faith in an effort to comply with Section 409A of the Code including, if necessary, amending this Agreement based on further guidance issued by the Internal Revenue Service from time to time, provided that the Corporation shall not be required to assume any increased economic burden. Notwithstanding anything contained herein to the contrary, to the extent required in order to avoid accelerated taxation and/or tax penalties under Section 409A of the Code, the Grantee shall not be considered to have terminated employment with Corporation for purposes of this Agreement and no payments shall be due to him or her under this Agreement which are payable upon his or her termination of employment until he or she would be considered to have incurred a “separation from service” from the Corporation within the meaning of Section 409A of the Code. To the extent required in order to avoid accelerated taxation and/or tax penalties under Section 409A of the Code, amounts that would otherwise be payable and benefits that would otherwise be provided pursuant to this Agreement during the six-month period immediately following the Grantee’s termination of employment shall instead be paid within 60 days following the first business day after the date that is six months following his or her termination of employment (or upon his or her death or the regularly scheduled Vesting Date, if earlier). In addition, for purposes of this Agreement, each amount to be paid or benefit to be provided to the Grantee pursuant to this Agreement shall be construed as a separate identified payment for purposes of Section 409A of the Code.

Section 12.    Compliance with Law.  The Corporation shall make reasonable efforts to comply with all applicable federal and state securities laws applicable to the Plan and this Award; provided, however, notwithstanding any other provision of this Award, the Corporation shall not be obligated to deliver any shares of Common Stock pursuant to this Award if the delivery thereof would result in a violation of any such law.

Notwithstanding the foregoing, this Award is subject to cancellation by the Corporation in its sole discretion unless the Grantee, by not later than ___________, ______, has signed a duplicate of this Agreement, in the space provided below, and returned the signed duplicate to the Executive Compensation and Benefits Department – Restricted Stock Units____________________________________________________, which, if, and to the extent, permitted by the Executive Compensation and Benefits Department, may be accomplished by electronic means.

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IN WITNESS WHEREOF, the Corporation has caused this Agreement to be executed and granted in Charlotte, North Carolina, to be effective as of the Date of Grant.

DUKE ENERGY CORPORATION

By: ____________________________

                        Its:

Acceptance of Performance-Based Retention Award

IN WITNESS OF Grantee's acceptance of this Award and Grantee's agreement to be bound by the provisions of this Agreement and the Plan, Grantee has signed this Agreement this _____ day of _____________________, _____.

____________________________

Grantee’s Signature

____________________________    

(print name)

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EX-10.3

Exhibit 10.3

PERFORMANCE AWARD AGREEMENT

This Performance Award Agreement (the "Agreement") has been made as of ________________ (the "Date of Grant") between Duke Energy Corporation, a Delaware corporation, with its principal offices in Charlotte, North Carolina (the "Corporation"), and ________________ (the "Grantee").

RECITALS

Under the Duke Energy Corporation 2015 Long-Term Incentive Plan, as it may, from time to time, be further amended (the "Plan"), the Compensation Committee of the Board of Directors of the Corporation (the "Committee"), or its delegatee, has determined the form of this Agreement and selected the Grantee, as an Employee, to receive the award evidenced by this Agreement (the “Award”) and the Performance Shares and tandem Dividend Equivalents that are subject hereto. The applicable provisions of the Plan are incorporated in this Agreement by reference, including the definitions of terms contained in the Plan (unless such terms are otherwise defined herein).

AWARD

In accordance with the Plan, the Corporation has made this Award, effective as of the Date of Grant and upon the following terms and conditions:

Section 1.    Number and Nature of Performance Shares and Tandem Dividend Equivalents.  At target performance, the number of Performance Shares and the number of tandem Dividend Equivalents subject to this Award are each ______________________________. Each Performance Share, upon becoming vested, represents a right to receive payment in the form of one (1) share of Common Stock. Each tandem Dividend Equivalent, after its tandem Performance Share vests, represents a right to receive a cash payment equivalent in amount to the aggregate cash dividends declared and paid on one (1) share of Common Stock for the period beginning on the Date of Grant and ending on the date the vested, tandem Performance Share is paid or deferred and before the Dividend Equivalent expires. Performance Shares and Dividend Equivalents are used solely as units of measurement, and are not shares of Common Stock and the Grantee is not, and has no rights as, a shareholder of the Corporation by virtue of this Award.

Section 2.    Vesting of Performance Shares.

(a) Performance Goals. Except as otherwise provided in this Section 2, the Performance Shares shall vest only if and to the extent the Committee, or its delegatee, determines that the Performance Goals (as defined below) have been met (provided that such determination shall be made not later than the first March 15 following the end of the Performance Period, as defined below). To the extent Performance Goals are not met, the Performance Shares that do not so become vested shall be forfeited. The Committee reserves the right to reduce any vesting to the extent the Committee determines that such reduction is equitable and appropriate for any reason, including reductions based on overall financial performance, such as, adjusted and reported earnings, capital deployment and credit position during the Performance Period (as defined below). 

(i) The following Performance Goal shall apply with respect to ____ of the Performance Shares and Dividend Equivalents covered by this Agreement. Provided Grantee’s continuous employment by the Corporation, including Subsidiaries, has not terminated, or as otherwise provided in Sections 2(b) or 2(c), _____ of the Performance Shares subject to this Award shall become vested upon the written determination by the Committee, or its delegatee, in its sole discretion, of the extent to which the Corporation achieves the “TSR Performance Goal,” which is the Corporation’s Total Shareholder Return (“TSR”) percentile ranking among the companies that are in the Philadelphia Utility Index as of the beginning of the Performance Period, with higher percentile ranking for more positive/less negative TSR, for the period beginning ___________ and ending ____________ (“Performance Period”), in accordance with the applicable vesting percentage specified for such percentile ranking in the following schedule:

Percentile Ranking Vesting Percentage (Applicable to Target # of Shares)

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*When such determination is of a percentile ranking between those specified, the Committee, or its delegatee, in its sole discretion, shall interpolate to determine the applicable vesting percentage. If the Corporation’s TSR is at least ____ during the Performance Period, the vesting percentage for this portion of the Performance Shares and Dividend Equivalents shall not be less than _____, and if the Corporation’s TSR is less than _____ during the Performance Period, the vesting percentage for this portion of the Performance Shares and Dividend Equivalents shall not be more than _______.

Such Performance Shares that do not so become vested shall be forfeited. For purposes of this Agreement, TSR means, with respect to any company, the percentage change in total stockholder return, determined by dividing (A) the difference between the price of a share of the company’s common stock from the Opening Value (as defined below) to the Closing Value (as defined below), with any dividends with ex-dividend dates falling inside the Performance Period deemed reinvested in the company’s common stock on the ex-dividend date, by (B) the Opening Value. The term “Opening Value” means, with respect to any company, the average of the closing prices per share of the company’s common stock on each trading day during the calendar month preceding the start of the Performance Period, assuming any dividends with ex-dividend dates falling inside such calendar month are deemed reinvested in the company’s common stock on the ex-dividend date. The term “Closing Value” means, with respect to any company, the average of the closing prices per share of the company’s common stock on each trading day during the last calendar month of the Performance Period, assuming any dividends with ex-dividend dates falling inside such calendar month are deemed reinvested in the company’s common stock on the ex-dividend date. In the event that a company becomes a member of the Philadelphia Utility Index following __________, or if a member of the Philadelphia Utility Index on ____________ ceases to exist during the Performance Period as a separate publicly-traded company due to a merger, acquisition or privatization, such company shall not be taken into account for purposes of this Agreement. If a member of the Philadelphia Utility Index on __________ becomes bankrupt or insolvent during the Performance Period and ceases to be publicly-traded, for purposes of this Agreement its TSR shall be -100%.

(ii) The following Performance Goal shall apply with respect to ______ of the Performance Shares and Dividend Equivalents covered by this Agreement. Provided Grantee’s continuous employment by the Corporation, including Subsidiaries, has not terminated, or as otherwise provided in Sections 2(b) or 2(c), ______ of the Performance Shares subject to this Award shall become vested upon the written determination by the Committee, or its delegatee, in its sole discretion, of the extent to which the Corporation achieves the “Cumulative Adjusted EPS Performance Goal,” which is based on the Corporation’s cumulative adjusted earnings per share (“EPS”), for the Performance Period, in accordance with the applicable vesting percentage specified for Cumulative Adjusted EPS in the following schedule:

Cumulative Adjusted EPS Vesting Percentage (Applicable to Target # of Shares)

*When such determination is at a level between those specified, the Committee, or its delegatee, in its sole discretion, shall interpolate to determine the applicable vesting percentage. The Committee shall have the authority to calculate and adjust the Cumulative Adjusted EPS and the Cumulative Adjusted EPS Performance Goal in the same manner as adjusted diluted EPS is calculated and adjusted pursuant to the __________________________.

Such Performance Shares that do not so become vested shall be forfeited.  

(iii) The following Performance Goal shall apply with respect to _____ of the Performance Shares and Dividend Equivalents covered by this Agreement. Provided Grantee’s continuous employment by the Corporation, including Subsidiaries, has not terminated, or as otherwise provided in Sections 2(b) or 2(c), _____ of the Performance Shares subject to this Award shall become vested upon the written determination by the Committee, or its delegatee, in its sole discretion, of the extent to which the Corporation achieves the “TICR Performance Goal,” which is the Corporation’s total incident case rate for employees (“TICR”) as compared to the applicable vesting percentage specified in the following schedule:

Percentile Ranking Vesting Percentage (Applicable to Target # of Shares)

2

*When such determination is of a percentile ranking between those specified, the Committee, or its delegatee, in its sole discretion, shall interpolate to determine the applicable vesting percentage. [The employees of the legacy Piedmont Natural Gas Company, or of any company acquired during the Performance Period, shall not be taken into account when measuring the Corporation’s TICR for the Performance Period.]

Such Performance Shares that do not so become vested shall be forfeited.

(iv) If the Committee determines that a merger, consolidation, liquidation, issuance of rights or warrants to purchase securities, recapitalization, reclassification, stock dividend, spin-off, split-off, stock split, reverse stock split or other distribution with respect to the shares of Common Stock, or any similar corporate transaction or event in respect of the Common Stock, the manner in which the Corporation conducts its business, changes in the law or regulations or regulatory structure, changes in accounting practices, other unusual or nonrecurring items or occurrences, or other events or circumstances, render the Performance Goals to be unsuitable, the Committee may, in its sole discretion, and without the consent of the Grantee or any other persons, modify the calculation of the Performance Goals, or any of the related minimum, target or maximum levels of achievement, in whole or in part, as the Committee deems equitable and appropriate to reflect such event; provided, however, that no such action may result in the loss of the otherwise available exemption of the Award under Section 162(m) of the Code. 

(b) In the event that, prior to the date that the determination of the achievement of each Performance Goal is made, the Grantee’s continuous employment by the Corporation, including Subsidiaries, terminates, the Performance Shares subject to this Award are thereupon forfeited, except that if such employment terminates (i) upon Retirement (as defined below), (ii) as the result of the Grantee’s death, (iii) as the result of the Grantee’s permanent and total disability within the meaning of Code Section 22(e)(3), (iv) as the result of the termination of such employment by the Corporation, or employing Subsidiary, other than for cause, as determined by the Corporation or employing Subsidiary, in its sole discretion, or (v) as the direct and sole result, as determined by the Corporation, or employing Subsidiary, in its sole discretion, of the divestiture of assets, a business, or a company, by the Corporation or a Subsidiary, then, unless the Committee, or its delegate, in its sole discretion determine that Grantee is in violation of any obligation identified in Section 3, the Performance Shares subject to this Award shall vest upon such determination of the achievement of each Performance Goal, at such vesting percentage determined by the Committee, or its delegatee, in its sole discretion, by prorating on the basis of the portion of the Performance Period that such employment continued while Grantee was entitled to payment of salary (unless such termination occurs after the end of the Performance Period, in which event the number of Performance Shares earned, if any, shall not be prorated). “Retirement” shall mean Grantee’s voluntary termination of employment with the Corporation and its Subsidiaries after having attained age 55 and completed 10 years of service (as determined for purposes of access to retiree medical coverage).

In the event that Grantee is on an employer-approved, personal leave of absence on the date that the determination of the achievement of each Performance Goal is made, then, unless prohibited by law, vesting shall be postponed and shall not occur unless and until Grantee returns to active service in accordance with the terms of the approved personal leave of absence and before November 1 of the calendar year immediately following the calendar year in which the Performance Period ends. In the event Grantee does not return to active service from such leave of absence prior to November 1 of the calendar year immediately following the calendar year in which the Performance Period ends, any Performance Shares covered by this Award that were not vested as of the commencement of such leave shall be immediately forfeited (as if Grantee terminated employment for purposes of Section 4 hereof). Further, in the event that such determination is made and during any portion of the Performance Period the Grantee was on employer-approved, personal leave of absence, the applicable vesting percentage shall be determined by the Committee, or its delegatee, in its sole discretion, to reflect only that portion of the Performance Period during which such employment continued while the Grantee was entitled to payment of salary.

(c) In the event that a Change in Control occurs before the Performance Period has ended and (i) before the Grantee’s continuous employment by the Corporation, including Subsidiaries, terminates, or (ii) after such employment terminates during the Performance Period, (A) at a time when Grantee is considered "retired", unless the Corporation, in its sole discretion, determines that Grantee is in violation of any obligation identified in Section 3, or (B) as the result of an event listed in items (ii) – (v) of the first sentence of Section 2(b), the Performance Shares subject to this Award shall vest upon such occurrence, at such vesting percentage determined by the Committee, or its delegatee, in its sole discretion, by prorating down, assuming performance at the target level for each Performance Goal, on the basis of the portion of the Performance Period that has elapsed prior to the time of such occurrence (or such earlier termination of employment), and the remaining Performance Shares shall be forfeited, irrespective of any subsequent determination of the achievement of each Performance Goal.

Section 3.    Restrictive Covenants. 

(a)       In consideration of the Award, Grantee agrees that during the period beginning with termination of employment and ending with the ______ anniversary of the Date of Grant ("Restricted Period"), Grantee shall not for any reason, directly or indirectly, without the prior written consent of the Corporation or its delegatee: (i) become employed, engaged or involved with a competitor (defined below) of the Corporation or any Subsidiary in a position that involves: providing services that relate to or are similar in nature or purpose to the services performed by the Grantee for the Corporation or any Subsidiary at any time during his or her previous _______ years of employment with the Corporation or any Subsidiary; or, supervision, management, direction or advice regarding such services; either as principal, agent, manager, employee, partner, shareholder, director, officer or consultant (other than as a less-than three percent (3%) equity owner of any corporation traded on any national, international or regional stock exchange or in the over-the-

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counter market); or, (ii) induce or attempt to induce any customer, client, supplier, employee, agent or independent contractor of the Corporation or any of the Subsidiaries to reduce, terminate, restrict or otherwise alter (to the Corporation’s detriment) its business relationship with the Corporation. 

(b)       The noncompetition obligations of clause (i) of the preceding sentence shall be effective only with respect to a “competitor” of the Corporation or any Subsidiary which is understood to mean any person or entity in competition with the Corporation or any Subsidiary, and more particularly those persons and entities in the businesses of:  production, transmission, distribution, or retail or wholesale marketing or selling of electricity; resale or arranging for the purchase or for the resale, brokering, marketing, or trading of electricity or derivatives thereof; energy management and the provision of energy solutions; development and operation of power generation facilities, and sales and marketing of electric power and natural gas, domestically and abroad; and any other business in which the Corporation, including Subsidiaries, is engaged at the termination of Grantee’s continuous employment by the Corporation, including Subsidiaries; and within the following geographical areas: (i) any country in the world (other than the United States) where the Corporation, including Subsidiaries, has at least $25 million in capital deployed as of termination of Grantee's continuous employment by Corporation, including through its Subsidiaries; (ii) the states of Colorado, Florida, Georgia, Illinois, Indiana, Kentucky, Michigan, Minnesota, Mississippi, New York, North Carolina, Tennessee, Ohio, Pennsylvania, South Carolina, Texas, Vermont, Wisconsin and Wyoming (iii) any other state in the United States where the Corporation including the Subsidiaries, has at least $25 million in capital deployed as of the termination of the Grantee’s employment with the Corporation or any Subsidiary.  The Corporation and Grantee intend the above restrictions on competition in geographical areas to be entirely severable and independent, and any invalidity or enforceability of this provision with respect to any one or more of such restrictions, including geographical areas, shall not render this provision unenforceable as applied to any one or more of the other restrictions, including geographical areas. 

(c)        Grantee agrees not to: (i) disclose to any third party or otherwise misappropriate any confidential or proprietary information of the Corporation or of any Subsidiary (except as required by subpoena or other legal process, in which event the Grantee will give the Chief Legal Officer of the Corporation prompt notice of such subpoena or other legal process in order to permit the Corporation or any affected individual to seek appropriate protective orders); or, (ii) publish or provide any oral or written statements about the Corporation or any Subsidiary, any of the Corporation's or any Subsidiary's current or former officers, executives, directors, employees, agents or representatives that are false, disparaging or defamatory, or that disclose private or confidential information about their business or personal affairs.   The obligations of this paragraph are in addition to, and do not replace, eliminate, or reduce in any way, all other contractual, statutory, or common law obligations Grantee may have to protect the Corporation’s confidential information and trade secrets and to avoid defamation or business disparagement.

(d)       Notwithstanding any other provision of Section 3, the Grantee remains free to report or otherwise communicate any nuclear safety concern, any workplace safety concern, or any public safety concern to the Nuclear Regulatory Commission, United States Department of Labor, Securities and Exchange Commission, or any other appropriate governmental agency without providing the notice described in Section 3(c), and the Grantee remains free to participate in any governmental proceeding or investigation without providing the notice described in Section 3(c).

(e)       If any part of this Section is held to be unenforceable because of the duration, scope or geographical area covered, the Corporation and Grantee agree to modify such part, or that the court making such holding shall have the power to modify such part, to reduce its duration, scope or geographical area.

(f)        Nothing in Section 3 shall be construed to prohibit Grantee from being retained during the Restricted Period in a capacity as an attorney licensed to practice law, or to restrict Grantee from providing advice and counsel in such capacity, in any jurisdiction where such prohibition or restriction is contrary to law.  Notwithstanding any provisions of this Award to the contrary, Grantee may be entitled to immunity and protection from retaliation under the Defend Trade Secrets Act of 2016 for disclosing a trade secret under limited circumstances, as set forth in the Corporation’s Innovations – Inventions, Patents and Intellectual Properties Policy.

(g)       Grantee’s agreement to the restrictions provided for in this Agreement and the Corporation’s agreement to provide the Award are mutually dependent consideration. Therefore, notwithstanding any other provision to the contrary in this Agreement, if the enforceability of any material restriction on Grantee provided for in this Agreement is challenged and found unenforceable by a court of law then the Corporation shall, at its election, have the right to (i) cancel the Award, (ii) recover from Grantee any shares of Common Stock, Dividend Equivalents or other cash paid under Award, or (iii) with respect to any shares of Common Stock paid under the Award that have been disposed of, require the Grantee to repay to the Corporation the fair market value of such shares of Common Stock on the date such shares were sold, transferred, or otherwise disposed of by Grantee.  This provision shall be construed as a return of consideration or ill-gotten gains due to the failure of Grantee’s promises under the Agreement, and not as a liquidated damages clause.  Nothing herein shall (i) reduce or eliminate the Corporation’s right to assert that the restrictions provided for in this agreement are fully enforceable as written, or as modified by a court pursuant to Section 3, or (ii) eliminate, reduce, or compromise the application of temporary or permanent injunctive relief as a fully appropriate and applicable remedy to enforce the restrictions provided for in Section 3 (inclusive of its subparts), in addition to recovery of damages or other remedies otherwise allowed by law.

Section 4.    Forfeiture. Any Performance Share subject to this Award shall be forfeited upon the termination of the Grantee's continuous employment by the Corporation, including Subsidiaries, from the Date of Grant, except to the extent otherwise provided in Section 2. Any Dividend Equivalent subject to this Award shall expire at the time its tandem Performance Share (i) is vested and paid, or deferred, or (ii) is forfeited.

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Section 5.    Dividend Equivalent Payment. Payment with respect to any Dividend Equivalent subject to this Award that is in tandem with a Performance Share that is vested and paid shall be paid in cash to the Grantee at the same time as the vested Performance Share as provided in Section 6, or, if the vested Performance Share is deferred by Grantee as provided in Section 6, payment with respect to the tandem Dividend Equivalent shall likewise be deferred. The Dividend Equivalent payment amount shall equal the aggregate cash dividends declared and paid with respect to one (1) share of Common Stock for the period beginning on the Date of Grant and ending on the date the vested, tandem Performance Share is paid or deferred and before the Dividend Equivalent expires. However, should the timing of a particular payment under Section 6 to the Grantee in shares of Common Stock in conjunction with the timing of a particular cash dividend declared and paid on Common Stock be such that the Grantee receives such shares without the right to receive such dividend and the Grantee would not otherwise be entitled to payment under the expiring Dividend Equivalent with respect to such dividend, the Grantee, nevertheless, shall be entitled to such payment. Dividend Equivalent payments shall be subject to withholding for taxes. Any required income tax withholdings in respect of Dividend Equivalents attributable to Performance Shares shall be satisfied by reducing the cash payment in respect of the required withholding amount, unless the Committee, or its delegatee, in its discretion, requires Grantee to satisfy such tax obligation by other payment to the Corporation.

Section 6.    Payment of Performance Shares. Payment of Performance Shares subject to this Award that become vested shall be made to the Grantee on the earlier of: (i) the calendar year immediately following the Performance Period, or (ii) within 30 days after the occurrence of a "change in the ownership," a "change in the effective control" or a "change in the ownership of a substantial portion of the assets" of the Corporation within the meaning of Section 409A of the Code, except to the extent deferred by the Grantee in accordance with such procedures as the Committee, or its delegatee, may prescribe from time to time or except to the extent required to avoid accelerated taxation and/or tax penalties under Section 409A of the Code. Payment (or deferrals, as applicable) shall be subject to withholding for taxes. Payment shall be in the form of one (1) share of Common Stock for each full vested Performance Share, and any fractional vested Performance Share shall be rounded up to the next whole share for purposes of both vesting under Section 2 and payment under Section 6. Notwithstanding the foregoing, the number of shares of Common Stock that would otherwise be paid or deferred (valued at Fair Market Value on the date the respective Performance Share became vested, or if later, payable) shall be reduced by the Committee, or its delegate, in its sole discretion, to fully satisfy tax withholding requirements, unless the Committee, or its delegate, in its discretion requires Grantee to satisfy such tax obligation by other payment to the Corporation. In the event that payment, after any reduction in the number of shares of Common Stock to satisfy withholding for tax requirements, would be for less than ten (10) shares of Common Stock, then, if so determined by the Committee, or its delegate, in its sole discretion, payment, instead of being made in shares of Common Stock, shall be made in a cash amount equal in value to the shares of Common Stock that would otherwise be paid, valued at Fair Market Value on the date the respective Performance Shares became vested.

Section 7.    No Employment Right. Nothing in this Agreement or in the Plan shall confer upon the Grantee the right to continued employment with the Corporation or any Subsidiary, or affect the right of the Corporation or any Subsidiary to terminate the employment or service of the Grantee at any time for any reason.

Section 8.    Nonalienation. The Performance Shares and Dividend Equivalents subject to this Award are not assignable or transferable by Grantee. Upon any attempt to transfer, assign, pledge, hypothecate, sell or otherwise dispose of any such Performance Share or Dividend Equivalent, or of any right or privilege conferred hereby, or upon the levy of any attachment or similar process upon such Performance Share or Dividend Equivalent, or upon such right or privilege, such Performance Share or Dividend Equivalent, or such right or privilege, shall immediately become null and void.

Section 9.    Determinations. Determinations by the Committee, or its delegatee, shall be final and conclusive with respect to the interpretation of the Plan and this Agreement.

Section 10.    Governing Law. This Agreement shall be governed, construed and enforced in accordance with the laws of the State of Delaware applicable to transactions that take place entirely within that state.

Section 11.    Conflicts with Plan, Correction of Errors, Section 409A and Grantee’s Consent. In the event that any provision of this Agreement conflicts in any way with a provision of the Plan, such Plan provision shall be controlling and the applicable provision of this Agreement shall be without force and effect to the extent necessary to cause such Plan provision to be controlling. In the event that, due to administrative error, this Agreement does not accurately reflect an Award properly granted to the Grantee pursuant to the Plan, the Corporation, acting through its Executive Compensation and Benefits Department, reserves the right to cancel any erroneous document and, if appropriate, to replace the cancelled document with a corrected document. It is the intention of the Corporation and the Grantee that this Award not result in unfavorable tax consequences to Grantee under Code Section 409A. Accordingly, Grantee consents to such amendment of this Agreement as the Corporation may reasonably make in furtherance of such intention, and the Corporation shall promptly provide, or make available to, Grantee a copy of any such amendment.

To the extent applicable, it is intended that this Agreement comply with the provisions of Section 409A of the Code and that this Award not result in unfavorable tax consequences to Grantee under Section 409A of the Code. This Agreement will be administered and interpreted in a manner consistent with this intent, and any provision that would cause this Agreement to fail to satisfy Section 409A of the Code will have no force and effect until amended to comply therewith (which amendment may be retroactive to the extent permitted by Section 409A of the Code). The Corporation and the Grantee agree to work together in good faith in an effort to comply with Section 409A of the Code including, if necessary, amending this Agreement based on further guidance issued by the Internal Revenue Service from time to time, provided that the Corporation shall not be required to assume any increased economic burden. Notwithstanding anything contained herein to the contrary, to the extent required in order to avoid accelerated taxation and/or tax

5

penalties under Section 409A of the Code, the Grantee shall not be considered to have terminated employment with Corporation for purposes of this Agreement and no payments shall be due to him under this Agreement which are payable upon his termination of employment until he would be considered to have incurred a “separation from service” from the Corporation within the meaning of Section 409A of the Code. To the extent required in order to avoid accelerated taxation and/or tax penalties under Section 409A of the Code, amounts that would otherwise be payable and benefits that would otherwise be provided pursuant to this Agreement during the six-month period immediately following the Grantee’s termination of employment shall instead be paid within 30 days following the first business day after the date that is six months following his termination of employment (or upon his death, if earlier). In addition, for purposes of this Agreement, each amount to be paid or benefit to be provided to the Grantee pursuant to this Agreement shall be construed as a separate identified payment for purposes of Section 409A of the Code.

Grantee acknowledges and agrees that payments made under this Agreement are subject to the Corporation's requirement that the Grantee reimburse the portion of any payment where such portion of the payment was (i) inadvertently paid based on an incorrect calculation, or (ii) predicated upon the achievement of financial results that are subsequently the subject of a restatement caused or partially caused by Grantee's fraud or misconduct.

Section 12.    Compliance with Law. The Corporation shall make reasonable efforts to comply with all applicable federal and state securities laws applicable to the Plan and this Award; provided, however, notwithstanding any other provision of this Award, the Corporation shall not be obligated to deliver any shares of Common Stock pursuant to this Award if the delivery thereof would result in a violation of any such law.

Notwithstanding the foregoing, this Award is subject to cancellation by the Corporation in its sole discretion unless the Grantee, by not later than___________, _______, has signed a duplicate of this Agreement, in the space provided below, and returned the signed duplicate to the Executive Compensation and Benefits Department - Performance Award ____________________________________, which, if, and to the extent, permitted by the Executive Compensation and Benefits Department, may be accomplished by electronic means.

IN WITNESS WHEREOF, the Corporation has caused this Agreement to be executed and granted in Charlotte, North Carolina, to be effective as of the Date of Grant.

DUKE ENERGY CORPORATION

By: ____________________________

Its:

Acceptance of Performance Award

IN WITNESS OF Grantee's acceptance of this Performance Award and Grantee's agreement to be bound by the provisions of this Agreement and the Plan, Grantee has signed this Agreement this _____ day of _____________________, _________.

____________________________

Grantee's Signature

____________________________

(print name)

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EX-10.4

Exhibit 10.4

RESTRICTED STOCK UNIT AWARD AGREEMENT

This Restricted Stock Unit Award Agreement (the "Agreement") has been made as of_________________, (the "Date of Grant") between Duke Energy Corporation, a Delaware corporation, with its principal offices in Charlotte, North Carolina (the "Corporation"), and _______________ (the "Grantee").

RECITALS

Under the Duke Energy Corporation 2015 Long-Term Incentive Plan, as it may, from time to time, be further amended (the "Plan"), the Compensation Committee of the Board of Directors of the Corporation (the "Committee"), or its delegate, has determined the form of this Agreement and selected the Grantee, as an Employee, to receive the award evidenced by this Agreement (the "Award") and the “Restricted Stock Units” and tandem Dividend Equivalents that are subject hereto. The applicable provisions of the Plan are incorporated in this Agreement by reference, including the definitions of terms contained in the Plan (unless such terms are otherwise defined herein).

AWARD

In accordance with the Plan, the Corporation has made this Award, effective as of the Date of Grant and upon the following terms and conditions:

Section 1.Number and Nature of Restricted Stock Units and Tandem Dividend Equivalents.  The number of Restricted Stock Units and the number of tandem Dividend Equivalents subject to this Award are each __________________________________. Each Restricted Stock Unit, upon becoming vested, represents a right to receive payment in the form of one (1) share of Common Stock. Each tandem Dividend Equivalent represents a right to receive cash payments equivalent to the amount of cash dividends declared and paid on one (1) share of Common Stock after the Date of Grant and before the Dividend Equivalent expires. Restricted Stock Units and Dividend Equivalents are used solely as units of measurement and are not shares of Common Stock, and the Grantee is not, and has no rights as, a shareholder of the Corporation by virtue of this Award.

Section 2.Vesting of Restricted Stock Units.  The specified percentage of the Restricted Stock Units subject to this Award, and not previously forfeited, shall vest, with such percentage considered satisfied to the extent such Restricted Stock Units have not previously vested, as follows:

(a)Upon Grantee remaining continuously employed by the Corporation, including Subsidiaries, through the specified anniversary of the Date of Grant (each a "Vesting Date"), the percentage of Restricted Stock Units set forth next to such date shall become vested:

Vesting Percentage Anniversary

(b)    If such employment terminates (i) as the result of Grantee’s death or (ii) as the result of Grantee’s permanent and total disability within the meaning of Code Section 22(e)(3), all Restricted Stock Units subject to this Award, which units have not previously been forfeited or vested, immediately shall become fully vested, unless the Committee or its delegate, in its sole discretion, determines that Grantee is in violation of any obligation identified in Section 3, in which case any Restricted Stock Units not previously vested shall be forfeited.

(c)    If such employment terminates: (i) upon Retirement (as defined below), (ii) as the result of termination of such employment by the Corporation, or employing Subsidiary, other than for cause, as determined by the Committee or its delegate, or (iii) as the direct and sole result, as determined by the Committee or its delegate, in its sole discretion, of the divestiture of assets, a business or a company by the Corporation or a Subsidiary, then, unless the Committee or its delegate, in its sole discretion, determines that Grantee is in violation of any obligation identified in Section 3, in which case any Restricted Stock Units not previously vested shall be forfeited, the Restricted Stock Units subject to this Award shall vest at such vesting percentage determined by the Committee or its delegate, in its sole discretion, by prorating from the above schedule to reflect only that portion of the period beginning on the Date of Grant and ending with the __________ anniversary of the Date of Grant during which such employment continued while Grantee was entitled to payment of salary, and any such Restricted Stock Units not then or previously vested shall be forfeited. For purposes of this Agreement, “Retirement” shall mean Grantee’s voluntary termination of employment with the Corporation and its Subsidiaries after having attained age 55 and completed 10 years of service (as determined for purposes of access to retiree medical coverage).

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(d)    100% of the Restricted Stock Units shall become vested, if, following the occurrence of a Change in Control and before the second anniversary of such occurrence, such employment is terminated involuntarily, and not for cause, by the Corporation, or employing Subsidiary, as determined by the Committee or its delegate in its sole discretion.

(e)    Unless the Grantee's right to receive payment of the Restricted Stock Units constitutes a "deferral of compensation" within the meaning of Section 409A of the Code, in the event that at a time when vesting would otherwise occur under Section 2(a), 2(b) or 2(c) Grantee is on an employer-approved, personal leave of absence, then, unless prohibited by law, vesting shall be postponed and shall not occur unless and until Grantee returns to active service in accordance with the terms of the approved personal leave of absence and before January 14 of the calendar year immediately following the calendar year in which the leave commenced. In the event Grantee does not return to active service from such leave of absence prior to January 14 of the calendar year immediately following the calendar year in which the leave commenced, any Restricted Stock Units covered by this Award that were not vested as of the commencement of such leave shall be immediately forfeited (as if Grantee terminated employment for purposes of Section 4 hereof).

Section 3.     Restrictive Covenants. 

(a)       In consideration of the Award, Grantee agrees that during the period ending on the _______ anniversary of the Date of Grant ("Restricted Period"), Grantee shall not for any reason, directly or indirectly, without the prior written consent of the Corporation or its delegate: (i) become employed, engaged or involved with a competitor (defined below) of the Corporation or any Subsidiary in a position that involves: providing services that relate to or are similar in nature or purpose to the services performed by the Grantee for the Corporation or any Subsidiary at any time during his or her previous ________ years of employment with the Corporation or any Subsidiary; or, supervision, management, direction or advice regarding such services; either as principal, agent, manager, employee, partner, shareholder, director, officer or consultant (other than as a less-than three percent (3%) equity owner of any corporation traded on any national, international or regional stock exchange or in the over-the-counter market); or, (ii) induce or attempt to induce any customer, client, supplier, employee, agent or independent contractor of the Corporation or any of the Subsidiaries to reduce, terminate, restrict or otherwise alter (to the Corporation’s detriment) its business relationship with the Corporation. 

(b)       The noncompetition obligations of clause (i) of the preceding sentence shall be effective only with respect to a “competitor” of the Corporation or any Subsidiary which is understood to mean any person or entity in competition with the Corporation or any Subsidiary, and more particularly those persons and entities in the businesses of:  production, transmission, distribution, or retail or wholesale marketing or selling of electricity; resale or arranging for the purchase or for the resale, brokering, marketing, or trading of electricity or derivatives thereof; energy management and the provision of energy solutions; development and operation of power generation facilities, and sales and marketing of electric power and natural gas, domestically and abroad; and any other business in which the Corporation, including Subsidiaries, is engaged at the termination of Grantee’s continuous employment by the Corporation, including Subsidiaries; and within the following geographical areas: (i) any country in the world (other than the United States) where the Corporation, including Subsidiaries, has at least $25 million in capital deployed as of termination of Grantee's continuous employment by Corporation, including through its Subsidiaries; (ii) the states of Colorado, Florida, Georgia, Illinois, Indiana, Kentucky, Michigan, Minnesota, Mississippi, New York, North Carolina, Ohio, Pennsylvania, South Carolina, Tennessee, Texas, Vermont, Wisconsin and Wyoming, and (iii) any other state in the United States where the Corporation including the Subsidiaries, has at least $25 million in capital deployed as of the termination of the Grantee’s employment with the Corporation or any Subsidiary.  The Corporation and Grantee intend the above restrictions on competition in geographical areas to be entirely severable and independent, and any invalidity or enforceability of this provision with respect to any one or more of such restrictions, including geographical areas, shall not render this provision unenforceable as applied to any one or more of the other restrictions, including geographical areas. 

(c)        Grantee agrees not to: (i) disclose to any third party or otherwise misappropriate any confidential or proprietary information of the Corporation or of any Subsidiary (except as required by subpoena or other legal process, in which event the Grantee will give the Chief Legal Officer of the Corporation prompt notice of such subpoena or other legal process in order to permit the Corporation or any affected individual to seek appropriate protective orders); or, (ii) publish or provide any oral or written statements about the Corporation or any Subsidiary, any of the Corporation's or any Subsidiary's current or former officers, executives, directors, employees, agents or representatives that are false, disparaging or defamatory, or that disclose private or confidential information about their business or personal affairs.   The obligations of this paragraph are in addition to, and do not replace, eliminate, or reduce in any way, all other contractual, statutory, or common law obligations Grantee may have to protect the Corporation’s confidential information and trade secrets and to avoid defamation or business disparagement.

(d)       Notwithstanding any other provision of Section 3, the Grantee remains free to report or otherwise communicate with the Nuclear Regulatory Commission, United States Department of Labor, Securities and Exchange Commission, or any other appropriate governmental agency concerning any nuclear safety, workplace safety or any public safety concern, any potential violations or any other matters within such agency’s regulatory responsibility without providing the notice described in Section 3(c), and the Grantee remains free to participate in any governmental proceeding or investigation without providing the notice described in Section 3(c).

(e)       If any part of this Section is held to be unenforceable because of the duration, scope or geographical area covered, the Corporation and Grantee agree to modify such part, or that the court making such holding shall have the power to modify such part, to reduce its duration, scope or geographical area.

(f)        Nothing in Section 3 shall be construed to prohibit Grantee from being retained during the Restricted Period in a capacity as an attorney licensed to practice law, or to restrict Grantee from providing advice and counsel in such capacity, in any jurisdiction where such prohibition or restriction is contrary to law.  Notwithstanding any provisions of this Award to the contrary, Grantee

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may be entitled to immunity and protection from retaliation under the Defend Trade Secrets Act of 2016 for disclosing a trade secret under limited circumstances, as set forth in the Corporation’s Innovations - Inventions, Patents and Intellectual Properties Policy.

(g)       Grantee’s agreement to the restrictions provided for in this Agreement and the Corporation’s agreement to provide the Award are mutually dependent consideration. Therefore, notwithstanding any other provision to the contrary in this Agreement, if Grantee materially breaches any provision of this Section 3 or if the enforceability of any material restriction on Grantee provided for in this Agreement is challenged and found unenforceable by a court of law then the Corporation shall, at its election, have the right to (i) cancel the Award, (ii) recover from Grantee any shares of Common Stock, Dividend Equivalents or other cash paid under Award, or (iii) with respect to any shares of Common Stock paid under the Award that have been disposed of, require the Grantee to repay to the Corporation the fair market value of such shares of Common Stock on the date such shares were sold, transferred, or otherwise disposed of by Grantee.   This provision shall be construed as a return of consideration or ill-gotten gains due to the failure of Grantee’s promises under the Agreement, and not as a liquidated damages clause.  Nothing herein shall (i) reduce or eliminate the Corporation’s right to assert that the restrictions provided for in this agreement are fully enforceable as written, or as modified by a court pursuant to Section 3, or (ii) eliminate, reduce, or compromise the application of temporary or permanent injunctive relief as a fully appropriate and applicable remedy to enforce the restrictions provided for in Section 3 (inclusive of its subparts), in addition to recovery of damages or other remedies otherwise allowed by law.

Section 4.    Forfeiture. Any unvested Restricted Stock Unit subject to this Award shall be forfeited upon the termination of Grantee's continuous employment by the Corporation, including Subsidiaries, prior to a Vesting Date, except to the extent otherwise provided in Section 2. Any Dividend Equivalent subject to this Award shall expire at the time the Restricted Stock Unit with respect to which the Dividend Equivalent is in tandem (i) is vested and paid, or deferred, or (ii) is forfeited.

Section 5.Dividend Equivalent Payments.  Payments with respect to any Dividend Equivalent subject to this Award shall be paid in cash to the Grantee within 60 days after the time cash dividends are declared and paid with respect to the Common Stock on or after the Date of Grant and before the Dividend Equivalent expires, but in no event later than the calendar year in which the dividends are declared and paid. However, should the timing of a particular payment under Section 6 to the Grantee in shares of Common Stock in conjunction with the timing of a particular cash dividend declared and paid on Common Stock be such that the Grantee receives such shares without the right to receive such dividend and the Grantee would not otherwise be entitled to payment under the expiring Dividend Equivalent with respect to such dividend, the Grantee, nevertheless, shall be entitled to such payment. Dividend Equivalent payments shall be subject to withholding for taxes. Any required income tax withholdings in respect of Dividend Equivalents attributable to Restricted Stock Units shall be satisfied by reducing the cash payment in respect of the required withholding amount, unless the Committee, or its delegate, in its discretion, requires Grantee to satisfy such tax obligation by other payment to the Corporation.    

Section 6.    Payment of Restricted Stock Units.  Payment of Restricted Stock Units subject to this Award shall be made to the Grantee as soon as practicable following the time such units become vested in accordance with Section 2 but in no event later than 60 days following such vesting, except to the extent deferred by Grantee in accordance with such procedures as the Committee, or its delegate, may prescribe from time to time or except to the extent required to avoid accelerated taxation and/or tax penalties under Section 409A of the Code. To the extent the Grantee's right to receive payment of the Restricted Stock Units constitutes a "deferral of compensation" within the meaning of Section 409A of the Code, then notwithstanding the first sentence of this Section 6, except in the event that the Grantee’s employment terminates as a result of death, payment of vested Restricted Stock Units subject to this Award shall be made to the Grantee within 60 days following the applicable Vesting Date(s) as provided in Section 2(a). Payment (or deferrals, as applicable) shall be subject to withholding for taxes. Payment shall be in the form of one (1) share of Common Stock for each full Restricted Stock Unit and any fractional Restricted Stock Unit shall be made in a cash amount equal in value to the shares of Common Stock that would otherwise be paid, valued at Fair Market Value on the date the respective Restricted Stock Units became vested, or if later, payable. Notwithstanding the foregoing, the number of shares of Common Stock that would otherwise be paid or deferred (valued at Fair Market Value on the date the respective Restricted Stock Unit became vested, or if later, payable) shall be reduced by the Committee, or its delegate, in its sole discretion, to fully satisfy tax withholding requirements, unless the Committee, or its delegate, in its discretion requires Grantee to satisfy such tax obligation by other payment to the Corporation. In the event that payment, after any such reduction in the number of shares of Common Stock to satisfy withholding for tax requirements, would be less than ten (10) shares of Common Stock, then, if so determined by the Committee, or its delegate, in its sole discretion, payment, instead of being made in shares of Common Stock, shall be made in a cash amount equal in value to the shares of Common Stock that would otherwise be paid, valued at Fair Market Value on the date the respective Restricted Stock Units became vested, or if later, payable.

Section 7.No Employment Rights. Nothing in this Agreement or in the Plan shall confer upon the Grantee the right to continued employment by the Corporation or any Subsidiary, or affect the right of the Corporation or any Subsidiary to terminate the employment or service of the Grantee at any time for any reason.

Section 8.Nonalienation.  The Restricted Stock Units and Dividend Equivalents subject to this Award are not assignable or transferable by the Grantee. Upon any attempt to transfer, assign, pledge, hypothecate, sell or otherwise dispose of any such Restricted Stock Unit or Dividend Equivalent, or of any right or privilege conferred hereby, or upon the levy of any attachment or similar process upon such Restricted Stock Unit or Dividend Equivalent, or upon such right or privilege, such Restricted Stock Unit or Dividend Equivalent or right or privilege, shall immediately become null and void.

Section 9.    Determinations.  Determinations by the Committee, or its delegate, shall be final and conclusive with respect to the interpretation of the Plan and this Agreement.

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Section 10.    Governing Law.  The validity and construction of this Agreement shall be governed by the laws of the state of Delaware applicable to transactions taking place entirely within that state.

Section 11.Conflicts with Plan, Correction of Errors, Section 409A and Grantee’s Consent.  In the event that any provision of this Agreement conflicts in any way with a provision of the Plan, such Plan provision shall be controlling and the applicable provision of this Agreement shall be without force and effect to the extent necessary to cause such Plan provision to be controlling. In the event that, due to administrative error, this Agreement does not accurately reflect a Restricted Stock Unit Award properly granted to Grantee pursuant to the Plan, the Corporation, acting through its Executive Compensation and Benefits Department, reserves the right to cancel any erroneous document and, if appropriate, to replace the cancelled document with a corrected document. It is the intention of the Corporation and the Grantee that this Award not result in unfavorable tax consequences to Grantee under Code Section 409A. Accordingly, Grantee consents to such amendment of this Agreement as the Corporation may reasonably make in furtherance of such intention, and the Corporation shall promptly provide, or make available to, Grantee a copy of any such amendment.

To the extent applicable, it is intended that this Agreement comply with the provisions of Section 409A of the Code and that this Award not result in unfavorable tax consequences to Grantee under Section 409A of the Code. This Agreement will be administered and interpreted in a manner consistent with this intent, and any provision that would cause this Agreement to fail to satisfy Section 409A of the Code will have no force and effect until amended to comply therewith (which amendment may be retroactive to the extent permitted by Section 409A of the Code). The Corporation and the Grantee agree to work together in good faith in an effort to comply with Section 409A of the Code including, if necessary, amending this Agreement based on further guidance issued by the Internal Revenue Service from time to time, provided that the Corporation shall not be required to assume any increased economic burden. Notwithstanding anything contained herein to the contrary, to the extent required in order to avoid accelerated taxation and/or tax penalties under Section 409A of the Code, the Grantee shall not be considered to have terminated employment with Corporation for purposes of this Agreement and no payments shall be due to him or her under this Agreement which are payable upon his or her termination of employment until he or she would be considered to have incurred a “separation from service” from the Corporation within the meaning of Section 409A of the Code. To the extent required in order to avoid accelerated taxation and/or tax penalties under Section 409A of the Code, amounts that would otherwise be payable and benefits that would otherwise be provided pursuant to this Agreement during the six-month period immediately following the Grantee’s termination of employment shall instead be paid within 60 days following the first business day after the date that is six months following his or her termination of employment (or upon his or her death or a regularly scheduled Vesting Date, if earlier). In addition, for purposes of this Agreement, each amount to be paid or benefit to be provided to the Grantee pursuant to this Agreement shall be construed as a separate identified payment for purposes of Section 409A of the Code.

Section 12.    Compliance with Law.  The Corporation shall make reasonable efforts to comply with all applicable federal and state securities laws applicable to the Plan and this Award; provided, however, notwithstanding any other provision of this Award, the Corporation shall not be obligated to deliver any shares of Common Stock pursuant to this Award if the delivery thereof would result in a violation of any such law.

Notwithstanding the foregoing, this Award is subject to cancellation by the Corporation in its sole discretion unless the Grantee, by not later than ___________, _______, has signed a duplicate of this Agreement, in the space provided below, and returned the signed duplicate to the Executive Compensation and Benefits Department – Restricted Stock Units________________________________________________, which, if, and to the extent, permitted by the Executive Compensation and Benefits Department, may be accomplished by electronic means.

IN WITNESS WHEREOF, the Corporation has caused this Agreement to be executed and granted in Charlotte, North Carolina, to be effective as of the Date of Grant.

DUKE ENERGY CORPORATION

By: ____________________________

                        Its:

Acceptance of Restricted StockUnit Award

IN WITNESS OF Grantee's acceptance of this Award and Grantee's agreement to be bound by the provisions of this Agreement and the Plan, Grantee has signed this Agreement this _____ day of _____________________, _____.

____________________________

Grantee’s Signature

____________________________

(print name)

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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.

	Three Months Ended March 31,		Years Ended December 31,
(in millions)	2017		2016		2015		2014		2013		2012 (a)
Earnings as defined for fixed charges calculation
Add:
Pretax income from continuing operations(b)	$	1,031	$	3,668	$	3,832	$	3,636	$	3,204	$	1,622
Fixed charges	532		2,170		1,859		1,871		1,886		1,510
Distributed income of equity investees	2		30		104		136		109		151
Deduct:
Preferred dividend requirements of subsidiaries	—		—		—		—		—		3
Interest capitalized	—		10		18		7		8		30
Total earnings	$	1,565	$	5,858	$	5,777	$	5,636	$	5,191	$	3,250
Fixed charges:
Interest on debt, including capitalized portions	$	507	$	2,066	$	1,733	$	1,733	$	1,760	$	1,420
Estimate of interest within rental expense	25		104		126		138		126		87
Preferred dividend requirements of subsidiaries	—		—		—		—		—		3
Total fixed charges	$	532	$	2,170	$	1,859	$	1,871	$	1,886	$	1,510
Ratio of earnings to fixed charges	2.9		2.7		3.1		3.0		2.8		2.2
Ratio of earnings to fixed charges and preferred dividends combined(c)	2.9		2.7		3.1		3.0		2.8		2.2

(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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.8

EXHIBIT 31.1.8

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 Piedmont Natural Gas Company, 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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/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: May 9, 2017

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.8

EXHIBIT 31.2.8

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 Piedmont Natural Gas Company, 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: May 9, 2017

/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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

EX-32.1.8

EXHIBIT 32.1.8

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 Piedmont Natural Gas Company, Inc. (“Piedmont”) on Form 10-Q for the period ending March 31, 2017 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Piedmont, 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 Piedmont.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

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 March 31, 2017 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

May 9, 2017

EX-32.2.8

EXHIBIT 32.2.8

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 Piedmont Natural Gas Company, Inc. (“Piedmont”) on Form 10-Q for the period ending March 31, 2017 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 Piedmont, 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 Piedmont.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 9, 2017

XML

Document and Entity Information	3 Months Ended
	Mar. 31, 2017 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	Mar. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding	699,883,528
Trading Symbol	DUK
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
Piedmont Natural Gas [Member]
Document Information [Line Items]
Entity Registrant Name	Piedmont Natural Gas Company, Inc.
Entity Central Index Key	0000078460
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
	Mar. 31, 2017	Mar. 31, 2016
Operating Revenues
Regulated electric	$ 4,913	$ 5,053
Regulated natural gas	646	169
Nonregulated electric and other	170	155
Total operating revenues	5,729	5,377
Operating Expenses
Fuel used in electric generation and purchased power	1,449	1,588
Cost of natural gas	258	49
Operation, maintenance and other	1,433	1,416
Depreciation and amortization	859	793
Property and other taxes	304	295
Impairment charges		3
Total operating expenses	4,303	4,144
Gains on Sales of Other Assets and Other, net	11	7
Operating Income	1,437	1,240
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	29	8
Other income and expenses, net	86	70
Total other income and expenses	115	78
Interest Expense	491	489
Income From Continuing Operations Before Income Taxes	1,061	829
Income Tax Expense from Continuing Operations	344	252
Income from Continuing Operations	717	577
Income From Discontinued Operations, net of tax		122
Net income	717	699
Less: Net Income Attributable to Noncontrolling Interests	1	5
Net Income Attributable to Parent	716	694
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments	1
Reclassification into earnings from cash flow hedges	1	2
Unrealized gains on available-for-sale securities	4	4
Other Comprehensive Income, net of tax	8	41
Comprehensive Income	725	740
Less: Comprehensive Income Attributable to Noncontrolling Interests	1	6
Comprehensive Income Attributable to Parent	$ 724	$ 734
Income from continuing operations attributable to Duke Energy Corporation common stockholders
Basic (usd per share)	$ 1.02	$ 0.83
Diluted (usd per share)	1.02	0.83
Income from discontinued operations attributable to Duke Energy Corporation common stockholders
Basic (usd per share)		0.18
Diluted (usd per share)		0.18
Net income attributable to Duke Energy Corporation common stockholders
Basic (usd per share)	1.02	1.01
Diluted (usd per share)	$ 1.02	$ 1.01
Weighted average shares outstanding
Basic (shares)	700	689
Diluted (shares)	700	689
Duke Energy Carolinas [Member]
Operating Revenues
Total operating revenues	$ 1,716	$ 1,740
Operating Expenses
Fuel used in electric generation and purchased power	428	421
Operation, maintenance and other	482	512
Depreciation and amortization	254	259
Property and other taxes	68	67
Total operating expenses	1,232	1,259
Operating Income	484	481
Other Income and Expenses
Other income and expenses, net	37	37
Interest Expense	103	107
Income From Continuing Operations Before Income Taxes	418	411
Income Tax Expense from Continuing Operations	148	140
Net Income Attributable to Parent	270	271
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	270	272
Progress Energy [Member]
Operating Revenues
Total operating revenues	2,179	2,332
Operating Expenses
Fuel used in electric generation and purchased power	726	860
Operation, maintenance and other	544	592
Depreciation and amortization	313	290
Property and other taxes	117	119
Impairment charges		2
Total operating expenses	1,700	1,863
Gains on Sales of Other Assets and Other, net	8	6
Operating Income	487	475
Other Income and Expenses
Other income and expenses, net	24	20
Interest Expense	206	160
Income From Continuing Operations Before Income Taxes	305	335
Income Tax Expense from Continuing Operations	104	123
Net income	201	212
Less: Net Income Attributable to Noncontrolling Interests	2	3
Net Income Attributable to Parent	199	209
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments	1	1
Reclassification into earnings from cash flow hedges	1	1
Unrealized gains on available-for-sale securities	1	1
Other Comprehensive Income, net of tax	3	3
Comprehensive Income	204	215
Less: Comprehensive Income Attributable to Noncontrolling Interests	2	3
Comprehensive Income Attributable to Parent	202	212
Duke Energy Progress [Member]
Operating Revenues
Total operating revenues	1,219	1,307
Operating Expenses
Fuel used in electric generation and purchased power	364	448
Operation, maintenance and other	350	386
Depreciation and amortization	181	175
Property and other taxes	40	41
Total operating expenses	935	1,050
Gains on Sales of Other Assets and Other, net	2	1
Operating Income	286	258
Other Income and Expenses
Other income and expenses, net	19	17
Interest Expense	82	63
Income From Continuing Operations Before Income Taxes	223	212
Income Tax Expense from Continuing Operations	76	75
Net Income Attributable to Parent	147	137
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Attributable to Parent	147	137
Duke Energy Florida [Member]
Operating Revenues
Total operating revenues	959	1,024
Operating Expenses
Fuel used in electric generation and purchased power	362	412
Operation, maintenance and other	191	205
Depreciation and amortization	132	114
Property and other taxes	77	78
Impairment charges	1	2
Total operating expenses	763	811
Operating Income	196	213
Other Income and Expenses
Other income and expenses, net	16	5
Interest Expense	70	41
Income From Continuing Operations Before Income Taxes	142	177
Income Tax Expense from Continuing Operations	52	67
Net Income Attributable to Parent	90	110
Other Comprehensive Income (Loss), net of tax
Unrealized gains on available-for-sale securities	1	1
Other Comprehensive Income, net of tax	1	1
Comprehensive Income Attributable to Parent	91	111
Duke Energy Ohio [Member]
Operating Revenues
Regulated electric	337	340
Regulated natural gas	170	170
Nonregulated electric and other	11	6
Total operating revenues	518	516
Operating Expenses
Fuel used in electric generation and purchased power	97	111
Fuel used in electric generation and purchased power – nonregulated	15	10
Cost of natural gas	54	49
Operation, maintenance and other	130	119
Depreciation and amortization	67	61
Property and other taxes	72	71
Total operating expenses	435	421
Gains on Sales of Other Assets and Other, net		1
Operating Income	83	96
Other Income and Expenses
Other income and expenses, net	4	2
Interest Expense	22	20
Income From Continuing Operations Before Income Taxes	65	78
Income Tax Expense from Continuing Operations	23	21
Income from Continuing Operations	42	57
Income From Discontinued Operations, net of tax		2
Net Income Attributable to Parent	42	59
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Attributable to Parent	42	59
Duke Energy Indiana [Member]
Operating Revenues
Total operating revenues	758	714
Operating Expenses
Fuel used in electric generation and purchased power	251	228
Operation, maintenance and other	174	162
Depreciation and amortization	125	125
Property and other taxes	22	23
Total operating expenses	572	538
Operating Income	186	176
Other Income and Expenses
Other income and expenses, net	8	4
Interest Expense	44	44
Income From Continuing Operations Before Income Taxes	150	136
Income Tax Expense from Continuing Operations	59	41
Net Income Attributable to Parent	91	95
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	91	94
Piedmont Natural Gas [Member]
Operating Revenues
Regulated natural gas	498	481
Nonregulated electric and other	2	2
Total operating revenues	500	483
Operating Expenses
Cost of natural gas	205	197
Operation, maintenance and other	77	74
Depreciation and amortization	35	34
Property and other taxes	13	11
Total operating expenses	330	316
Operating Income	170	167
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	3	16
Interest Expense	20	17
Income From Continuing Operations Before Income Taxes	153	166
Income Tax Expense from Continuing Operations	58	63
Net Income Attributable to Parent	95	103
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Attributable to Parent	$ 95	$ 103

XML

Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest [Abstract]
Net income	$ 717	$ 699
Other Comprehensive (Loss) Income, net of tax
Foreign currency translation adjustments		49
Pension and OPEB adjustments	1
Net unrealized gains (losses) on cash flow hedges	2	(14)
Reclassification into earnings from cash flow hedges	1	2
Unrealized gains on available-for-sale securities	4	4
Other Comprehensive Income, net of tax	8	41
Comprehensive Income	725	740
Less: Comprehensive Income (Loss) Attributable to Noncontrolling Interests	1	6
Comprehensive Income Attributable to Parent	$ 724	$ 734

XML

Condensed Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Current Assets
Cash and cash equivalents	$ 878	$ 392
Receivables (net of allowance for doubtful accounts)	623	751
Receivables of VIEs (net of allowance for doubtful accounts)	1,682	1,893
Inventory	3,366	3,522
Regulatory assets	1,031	1,023
Other	425	458
Total current assets	8,005	8,039
Property, Plant and Equipment
Cost	123,301	121,397
Accumulated depreciation and amortization	(40,293)	(39,406)
Generation facilities to be retired, net	508	529
Net property, plant and equipment	83,516	82,520
Other Noncurrent Assets
Goodwill	19,425	19,425
Regulatory assets	12,838	12,878
Nuclear decommissioning trust funds	6,448	6,205
Investments in equity method unconsolidated affiliates	1,122	925
Other	2,754	2,769
Total other noncurrent assets	42,587	42,202
Total Assets	134,108	132,761
Current Liabilities
Accounts payable	2,203	2,994
Notes payable and commercial paper	3,558	2,487
Taxes accrued	363	384
Interest accrued	526	503
Current maturities of long-term debt	1,977	2,319
Asset retirement obligation	404	411
Regulatory liabilities	340	409
Other	1,570	2,044
Total current liabilities	10,941	11,551
Long-Term Debt	47,021	45,576
Other Noncurrent Liabilities
Deferred income taxes	14,443	14,155
Asset retirement obligations	10,186	10,200
Regulatory liabilities	6,972	6,881
Accrued pension and other post-retirement benefit costs	1,115	1,111
Investment tax credits	537	493
Other	1,707	1,753
Total other noncurrent liabilities	34,960	34,593
Commitments and Contingencies
Equity
Common stock	1	1
Additional paid-in capital	38,742	38,741
Retained earnings	2,521	2,384
Accumulated other comprehensive income (loss)	(85)	(93)
Total Parent stockholders' equity	41,179	41,033
Noncontrolling interests	7	8
Total equity	41,186	41,041
Total Liabilities and Equity	134,108	132,761
Duke Energy Carolinas [Member]
Current Assets
Cash and cash equivalents	11	14
Receivables (net of allowance for doubtful accounts)	166	160
Receivables of VIEs (net of allowance for doubtful accounts)	563	645
Receivables from affiliated companies	109	163
Notes receivable from affiliated companies		66
Inventory	1,051	1,055
Regulatory assets	233	238
Other	65	37
Total current assets	2,198	2,378
Property, Plant and Equipment
Cost	41,600	41,127
Accumulated depreciation and amortization	(14,649)	(14,365)
Net property, plant and equipment	26,951	26,762
Other Noncurrent Assets
Regulatory assets	3,098	3,159
Nuclear decommissioning trust funds	3,406	3,273
Other	926	943
Total other noncurrent assets	7,430	7,375
Total Assets	36,579	36,515
Current Liabilities
Accounts payable	602	833
Accounts payable to affiliated companies	250	247
Notes payable to affiliated companies	337
Taxes accrued	90	143
Interest accrued	134	102
Current maturities of long-term debt	404	116
Asset retirement obligation	224	222
Regulatory liabilities	118	161
Other	345	468
Total current liabilities	2,504	2,292
Long-Term Debt	8,787	9,187
Long-Term Debt Payable to Affiliated Companies	300	300
Other Noncurrent Liabilities
Deferred income taxes	6,668	6,544
Asset retirement obligations	3,658	3,673
Regulatory liabilities	2,860	2,840
Accrued pension and other post-retirement benefit costs	103	97
Investment tax credits	237	203
Other	595	607
Total other noncurrent liabilities	14,121	13,964
Commitments and Contingencies
Equity
Member's equity	10,876	10,781
Accumulated other comprehensive income (loss)	(9)	(9)
Total member's equity	10,867	10,772
Total Liabilities and Equity	36,579	36,515
Progress Energy [Member]
Current Assets
Cash and cash equivalents	38	46
Receivables (net of allowance for doubtful accounts)	80	114
Receivables of VIEs (net of allowance for doubtful accounts)	612	692
Receivables from affiliated companies	2	106
Notes receivable from affiliated companies	184	80
Inventory	1,652	1,717
Regulatory assets	447	401
Other	252	148
Total current assets	3,267	3,304
Property, Plant and Equipment
Cost	45,902	44,864
Accumulated depreciation and amortization	(15,618)	(15,212)
Generation facilities to be retired, net	508	529
Net property, plant and equipment	30,792	30,181
Other Noncurrent Assets
Goodwill	3,655	3,655
Regulatory assets	5,815	5,722
Nuclear decommissioning trust funds	3,041	2,932
Other	851	856
Total other noncurrent assets	13,362	13,165
Total Assets	47,421	46,650
Current Liabilities
Accounts payable	678	1,003
Accounts payable to affiliated companies	316	348
Notes payable to affiliated companies	866	729
Taxes accrued	96	83
Interest accrued	224	201
Current maturities of long-term debt	521	778
Asset retirement obligation	180	189
Regulatory liabilities	157	189
Other	627	745
Total current liabilities	3,665	4,265
Long-Term Debt	16,454	15,590
Long-Term Debt Payable to Affiliated Companies	1,173	1,173
Other Noncurrent Liabilities
Deferred income taxes	5,484	5,246
Asset retirement obligations	5,289	5,286
Regulatory liabilities	2,472	2,395
Accrued pension and other post-retirement benefit costs	540	547
Other	332	341
Total other noncurrent liabilities	14,117	13,815
Commitments and Contingencies
Equity
Additional paid-in capital	8,094	8,094
Retained earnings	3,963	3,764
Accumulated other comprehensive income (loss)	(35)	(38)
Total Parent stockholders' equity	12,022	11,820
Noncontrolling interests	(10)	(13)
Total equity	12,012	11,807
Total Liabilities and Equity	47,421	46,650
Duke Energy Progress [Member]
Current Assets
Cash and cash equivalents	11	11
Receivables (net of allowance for doubtful accounts)	28	51
Receivables of VIEs (net of allowance for doubtful accounts)	364	404
Receivables from affiliated companies	6	5
Notes receivable from affiliated companies		165
Inventory	1,053	1,076
Regulatory assets	187	188
Other	102	57
Total current assets	1,751	1,957
Property, Plant and Equipment
Cost	28,769	28,419
Accumulated depreciation and amortization	(10,716)	(10,561)
Generation facilities to be retired, net	508	529
Net property, plant and equipment	18,561	18,387
Other Noncurrent Assets
Regulatory assets	3,338	3,243
Nuclear decommissioning trust funds	2,315	2,217
Other	535	525
Total other noncurrent assets	6,188	5,985
Total Assets	26,500	26,329
Current Liabilities
Accounts payable	317	589
Accounts payable to affiliated companies	244	227
Notes payable to affiliated companies	502
Taxes accrued	35	104
Interest accrued	90	102
Current maturities of long-term debt	202	452
Asset retirement obligation	180	189
Regulatory liabilities	149	158
Other	294	365
Total current liabilities	2,013	2,186
Long-Term Debt	6,409	6,409
Long-Term Debt Payable to Affiliated Companies	150	150
Other Noncurrent Liabilities
Deferred income taxes	3,453	3,323
Asset retirement obligations	4,516	4,508
Regulatory liabilities	2,012	1,946
Accrued pension and other post-retirement benefit costs	247	252
Investment tax credits	146	146
Other	49	51
Total other noncurrent liabilities	10,423	10,226
Commitments and Contingencies
Equity
Total member's equity	7,505	7,358
Total Liabilities and Equity	26,500	26,329
Duke Energy Florida [Member]
Current Assets
Cash and cash equivalents	7	16
Receivables (net of allowance for doubtful accounts)	50	61
Receivables of VIEs (net of allowance for doubtful accounts)	248	288
Receivables from affiliated companies	2	5
Notes receivable from affiliated companies	293
Inventory	599	641
Regulatory assets	260	213
Other	104	125
Total current assets	1,563	1,349
Property, Plant and Equipment
Cost	17,122	16,434
Accumulated depreciation and amortization	(4,894)	(4,644)
Net property, plant and equipment	12,228	11,790
Other Noncurrent Assets
Regulatory assets	2,476	2,480
Nuclear decommissioning trust funds	726	715
Other	268	278
Total other noncurrent assets	3,470	3,473
Total Assets	17,261	16,612
Current Liabilities
Accounts payable	361	413
Accounts payable to affiliated companies	77	125
Notes payable to affiliated companies		297
Taxes accrued	62	33
Interest accrued	76	49
Current maturities of long-term debt	319	326
Regulatory liabilities	7	31
Other	309	352
Total current liabilities	1,211	1,626
Long-Term Debt	6,662	5,799
Other Noncurrent Liabilities
Deferred income taxes	2,800	2,694
Asset retirement obligations	773	778
Regulatory liabilities	459	448
Accrued pension and other post-retirement benefit costs	261	262
Other	104	105
Total other noncurrent liabilities	4,397	4,287
Commitments and Contingencies
Equity
Member's equity	4,989	4,899
Accumulated other comprehensive income (loss)	2	1
Total member's equity	4,991	4,900
Total Liabilities and Equity	17,261	16,612
Duke Energy Ohio [Member]
Current Assets
Cash and cash equivalents	13	13
Receivables (net of allowance for doubtful accounts)	63	71
Receivables from affiliated companies	88	129
Notes receivable from affiliated companies	179	94
Inventory	118	137
Regulatory assets	21	37
Other	34	37
Total current assets	516	518
Property, Plant and Equipment
Cost	8,236	8,126
Accumulated depreciation and amortization	(2,611)	(2,579)
Net property, plant and equipment	5,625	5,547
Other Noncurrent Assets
Goodwill	920	920
Regulatory assets	525	520
Other	23	23
Total other noncurrent assets	1,468	1,463
Total Assets	7,609	7,528
Current Liabilities
Accounts payable	252	282
Accounts payable to affiliated companies	64	63
Notes payable to affiliated companies	8	16
Taxes accrued	127	178
Interest accrued	33	19
Current maturities of long-term debt	1	1
Regulatory liabilities	21	21
Other	83	91
Total current liabilities	589	671
Long-Term Debt	1,951	1,858
Long-Term Debt Payable to Affiliated Companies	25	25
Other Noncurrent Liabilities
Deferred income taxes	1,472	1,443
Asset retirement obligations	76	77
Regulatory liabilities	236	236
Accrued pension and other post-retirement benefit costs	56	56
Other	166	166
Total other noncurrent liabilities	2,006	1,978
Commitments and Contingencies
Equity
Common stock	762	762
Additional paid-in capital	2,695	2,695
Retained earnings	(419)	(461)
Total Parent stockholders' equity	3,038	2,996
Total Liabilities and Equity	7,609	7,528
Duke Energy Indiana [Member]
Current Assets
Cash and cash equivalents	15	17
Receivables (net of allowance for doubtful accounts)	72	105
Receivables from affiliated companies	88	114
Notes receivable from affiliated companies	199	86
Inventory	478	504
Regulatory assets	156	149
Other	35	45
Total current assets	1,043	1,020
Property, Plant and Equipment
Cost	14,411	14,241
Accumulated depreciation and amortization	(4,426)	(4,317)
Net property, plant and equipment	9,985	9,924
Other Noncurrent Assets
Regulatory assets	1,066	1,073
Other	156	147
Total other noncurrent assets	1,222	1,220
Total Assets	12,250	12,164
Current Liabilities
Accounts payable	210	263
Accounts payable to affiliated companies	75	74
Taxes accrued	72	31
Interest accrued	52	61
Current maturities of long-term debt	3	3
Regulatory liabilities	44	40
Other	75	93
Total current liabilities	531	565
Long-Term Debt	3,631	3,633
Long-Term Debt Payable to Affiliated Companies	150	150
Other Noncurrent Liabilities
Deferred income taxes	1,921	1,900
Asset retirement obligations	867	866
Regulatory liabilities	743	748
Accrued pension and other post-retirement benefit costs	77	71
Investment tax credits	148	137
Other	24	27
Total other noncurrent liabilities	3,780	3,749
Commitments and Contingencies
Equity
Total member's equity	4,158	4,067
Total Liabilities and Equity	12,250	12,164
Piedmont Natural Gas [Member]
Current Assets
Cash and cash equivalents	15	25
Receivables (net of allowance for doubtful accounts)	193	232
Receivables from affiliated companies	7	7
Inventory	29	66
Regulatory assets	98	124
Other	21	21
Total current assets	363	475
Property, Plant and Equipment
Cost	6,297	6,174
Accumulated depreciation and amortization	(1,390)	(1,360)
Net property, plant and equipment	4,907	4,814
Other Noncurrent Assets
Goodwill	49	49
Regulatory assets	350	373
Investments in equity method unconsolidated affiliates	225	212
Other	19	21
Total other noncurrent assets	643	655
Total Assets	5,913	5,944
Current Liabilities
Accounts payable	104	155
Accounts payable to affiliated companies	3	8
Notes payable and commercial paper		330
Notes payable to affiliated companies	261
Taxes accrued	69	67
Interest accrued	27	33
Current maturities of long-term debt	35	35
Other	70	102
Total current liabilities	569	730
Long-Term Debt	1,786	1,786
Other Noncurrent Liabilities
Deferred income taxes	981	931
Asset retirement obligations	14	14
Regulatory liabilities	613	608
Accrued pension and other post-retirement benefit costs	14	14
Other	169	189
Total other noncurrent liabilities	1,791	1,756
Commitments and Contingencies
Equity
Common stock	860	860
Retained earnings	907	812
Total Parent stockholders' equity	1,767	1,672
Total Liabilities and Equity	$ 5,913	$ 5,944

XML

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Allowance for Doubtful Accounts and Other Receivables, Current	$ 13	$ 14
Regulatory assets	1,031	1,023
Current Assets: Other	425	458
Regulatory assets	12,838	12,878
Current maturities of long-term debt	1,977	2,319
Long-term Debt of VIEs	$ 47,021	$ 45,576
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	700,000,000	700,000,000
Variable Interest Entity [Member]
Allowance for Doubtful Accounts Receivable, Current	$ 57	$ 54
Regulatory assets	53	50
Regulatory assets	1,131	1,142
Current maturities of long-term debt	281	260
Long-term Debt of VIEs	4,108	3,587
Duke Energy Carolinas [Member]
Allowance for Doubtful Accounts and Other Receivables, Current	2	2
Regulatory assets	233	238
Current Assets: Other	65	37
Regulatory assets	3,098	3,159
Current maturities of long-term debt	404	116
Long-term Debt of VIEs	8,787	9,187
Duke Energy Carolinas [Member] | Variable Interest Entity [Member]
Allowance for Doubtful Accounts Receivable, Current	7	7
Progress Energy [Member]
Allowance for Doubtful Accounts and Other Receivables, Current	3	6
Regulatory assets	447	401
Current Assets: Other	252	148
Regulatory assets	5,815	5,722
Current maturities of long-term debt	521	778
Long-term Debt of VIEs	$ 16,454	$ 15,590
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]
Allowance for Doubtful Accounts Receivable, Current	$ 7	$ 7
Regulatory assets	53	50
Regulatory assets	1,131	1,142
Current maturities of long-term debt	55	62
Long-term Debt of VIEs	1,713	1,741
Duke Energy Progress [Member]
Allowance for Doubtful Accounts and Other Receivables, Current	1	4
Regulatory assets	187	188
Current Assets: Other	102	57
Regulatory assets	3,338	3,243
Current maturities of long-term debt	202	452
Long-term Debt of VIEs	6,409	6,409
Duke Energy Progress [Member] | Variable Interest Entity [Member]
Allowance for Doubtful Accounts Receivable, Current	5	5
Duke Energy Florida [Member]
Allowance for Doubtful Accounts and Other Receivables, Current	2	2
Regulatory assets	260	213
Current Assets: Other	104	125
Regulatory assets	2,476	2,480
Current maturities of long-term debt	319	326
Long-term Debt of VIEs	6,662	5,799
Duke Energy Florida [Member] | Variable Interest Entity [Member]
Allowance for Doubtful Accounts Receivable, Current	2	2
Regulatory assets	53	50
Current Assets: Other	14	53
Regulatory assets	1,131	1,142
Current maturities of long-term debt	55	62
Long-term Debt of VIEs	1,414	1,442
Duke Energy Ohio [Member]
Allowance for Doubtful Accounts and Other Receivables, Current	2	2
Regulatory assets	21	37
Current Assets: Other	34	37
Regulatory assets	525	520
Current maturities of long-term debt	1	1
Long-term Debt of VIEs	$ 1,951	$ 1,858
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]
Allowance for Doubtful Accounts and Other Receivables, Current	$ 1	$ 1
Regulatory assets	156	149
Current Assets: Other	35	45
Regulatory assets	1,066	1,073
Current maturities of long-term debt	3	3
Long-term Debt of VIEs	3,631	3,633
Piedmont Natural Gas [Member]
Allowance for Doubtful Accounts and Other Receivables, Current	5	3
Regulatory assets	98	124
Current Assets: Other	21	21
Regulatory assets	350	373
Current maturities of long-term debt	35	35
Long-term Debt of VIEs	$ 1,786	$ 1,786
Common stock, par or stated value	$ 0	$ 0
Common stock, shares authorized	100	100
Common stock, shares outstanding	100	100

XML

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 717	$ 699
Net income (attributable to parent)	716	694
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	991	931
Equity component of AFUDC	(62)	(42)
Gains on sales of other assets	(11)	(9)
Impairment charges		3
Deferred income taxes	342	181
Equity in earnings of unconsolidated affiliates	(29)	(8)
Accrued pension and other post-retirement benefit costs	6	4
Payments for asset retirement obligations	(134)	(112)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(38)	102
Receivables	343	139
Inventory	155	89
Other current assets	16	13
Increase (decrease) in
Accounts payable	(463)	(210)
Taxes accrued	(28)	40
Other current liabilities	(478)	(81)
Other assets	(40)	45
Other liabilities	2	(102)
Net cash provided by operating activities	1,289	1,682
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,160)	(1,645)
Contributions to equity method investments	(175)	(59)
Purchases of available-for-sale securities	(1,386)	(1,347)
Proceeds from sales and maturities of available-for-sale securities	1,405	1,362
Change in restricted cash	(34)	(32)
Other	(49)	(37)
Net cash used in investing activities	(2,399)	(1,758)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,563	1,140
Proceeds from the issuance of common stock related to employee benefit plans		7
Payments for the redemption of long-term debt	(408)	(389)
Proceeds from issuance of short-term debt with original maturities greater than 90 days	25
Payments for the redemption of short-term debt with original maturities greater than 90 days	(7)	(92)
Notes payable and commercial paper	1,045	(66)
Change in bank overdrafts	5
Dividends paid	(600)	(570)
Other	(27)	(33)
Net cash provided by (used in) financing activities	1,596	(3)
Change in cash and cash equivalents associated with assets held for sale		30
Net increase (decrease) in cash and cash equivalents	486	(49)
Cash and cash equivalents at beginning of period	392	383
Cash and cash equivalents at end of period	878	334
Significant non-cash transactions:
Accrued capital expenditures	575	576
Duke Energy Carolinas [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	270	271
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	339	330
Equity component of AFUDC	(30)	(23)
Deferred income taxes	162	145
Accrued pension and other post-retirement benefit costs		1
Payments for asset retirement obligations	(65)	(52)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3	3
Receivables	66	2
Receivable from affiliated companies	54	33
Inventory	4	40
Other current assets	(26)	102
Increase (decrease) in
Accounts payable	(131)	(165)
Accounts payable to affiliated companies	3	21
Taxes accrued	(53)	52
Other current liabilities	(125)	21
Other assets	(3)	26
Other liabilities	(2)	(26)
Net cash provided by operating activities	466	781
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(563)	(459)
Purchases of available-for-sale securities	(722)	(785)
Proceeds from sales and maturities of available-for-sale securities	722	785
Notes receivable from affiliated companies	66
Notes receivable from affiliated companies		(691)
Other	(20)	(18)
Net cash used in investing activities	(517)	(1,168)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		992
Payments for the redemption of long-term debt	(113)	(1)
Notes payable to affiliated companies	337
Distributions to parent	(175)	(600)
Other	(1)
Net cash provided by (used in) financing activities	48	391
Net increase (decrease) in cash and cash equivalents	(3)	4
Cash and cash equivalents at beginning of period	14	13
Cash and cash equivalents at end of period	11	17
Significant non-cash transactions:
Accrued capital expenditures	164	179
Progress Energy [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	201	212
Net income (attributable to parent)	199	209
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	365	342
Equity component of AFUDC	(24)	(14)
Gains on sales of other assets	(9)	(7)
Impairment charges		2
Deferred income taxes	220	182
Accrued pension and other post-retirement benefit costs	(3)	(6)
Payments for asset retirement obligations	(60)	(54)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(2)	6
Receivables	115	70
Receivable from affiliated companies	100	295
Inventory	65	3
Other current assets	(173)	(76)
Increase (decrease) in
Accounts payable	(228)	9
Accounts payable to affiliated companies	(32)	(55)
Taxes accrued	12	42
Other current liabilities	(121)	(64)
Other assets	(53)	(46)
Other liabilities	(14)	(7)
Net cash provided by operating activities	359	834
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,011)	(750)
Purchases of available-for-sale securities	(629)	(533)
Proceeds from sales and maturities of available-for-sale securities	635	548
Proceeds from Insurance	4	43
Notes receivable from affiliated companies	(104)
Change in restricted cash	5
Other	(4)	(15)
Net cash used in investing activities	(1,104)	(707)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	892	53
Payments for the redemption of long-term debt	(288)	(310)
Notes payable to affiliated companies	137	128
Distributions to noncontrolling interests	(1)	(1)
Other	(3)
Net cash provided by (used in) financing activities	737	(130)
Net increase (decrease) in cash and cash equivalents	(8)	(3)
Cash and cash equivalents at beginning of period	46	44
Cash and cash equivalents at end of period	38	41
Significant non-cash transactions:
Accrued capital expenditures	219	228
Duke Energy Progress [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	147	137
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	228	223
Equity component of AFUDC	(13)	(10)
Gains on sales of other assets	(3)	(2)
Deferred income taxes	120	100
Accrued pension and other post-retirement benefit costs	(5)	(8)
Payments for asset retirement obligations	(47)	(42)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(2)	(1)
Receivables	65	18
Receivable from affiliated companies	(1)	10
Inventory	23	15
Other current assets	(60)	83
Increase (decrease) in
Accounts payable	(192)	(16)
Accounts payable to affiliated companies	17	(14)
Taxes accrued	(68)	18
Other current liabilities	(81)	(39)
Other assets	(44)	(17)
Other liabilities	(10)	(4)
Net cash provided by operating activities	74	451
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(474)	(379)
Purchases of available-for-sale securities	(476)	(390)
Proceeds from sales and maturities of available-for-sale securities	470	384
Notes receivable from affiliated companies	165
Other	(9)	(13)
Net cash used in investing activities	(324)	(398)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		53
Payments for the redemption of long-term debt	(250)	(8)
Notes payable to affiliated companies	502	(101)
Other	(2)	(1)
Net cash provided by (used in) financing activities	250	(57)
Net increase (decrease) in cash and cash equivalents		(4)
Cash and cash equivalents at beginning of period	11	15
Cash and cash equivalents at end of period	11	11
Significant non-cash transactions:
Accrued capital expenditures	66	55
Duke Energy Florida [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	90	110
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	134	116
Equity component of AFUDC	(11)	(4)
Impairment charges	1	2
Deferred income taxes	100	83
Accrued pension and other post-retirement benefit costs	1	1
Payments for asset retirement obligations	(14)	(12)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions		7
Receivables	51	52
Receivable from affiliated companies	(1)	14
Inventory	42	(12)
Other current assets	(33)	(44)
Increase (decrease) in
Accounts payable	(35)	25
Accounts payable to affiliated companies	(48)	(40)
Taxes accrued	29	(70)
Other current liabilities	(47)	(14)
Other assets	(13)	(30)
Other liabilities	(5)	(6)
Net cash provided by operating activities	241	178
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(538)	(370)
Purchases of available-for-sale securities	(153)	(143)
Proceeds from sales and maturities of available-for-sale securities	165	164
Proceeds from Insurance	4	43
Notes receivable from affiliated companies	(293)
Other	9	(1)
Net cash used in investing activities	(806)	(307)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	892
Payments for the redemption of long-term debt	(38)	(2)
Notes payable to affiliated companies	(297)	135
Other	(1)
Net cash provided by (used in) financing activities	556	133
Net increase (decrease) in cash and cash equivalents	(9)	4
Cash and cash equivalents at beginning of period	16	8
Cash and cash equivalents at end of period	7	12
Significant non-cash transactions:
Accrued capital expenditures	153	173
Duke Energy Ohio [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	42	59
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	68	62
Equity component of AFUDC	(2)	(1)
Gains on sales of other assets		(1)
Deferred income taxes	30	11
Accrued pension and other post-retirement benefit costs	1	1
Payments for asset retirement obligations	(2)	(1)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	1	2
Receivables	7	(18)
Receivable from affiliated companies	41	(9)
Inventory	19	1
Other current assets	9	78
Increase (decrease) in
Accounts payable	(10)	(1)
Accounts payable to affiliated companies	1
Taxes accrued	(52)	(31)
Other current liabilities	9	14
Other assets	(6)	(2)
Other liabilities	(3)
Net cash provided by operating activities	153	164
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(143)	(85)
Notes receivable from affiliated companies	(85)	(19)
Other	(8)	(4)
Net cash used in investing activities	(236)	(108)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	93	95
Payments for the redemption of long-term debt	(1)	(51)
Notes payable to affiliated companies	(8)	(95)
Other	(1)
Net cash provided by (used in) financing activities	83	(51)
Net increase (decrease) in cash and cash equivalents		5
Cash and cash equivalents at beginning of period	13	14
Cash and cash equivalents at end of period	13	19
Significant non-cash transactions:
Accrued capital expenditures	57	31
Duke Energy Indiana [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	91	95
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	126	127
Equity component of AFUDC	(6)	(3)
Deferred income taxes	37	(16)
Accrued pension and other post-retirement benefit costs	1	2
Payments for asset retirement obligations	(7)	(5)
(Increase) decrease in
Receivables	44	16
Receivable from affiliated companies	26	7
Inventory	26	45
Other current assets	(2)	(19)
Increase (decrease) in
Accounts payable	(32)	(44)
Accounts payable to affiliated companies	1	(22)
Taxes accrued	41	30
Other current liabilities	(15)	(18)
Other assets	(11)	(4)
Other liabilities	(3)	(11)
Net cash provided by operating activities	317	180
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(189)	(151)
Purchases of available-for-sale securities	(4)	(5)
Proceeds from sales and maturities of available-for-sale securities	2	4
Notes receivable from affiliated companies	(113)	(19)
Other	(12)	(1)
Net cash used in investing activities	(316)	(172)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt	(2)
Other	(1)
Net cash provided by (used in) financing activities	(3)
Net increase (decrease) in cash and cash equivalents	(2)	8
Cash and cash equivalents at beginning of period	17	9
Cash and cash equivalents at end of period	15	17
Significant non-cash transactions:
Accrued capital expenditures	84	42
Piedmont Natural Gas [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	95	103
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	37	37
Deferred income taxes	50	68
Equity in earnings of unconsolidated affiliates	(3)	(16)
Accrued pension and other post-retirement benefit costs	3	1
Payments for asset retirement obligations		(1)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(41)
Receivables	40	(14)
Inventory	37	49
Other current assets	24	20
Increase (decrease) in
Accounts payable	(31)	(21)
Accounts payable to affiliated companies	(5)
Taxes accrued	2	3
Other current liabilities	(17)	(9)
Other assets	25	23
Other liabilities	(1)	(20)
Net cash provided by operating activities	215	223
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(141)	(132)
Contributions to equity method investments	(12)	(9)
Other	(3)	(1)
Net cash used in investing activities	(156)	(142)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of common stock related to employee benefit plans		7
Notes payable and commercial paper	(330)	(80)
Notes payable to affiliated companies	261
Dividends paid		(27)
Net cash provided by (used in) financing activities	(69)	(100)
Net increase (decrease) in cash and cash equivalents	(10)	(19)
Cash and cash equivalents at beginning of period	25	33
Cash and cash equivalents at end of period	15	14
Significant non-cash transactions:
Accrued capital expenditures	$ 24	$ 43

XML

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 Unrealized Gains (Losses) on Available for Sale Securities [Member]	Pension and OPEB 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]	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 Unrealized Gains (Losses) on Available for Sale Securities [Member]	Progress Energy [Member] Pension and OPEB Adjustments [Member]	Progress Energy [Member] Common Stockholders' Equity [Member]	Progress Energy [Member] Noncontrolling Interest [Member]	Duke Energy Progress [Member]	Duke Energy Florida [Member]	Duke Energy Florida [Member] Members Equity [Member]	Duke Energy Florida [Member] Net Unrealized 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]	Piedmont Natural Gas [Member]	Piedmont Natural Gas [Member] Common Stock [Member]	Piedmont Natural Gas [Member] Retained Earnings [Member]	Piedmont Natural Gas [Member] Net Gains (Losses) on Cash Flow Hedges [Member]
Beginning 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)
Beginning Balance, in shares at Dec. 31, 2015			688,000,000
Beginning Balance (member's equity) at Dec. 31, 2015														$ 11,606	$ 11,617	$ (11)									$ 7,059	$ 5,121	$ 5,121
Beginning Balance (parent) at Dec. 31, 2015																													$ 2,784	$ 762	$ 2,720	$ (698)	$ 3,836	$ 1	$ 1,384	$ 2,450		$ 1	$ 1,458	$ 728	$ 731	$ (1)
Net income	699				694						694		5				212		209				209	3
Net income (attributable to parent)	694													271	271		209								137	110	110		59			59	95				$ 95		103		103
Other comprehensive income (loss)	41						48	(12)	4		40		1	1		1	3			1	$ 1	1	3			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	1			1							1																												7	7
Common stock dividends	(570)				(570)						(570)																												(27)		(27)
Distributions to parent														(600)	(600)
Distributions to noncontrolling interest in subsidiaries	(1)												(1)				(1)							(1)
Other																																		$ (1)	$ (1,384)	$ (2,450)	3,835
Ending Balance at Mar. 31, 2016	39,941		$ 1	37,969	2,688		$ (644)	(62)	1	(61)	39,892		49				13,067	8,092	5,040	(30)	1	(16)	13,087	(20)
Ending Balance, in shares at Mar. 31, 2016			689,000,000
Ending Balance (member's equity) at Mar. 31, 2016														11,278	11,288	(10)									7,196	5,232	5,231	1					3,930				3,930
Ending Balance (parent) at Mar. 31, 2016																													$ 2,843	762	2,720	(639)							$ 1,541	735	807	$ (1)
Beginning Balance at Dec. 31, 2016	$ 41,041		$ 1	38,741	2,384			(20)	(1)	(72)	41,033		8				$ 11,807	8,094	3,764	(23)	1	(16)	11,820	(13)
Beginning Balance, in shares at Dec. 31, 2016	700,000,000		700,000,000														100												89,663,086										100
Beginning Balance (member's equity) at Dec. 31, 2016														10,772	10,781	(9)									7,358	4,900	4,899	1					4,067				4,067
Beginning Balance (parent) at Dec. 31, 2016	$ 41,033																$ 11,820												$ 2,996	762	2,695	(461)							$ 1,672	860	812
Net income	717				716						716		1				201		199				199	2
Net income (attributable to parent)	716													270	270		199								147	90	90		$ 42			42	91				91		$ 95		95
Other comprehensive income (loss)	8							3	4	1	8						3			1	1	1	3			1		1
Common stock issuances, including dividend reinvestment and employee benefits	1			1							1
Common stock dividends	(600)				(600)						(600)
Distributions to parent														(175)	(175)
Distributions to noncontrolling interest in subsidiaries	(2)												(2)
Other	21	[1]			21	[1]					21	[1]					1							1
Ending Balance at Mar. 31, 2017	$ 41,186		$ 1	$ 38,742	$ 2,521			$ (17)	$ 3	$ (71)	$ 41,179		$ 7				$ 12,012	$ 8,094	$ 3,963	$ (22)	$ 2	$ (15)	$ 12,022	$ (10)
Ending Balance, in shares at Mar. 31, 2017	700,000,000		700,000,000														100												89,663,086										100
Ending Balance (member's equity) at Mar. 31, 2017														$ 10,867	$ 10,876	$ (9)									$ 7,505	$ 4,991	$ 4,989	$ 2					$ 4,158				$ 4,158
Ending Balance (parent) at Mar. 31, 2017	$ 41,179																$ 12,022												$ 3,038	$ 762	$ 2,695	$ (419)							$ 1,767	$ 860	$ 907

[1] Cumulative-effect adjustment due to implementation of a new accounting standard related to stock-based compensation and the associated income taxes. See Note 1 for more information.

XML

Organization and Basis of Presentation

3 Months Ended

Mar. 31, 2017

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.

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.

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Progress, LLC

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Florida, LLC

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Ohio, Inc.

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Indiana, LLC

•

•

•

•

•

•

•

•

•

•

•

•

•

Piedmont Natural Gas Company, Inc.

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Tables within the notes may not sum across due to (i) Progress Energy's consolidation of Duke Energy Progress, Duke Energy Florida and other subsidiaries that are not registrants, (ii) subsidiaries that are not registrants but included in the consolidated Duke Energy balances and (iii) the Piedmont registrant not included in the consolidated Duke Energy results for the three months ended March 31, 2016, as Piedmont results were not consolidated by Duke Energy until after the acquisition date of October 3, 2016.

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.) primarily through its direct and indirect subsidiaries. Certain Duke Energy subsidiaries are also subsidiary registrants, including 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), Duke Energy Indiana, LLC (Duke Energy Indiana) and Piedmont Natural Gas Company, Inc. (Piedmont). When discussing Duke Energy’s consolidated financial information, it necessarily includes the results of its separate subsidiary registrants (collectively referred to as the Subsidiary Registrants), which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants.

On October 3, 2016, Duke Energy completed the acquisition of Piedmont. Piedmont's results of operations and cash flows are included in the accompanying condensed consolidated financial statements of Duke Energy for the three months ended March 31, 2017, but not for the three months ended March 31, 2016, as Piedmont's earnings and cash flows are only included in Duke Energy's consolidated results subsequent to the acquisition date. See Note 2 for additional information regarding the acquisition.

In December 2016, Duke Energy completed an exit of the Latin American market to focus on its domestic regulated business, which was further bolstered by the acquisition of Piedmont. The sale of the International Energy business segment, excluding an equity method investment in National Methanol Company (NMC), was completed through two transactions including a sale of assets in Brazil to China Three Gorges (Luxembourg) Energy S.à.r.l. (China Three Gorges) and a sale of Duke Energy's remaining Latin American assets in Peru, Chile, Ecuador, Guatemala, El Salvador and Argentina to ISQ Enerlam Aggregator, L.P. and Enerlam (UK) Holding Ltd. (I Squared Capital) (collectively, the International Disposal Group). See Note 2 for additional information on the sale of International Energy.

The results of operations of the International Disposal Group 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 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. Substantially all of the Subsidiary Registrants' operations qualify for regulatory accounting.

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.

Progress Energy is a public utility holding company headquartered in Raleigh, North Carolina, subject to regulation by FERC. Progress Energy conducts operations through its wholly owned subsidiaries, Duke Energy Progress and Duke Energy Florida.

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.

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.

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.

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.

Piedmont is a regulated public utility primarily engaged in the distribution of natural gas in portions of North Carolina, South Carolina and Tennessee. Piedmont is also invested in joint venture, energy-related businesses, including regulated interstate natural gas transportation and storage and intrastate natural gas transportation businesses. Piedmont is subject to the regulatory provisions of the NCUC, PSCSC, Tennessee Public Utility Commission (formerly the Tennessee Regulatory Authority) (TPUC) and FERC.

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles (GAAP) in the U.S. for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all information and notes required by GAAP in the U.S. for annual financial statements. 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, 2016, and the Consolidated Financial Statements and Notes in the Piedmont Annual Report on Form 10-K for the year ended October 31, 2016.

Effective November 1, 2016, Piedmont's fiscal year-end was changed from October 31 to December 31, the year-end of Duke Energy. A transition report was filed on Form 10-Q (Form 10-QT) as of December 31, 2016, for the transition period from November 1, 2016 to December 31, 2016.

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 and natural gas 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, meter reading schedules, and the impact of weather normalization or margin decoupling mechanisms.

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

(in millions)	March 31, 2017		December 31, 2016
Duke Energy	$	724	$	831
Duke Energy Carolinas	296		313
Progress Energy	151		161
Duke Energy Progress	84		102
Duke Energy Florida	67		59
Duke Energy Ohio	2		2
Duke Energy Indiana	27		32
Piedmont	38		77

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)	March 31, 2017		December 31, 2016
Duke Energy Ohio	$	69	$	97
Duke Energy Indiana	106		123

AMOUNTS ATTRIBUTABLE TO CONTROLLING INTERESTS

Duke Energy's amount of Income from Discontinued Operations, net of tax presented on the Condensed Consolidated Statements of Operations for the three months ended March 31, 2016, includes amounts attributable to noncontrolling interest. The following table presents Net Income Attributable to Duke Energy Corporation for continuing operations and discontinued operations.

	Three Months Ended
(in millions)	March 31, 2016
Income from Continuing Operations	$	577
Income from Continuing Operations Attributable to Noncontrolling Interests	3
Income from Continuing Operations Attributable to Duke Energy Corporation	$	574
Income from Discontinued Operations, net of tax	$	122
Income from Discontinued Operations Attributable to Noncontrolling Interests, net of tax	2
Income from Discontinued Operations Attributable to Duke Energy Corporation, net of tax	$	120
Net Income	$	699
Net Income Attributable to Noncontrolling Interests	5
Net Income Attributable to Duke Energy Corporation	$	694

INVENTORY

Inventory is used for operations and is recorded primarily using the average cost method. Inventory related to regulated operations is valued at historical cost. Inventory related to nonregulated operations is valued at the lower of cost or market. Materials and supplies are recorded as inventory when purchased and subsequently charged to expense or capitalized to property, plant and equipment when installed. Inventory, including excess or obsolete inventory, is written-down to the lower of cost or market value. Once inventory has been written-down, it creates a new cost basis for the inventory that is not subsequently written-up. Provisions for inventory write-offs were not material for the three months ended March 31, 2017 and December 31, 2016. The components of inventory are presented in the tables below.

	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Materials and supplies	$	2,328	$	766	$	1,122	$	780	$	341	$	85	$	315	$	2
Coal	724		248		297		162		135		17		161		—
Natural gas, oil and other fuel	314		37		233		111		123		16		2		27
Total inventory	$	3,366	$	1,051	$	1,652	$	1,053	$	599	$	118	$	478	$	29

	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Materials and supplies	$	2,374	$	767	$	1,167	$	813	$	354	$	84	$	312	$	1
Coal	774		251		314		148		166		19		190		—
Natural gas, oil and other fuel	374		37		236		115		121		34		2		65
Total inventory	$	3,522	$	1,055	$	1,717	$	1,076	$	641	$	137	$	504	$	66

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 March 31,
(in millions)	2017		2016
Duke Energy	$	91	$	91
Duke Energy Carolinas	9		8
Progress Energy	46		47
Duke Energy Progress	5		5
Duke Energy Florida	41		42
Duke Energy Ohio	28		28
Duke Energy Indiana	7		8
Piedmont	1		1

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2017 and 2016 had no material impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. While immaterial, adoption of the following accounting standard had the most significant impact on the Duke Energy results of operations, cash flows and financial position for the three months ended March 31, 2017.

Stock-Based Compensation and Income Taxes. In March 2017, Duke Energy adopted Financial Accounting Standards Board (FASB) guidance, which revised the accounting for stock-based compensation and the associated income taxes. The adopted guidance changes certain aspects of accounting for stock-based payment awards to employees including the accounting for income taxes and classification on the Condensed Consolidated Statements of Cash Flows. The primary impact to Duke Energy as a result of implementing this guidance was a cumulative-effect adjustment to retained earnings for tax benefits not previously recognized and higher income tax expense for the three months ended March 31, 2017. See the Duke Energy Condensed Consolidated Statements of Changes in Equity and Note 16 for further information.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of March 31, 2017.

Retirement Benefits. In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic costs related to benefit plans. Current GAAP permits the aggregation of all the components of net periodic costs on the income statement and does not require the disclosure of the location of net periodic costs on the Condensed Consolidated Statement of Operations. Under the amended guidance, the service cost component of net periodic costs must be included within Operating income within the same line as other compensation expenses. All other components of net periodic costs must be outside of Operating income. In addition, the updated guidance permits only the service cost component of net periodic costs to be capitalized to Inventory or Property, Plant and Equipment. This represents a change from current GAAP, which permits all components of net periodic costs to be capitalized. The guidance allows for a practical expedient that permits a company to use amounts disclosed in prior-period financial statements as the estimation basis for applying the retrospective presentation requirements.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2018. These amendments should be applied retrospectively for the presentation of the various components of net periodic costs and prospectively for the change in eligible costs to be capitalized. Duke Energy currently presents all of the components of net periodic costs that are not capitalized within Operation, maintenance and other on the Condensed Consolidated Statement of Operations. Under this updated guidance, Duke Energy will retrospectively move all the components of net periodic costs except for the service cost component to below Operating income. However, Duke Energy will continue to present the service cost component not capitalized within Operation, maintenance and other as this line item includes other compensation expense. Duke Energy is currently evaluating the financial statement impact, if any, of adopting this standard and whether or not the practical expedient will be utilized.

Goodwill Impairment. In January 2017, the FASB issued revised guidance for subsequent measurement of goodwill. Under the guidance, a company will recognize an impairment to goodwill for the amount by which a reporting unit's carrying value exceeds the reporting unit's fair value, not to exceed the amount of goodwill allocated to that reporting unit. For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2020. However, Duke Energy expects to early adopt this guidance on a prospective basis for the next interim or annual goodwill impairment test. Duke Energy does not expect adopting this guidance will have a material impact to its results of operations or financial position.

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.

Most of Duke Energy’s revenue is expected to be in scope of the new guidance. The majority of our sales, including energy provided to residential customers, are from tariff offerings that provide natural gas or electricity without a defined contractual term (‘at-will’). For such arrangements, Duke Energy expects that the revenue from contracts with customers will be equivalent to the electricity or natural gas supplied and billed in that period (including estimated billings). As such, Duke Energy does not expect that there will be a significant shift in the timing or pattern of revenue recognition for such sales. The evaluation of other revenue streams is ongoing, including long-term contracts with industrial customers and long-term purchase power agreements (PPA).

Duke Energy continues to evaluate what information would be most useful for users of the financial statements, including information already provided in disclosures outside of the financial statement footnotes. These additional disclosures could include the disaggregation of revenues by geographic location, type of service, customer class or by duration of contract (‘at-will’ versus contracted revenue). Revenues from contracts with customers, revenue recognized under regulated operations accounting and revenue from lease accounting will also be disclosed.

Duke Energy intends to use the modified retrospective method of adoption effective January 1, 2018. This method results in a cumulative-effect adjustment that will be recorded to retained earnings as of January 1, 2018, as if the standard had always been in effect. Disclosures for 2018 will include a comparison to what would have been reported for 2018 under the current revenue recognition rules in order to assist financial statement users in understanding how revenue recognition has changed as a result of this standard and to facilitate comparability with prior year reported results, which are not restated under the modified retrospective approach.

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 financial statement impact of adopting this standard. Other than an expected increase in assets and liabilities, the ultimate impact of the new standard has not yet been determined. Significant system enhancements may be required to facilitate the identification, tracking and reporting of potential leases based upon requirements of the new lease standard.

Statement of Cash Flows. In November 2016, the FASB issued revised accounting guidance to reduce diversity in practice for the presentation and classification of restricted cash on the statement of cash flows. Under the updated guidance, restricted cash and restricted cash equivalents will be included within beginning-of-period and end-of-period cash and cash equivalents on the statement of cash flows.

For Duke Energy, this guidance is effective for the interim and annual periods beginning January 1, 2018, although it can be early adopted. The guidance will be applied using a retrospective transition method to each period presented. Upon adoption by Duke Energy, the revised guidance will result in a change to the amount of cash and cash equivalents and restricted cash explained when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Prior to adoption, the Duke Energy Registrants reflect changes in restricted cash within Cash Flows from Investing Activities on the Condensed Consolidated Statement of Cash Flows.

Financial Instruments Classification and Measurement. In January 2016, the FASB issued revised accounting guidance for the classification and measurement of financial instruments. Changes in the fair value of all equity securities will be required to be recorded in net income. Current GAAP allows some changes in fair value for available-for-sale equity securities to be recorded in Accumulated other comprehensive income (AOCI). Additional disclosures will be required to present separately the financial assets and financial liabilities by measurement category and form of financial asset. An entity's equity investments that are accounted for under the equity method of accounting are not included within the scope of the new guidance.

For Duke Energy, the revised accounting guidance is effective for interim and annual periods beginning January 1, 2018, by recording a cumulative-effect adjustment to retained earnings as of January 1, 2018. This guidance is expected to have minimal impact on the Duke Energy Registrant's Condensed Consolidated Statements of Operations and Comprehensive Income as changes in the fair value of most of the Duke Energy Registrants' available-for-sale equity securities are deferred as regulatory assets or liabilities pursuant to accounting guidance for regulated operations.

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Acquisitions and Dispositions

3 Months Ended

Mar. 31, 2017

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 3, 2016, Duke Energy acquired all outstanding common stock of Piedmont for a total cash purchase price of $5.0 billion and assumed Piedmont's existing long-term debt, which had a fair value of approximately $2.0 billion at the time of the acquisition. The acquisition provides a foundation for Duke Energy to establish a broader, long-term strategic natural gas infrastructure platform to complement its existing natural gas pipeline investments and regulated natural gas business in the Midwest. In connection with the closing of the acquisition, Piedmont became a wholly owned subsidiary of Duke Energy.

Purchase Price Allocation

The purchase price allocation of the Piedmont acquisition is as follows:

(in millions)
Current assets	$	497
Property, plant and equipment, net	4,714
Goodwill	3,353
Other long-term assets	804
Total assets	9,368
Current liabilities, including current maturities of long-term debt	576
Long-term liabilities	1,790
Long-term debt	2,002
Total liabilities	4,368
Total purchase price	$	5,000

The fair value of Piedmont's assets and liabilities were determined based on significant estimates and assumptions that are judgmental in nature, including projected future cash flows (including timing), discount rates reflecting risk inherent in the future cash flows and market prices of long-term debt.

The majority of Piedmont’s operations are subject to the rate-setting authority of the NCUC, the PSCSC and the TPUC and are accounted for pursuant to accounting guidance for regulated operations. The rate-setting and cost recovery provisions currently in place for Piedmont’s regulated operations provide revenues derived from costs, including a return on investment of assets and liabilities included in rate base. Thus, the fair value of Piedmont's assets and liabilities subject to these rate-setting provisions approximates the pre-acquisition carrying value and does not reflect any net valuation adjustments.

The significant assets and liabilities for which valuation adjustments were reflected within the purchase price allocation include the acquired equity method investments and long-term debt. The difference between the fair value and the pre-acquisition carrying value of long-term debt for regulated operations was recorded as a regulatory asset.

The excess of the purchase price over the fair value of Piedmont's assets and liabilities on the acquisition date was recorded as goodwill. The goodwill reflects the value paid by Duke Energy primarily for establishing a broader, long-term strategic natural gas infrastructure platform, an improved risk profile and expected synergies resulting from the combined entities.

Under Securities and Exchange Commission (SEC) regulations, Duke Energy elected not to apply push down accounting to the stand-alone Piedmont financial statements.

Accounting Charges Related to the Acquisition

Duke Energy incurred pretax nonrecurring transaction and integration costs associated with the acquisition of $16 million and $101 million for the three months ended March 31, 2017 and 2016, respectively. The 2016 amount includes $100 million of Interest Expense, which was driven by $93 million of unrealized losses on forward-starting interest rate swaps related to the acquisition financing. See Note 9 for additional information on the swaps.

Pro Forma Financial Information

The following unaudited pro forma financial information reflects the combined results of operations of Duke Energy and Piedmont as if the merger had occurred as of January 1, 2016. The pro forma financial information excludes potential cost savings, intercompany revenues, Piedmont’s earnings from the equity method investment in SouthStar sold immediately prior to the merger, and after-tax nonrecurring transaction and integration costs incurred by Duke Energy and Piedmont of $63 million. See Note 3 for additional information on Piedmont's sale of SouthStar.

This information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of Duke Energy.

	Three Months Ended
(in millions)	March 31, 2016
Operating Revenues	$	5,840
Net Income Attributable to Duke Energy Corporation	832

DISPOSITIONS

Sale of International Energy

In December 2016, Duke Energy sold its International Energy businesses, excluding the equity method investment in NMC (the International Disposal Group), in two separate transactions. Duke Energy sold its Brazilian business to China Three Gorges for approximately $1.2 billion, including the assumption of debt, and its remaining Central and South American businesses to I Squared Capital in a deal also valued at approximately $1.2 billion, including the assumption of debt. The transactions generated cash proceeds of $1.9 billion, excluding transaction costs, which were primarily used to reduce Duke Energy holding company debt.

The following table presents the results of the International Disposal Group, which are included in Income from Discontinued Operations, net of tax in Duke Energy's Condensed Consolidated Statements of Operations. Interest expense directly associated with the International Disposal Group was allocated to discontinued operations. No interest from corporate level debt was allocated to discontinued operations.

	Three Months Ended
(in millions)	March 31, 2016
Operating Revenues	$	246
Fuel used in electric generation and purchased power	47
Cost of natural gas	11
Operation, maintenance and other	71
Depreciation and amortization	22
Property and other taxes	3
Other Income and Expenses, net	10
Interest Expense	22
Income before income taxes	80
Income tax benefit(a)	(39		)
Income from discontinued operations of the International Disposal Group	119
Income from discontinued operations of other businesses	3
Income from Discontinued Operations, net of tax	$	122

(a) Includes an income tax benefit of $95 million related to historical undistributed foreign earnings. See Note 16 for additional information.

Duke Energy has elected not to separately disclose discontinued operations on the Condensed Consolidated Statements of Cash Flows. The following table summarizes Duke Energy's cash flows from discontinued operations related to the International Disposal Group.

	Three Months Ended
(in millions)	March 31, 2016
Cash flows provided by (used in):
Operating activities	$	85
Investing activities	(9		)

Other Sale Related Matters

Duke Energy will provide certain transition services to China Three Gorges and I Squared Capital for a period not to extend beyond November 2017 and December 2017, respectively. Cash flows related to providing the transition services are not material. In addition, Duke Energy will reimburse China Three Gorges and I Squared Capital for all tax obligations arising from the period preceding consummation on the transactions, totaling approximately $78 million. Duke Energy has not recorded any other liabilities, contingent liabilities or indemnifications related to the International Disposal Group.

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Business Segments

3 Months Ended

Mar. 31, 2017

Segment Reporting [Abstract]

Business Segments

BUSINESS SEGMENTS

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. 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 includes intercompany revenues and expenses that are eliminated in the Condensed Consolidated Financial Statements. Products and services are sold between affiliate companies and reportable segments of Duke Energy at cost.

Duke Energy

Due to the Piedmont acquisition and the sale of International Energy in the fourth quarter of 2016, Duke Energy's segment structure has been realigned to include the following segments: Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables. Prior period information has been recast to conform to the current segment structure. See Note 2 for further information on the Piedmont and International Energy transactions.

The Electric Utilities and Infrastructure segment includes Duke Energy's regulated electric utilities in the Carolinas, Florida and the Midwest. The regulated electric utilities conduct operations through the Subsidiary Registrants that are substantially all regulated and, accordingly, qualify for regulatory accounting treatment. Electric Utilities and Infrastructure also includes Duke Energy's electric transmission infrastructure investments.

The Gas Utilities and Infrastructure segment includes Piedmont, Duke Energy's natural gas local distribution companies in Ohio and Kentucky, and Duke Energy's natural gas storage and mid-stream pipeline investments. Gas Utilities and Infrastructure's operations are substantially all regulated and, accordingly, qualify for regulatory accounting treatment.

Commercial Renewables is primarily comprised of nonregulated utility scale wind and solar generation assets located throughout the U.S.

The remainder 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). Other also includes Duke Energy's 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.

Business segment information is presented in the following tables. Segment assets presented exclude intercompany assets.

	Three Months Ended March 31, 2017
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	4,939	$	648	$	128	$	5,715	$	14		$	—		$	5,729
Intersegment revenues	8		22		—		30		19			(49		)	—
Total revenues	$	4,947	$	670	$	128	$	5,745	$	33		$	(49	)	$	5,729
Segment income (loss)	$	635	$	133	$	25	$	793	$	(77	)	$	—		$	716
Add back noncontrolling interests															1
Net income															$	717
Segment assets	$	115,766	$	10,866	$	4,400	$	131,032	$	2,898		$	178		$	134,108

	Three Months Ended March 31, 2016
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,081	$	169	$	114	$	5,364	$	13		$	—		$	5,377
Intersegment revenues	8		1		—		9		16			(25		)	—
Total revenues	$	5,089	$	170	$	114	$	5,373	$	29		$	(25	)	$	5,377
Segment income (loss)(a)	$	664	$	32	$	26	$	722	$	(148	)	$	—		$	574
Add back noncontrolling interests															3
Income from discontinued operations, net of tax															122
Net income															$	699

(a) Other includes $74 million of after-tax costs to achieve mergers, including losses on forward-starting interest rate swaps related to the Piedmont acquisition financing. See Note 9 for additional information.

Duke Energy Ohio

Duke Energy Ohio has two reportable operating segments, Electric Utilities and Infrastructure and Gas Utilities and Infrastructure.

Electric Utilities and Infrastructure transmits and distributes electricity in portions of Ohio and generates, distributes and sells electricity in portions of Kentucky. Gas Utilities and Infrastructure transports and sells natural gas in portions of Ohio and northern Kentucky. It conducts operations primarily through Duke Energy Ohio and its wholly owned subsidiary, Duke Energy Kentucky.

Other is primarily comprised of governance costs allocated by its parent, Duke Energy, and revenues and expenses related to Duke Energy Ohio's contractual arrangement to buy power from the Ohio Valley Electric Corporation's (OVEC) power plants. See Note 8 for additional information on related party transactions.

	Three Months Ended March 31, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Consolidated
Total revenues	$	337	$	170	$	507	$	11		$	—		$	518
Segment income (loss)/Net Income	24		26		50		(8		)	—			42
Segment assets	4,856		2,696		7,552		71			(14		)	7,609

	Three Months Ended March 31, 2016
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Consolidated
Total revenues	$	340	$	170	$	510	$	6		$	—		$	516
Segment income (loss)	$	36	$	31	$	67	$	(9	)	$	(1	)	$	57
Income from discontinued operations, net of tax													2
Net income													$	59

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

Piedmont has one reportable segment, Gas Utilities and Infrastructure, which transports and sells natural gas. The remainder of Piedmont's operations is classified as Other. While not considered a reportable segment, Other primarily consists of certain unallocated corporate costs, including acquisition-related expenses, and Piedmont's equity method investment in SouthStar Energy Services, LLC (SouthStar) prior to its sale. Piedmont sold its 15 percent membership interest in SouthStar on October 3, 2016. Piedmont's income, net of tax, from SouthStar for the three months ended March 31, 2016 was $7 million.

The remaining Subsidiary Registrants each have one reportable operating segment, Electric Utilities and Infrastructure, which generates, transmits, distributes and sells electricity. The remainder of each company's operations is classified as Other. While not considered a reportable segment for any of these companies, Other consists of certain unallocated corporate costs. Other for Progress Energy also includes interest expense on corporate debt instruments of $55 million and $56 million for the three months ended March 31, 2017 and 2016, respectively. The following table summarizes the net loss of Other for each of these entities.

	Three Months Ended
	March 31,
(in millions)	2017			2016
Duke Energy Carolinas	$	(6	)	$	(17	)
Progress Energy	(43		)	(49		)
Duke Energy Progress	(3		)	(8		)
Duke Energy Florida	(2		)	(4		)
Duke Energy Indiana	(2		)	(2		)
Piedmont	(4		)	6

The assets at Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana are substantially all included within the Electric Utilities and Infrastructure segment at March 31, 2017. The assets at Piedmont are substantially all included within the Gas Utilities and Infrastructure segment at March 31, 2017.

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Regulatory Matters

3 Months Ended

Mar. 31, 2017

Regulated Operations [Abstract]

Regulatory Matters

REGULATORY MATTERS

RATE RELATED INFORMATION

The NCUC, PSCSC, FPSC, IURC, PUCO, TPUC and KPSC approve rates for retail electric and natural gas services within their states. The FERC approves rates for electric sales to wholesale customers served under cost-based rates (excluding Ohio and Indiana), as well as sales of transmission service. The FERC also regulates certification and siting of new interstate natural gas pipeline projects.

Duke Energy Carolinas and Duke Energy Progress

Ash Basin Closure Costs Deferral

On December 30, 2016, Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the NCUC seeking an accounting order authorizing deferral 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 North Carolina. Initial comments were received in March 2017, and reply comments were filed on April 19, 2017. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

Duke Energy Carolinas

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 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. On March 24, 2017, the South Carolina Supreme Court denied the request for review, thus concluding the matter.

William States Lee III Nuclear Station

In December 2007, Duke Energy Carolinas applied to the NRC for combined operating licenses (COLs) for two Westinghouse Electric Company (Westinghouse) AP1000 reactors for the proposed William States Lee III Nuclear Station to be located at a site in Cherokee County, South Carolina. The NCUC and PSCSC have concurred with the prudency of Duke Energy Carolinas decisions to incur certain project development and preconstruction costs through several separately issued orders, although full cost recovery is not guaranteed. In December 2016, the NRC issued a COL for each reactor. Duke Energy Carolinas is not required to build the nuclear reactors as a result of the COLs being issued.

On March 29, 2017, Westinghouse filed for voluntary Chapter 11 bankruptcy in the U.S. Bankruptcy Court for the Southern District of New York. Duke Energy Carolinas is monitoring the bankruptcy proceedings to assess the impact it will have on the future construction of nuclear plants.

Duke Energy Progress

Storm Cost Deferral Filing

On December 16, 2016, Duke Energy Progress filed a petition with the NCUC requesting an accounting order to defer certain costs incurred in connection with response to Hurricane Matthew and other significant storms in 2016. Duke Energy Progress proposed in the filing to true-up the total costs quarterly through August 2017. The current estimate of incremental operation and maintenance and capital costs is $116 million. On March 15, 2017, the Public Staff filed comments supporting deferral of a portion of Duke Energy Progress’ requested amount. Duke Energy Progress filed reply comments on April 12, 2017. Duke Energy Progress cannot predict the outcome of this matter.

Western Carolinas Modernization Plan

On November 4, 2015, Duke Energy Progress announced a Western Carolinas Modernization Plan, which included 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 plan also included upgrades to existing transmission lines and substations, installation of solar generation and 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.

On March 28, 2016, the NCUC issued an order approving a Certificate of Public Convenience and Necessity (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. On March 28, 2017, Duke Energy Progress filed an annual progress report for the construction of the combined-cycle plants with the NCUC, with an estimated cost of $893 million. Site preparation activities for the combined-cycle plants are underway and construction of these plants is scheduled to begin in fall 2017, with an expected in-service date in late 2019. Duke Energy Progress plans to file for future approvals related to the proposed solar generation and pilot battery storage project.

The carrying value of the 376-MW Asheville coal-fired plant, including associated ash basin closure costs, of $471 million and $492 million are included in Generation facilities to be retired, net on Duke Energy Progress' Condensed Consolidated Balance Sheet as of March 31, 2017 and December 31, 2016, respectively.

Duke Energy Florida

Hines Chiller Uprate Project

On February 2, 2017, 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 Energy Complex. The Uprate Project was placed into service in March 2017 at a cost of approximately $150 million. The retail revenue requirement is approximately $19 million. On March 28, 2017, the FPSC issued an order approving the revenue requirement which were included in base rates for the first billing cycle of April 2017.

Levy Nuclear Project

On July 28, 2008, Duke Energy Florida applied to the NRC for COLs for two Westinghouse AP1000 reactors at Levy. In 2008, the FPSC granted Duke Energy Florida’s petition for an affirmative Determination of Need and related orders requesting cost recovery under Florida’s nuclear cost-recovery rule, together with the associated facilities, including transmission lines and substation facilities. In October 2016, the NRC issued COLs for the proposed Levy Nuclear Plant Units 1 and 2. Duke Energy Florida is not required to build the nuclear reactors as a result of the COLs being issued.

On January 28, 2014, Duke Energy Florida terminated the Levy engineering, procurement and construction agreement (EPC). Duke Energy Florida may be required to pay for work performed under the EPC. Duke Energy Florida recorded an exit obligation in 2014 for the termination of the EPC. This liability was recorded within Other in Deferred Credits and Other Liabilities with an offset primarily to Regulatory assets on the Condensed Consolidated Balance Sheets. Duke Energy Florida is allowed to recover reasonable and prudent EPC cancellation costs from its retail customers. On May 1, 2017, Duke Energy Florida filed a request with the FPSC to recover approximately $82 million of Levy Nuclear Project costs from retail customers in 2018. A hearing is scheduled in August 2017. Duke Energy Florida cannot predict the outcome of this matter.

On March 29, 2017, Westinghouse filed for voluntary Chapter 11 bankruptcy in the U.S. Bankruptcy Court for the Southern District of New York. Duke Energy Florida is monitoring the bankruptcy proceedings to assess the impact it will have on the future construction of nuclear plants.

Duke Energy Ohio

Ohio Valley Electric Corporation

On March 31, 2017, Duke Energy Ohio filed for approval to adjust its existing price stabilization rider (Rider PSR) to pass through net costs related to its contractual entitlement to capacity and energy from the generating assets owned by OVEC. The PUCO approved Rider PSR, but set it at zero dollars in connection with the most recent electric security plan. The application seeks to adjust Rider PSR as of April 1, 2017. Duke Energy Ohio is seeking deferral authority for net costs incurred from April 1, 2017, until the new rates under Rider PSR are put into effect. See Note 12 for additional discussion of Duke Energy Ohio's ownership interest in OVEC. Duke Energy Ohio cannot predict the outcome of this proceeding.

East Bend Coal Ash Basin Filing

On December 2, 2016, Duke Energy Kentucky filed with the KPSC a request for a CPCN for construction projects necessary to close and repurpose an ash basin at the East Bend facility as a result of current and proposed U.S. Environmental Protection Agency (EPA) regulations. Duke Energy Kentucky estimated a total cost of approximately $93 million in the filing and expects in-service date in the fourth quarter of 2018. Duke Energy Kentucky expects the KPSC to issue an order in the second quarter of 2017.

Base Rate Case

Duke Energy Ohio filed with the PUCO an electric distribution base rate case application and supporting testimony in March 2017. Duke Energy Ohio has requested an estimated annual increase of approximately $15 million and a return on equity of 10.4 percent. The application also includes requests to continue certain current riders and establish new riders related to LED Outdoor Lighting Service and regulatory mandates. Duke Energy Ohio cannot predict the outcome of this matter.

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. On January 20, 2017, Duke Energy Ohio filed an amended application with the Ohio Power Siting Board for approval of one of two proposed routes. If approved, construction of the pipeline extension is expected to be completed before the 2019/2020 winter season. A public hearing is scheduled for June 15, 2017, and an adjudicatory hearing is scheduled to begin July 12, 2017. The proposed project involves the installation of a natural gas line and is estimated to cost between $86 million and $110 million, excluding AFUDC.

Advanced Metering Infrastructure

On April 25, 2016, Duke Energy Kentucky filed with the KPSC an application for approval of a CPCN for the construction of advanced metering infrastructure. Duke Energy Kentucky estimates the $49 million project, if approved, will take 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 to be replaced. Duke Energy Kentucky and the Kentucky Attorney General entered into a stipulation to settle matters related to the application. An evidentiary hearing on the application and stipulation was held on December 8, 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 proposed to replace certain natural gas service lines on an accelerated basis over a 10-year period. Duke Energy Ohio also proposed 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's current projected total capital and operations and maintenance expenditures under the ASRP are approximately $240 million. The filing also sought approval of a rider mechanism (Rider ASRP) to recover related expenditures. Duke Energy Ohio proposed to update Rider ASRP on an annual basis. Intervenors opposed the ASRP, primarily because they believe the program is neither required nor necessary under federal pipeline regulation. On October 26, 2016, the PUCO issued an order denying the proposed ASRP. The PUCO did, however, encourage Duke Energy Ohio to work with the PUCO Staff and intervenors. Duke Energy Ohio filed an application for rehearing of the PUCO decision. In December 2016, the PUCO granted the request for the purpose of further review. 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. 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 upon 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 January 6, 2016, Duke Energy Ohio and the PUCO Staff entered into a stipulation, pending the PUCO's approval, to resolve issues related to performance incentives and the PUCO Staff audit of 2013 costs, among other issues. In December 2015, based upon the stipulation, Duke Energy Ohio re-established approximately $20 million of the revenues that had been previously reversed. On October 26, 2016, the PUCO issued an order approving the stipulation without modification. Intervenors requested a rehearing of the PUCO decision. In December 2016, the PUCO granted a rehearing for the purpose of further review. 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 PUCO order also authorized Duke Energy Ohio to continue deferring MGP environmental investigation and remediation costs incurred subsequent to 2012 and to submit annual filings to adjust the MGP rider for future costs. Intervening parties appealed this decision to the Ohio Supreme Court and that appeal remains pending. Oral argument was heard on February 28, 2017. Incurred and projected investigation and remediation expenses at these MGP sites that have not been collected through the MGP rider are approximately $100 million and are recorded as Regulatory assets on Duke Energy Ohio's Condensed Consolidated Balance Sheet as of March 31, 2017. 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 $90 million at March 31, 2017, and December 31, 2016, recorded within Other in Current liabilities and Other in Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets. The retail portions of MTEP costs billed by MISO are recovered by Duke Energy Ohio through a non-bypassable rider. As of March 31, 2017, and December 31, 2016, Duke Energy Ohio had $71 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 EPA's 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, including AFUDC, under a federal mandate tracker that 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. On January 24, 2017, Duke Energy Indiana and various Intervenors filed a settlement agreement with the IURC. Terms of the settlement include recovery of 60 percent of the estimated CCR compliance construction project capital costs through existing rider mechanisms and deferral of 40 percent of these costs until Duke Energy Indiana's next general retail rate case. The deferred costs will earn a return based on Duke Energy Indiana's long-term debt rate of 4.73 percent until costs are included in retail rates, at which time the deferred costs will earn a full return. Costs are to be capped at $365 million, plus actual AFUDC. Costs above the cap may be recoverable in the next rate case. Terms of the settlement agreement also require Duke Energy Indiana to perform certain reporting and groundwater monitoring. The settlement is subject to approval by the IURC. An evidentiary hearing was held on February 23, 2017, and Duke Energy Indiana filed a proposed order with the IURC on March 30, 2017. Duke Energy Indiana cannot predict the outcome of this matter.

FERC Transmission Return on Equity Complaints

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 complaints, among other things, claim that the current base rate of return on equity earned by MISO transmission owners should be reduced to 8.67 percent. On January 5, 2015, the FERC issued an order accepting the MISO transmission owners' adder of 0.50 percent 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. On December 22, 2015, the presiding FERC ALJ in the first complaint issued an Initial Decision in which the base rate of return on equity was set at 10.32 percent. On September 28, 2016, the Initial Decision in the first complaint was affirmed by FERC, but is subject to rehearing requests. 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 Decision in the second complaint is pending FERC review. On April 14, 2017, the U.S. Court of Appeals for the District of Columbia Circuit, in Emera Maine v. FERC, reversed and remanded certain aspects of the methodology employed by FERC to establish rates of return on equity. This decision may affect the outcome of the complaints against Duke Energy Indiana. Duke Energy Indiana currently believes these matters will not have a material impact on its results of operations, cash flows and financial position.

Piedmont

North Carolina Integrity Management Rider Filings

In October 2016, Piedmont filed a petition with the NCUC under the integrity management rider (IMR) mechanism seeking authority to collect an additional $8 million in annual revenues, effective December 2016, based on the eligible capital investments closed to integrity and safety projects over the six-month period ending September 30, 2016. In November 2016, the NCUC approved the request.

On May 1, 2017, Piedmont filed a petition with the NCUC under the IMR mechanism to collect an additional $11.6 million in annual revenues, effective June 2017, based on the eligible capital investments closed to integrity and safety projects over the six-month period ending March 31, 2017.  A ruling from the NCUC is pending.

Tennessee IMR Filings

In November 2016, Piedmont filed an annual report with the TPUC under the IMR mechanism seeking authority to collect an additional $1.7 million in annual revenues effective January 2017, based on the capital investments in integrity and safety projects over the 12-month period ending October 31, 2016. The TPUC approved the request at a hearing on April 10, 2017.

OTHER REGULATORY MATTERS

Atlantic Coast Pipeline

On September 2, 2014, Duke Energy, Dominion Resources (Dominion), Piedmont and Southern Company Gas announced the formation of Atlantic Coast Pipeline, LLC (ACP) to build and own the proposed Atlantic Coast Pipeline (ACP pipeline), an approximately 600-mile interstate natural gas pipeline running from West Virginia to North Carolina. The ACP pipeline is designed to meet the needs identified in RFPs by Duke Energy Carolinas, Duke Energy Progress and Piedmont. The ACP pipeline development costs are estimated between $5.0 billion to $5.5 billion. Dominion will build and operate the ACP pipeline and holds a leading ownership percentage in ACP of 48 percent. Duke Energy owns a 47 percent interest through its Gas Utilities and Infrastructure segment. Southern Company Gas maintains a 5 percent interest. See Note 12 for additional information related to Duke Energy's ownership interest.

Duke Energy Carolinas, Duke Energy Progress and Piedmont, among others, will be customers of the pipeline. Purchases will be made under several 20-year supply contracts, subject to state regulatory approval. On September 18, 2015, ACP filed an application with the FERC requesting a CPCN authorizing ACP to construct the pipeline. ACP executed a construction agreement in September 2016. ACP also requested approval of an open access tariff and the precedent agreements it entered into with future pipeline customers. In December 2016, FERC issued a draft Environmental Impact Statement (EIS) indicating that the proposed pipeline would not cause significant harm to the environment or protected populations. The draft EIS comment period ended in April 2017, and ACP is working to resolve items identified through the comment process. The final EIS is expected in summer 2017. FERC approval of the application is expected within 90 days of the issuance of the final EIS. Construction is projected to begin in the second-half of 2017, with a targeted in-service date in the second half of 2019.

Sabal Trail Transmission, LLC Pipeline

On May 4, 2015, Duke Energy acquired a 7.5 percent ownership interest in Sabal Trail Transmission, LLC (Sabal Trail) from Spectra Energy Partners, LP, a master limited partnership, formed by Enbridge Inc. (formerly Spectra Energy Corp.). Spectra Energy Partners, LP holds a 50 percent ownership interest in Sabal Trail and NextEra Energy has a 42.5 percent ownership interest. Sabal Trail is a joint venture that is constructing a 515-mile natural gas pipeline (Sabal Trail pipeline) to transport natural gas to Florida. Total estimated project costs are approximately $3.2 billion. The Sabal Trail pipeline will traverse Alabama, Georgia and Florida. 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 pipeline. On September 7, 2016, FERC denied the intervenors' rehearing requests. On September 21, 2016, intervenors filed an appeal of FERC's CPCN orders to the U.S. Court of Appeals for the District of Columbia Circuit. Oral argument on the appeal was held on April 18, 2017, and a decision is expected in the summer of 2017. The Sabal Trail pipeline has received other required regulatory approvals and construction began in the summer of 2016, with an expected in-service date in mid-2017. See Note 12 for additional information related to Duke Energy's ownership interest.

Constitution Pipeline

Duke Energy owns a 24 percent ownership interest in Constitution Pipeline Company, LLC (Constitution). Constitution is a natural gas pipeline project slated to transport natural gas supplies from the Marcellus supply region in northern Pennsylvania to major northeastern markets. The pipeline will be constructed and operated by Williams Partners L.P., which has a 41 percent ownership share. The remaining interest is held by Cabot Oil and Gas Corporation and WGL Holdings, Inc.

On April 22, 2016, the New York State Department of Environmental Conservation (NYSDEC) denied Constitution’s application for a necessary water quality certification for the New York portion of the Constitution pipeline. Constitution filed legal actions in the U.S. District Court for the Northern District of New York and in the U.S. Court of Appeals for the Second Circuit (U.S. Court of Appeals) challenging the legality and appropriateness of the NYSDEC’s decision. Both courts granted Constitution's motions to expedite the schedules for the legal actions. On November 16, 2016, oral arguments were heard in the U.S. Court of Appeals. On March 16, 2017, the U.S. District Court for the Northern District of New York dismissed without prejudice Constitution’s claim that New York State permits were preempted by the federal permitting process. The ruling on oral arguments made in the U.S. Court of Appeals regarding NYSDEC's denial of the water quality certification is currently expected in mid-2017.

Constitution remains steadfastly committed to pursuing the project and intends to pursue all available options to challenge the NYSDEC's decision. In light of the denial of the certification, Constitution revised its target in-service date of the project to be as early as the second half of 2018, assuming that the challenge process is satisfactorily and promptly concluded.

In July 2016, Constitution requested, and the FERC approved, an extension of the construction period and in-service deadline of the project to December 2018. Also in July, the FERC denied the New York Attorney General's (NYAG) complaint and request for a stay of the certificate order authorizing the project on the grounds that Constitution had improperly cut trees along the proposed route. The FERC found the complaint procedurally deficient and that there was no justification for a stay; it did find the filing constituted a valid request for investigation and thus referred the matter to FERC staff for further examination as may be appropriate. On November 22, 2016, the FERC denied the NYAG's request for reconsideration of this order.

Since April 2016, with the actions of the NYSDEC, Constitution stopped construction and discontinued capitalization of future development costs until the project's uncertainty is resolved. As a result, Duke Energy evaluated the investment in the Constitution project for other-than-temporary impairments (OTTIs). At this time, no OTTI has been determined and therefore no impairment charge to reduce the carrying value of the investment has been recorded. However, to the extent that the legal and regulatory proceedings have unfavorable outcomes, or if Constitution concludes that the project is not viable or does not go forward as legal and regulatory actions progress, the conclusions with respect to OTTIs could change and may require that an impairment charge of up to the recorded investment in the project, net of any cash and working capital returned, be recorded. Duke Energy will continue to monitor and update the OTTI analysis as required. Different assumptions could affect the timing and amount of any charge recorded in a period.

Pending the outcome of the matters described above, and when construction proceeds, Duke Energy remains committed to fund an amount in proportion to its ownership interest for the development and construction of the new pipeline. Duke Energy's total anticipated contributions are approximately $229 million.

See Note 12 for additional information related to ownership interest and carrying value of the investment.

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 North Carolina, Florida and Indiana earlier than their current estimated useful lives primarily because facilities do not have the requisite emission control equipment 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. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2017, and exclude capitalized asset retirement costs.

		Remaining Net
	Capacity	Book Value
	(in MW)	(in millions)
Duke Energy Carolinas
Allen Steam Station Units 1-3(a)	585	$	167
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2(b)	873	117
Duke Energy Indiana
Gallagher Units 2 and 4(c)	280	135
Total Duke Energy	1,738	$	419

(a) Duke Energy Carolinas will retire Allen Steam Station Units 1 through 3 by December 31, 2024, as part of the resolution of a lawsuit involving alleged New Source Review violations.

(b) Duke Energy Florida will likely retire these coal units by 2018 to comply with environmental regulations.

(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 settlement of Edwardsport IGCC matters.

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

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments And Contingencies

COMMITMENTS AND CONTINGENCIES

ENVIRONMENTAL

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

Remediation Activities

In addition to asset retirement obligations (AROs) 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 at all sites. 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 Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets.

	Three Months Ended March 31, 2017
				Duke					Duke		Duke			Duke			Duke
	Duke			Energy		Progress			Energy		Energy			Energy			Energy
(in millions)	Energy			Carolinas		Energy			Progress		Florida			Ohio			Indiana			Piedmont
Balance at beginning of period	$	98		$	10	$	18		$	3	$	14		$	59		$	10		$	1
Provisions/adjustments	6			1		—			—		1			4			(1		)	1
Cash reductions	(6		)	—		(1		)	—		(1		)	(4		)	—			—
Balance at end of period	$	98		$	11	$	17		$	3	$	14		$	59		$	9		$	2

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Balance at beginning of period	$	94		$	10		$	17		$	3		$	14		$	54	$	12	$	1
Provisions/adjustments	10			2			1			—			1			—		6		—
Cash reductions	(3		)	(1		)	(2		)	(1		)	(1		)	—		—		—
Balance at end of period	$	101		$	11		$	16		$	2		$	14		$	54	$	18	$	1

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	$	71
Duke Energy Carolinas	22
Duke Energy Ohio	36
Duke Energy Indiana	7
Piedmont	2

North Carolina and South Carolina Ash Basins

In February 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. 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 future state or federal civil enforcement proceedings, future regulatory directives, natural resources damages, future claims or litigation and long-term environmental impact costs, cannot be reasonably estimated at this time.

The North Carolina Department of Environmental Quality (NCDEQ) 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 ash release, Duke Energy Carolinas and Duke Energy Progress have been served with a higher level of NOVs, including assessed penalties for violations at L.V. Sutton Combined Cycle Plant (Sutton) and Dan River Steam Station. Duke Energy Carolinas and Duke Energy Progress cannot predict whether the NCDEQ will assess future penalties related to existing unresolved NOVs and if such penalties would be material. See "NCDEQ Notices of Violation" section below for additional discussion.

LITIGATION

Duke Energy

Duke Energy no longer has exposure to litigation matters related to the International Energy Disposal Group as a result of the divestiture of the business in December 2016. See Note 2 for additional information related to the sale of International 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 (collectively, the 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 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 December 14, 2016, the Delaware Chancery Court entered an order dismissing the Amended Complaint. Plaintiffs filed an appeal to the Delaware Supreme Court on January 9, 2017. The parties have completed briefing in the case and a date for oral argument has not been set.

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 appointed 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. On March 30, 2017, the court granted Defendants’ Motion to Dismiss on the claims relating to coal ash environmental issues and political contributions. A notice of appeal has not been filed. As discussed below, an agreement-in-principle has been reached to settle the merger related claims in the Bresalier Complaint, and those claims were also dismissed subject to that agreement.

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 (Merger Chancery Litigation). The lawsuit names as defendants the 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.

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 have reached an agreement-in-principle to settle the Merger Chancery Litigation, conditioned on dismissal as well, of the Tansey v. Rogers, et al case and the merger related claims in the Bresalier Complaint discussed above, for a total of $27 million. The entire settlement amount is to be funded by insurance. The settlement amount, less court-approved attorney fees, will be payable to Duke Energy. Settlement documents have been submitted to the court for approval and a hearing has been set for July 13, 2017.

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 in a consolidated federal court proceeding in Nevada. Each of these lawsuits contained 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 sought 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. The proposed settlement of the class action lawsuits was submitted to the Court and preliminarily approved on January 26, 2017. The Court will consider final approval of the class settlement following notice to the class members. The settlement amounts are not material to Duke Energy.

Duke Energy Carolinas and Duke Energy Progress

Coal Ash Insurance Coverage Litigation

In March 2017, Duke Energy Carolinas and Duke Energy Progress filed a civil action in North Carolina Superior Court against various insurance providers. The lawsuit seeks payment for coal ash related liabilities covered by third-party liability insurance policies. The insurance policies were issued between 1971 and 1986 and provide third-party liability insurance for property damage. The civil action seeks damages for breach of contract and indemnification for costs arising from the North Carolina Coal Ash Management Act of 2014, as amended, (Coal Ash Act) and the EPA CCR rule at 15 coal-fired plants in North Carolina and South Carolina. Duke Energy Carolinas and Duke Energy Progress 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. The 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, the 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.

The court issued orders in 2016 granting Motions' for Partial Summary Judgment for seven of the 14 North Carolina plants named in the enforcement actions. The litigation is concluded for these seven plants. Litigation continues for the remaining seven plants. In response to a motion for partial summary judgment on the groundwater claims filed by the environmental groups, on October 17, 2016, Duke Energy Carolinas and Duke Energy Progress filed a cross-motion for partial summary judgment on the groundwater claims. On February 13, 2017, the court issued an order denying both the environmental groups' motion for partial summary judgment and Duke Energy Carolinas and Duke Energy Progress' cross-motion for partial summary judgment. On March 15, 2017, Duke Energy Carolinas and Duke Energy Progress filed a Notice of Appeal to challenge the trial court’s denial of their cross-motion for partial summary judgment. The parties were unable to reach an agreement at mediation on April 18, 2017.

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

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. On August 19, 2016, Duke Energy Progress filed a Motion to Dismiss. On April 26, 2017, the court entered an order dismissing four of the claims in the federal citizen suit. Two claims relating to alleged violations of National Pollutant Discharge Elimination System permit provisions survived the motion to dismiss, and Duke Energy Progress’ response is due on May 10, 2017.

On March 16, 2017, the Roanoke River Basin Association served Duke Energy Progress with a 60-day notice of intent to bring suit pursuant to the citizen suit provision of the CWA for alleged violations of effluent standards and limitations at the Roxboro Plant.

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

Five previously filed cases involving the Riverbend, Cape Fear, H.F. Lee, Sutton and Buck plants were dismissed or settled in 2016.

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 the NCDEQ advising them not to drink water from the private wells on their land tested by the 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 basins, 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.

Duke Energy Carolinas and Duke Energy Progress have received formal demand letters from residents near Duke Energy Carolinas' and Duke Energy Progress' coal ash basins. The residents claim damages for nuisance and diminution in property value, among other things. The parties held three days of mediation discussions that ended at impasse. On January 6, 2017, Duke Energy Carolinas and Duke Energy Progress received the plaintiffs' notice of their intent to file suits should the matter not settle. The NCDEQ preliminarily approved Duke Energy’s permanent water solution plans on January 13, 2017, and as a result shortly thereafter, Duke Energy issued a press release, providing additional details regarding the homeowner compensation package. This package consists of three components: (i) a $5,000 goodwill payment to each eligible well owner to support the transition to a new water supply, (ii) where a public water supply is available and selected by the eligible well owner, a stipend to cover 25 years of water bills and (iii) the Property Value Protection Plan. The Property Value Protection Plan is a program offered by Duke Energy designed to guarantee eligible plant neighbors the fair market value of their residential property should they decide to sell their property during the time that the plan is offered. Duke Energy received a letter from Plaintiffs' counsel indicating their intent to file suit on February 2, 2017, should a settlement not be reached by that date. Plaintiff’s counsel did not file suit upon the expiration of the tolling agreement on February 2, 2017, and no suit has been filed to date. Duke Energy Carolinas and Duke Energy Progress have recognized reserves of $18 million and $4 million, respectively.

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 March 31, 2017, there were 111 asserted claims for non-malignant cases with the cumulative relief sought of up to $29 million, and 58 asserted claims for malignant cases with the cumulative relief sought of up to $16 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 $506 million at March 31, 2017 and $512 million at December 31, 2016. These reserves are classified in Other within Other Noncurrent 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 2036, 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 2036 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 $814 million in excess of the self-insured retention. Receivables for insurance recoveries were $587 million at March 31, 2017 and December 31, 2016. These amounts are classified in Other within Other Noncurrent 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. On September 21, 2016, the Court granted the motions to dismiss with prejudice. Plaintiffs filed a motion for reconsideration, which was denied. On January 4, 2017, plaintiffs filed a notice of appeal. Plaintiffs filed an appellate brief on March 16, 2017, and Duke Energy Florida filed responses on April 17, 2017. Duke Energy Florida cannot predict the outcome of this appeal.

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 an 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.

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. On July 11, 2016, Duke Energy Florida and Westinghouse filed separate Motions for Summary Judgment. On September 29, 2016, the court issued its ruling on the parties' respective Motions for Summary Judgment, ruling in favor of Westinghouse on a $30 million termination fee claim and dismissing Duke Energy Florida's $54 million refund claim, but stating that Duke Energy Florida could use the refund claim to offset any damages for termination costs. Westinghouse's claim for termination costs was unaffected by this ruling and continued to trial. At trial, Westinghouse reduced its claim for termination costs from $482 million to $424 million. Following a trial on the matter, the court issued its final order in December 2016 denying Westinghouse’s claim for termination costs and re-affirming its earlier ruling in favor of Westinghouse on the $30 million termination fee and Duke Energy Florida’s refund claim. Judgment was entered against Duke Energy Florida in the amount of approximately $34 million, which includes prejudgment interest. Westinghouse has appealed the trial court's order and Duke Energy Florida has cross-appealed.

It is not possible to predict the ultimate outcome of the appeal of the trial court's order. 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.

On March 29, 2017, Westinghouse filed Chapter 11 bankruptcy in the Southern District of New York, which could delay the timing of the appeal. Additional impacts, if any, of this bankruptcy filing on the resolution of the pending appeal and cross-appeal are unknown at this time.

MGP Cost Recovery Action

On December 30, 2011, Duke Energy Florida filed a lawsuit against FirstEnergy Corp. (FirstEnergy) to recover investigation and remediation costs incurred by Duke Energy Florida in connection with the restoration of two former MGP sites in Florida. Duke Energy Florida alleged that FirstEnergy, as the successor to Associated Gas & Electric Co., owes past and future contribution and response costs of up to $43 million for the investigation and remediation of MGP sites. On December 6, 2016, the trial court entered judgment against Duke Energy Florida in the case. In January 2017, Duke Energy Florida appealed the decision to the U.S. Court of Appeals for the 6th Circuit. Duke Energy Florida cannot predict the outcome of this appeal.

Duke Energy Indiana

Benton County Wind Farm Dispute

On December 16, 2013, Benton County Wind Farm LLC (BCWF) filed a lawsuit against Duke Energy Indiana seeking damages for past generation losses totaling approximately $16 million alleging Duke Energy Indiana violated its obligations under a 2006 PPA by refusing to offer electricity to the market at negative prices. Damage claims continue to increase during times that BCWF is not dispatched. Under 2013 revised MISO market rules, Duke Energy Indiana is required to make a price offer to MISO for the power it proposes to sell into MISO markets and MISO determines whether BCWF is dispatched. Because market prices would have been negative due to increased market participation, Duke Energy Indiana determined it would not bid at negative prices in order to balance customer needs against BCWF's need to run. BCWF contends Duke Energy Indiana must bid at the lowest negative price to ensure dispatch, while Duke Energy Indiana contends it is not obligated to bid at any particular price, that it cannot ensure dispatch with any bid and that is has reasonably balanced the parties' interests. On July 6, 2015, the U.S. District Court for the Southern District of Indiana entered judgment against BCWF on all claims. BCWF appealed the decision and on December 9, 2016, the appeals court ruled in favor of BCWF. The matter has been remanded to a lower court to determine damages. A settlement conference is scheduled on May 31, 2017. Duke Energy Indiana cannot predict the outcome of this matter. Ultimate resolution of this matter could have a material effect on the results of operations, financial position or cash flows of Duke Energy Indiana. However, appropriate regulatory recovery will be pursued for the retail portion of any costs incurred in connection with such resolution.

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 Other Noncurrent 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)	March 31, 2017		December 31, 2016
Reserves for Legal Matters
Duke Energy	$	91	$	98
Duke Energy Carolinas	23		23
Progress Energy	57		59
Duke Energy Progress	13		14
Duke Energy Florida	27		28
Duke Energy Ohio	4		4
Piedmont	2		2

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 or natural gas, 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

3 Months Ended

Mar. 31, 2017

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).

				Three Months Ended March 31, 2017
						Duke		Duke
	Maturity	Interest		Duke		Energy		Energy
Issuance Date	Date	Rate		Energy		Florida		Ohio
Secured Debt
February 2017(a)	June 2034	4.120	%	$	587	$	—	$	—
First Mortgage Bonds
January 2017(b)	January 2020	1.850	%	250		250		—
January 2017(b)	January 2027	3.200	%	650		650		—
March 2017(c)	June 2046	3.700	%	100		—		100
Total issuances				$	1,587	$	900	$	100

(a) Portfolio financing of four Texas and Oklahoma wind facilities. Secured by substantially all of the assets of these wind facilities and nonrecourse to Duke Energy. Proceeds were used to reimburse Duke Energy for a portion of previously funded construction expenditures.

(b) Debt issued to fund capital expenditures for ongoing construction and capital maintenance, to repay at maturity a $250 million aggregate principal amount of bonds due September 2017 and for general corporate purposes.

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

In April 2017, Duke Energy (Parent) issued $420 million of unsecured notes with a fixed interest rate of 3.364 percent and maturity date of April 2025. The net proceeds were used to refinance $400 million of unsecured debt at maturity and to repay outstanding commercial paper.

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		March 31, 2017
Unsecured Debt
Duke Energy (Parent)	August 2017	1.625	%	$	700
Piedmont	September 2017	8.510	%	35
Secured Debt
Duke Energy	June 2017	2.605	%	45
Duke Energy	June 2017	2.455	%	34
First Mortgage Bonds
Duke Energy Florida	September 2017	5.800	%	250
Duke Energy Progress	November 2017	1.252	%	200
Duke Energy Carolinas	January 2018	5.250	%	400
Other(a)				313
Current maturities of long-term debt				$	1,977

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

AVAILABLE CREDIT FACILITIES

Master Credit Facility

In March 2017, Duke Energy amended its Master Credit Facility to increase its capacity from $7.5 billion to $8 billion, and to extend the termination date of the facility from January 30, 2020, to March 16, 2022. The amendment also added Piedmont as a borrower within the Master Credit Facility. Piedmont's separate $850 million credit facility was terminated in connection with the amendment. With the amendment, 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.

	March 31, 2017
				Duke			Duke			Duke			Duke			Duke			Duke
	Duke			Energy			Energy			Energy			Energy			Energy			Energy
(in millions)	Energy			(Parent)			Carolinas			Progress			Florida			Ohio			Indiana			Piedmont
Facility size(a)	$	8,000		$	3,400		$	1,100		$	1,000		$	950		$	450		$	600		$	500
Reduction to backstop issuances
Commercial paper(b)	(3,134		)	(1,822		)	(469		)	(402		)	—			(30		)	(150		)	(261		)
Outstanding letters of credit	(71		)	(62		)	(4		)	(2		)	(1		)	—			—			(2		)
Tax-exempt bonds	(81		)	—			—			—			—			—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—			—
Available capacity	$	4,214		$	1,516		$	377		$	346		$	949		$	420		$	369		$	237

(a) Represents the sublimit of each borrower. Certain sublimits were reallocated in May 2017 to provide additional liquidity to certain borrowers in light of near-term funding needs.

(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

3 Months Ended

Mar. 31, 2017

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Intangible Assets

GOODWILL AND INTANGIBLE ASSETS

GOODWILL

Duke Energy

The following table presents the goodwill by reportable operating segment on Duke Energy's Condensed Consolidated Balance Sheets at March 31, 2017 and December 31, 2016.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables		Total
Goodwill	$	17,379	$	1,924	$	122	$	19,425

Duke Energy Ohio

Duke Energy Ohio's Goodwill balance of $920 million, allocated $596 million to Electric Utilities and Infrastructure and $324 million to Gas Utilities and Infrastructure, is presented net of accumulated impairment charges of $216 million on the Condensed Consolidated Balance Sheets at March 31, 2017 and December 31, 2016.

Progress Energy

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

Piedmont

Piedmont's Goodwill is included in the Gas Utilities and Infrastructure operating segment and there are no accumulated impairment charges. Effective November 1, 2016, Piedmont's fiscal year was changed from October 31 to December 31. Effective with this change, Piedmont changed the date of their annual impairment testing of goodwill from October 31 to August 31 to align with the other Duke Energy Registrants.

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Related Party Transactions

3 Months Ended

Mar. 31, 2017

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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

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 the year ended December 31, 2016 for more information regarding money pool. The net impact of these transactions was not material for the three months ended March 31, 2017 and 2016, 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.

Equity Method Investments

Piedmont has related party transactions as a customer of its equity method investments in natural gas storage and transportation facilities. Below are expenses for the three months ended March 31, 2017 and 2016, which are included in Operating Expenses – Cost of natural gas on Piedmont's Condensed Consolidated Statement of Operations and Comprehensive Income.

		Three Months Ended March 31,
(in millions)	Type of expense	2017		2016
Cardinal	Transportation Costs	$	2	$	2
Pine Needle	Gas Storage Costs	2		3
Hardy Storage	Gas Storage Costs	2		2
Total		$	6	$	7

In association with these transactions, Piedmont has accounts payable to its equity method investments of $2 million at March 31, 2017, and December 31, 2016. These amounts are included in Accounts payable on the Condensed Consolidated Balance Sheets.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

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Derivatives and Hedging

3 Months Ended

Mar. 31, 2017

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. Piedmont enters into gas supply contracts to provide diversification, reliability and gas cost benefits to their customers. 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 impacts 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 AOCI for the three months ended March 31, 2017, were not material. Duke Energy's interest rate derivatives designated as hedges include interest rate swaps used to hedge existing debt within the Commercial Renewables business.

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 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 March 31, 2016, Duke Energy entered into $1.4 billion of forward-starting interest rate swaps to manage interest rate exposure related to the Piedmont acquisition financing. The swaps did not qualify for hedge accounting and were marked-to-market, with any gains or losses included within earnings. For the three months ended March 31, 2016, unrealized losses on the swaps of $93 million were included within Interest Expense on Duke Energy's Condensed Consolidated Statements of Operations. The swaps were unwound in August 2016 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 as of March 31, 2017 and December 31, 2016.

			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	750	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	927		400		500		250		250		27
Total notional amount	$	1,677	$	400	$	500	$	250	$	250	$	27

(a)    Duke Energy includes amounts related to consolidated VIEs of $750 million as of March 31, 2017 and December 31, 2016.

COMMODITY PRICE RISK

The Duke Energy Registrants are exposed to the impact of changes in the prices of electricity purchased and sold in bulk power markets and coal and natural gas purchases, including Piedmont's gas supply contracts. Exposure to commodity price risk is influenced by a number of factors including the term of contracts, the liquidity of markets and delivery locations. For the Subsidiary Registrants, bulk power electricity and coal and natural gas purchases flow through fuel adjustment clauses, formula based contracts or other cost sharing mechanisms. Differences between the costs included in rates and the incurred costs, including undesignated derivative contracts, are largely deferred as regulatory assets or regulatory liabilities. Piedmont policies allow for the use of financial instruments to hedge commodity price risks. The strategy and objective of these hedging programs are to use the financial instruments to reduce gas costs volatility for customers.

Volumes

The tables below include 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.

	March 31, 2017
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	184	—	—	—	—	184	—
Natural gas (millions of dekatherms)	817	85	228	105	123	—	504

	December 31, 2016
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	147	—	—	—	—	147	—
Natural gas (millions of dekatherms)	890	91	269	118	151	1	529

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	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	58	$	16	$	30	$	19	$	11	$	—	$	9	$	2
Noncurrent	5		1		2		1		1		1		—		—
Total Derivative Assets – Commodity Contracts	$	63	$	17	$	32	$	20	$	12	$	1	$	9	$	2
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	18	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	2		—		2		—		2		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	20	$	—	$	2	$	—	$	2	$	—	$	—	$	—
Total Derivative Assets	$	83	$	17	$	34	$	20	$	14	$	1	$	9	$	2

Derivative Liabilities	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	32	$	—	$	17	$	1	$	17	$	—	$	—	$	14
Noncurrent	145		4		11		4		1		—		—		131
Total Derivative Liabilities – Commodity Contracts	$	177	$	4	$	28	$	5	$	18	$	—	$	—	$	145
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	8	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	9		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		—		—		—		1		—		—
Noncurrent	21		10		6		5		1		4		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	39	$	10	$	6	$	5	$	1	$	5	$	—	$	—
Total Derivative Liabilities	$	216	$	14	$	34	$	10	$	19	$	5	$	—	$	145

Derivative Assets	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	108	$	23	$	61	$	35	$	26	$	4	$	16	$	3
Noncurrent	32		10		21		10		11		1		—		—
Total Derivative Assets – Commodity Contracts	$	140	$	33	$	82	$	45	$	37	$	5	$	16	$	3
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	19	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	3		—		3		1		2		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	22	$	—	$	3	$	1	$	2	$	—	$	—	$	—
Total Derivative Assets	$	162	$	33	$	85	$	46	$	39	$	5	$	16	$	3

Derivative Liabilities	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	43	$	—	$	12	$	—	$	12	$	—	$	2	$	35
Noncurrent	166		1		7		1		—		—		—		152
Total Derivative Liabilities – Commodity Contracts	$	209	$	1	$	19	$	1	$	12	$	—	$	2	$	187
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	8	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	8		—		—		—		—		—		—		—
Not Designated as Hedging Instruments															—
Current	1		—		—		—		—		1		—		—
Noncurrent	26		15		6		6		—		5		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	43	$	15	$	6	$	6	$	—	$	6	$	—	$	—
Total Derivative Liabilities	$	252	$	16	$	25	$	7	$	12	$	6	$	2	$	187

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	March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	60		$	16		$	32		$	19		$	13		$	—	$	9	$	2
Gross amounts offset	(7		)	—			(7		)	(1		)	(6		)	—		—		—
Net amounts presented in Current Assets: Other	$	53		$	16		$	25		$	18		$	7		$	—	$	9	$	2
Noncurrent
Gross amounts recognized	$	23		$	1		$	2		$	1		$	1		$	1	$	—	$	—
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	21		$	—		$	1		$	—		$	1		$	1	$	—	$	—

Derivative Liabilities	March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	41		$	—		$	17		$	1		$	17		$	1	$	—	$	14
Gross amounts offset	(7		)	—			(7		)	(1		)	(6		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	34		$	—		$	10		$	—		$	11		$	1	$	—	$	14
Noncurrent
Gross amounts recognized	$	175		$	14		$	17		$	9		$	2		$	4	$	—	$	131
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	173		$	13		$	16		$	8		$	2		$	4	$	—	$	131

Derivative Assets	December 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	111		$	23		$	64		$	36		$	28		$	4	$	16	$	3
Gross amounts offset	(11		)	—			(11		)	—			(11		)	—		—		—
Net amounts presented in Current Assets: Other	$	100		$	23		$	53		$	36		$	17		$	4	$	16	$	3
Noncurrent
Gross amounts recognized	$	51		$	10		$	21		$	10		$	11		$	1	$	—	$	—
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	49		$	9		$	20		$	9		$	11		$	1	$	—	$	—

Derivative Liabilities	December 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	52		$	—		$	12		$	—		$	12		$	1	$	2	$	35
Gross amounts offset	(11		)	—			(11		)	—			(11		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	41		$	—		$	1		$	—		$	1		$	1	$	2	$	35
Noncurrent
Gross amounts recognized	$	200		$	16		$	13		$	7		$	—		$	5	$	—	$	152
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	198		$	15		$	12		$	6		$	—		$	5	$	—	$	152

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, Duke Energy Indiana and Piedmont were not material.

	March 31, 2017
			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	$	40	$	14	$	25	$	9	$	17
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	40		14		25		9		17

	December 31, 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	$	34	$	16	$	18	$	6	$	12
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	34		16		18		6		12

The Duke Energy Registrants have elected to offset cash collateral and fair values of derivatives. For amounts to be netted, the derivative and cash collateral must be executed with the same counterparty under the same master netting arrangement.

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Investments in Debt and Equity Securities

3 Months Ended

Mar. 31, 2017

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 either trading or available-for-sale.

TRADING SECURITIES

Piedmont's investments in debt and equity securities held in rabbi trusts associated with certain deferred compensation plans are classified as trading securities. The fair value of these investments was $5 million as of March 31, 2017 and December 31, 2016.

AVAILABLE-FOR-SALE SECURITIES

All other investments in debt and equity securities are classified 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 OTTIs 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.

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 OTTI exists, the unrealized credit loss is included in earnings. There were no material credit losses as of March 31, 2017 and December 31, 2016.

DUKE ENERGY

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	114	$	—	$	—	$	111
Equity securities	2,250		32		4,284		2,092		54		4,106
Corporate debt securities	10		5		576		10		8		528
Municipal bonds	3		6		336		3		10		331
U.S. government bonds	10		8		949		10		8		984
Other debt securities	—		3		132		—		3		124
Total NDTF	$	2,273	$	54	$	6,391	$	2,115	$	83	$	6,184
Other Investments
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	25
Equity securities	44		—		106		38		—		104
Corporate debt securities	1		—		60		1		1		66
Municipal bonds	2		1		84		2		1		82
U.S. government bonds	—		—		43		—		1		51
Other debt securities	—		2		42		—		2		42
Total Other Investments(b)	$	47	$	3	$	353	$	41	$	5	$	370
Total Investments	$	2,320	$	57	$	6,744	$	2,156	$	88	$	6,554

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	82
Due after one through five years	640
Due after five through 10 years	514
Due after 10 years	986
Total	$	2,222

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
	March 31,
(in millions)	2017		2016
Realized gains	$	93	$	54
Realized losses	62		50

DUKE ENERGY CAROLINAS

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	20	$	—	$	—	$	18
Equity securities	1,229		15		2,366		1,157		28		2,245
Corporate debt securities	5		4		388		5		6		354
Municipal bonds	1		1		67		1		2		67
U.S. government bonds	3		5		431		2		5		458
Other debt securities	—		3		120		—		3		116
Total NDTF	$	1,238	$	28	$	3,392	$	1,165	$	44	$	3,258
Other Investments
Other debt securities	$	—	$	1	$	3	$	—	$	1	$	3
Total Other Investments(b)	$	—	$	1	$	3	$	—	$	1	$	3
Total Investments	$	1,238	$	29	$	3,395	$	1,165	$	45	$	3,261

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	2
Due after one through five years	221
Due after five through 10 years	269
Due after 10 years	517
Total	$	1,009

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
	March 31,
(in millions)	2017		2016
Realized gains	$	66	$	34
Realized losses	40		37

PROGRESS ENERGY

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	94	$	—	$	—	$	93
Equity securities	1,021		17		1,918		935		26		1,861
Corporate debt securities	5		1		188		5		2		174
Municipal bonds	2		5		269		2		8		264
U.S. government bonds	7		3		518		8		3		526
Other debt securities	—		—		12		—		—		8
Total NDTF	$	1,035	$	26	$	2,999	$	950	$	39	$	2,926
Other Investments
Cash and cash equivalents	$	—	$	—	$	12	$	—	$	—	$	21
Municipal bonds	2		—		46		2		—		44
Total Other Investments(b)	$	2	$	—	$	58	$	2	$	—	$	65
Total Investments	$	1,037	$	26	$	3,057	$	952	$	39	$	2,991

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	72
Due after one through five years	355
Due after five through 10 years	189
Due after 10 years	417
Total	$	1,033

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
	March 31,
(in millions)	2017		2016
Realized gains	$	27	$	19
Realized losses	21		13

DUKE ENERGY PROGRESS

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	43	$	—	$	—	$	45
Equity securities	772		13		1,541		704		21		1,505
Corporate debt securities	4		1		131		4		1		120
Municipal bonds	2		5		268		2		8		263
U.S. government bonds	5		2		284		5		2		275
Other debt securities	—		—		7		—		—		5
Total NDTF	$	783	$	21	$	2,274	$	715	$	32	$	2,213
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	1
Total Other Investments(b)	$	—	$	—	$	1	$	—	$	—	$	1
Total Investments	$	783	$	21	$	2,275	$	715	$	32	$	2,214

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	17
Due after one through five years	215
Due after five through 10 years	142
Due after 10 years	316
Total	$	690

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
	March 31,
(in millions)	2017		2016
Realized gains	$	24	$	15
Realized losses	19		11

DUKE ENERGY FLORIDA

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	51	$	—	$	—	$	48
Equity securities	249		4		377		231		5		356
Corporate debt securities	1		—		57		1		1		54
Municipal bonds	—		—		1		—		—		1
U.S. government bonds	2		1		234		3		1		251
Other debt securities	—		—		5		—		—		3
Total NDTF(b)	$	252	$	5	$	725	$	235	$	7	$	713
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	4
Municipal bonds	2		—		46		2		—		44
Total Other Investments(c)	$	2	$	—	$	47	$	2	$	—	$	48
Total Investments	$	254	$	5	$	772	$	237	$	7	$	761

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) During the three months endedMarch 31, 2017, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing commissioning activity of the Crystal River Unit 3 nuclear plant.

(c) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	55
Due after one through five years	140
Due after five through 10 years	47
Due after 10 years	101
Total	$	343

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
	March 31,
(in millions)	2017		2016
Realized gains	$	3	$	4
Realized losses	2		2

DUKE ENERGY INDIANA

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

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
Other Investments
Equity securities	$	38	$	—	$	84	$	33	$	—	$	79
Corporate debt securities	—		—		2		—		—		2
Municipal bonds	—		1		28		—		1		28
U.S. government bonds	—		—		1		—		—		1
Total Other Investments(b)	$	38	$	1	$	115	$	33	$	1	$	110
Total Investments	$	38	$	1	$	115	$	33	$	1	$	110

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	2
Due after one through five years	15
Due after five through 10 years	9
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 months ended March 31, 2017 and 2016.

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Fair Value Measurements

3 Months Ended

Mar. 31, 2017

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 that 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 months endedMarch 31, 2017 and 2016.

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 New York Stock Exchange (NYSE) and Nasdaq Stock Market. 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, including Piedmont's gas supply contracts, are primarily valued using internally developed discounted cash flow models that incorporate forward price, adjustments for liquidity (bid-ask spread) and credit or non-performance risk (after reflecting credit enhancements such as collateral), and are discounted to present value. Pricing inputs are derived from published exchange transaction prices and other observable data sources. In the absence of an active market, the last available price may be used. If forward price curves are not observable for the full term of the contract and the unobservable period had more than an insignificant impact on the valuation, the commodity derivative is classified as Level 3. In isolation, increases (decreases) in natural gas forward prices result in favorable (unfavorable) fair value adjustments for gas purchase contracts; and increases (decreases) in electricity forward prices result in unfavorable (favorable) fair value adjustments for electricity sales contracts. Duke Energy regularly evaluates and validates pricing inputs used to estimate the fair value of gas commodity contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.

Interest rate derivatives

Most over-the-counter interest rate contract derivatives are valued using financial models that 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.

Other fair value considerations

See Note 2 related to the acquisition of Piedmont in 2016. See Note 11 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2016 for a discussion of the valuation of goodwill and intangible assets.

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3			Not categorized
Nuclear decommissioning trust fund equity securities	$	4,284		$	4,207	$	—		$	—		$	77
Nuclear decommissioning trust fund debt securities	2,107			602		1,505			—			—
Other trading and available-for-sale equity securities	110			110		—			—			—
Other trading and available-for-sale debt securities	248			61		182			5			—
Derivative assets	83			2		71			10			—
Total assets	6,832			4,982		1,758			15			77
Derivative liabilities	(216		)	—		(71		)	(145		)	—
Net assets (liabilities)	$	6,616		$	4,982	$	1,687		$	(130	)	$	77

	December 31, 2016
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not categorized
Nuclear decommissioning trust fund equity securities	$	4,106		$	4,029		$	—		$	—		$	77
Nuclear decommissioning trust fund debt securities	2,078			632			1,446			—			—
Other trading and available-for-sale equity securities	104			104			—			—			—
Other trading and available-for-sale debt securities	266			75			186			5			—
Derivative assets	162			5			136			21			—
Total assets	6,716			4,845			1,768			26			77
Derivative liabilities	(252		)	(2		)	(63		)	(187		)	—
Net assets (liabilities)	$	6,464		$	4,843		$	1,705		$	(161	)	$	77

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

	Three Months Ended March 31, 2017
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	5	$	(166	)	$	(161	)
Purchases, sales, issuances and settlements:
Settlements	—		(9		)	(9		)
Total amount included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		40			40
Balance at end of period	$	5	$	(135	)	$	(130	)

	Three Months Ended March 31, 2016
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	5		$	10		$	15
Purchases, sales, issuances and settlements:
Sales	(1		)	—			(1		)
Settlements	—			(7		)	(7		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—			(1		)	(1		)
Balance at end of period	$	4		$	2		$	6

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,366		$	2,289	$	—		$	—	$	77
Nuclear decommissioning trust fund debt securities	1,026			146		880			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	17			—		17			—		—
Total assets	3,412			2,435		897			3		77
Derivative liabilities	(14		)	—		(14		)	—		—
Net assets	$	3,398		$	2,435	$	883		$	3	$	77

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,245		$	2,168	$	—		$	—	$	77
Nuclear decommissioning trust fund debt securities	1,013			178		835			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	33			—		33			—		—
Total assets	3,294			2,346		868			3		77
Derivative liabilities	(16		)	—		(16		)	—		—
Net assets	$	3,278		$	2,346	$	852		$	3	$	77

There was no change to the Level 3 balance during the three months ended March 31, 2017 and March 31, 2016.

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,918		$	1,918	$	—
Nuclear decommissioning trust fund debt securities	1,081			456		625
Other available-for-sale debt securities	58			12		46
Derivative assets	34			—		34
Total assets	3,091			2,386		705
Derivative liabilities	(34		)	—		(34		)
Net assets	$	3,057		$	2,386	$	671

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,861		$	1,861	$	—
Nuclear decommissioning trust fund debt securities	1,065			454		611
Other available-for-sale debt securities	65			21		44
Derivative assets	85			—		85
Total assets	3,076			2,336		740
Derivative liabilities	(25		)	—		(25		)
Net assets	$	3,051		$	2,336	$	715

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,541		$	1,541	$	—
Nuclear decommissioning trust fund debt securities and other	733			221		512
Other available-for-sale debt securities and other	1			1		—
Derivative assets	20			—		20
Total assets	2,295			1,763		532
Derivative liabilities	(10		)	—		(10		)
Net assets	$	2,285		$	1,763	$	522

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,505		$	1,505	$	—
Nuclear decommissioning trust fund debt securities and other	708			207		501
Other available-for-sale debt securities and other	1			1		—
Derivative assets	46			—		46
Total assets	2,260			1,713		547
Derivative liabilities	(7		)	—		(7		)
Net assets	$	2,253		$	1,713	$	540

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	377		$	377	$	—
Nuclear decommissioning trust fund debt securities and other	348			235		113
Other available-for-sale debt securities and other	47			1		46
Derivative assets	14			—		14
Total assets	786			613		173
Derivative liabilities	(19		)	—		(19		)
Net assets	$	767		$	613	$	154

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	356		$	356	$	—
Nuclear decommissioning trust fund debt securities and other	357			247		110
Other available-for-sale debt securities and other	48			4		44
Derivative assets	39			—		39
Total assets	800			607		193
Derivative liabilities	(12		)	—		(12		)
Net assets	$	788		$	607	$	181

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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	1		$	—	$	—		$	1
Derivative liabilities	(5		)	—		(5		)	—
Net (liabilities) assets	$	(4	)	$	—	$	(5	)	$	1

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	5		$	—	$	—		$	5
Derivative liabilities	(6		)	—		(6		)	—
Net (liabilities) assets	$	(1	)	$	—	$	(6	)	$	5

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	5		$	3
Purchases, sales, issuances and settlements:
Settlements	(1		)	(2		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(3		)	(1		)
Balance at end of period	$	1		$	—

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.

	March 31, 2017
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Other available-for-sale equity securities	$	84	$	84	$	—	$	—
Other available-for-sale debt securities and other	31		—		31		—
Derivative assets	9		—		—		9
Net assets	$	124	$	84	$	31	$	9

	December 31, 2016
(in millions)	Total Fair Value			Level 1			Level 2		Level 3
Other available-for-sale equity securities	$	79		$	79		$	—	$	—
Other available-for-sale debt securities and other	31			—			31		—
Derivative assets	16			—			—		16
Total assets	126			79			31		16
Derivative liabilities	(2		)	(2		)	—		—
Net assets	$	124		$	77		$	31	$	16

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	16		$	7
Purchases, sales, issuances and settlements:
Settlements	(7		)	(5		)
Balance at end of period	$	9		$	2

PIEDMONT

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. See Note 10 for additional information related to investments.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 3
Other trading equity securities	4			4		—
Other trading debt securities	1			1		—
Derivative assets	2			2		—
Total assets	7			7		—
Derivative liabilities	(145		)	—		(145		)
Net (liabilities) assets	$	(138	)	$	7	$	(145	)

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 3
Other trading equity securities	$	4		$	4	$	—
Other trading debt securities	1			1		—
Derivative assets	3			3		—
Total assets	8			8		—
Derivative liabilities	(187		)	—		(187		)
Net (liabilities) assets	$	(179	)	$	8	$	(187	)

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	(187	)	$	(149	)
Total gains and settlements	42			23
Balance at end of period	$	(145	)	$	(126	)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

	March 31, 2017
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
Financial Transmission Rights (FTRs)	$	1		RTO auction pricing	FTR price – per megawatt-hour (MWh)	$	0.23		-	$	2.02
Duke Energy Indiana
FTRs	9			RTO auction pricing	FTR price – per MWh	(1.08		)	-	5.33
Piedmont
Natural gas contracts	(145		)	Discounted cash flow	Forward natural gas curves – price per million British thermal unit (MMBtu)	2.08			-	3.57
Duke Energy
Total Level 3 derivatives	$	(135	)

	December 31, 2016
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
FTRs	$	5		RTO auction pricing	FTR price – per MWh	$	0.77		-	$	3.52
Duke Energy Indiana
FTRs	16			RTO auction pricing	FTR price – per MWh	(0.83		)	-	9.32
Piedmont
Natural gas contracts	(187		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	2.31			-	4.18
Duke Energy
Total Level 3 derivatives	$	(166	)

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.

	March 31, 2017				December 31, 2016
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy	$	48,998	$	50,480	$	47,895	$	49,161
Duke Energy Carolinas	9,491		10,405		9,603		10,494
Progress Energy	18,148		19,742		17,541		19,107
Duke Energy Progress	6,761		7,103		7,011		7,357
Duke Energy Florida	6,981		7,596		6,125		6,728
Duke Energy Ohio	1,977		2,122		1,884		2,020
Duke Energy Indiana	3,784		4,292		3,786		4,260
Piedmont	1,821		1,954		1,821		1,933

At both March 31, 2017 and December 31, 2016, fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper, and nonrecourse 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

3 Months Ended

Mar. 31, 2017

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 three months ended March 31, 2017 and the year ended December 31, 2016, 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, natural gas 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.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
(in millions)	CRC		DERF		DEPR		DEFR
Expiration date	December 2018		December 2018		February 2019		April 2019
Credit facility amount	$	325	$	425	$	300	$	225
Amounts borrowed at March 31, 2017	325		425		300		225
Amounts borrowed at December 31, 2016	325		425		300		225

Nuclear Asset-Recovery Bonds – DEFPF

Duke Energy Florida Project Finance, LLC (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 Note 4.

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)	March 31, 2017		December 31, 2016
Receivables of VIEs	$	4	$	6
Current Assets: Regulatory assets	53		50
Current Assets: Other	14		53
Other Noncurrent Assets: Regulatory assets	1,131		1,142
Current Liabilities: Other	3		17
Current maturities of long-term debt	55		62
Long-Term Debt	1,189		1,217

Commercial Renewables

Certain of Duke Energy’s renewable energy facilities are VIEs due to Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. Assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders. The activities that most significantly impact the economic performance of these renewable energy facilities were decisions associated with siting, negotiating PPAs, 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)	March 31, 2017			December 31, 2016
Current Assets: Other	$	336		$	223
Property, plant and equipment, cost	3,671			3,419
Accumulated depreciation and amortization	(448		)	(453		)
Current maturities of long-term debt	227			198
Long-Term Debt	1,645			1,097
Deferred income taxes	321			275
Other Noncurrent Liabilities: Other	251			252

NON-CONSOLIDATED VIEs

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

	March 31, 2017
	Duke Energy										Duke		Duke
	Pipeline			Commercial		Other					Energy		Energy
(in millions)	Investments			Renewables		VIEs		Total			Ohio		Indiana		Piedmont
Receivables from affiliated companies	$	—		$	—	$	—	$	—		$	53	$	69	$	—
Investments in equity method unconsolidated affiliates	673			173		92		938			—		—		152
Other noncurrent assets	12			—		—		12			—		—		—
Total assets	$	685		$	173	$	92	$	950		$	53	$	69	$	152
Taxes accrued(a)	23			—		—		23			—		—		(1		)
Other current liabilities	—			—		2		2			—		—		—
Deferred income taxes(a)	(7		)	—		—		(7		)	—		—		4
Other noncurrent liabilities	—			—		13		13			—		—		—
Total liabilities	$	16		$	—	$	15	$	31		$	—	$	—	$	3
Net assets	$	669		$	173	$	77	$	919		$	53	$	69	$	149

(a) Taxes accrued and Deferred income taxes are netted by jurisdiction on a consolidated basis on the Condensed Consolidated Balance Sheets.

	December 31, 2016
	Duke Energy								Duke		Duke
	Pipeline		Commercial		Other				Energy		Energy
(in millions)	Investments		Renewables		VIEs		Total		Ohio		Indiana		Piedmont
Receivables from affiliated companies	$	—	$	—	$	—	$	—	$	82	$	101	$	—
Investments in equity method unconsolidated affiliates	487		174		90		751		—		—		139
Other noncurrent assets	12		—		—		12		—		—		—
Total assets	$	499	$	174	$	90	$	763	$	82	$	101	$	139
Other current liabilities	—		—		3		3		—		—		—
Other noncurrent liabilities	—		—		13		13		—		—		4
Total liabilities	$	—	$	—	$	16	$	16	$	—	$	—	4
Net assets	$	499	$	174	$	74	$	747	$	82	$	101	$	135

The Duke Energy Registrants are not aware of any situations where the maximum exposure to loss significantly exceeds the carrying values shown above except for the power purchase agreement with OVEC, which is discussed below, and various guarantees, some of which are reflected in the table above as Other noncurrent liabilities. For more information on various guarantees, refer to Note 5.

Pipeline Investments

Duke Energy has investments in various joint ventures with pipeline projects currently under construction. These entities are considered VIEs due to having insufficient equity to finance their own activities without subordinated financial support. Duke Energy does not have the power to direct the activities that most significantly impact the economic performance, the obligation to absorb losses or the right to receive benefits of these VIEs and therefore does not consolidate these entities.

The table below presents the ownership interest and investment balances in these joint ventures.

	Duke Energy						Piedmont
			Investment Amount (in millions)						Investment Amount (in millions)
	Ownership		March 31,		December 31,		Ownership		March 31,		December 31,
Entity Name	Interest		2017		2016		Interest(a)		2017		2016
ACP	47	%	$	403	$	265	7	%	$	59	$	46
Sabal Trail	7.5	%	188		140
Constitution(b)	24	%	82		82		24	%	93		93
Total			$	673	$	487			$	152	$	139

(a) On April 1, 2017, Piedmont transferred its ownership interests in ACP and Constitution to a wholly owned subsidiary of Duke Energy at Piedmont's book value.

(b) Duke Energy's investment amount includes purchase accounting adjustments not recorded at the Piedmont registrant.

Commercial Renewables

Duke Energy has investments in various renewable energy project entities. Some of these entities are VIEs due to Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. 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 VIEs

Duke Energy holds a 50 percent equity interest in Duke-American Transmission Company, LLC (DATC). DATC is considered a VIE due to having insufficient equity to finance their own activities without subordinated financial support. The activities that most significantly impact DATC's economic performance are 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, American Transmission Company, LLC, therefore Duke Energy does not consolidate DATC.

Duke Energy holds a 50 percent equity interest in Pioneer Transmission, LLC (Pioneer). Pioneer is considered a VIE due to having insufficient equity to finance their own activities without subordinated financial support. The activities that most significantly impact Pioneer's economic performance are decisions related to the 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, American Electric Power, therefore Duke Energy does not consolidate Pioneer.

OVEC

Duke Energy Ohio’s 9 percent ownership interest in OVEC is considered a non-consolidated VIE due to having insufficient equity to finance their activities without subordinated financial support. As a counterparty to an inter-company power agreement (ICPA), Duke Energy Ohio has a contractual arrangement to receive entitlements to capacity and energy from OVEC’s power plants through June 2040 commensurate with its power participation ratio, which is equivalent to Duke Energy Ohio's ownership interest. Costs, including fuel, operating expenses, fixed costs, debt amortization, and interest expense are allocated to counterparties to the ICPA based on their power participation ratio. The value of the ICPA is subject to variability due to fluctuation in power prices and changes in OVEC's cost of business, including costs associated with its 2,256 MW of coal-fired generation capacity. Deterioration in the credit quality, or bankruptcy of one or more parties to the ICPA could increase the costs of OVEC. In addition, certain proposed environmental rulemaking could result in future increased cost allocations.

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 OTTI has occurred.

Key assumptions used in estimating fair value are detailed in the following table.

	Duke Energy Ohio				Duke Energy Indiana
	2017		2016		2017		2016
Anticipated credit loss ratio	0.5	%	0.5	%	0.3	%	0.3	%
Discount rate	1.8	%	1.5	%	1.8	%	1.5	%
Receivable turnover rate	13.4	%	13.3	%	10.7	%	10.6	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Receivables sold	$	238	$	267	$	277	$	306
Less: Retained interests	53		82		69		101
Net receivables sold	$	185	$	185	$	208	$	205

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

	Duke Energy Ohio				Duke Energy Indiana
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(in millions)	2017		2016		2017		2016
Sales
Receivables sold	$	533	$	532	$	664	$	635
Loss recognized on sale	2		3		3		3
Cash flows
Cash proceeds from receivables sold	$	559	$	537	$	693	$	643
Return received on retained interests	1		1		2		1

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

3 Months Ended

Mar. 31, 2017

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 shares 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 shares outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as stock options and equity forward sale agreements, 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 shares outstanding to the diluted weighted average number of common shares outstanding.

	Three Months Ended March 31,
(in millions, except per share amounts)	2017		2016
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	715	$	574
Weighted average shares outstanding – basic	700		689
Weighted average shares outstanding – diluted	700		689
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	1.02	$	0.83
Diluted	$	1.02	$	0.83
Potentially dilutive items excluded from the calculation(a)	2		2
Dividends declared per common share	$	0.855	$	0.825

(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 forward sale agreements with Barclays (the Equity Forwards). The Equity Forwards required Duke Energy to either physically settle the transactions by issuing 10.6 million shares, or net settle in whole or in part through the delivery or receipt of cash or shares. As of March 31, 2016, share dilution resulting from the agreements was determined under the treasury stock method.

Duke Energy physically settled the Equity Forwards in full in October 2016 following the close of the Piedmont acquisition. See Note 2 for additional information related to the Piedmont acquisition.

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Stock-Based Compensation

3 Months Ended

Mar. 31, 2017

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
	March 31,
(in millions)	2017		2016
Restricted stock unit awards	$	8	$	7
Performance awards	7		5
Pretax stock-based compensation cost	$	15	$	12
Tax benefit associated with stock-based compensation expense	$	5	$	4
Stock-based compensation costs capitalized	1		1

Prior to Duke Energy acquiring Piedmont, Piedmont had an incentive compensation plan for eligible officers and other participants. Piedmont's total stock-based compensation costs were approximately $2 million for the three months ended March 31, 2016.

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Employee Benefit Plans

3 Months Ended

Mar. 31, 2017

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 and non-qualified, non-contributory defined benefit retirement plans. Duke Energy’s policy is to fund amounts on an actuarial basis to provide assets sufficient to meet benefit payments to be paid to plan participants. Duke Energy did not make any contributions to its U.S. qualified defined benefit pension plans during the three months ended March 31, 2017 and 2016.

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 March 31, 2017
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	40		$	12		$	12		$	6		$	5		$	1		$	2		$	3
Interest cost on projected benefit obligation	82			20			25			12			13			5			7			3
Expected return on plan assets	(136		)	(35		)	(43		)	(21		)	(21		)	(7		)	(11		)	(6		)
Amortization of actuarial loss	36			8			14			6			7			1			3			3
Amortization of prior service credit	(6		)	(2		)	(1		)	—			—			—			—			(1		)
Other	2			—			1			—			—			—			—			—
Net periodic pension costs	$	18		$	3		$	8		$	3		$	4		$	—		$	1		$	2

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	36		$	12		$	11		$	6		$	5		$	1		$	2		$	3
Interest cost on projected benefit obligation	83			21			26			12			14			5			7			2
Expected return on plan assets	(129		)	(35		)	(42		)	(21		)	(21		)	(7		)	(10		)	(6		)
Amortization of actuarial loss	33			8			14			6			7			1			3			2
Amortization of prior service credit	(4		)	(2		)	(1		)	—			—			—			—			—
Other	3			1			1			—			—			—			—			—
Net periodic pension costs	$	22		$	5		$	9		$	3		$	5		$	—		$	2		$	1

NON-QUALIFIED PENSION PLANS

Net periodic costs for non-qualified pension plans were not material for the three months ended March 31, 2017 and 2016.

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.

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

	Three Months Ended March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Service cost	$	1		$	—		$	—		$	—		$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			4			2			2			—		—		—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—		—
Amortization of actuarial loss (gain)	2			(1		)	5			3			2			—		—		—
Amortization of prior service credit	(29		)	(2		)	(21		)	(14		)	(8		)	—		—		—
Net periodic other post-retirement benefit	$	(20	)	$	(3	)	$	(12	)	$	(9	)	$	(4	)	$	—	$	—	$	—

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana			Piedmont
Service cost	$	1		$	—		$	—		$	—		$	—		$	—	$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	8			2			4			2			2			—		1			—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—			—
Amortization of actuarial loss (gain)	1			(1		)	5			3			2			—		(1		)	—
Amortization of prior service credit	(35		)	(3		)	(26		)	(17		)	(9		)	—		—			—
Net periodic other post-retirement benefit	$	(28	)	$	(4	)	$	(17	)	$	(12	)	$	(5	)	$	—	$	—		$	—

DEFINED CONTRIBUTION RETIREMENT PLANS

EMPLOYEE SAVINGS PLAN

Duke Energy sponsors, and the Subsidiary Registrants participate in, employee savings plans that cover substantially all U.S. employees.

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		Piedmont
Three Months Ended March 31,
2017	$	65	$	22	$	18	$	13	$	5	$	1	$	3	$	2
2016	52		18		15		11		4		1		2		2

MONEY PURCHASE PENSION PLAN

Duke Energy provides, and Piedmont participates in, the Money Purchase Pension (MPP) plan, which is a defined contribution pension plan that allows employees to direct investments and assume risk of investment returns. In January 2017, a $2 million contribution was made to the MPP plan.

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Income Taxes

3 Months Ended

Mar. 31, 2017

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

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
	March 31,
	2017		2016
Duke Energy	32.4	%	30.4	%
Duke Energy Carolinas	35.4	%	34.1	%
Progress Energy	34.1	%	36.7	%
Duke Energy Progress	34.1	%	35.4	%
Duke Energy Florida	36.6	%	37.9	%
Duke Energy Ohio	35.4	%	26.9	%
Duke Energy Indiana	39.3	%	30.2	%
Piedmont	37.9	%	38.0	%

The increase in the effective tax rate (ETR) for Duke Energy for the three months ended March 31, 2017, is primarily due to lower investment tax credits due to lower solar investments in the current year, the inclusion of Piedmont's earnings at a higher ETR, and a tax charge related to the implementation of a new accounting standard related to stock compensation; partially offset by higher production tax credits related to wind projects placed in service. See Note 1 for additional information on the new accounting standard.

The increase in the ETR for Duke Energy Carolinas for the three months ended March 31, 2017, is primarily due to a favorable state resolution booked in 2016 related to prior year tax returns.

The decrease in the ETR for Progress Energy for the three months ended March 31, 2017, is primarily due to higher AFUDC equity and the amortization of excess North Carolina deferred tax.

The decrease in the ETR for Duke Energy Progress for the three months ended March 31, 2017, is primarily due to the amortization of excess North Carolina deferred tax.

The decrease in the ETR for Duke Energy Florida for the three months ended March 31, 2017, is primarily due to higher AFUDC equity.

The increase in the ETR for Duke Energy Ohio for the three months ended March 31, 2017, is primarily due to an immaterial out of period adjustment in the prior year related to deferred tax balances associated with property, plant and equipment.

The increase in the ETR for Duke Energy Indiana for the three months ended March 31, 2017, is primarily due to an immaterial out of period adjustment in the prior year related to deferred tax balances associated with property, plant and equipment.

TAXES ON FOREIGN EARNINGS

As of December 31, 2015, Duke Energy's intention was to indefinitely reinvest any future undistributed foreign earnings earned after December 31, 2014. In February 2016, Duke Energy announced it had initiated a process to divest the International Disposal Group and, accordingly, no longer intended to indefinitely reinvest post-2014 undistributed foreign earnings. This change in the company's intent, combined with the extension of bonus depreciation by Congress in late 2015, allowed Duke Energy to more efficiently utilize foreign tax credits and reduce U.S. deferred tax liabilities associated with historical unremitted foreign earnings by approximately $95 million for the three months endedMarch 31, 2016. Due to the classification of the International Disposal Group as discontinued operations, income tax amounts related to the International Disposal Group's foreign earnings are presented within Income from Discontinued Operations, net of tax on the Condensed Consolidated Statements of Operations. See Note 2 for additional information related to the sale of the International Disposal Group.

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Subsequent Events

3 Months Ended

Mar. 31, 2017

Subsequent Events [Abstract]

Subsequent Events

SUBSEQUENT EVENTS

For information on additional subsequent events related to regulatory matters, commitments and contingencies, debt and credit facilities, and variable interest entities see Notes 4, 5, 6 and 12, respectively.

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Organization and Basis of Presentation (Policy)

3 Months Ended

Mar. 31, 2017

Policy Text Block [Line Items]

Basis of Accounting

The results of operations of the International Disposal Group 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.

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles (GAAP) in the U.S. for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all information and notes required by GAAP in the U.S. for annual financial statements. 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, 2016, and the Consolidated Financial Statements and Notes in the Piedmont Annual Report on Form 10-K for the year ended October 31, 2016.

Effective November 1, 2016, Piedmont's fiscal year-end was changed from October 31 to December 31, the year-end of Duke Energy. A transition report was filed on Form 10-Q (Form 10-QT) as of December 31, 2016, for the transition period from November 1, 2016 to December 31, 2016.

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.

Piedmont's results of operations and cash flows are included in the accompanying condensed consolidated financial statements of Duke Energy for the three months ended March 31, 2017, but not for the three months ended March 31, 2016, as Piedmont's earnings and cash flows are only included in Duke Energy's consolidated results subsequent to the acquisition date.

Consolidation

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.

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 and natural gas 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, meter reading schedules, and the impact of weather normalization or margin decoupling mechanisms.

Inventory

INVENTORY

Inventory is used for operations and is recorded primarily using the average cost method. Inventory related to regulated operations is valued at historical cost. Inventory related to nonregulated operations is valued at the lower of cost or market. Materials and supplies are recorded as inventory when purchased and subsequently charged to expense or capitalized to property, plant and equipment when installed. Inventory, including excess or obsolete inventory, is written-down to the lower of cost or market value. Once inventory has been written-down, it creates a new cost basis for the inventory that is not subsequently written-up.

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.

New Accounting Standards

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2017 and 2016 had no material impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. While immaterial, adoption of the following accounting standard had the most significant impact on the Duke Energy results of operations, cash flows and financial position for the three months ended March 31, 2017.

Stock-Based Compensation and Income Taxes. In March 2017, Duke Energy adopted Financial Accounting Standards Board (FASB) guidance, which revised the accounting for stock-based compensation and the associated income taxes. The adopted guidance changes certain aspects of accounting for stock-based payment awards to employees including the accounting for income taxes and classification on the Condensed Consolidated Statements of Cash Flows. The primary impact to Duke Energy as a result of implementing this guidance was a cumulative-effect adjustment to retained earnings for tax benefits not previously recognized and higher income tax expense for the three months ended March 31, 2017. See the Duke Energy Condensed Consolidated Statements of Changes in Equity and Note 16 for further information.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of March 31, 2017.

Retirement Benefits. In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic costs related to benefit plans. Current GAAP permits the aggregation of all the components of net periodic costs on the income statement and does not require the disclosure of the location of net periodic costs on the Condensed Consolidated Statement of Operations. Under the amended guidance, the service cost component of net periodic costs must be included within Operating income within the same line as other compensation expenses. All other components of net periodic costs must be outside of Operating income. In addition, the updated guidance permits only the service cost component of net periodic costs to be capitalized to Inventory or Property, Plant and Equipment. This represents a change from current GAAP, which permits all components of net periodic costs to be capitalized. The guidance allows for a practical expedient that permits a company to use amounts disclosed in prior-period financial statements as the estimation basis for applying the retrospective presentation requirements.

For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2018. These amendments should be applied retrospectively for the presentation of the various components of net periodic costs and prospectively for the change in eligible costs to be capitalized. Duke Energy currently presents all of the components of net periodic costs that are not capitalized within Operation, maintenance and other on the Condensed Consolidated Statement of Operations. Under this updated guidance, Duke Energy will retrospectively move all the components of net periodic costs except for the service cost component to below Operating income. However, Duke Energy will continue to present the service cost component not capitalized within Operation, maintenance and other as this line item includes other compensation expense. Duke Energy is currently evaluating the financial statement impact, if any, of adopting this standard and whether or not the practical expedient will be utilized.

Goodwill Impairment. In January 2017, the FASB issued revised guidance for subsequent measurement of goodwill. Under the guidance, a company will recognize an impairment to goodwill for the amount by which a reporting unit's carrying value exceeds the reporting unit's fair value, not to exceed the amount of goodwill allocated to that reporting unit. For Duke Energy, this guidance is effective for interim and annual periods beginning January 1, 2020. However, Duke Energy expects to early adopt this guidance on a prospective basis for the next interim or annual goodwill impairment test. Duke Energy does not expect adopting this guidance will have a material impact to its results of operations or financial position.

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.

Most of Duke Energy’s revenue is expected to be in scope of the new guidance. The majority of our sales, including energy provided to residential customers, are from tariff offerings that provide natural gas or electricity without a defined contractual term (‘at-will’). For such arrangements, Duke Energy expects that the revenue from contracts with customers will be equivalent to the electricity or natural gas supplied and billed in that period (including estimated billings). As such, Duke Energy does not expect that there will be a significant shift in the timing or pattern of revenue recognition for such sales. The evaluation of other revenue streams is ongoing, including long-term contracts with industrial customers and long-term purchase power agreements (PPA).

Duke Energy continues to evaluate what information would be most useful for users of the financial statements, including information already provided in disclosures outside of the financial statement footnotes. These additional disclosures could include the disaggregation of revenues by geographic location, type of service, customer class or by duration of contract (‘at-will’ versus contracted revenue). Revenues from contracts with customers, revenue recognized under regulated operations accounting and revenue from lease accounting will also be disclosed.

Duke Energy intends to use the modified retrospective method of adoption effective January 1, 2018. This method results in a cumulative-effect adjustment that will be recorded to retained earnings as of January 1, 2018, as if the standard had always been in effect. Disclosures for 2018 will include a comparison to what would have been reported for 2018 under the current revenue recognition rules in order to assist financial statement users in understanding how revenue recognition has changed as a result of this standard and to facilitate comparability with prior year reported results, which are not restated under the modified retrospective approach.

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 financial statement impact of adopting this standard. Other than an expected increase in assets and liabilities, the ultimate impact of the new standard has not yet been determined. Significant system enhancements may be required to facilitate the identification, tracking and reporting of potential leases based upon requirements of the new lease standard.

Statement of Cash Flows. In November 2016, the FASB issued revised accounting guidance to reduce diversity in practice for the presentation and classification of restricted cash on the statement of cash flows. Under the updated guidance, restricted cash and restricted cash equivalents will be included within beginning-of-period and end-of-period cash and cash equivalents on the statement of cash flows.

For Duke Energy, this guidance is effective for the interim and annual periods beginning January 1, 2018, although it can be early adopted. The guidance will be applied using a retrospective transition method to each period presented. Upon adoption by Duke Energy, the revised guidance will result in a change to the amount of cash and cash equivalents and restricted cash explained when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Prior to adoption, the Duke Energy Registrants reflect changes in restricted cash within Cash Flows from Investing Activities on the Condensed Consolidated Statement of Cash Flows.

Financial Instruments Classification and Measurement. In January 2016, the FASB issued revised accounting guidance for the classification and measurement of financial instruments. Changes in the fair value of all equity securities will be required to be recorded in net income. Current GAAP allows some changes in fair value for available-for-sale equity securities to be recorded in Accumulated other comprehensive income (AOCI). Additional disclosures will be required to present separately the financial assets and financial liabilities by measurement category and form of financial asset. An entity's equity investments that are accounted for under the equity method of accounting are not included within the scope of the new guidance.

For Duke Energy, the revised accounting guidance is effective for interim and annual periods beginning January 1, 2018, by recording a cumulative-effect adjustment to retained earnings as of January 1, 2018. This guidance is expected to have minimal impact on the Duke Energy Registrant's Condensed Consolidated Statements of Operations and Comprehensive Income as changes in the fair value of most of the Duke Energy Registrants' available-for-sale equity securities are deferred as regulatory assets or liabilities pursuant to accounting guidance for regulated operations.

Environmental Costs

Liabilities are recorded when losses become probable and are reasonably estimable.

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.

Derivatives

Duke Energy’s interest rate swaps for its regulated 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.

For the Subsidiary Registrants, bulk power electricity and coal and natural gas purchases flow through fuel adjustment clauses, formula based contracts or other cost sharing mechanisms. Differences between the costs included in rates and the incurred costs, including undesignated derivative contracts, are largely deferred as regulatory assets or regulatory liabilities.

Investment

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 OTTIs 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.

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 OTTI exists, the unrealized credit loss is included in earnings.

Earnings Per Share

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 shares 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 shares outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as stock options and equity forward sale agreements, were exercised or settled.

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.

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.

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Organization and Basis of Presentation (Tables)

3 Months Ended

Mar. 31, 2017

Organization And Basis Of Presentation [Line Items]

Schedule Of Unbilled Revenues With Restricted Receivables

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

(in millions)	March 31, 2017		December 31, 2016
Duke Energy	$	724	$	831
Duke Energy Carolinas	296		313
Progress Energy	151		161
Duke Energy Progress	84		102
Duke Energy Florida	67		59
Duke Energy Ohio	2		2
Duke Energy Indiana	27		32
Piedmont	38		77

Schedule Of Net Income Amounts Attributable To Controlling Interests

The following table presents Net Income Attributable to Duke Energy Corporation for continuing operations and discontinued operations.

	Three Months Ended
(in millions)	March 31, 2016
Income from Continuing Operations	$	577
Income from Continuing Operations Attributable to Noncontrolling Interests	3
Income from Continuing Operations Attributable to Duke Energy Corporation	$	574
Income from Discontinued Operations, net of tax	$	122
Income from Discontinued Operations Attributable to Noncontrolling Interests, net of tax	2
Income from Discontinued Operations Attributable to Duke Energy Corporation, net of tax	$	120
Net Income	$	699
Net Income Attributable to Noncontrolling Interests	5
Net Income Attributable to Duke Energy Corporation	$	694

Schedule of Utility Inventory

The components of inventory are presented in the tables below.

	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Materials and supplies	$	2,328	$	766	$	1,122	$	780	$	341	$	85	$	315	$	2
Coal	724		248		297		162		135		17		161		—
Natural gas, oil and other fuel	314		37		233		111		123		16		2		27
Total inventory	$	3,366	$	1,051	$	1,652	$	1,053	$	599	$	118	$	478	$	29

	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Materials and supplies	$	2,374	$	767	$	1,167	$	813	$	354	$	84	$	312	$	1
Coal	774		251		314		148		166		19		190		—
Natural gas, oil and other fuel	374		37		236		115		121		34		2		65
Total inventory	$	3,522	$	1,055	$	1,717	$	1,076	$	641	$	137	$	504	$	66

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 March 31,
(in millions)	2017		2016
Duke Energy	$	91	$	91
Duke Energy Carolinas	9		8
Progress Energy	46		47
Duke Energy Progress	5		5
Duke Energy Florida	41		42
Duke Energy Ohio	28		28
Duke Energy Indiana	7		8
Piedmont	1		1

Duke Energy Ohio [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)	March 31, 2017		December 31, 2016
Duke Energy Ohio	$	69	$	97
Duke Energy Indiana	106		123

Duke Energy Indiana [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)	March 31, 2017		December 31, 2016
Duke Energy Ohio	$	69	$	97
Duke Energy Indiana	106		123

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Acquisitions and Dispositions (Tables)

3 Months Ended

Mar. 31, 2017

Business Combinations [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]

The purchase price allocation of the Piedmont acquisition is as follows:

(in millions)
Current assets	$	497
Property, plant and equipment, net	4,714
Goodwill	3,353
Other long-term assets	804
Total assets	9,368
Current liabilities, including current maturities of long-term debt	576
Long-term liabilities	1,790
Long-term debt	2,002
Total liabilities	4,368
Total purchase price	$	5,000

Business Acquisition, Pro Forma Information [Table Text Block]

This information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of Duke Energy.

	Three Months Ended
(in millions)	March 31, 2016
Operating Revenues	$	5,840
Net Income Attributable to Duke Energy Corporation	832

Income Statement Disclosures

The following table presents the results of the International Disposal Group, which are included in Income from Discontinued Operations, net of tax in Duke Energy's Condensed Consolidated Statements of Operations. Interest expense directly associated with the International Disposal Group was allocated to discontinued operations. No interest from corporate level debt was allocated to discontinued operations.

	Three Months Ended
(in millions)	March 31, 2016
Operating Revenues	$	246
Fuel used in electric generation and purchased power	47
Cost of natural gas	11
Operation, maintenance and other	71
Depreciation and amortization	22
Property and other taxes	3
Other Income and Expenses, net	10
Interest Expense	22
Income before income taxes	80
Income tax benefit(a)	(39		)
Income from discontinued operations of the International Disposal Group	119
Income from discontinued operations of other businesses	3
Income from Discontinued Operations, net of tax	$	122

(a) Includes an income tax benefit of $95 million related to historical undistributed foreign earnings. See Note 16 for additional information.

Duke Energy has elected not to separately disclose discontinued operations on the Condensed Consolidated Statements of Cash Flows. The following table summarizes Duke Energy's cash flows from discontinued operations related to the International Disposal Group.

	Three Months Ended
(in millions)	March 31, 2016
Cash flows provided by (used in):
Operating activities	$	85
Investing activities	(9		)

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Business Segments (Tables)

3 Months Ended

Mar. 31, 2017

Segment Reporting Information [Line Items]

Business Segment Data

Business segment information is presented in the following tables. Segment assets presented exclude intercompany assets.

	Three Months Ended March 31, 2017
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	4,939	$	648	$	128	$	5,715	$	14		$	—		$	5,729
Intersegment revenues	8		22		—		30		19			(49		)	—
Total revenues	$	4,947	$	670	$	128	$	5,745	$	33		$	(49	)	$	5,729
Segment income (loss)	$	635	$	133	$	25	$	793	$	(77	)	$	—		$	716
Add back noncontrolling interests															1
Net income															$	717
Segment assets	$	115,766	$	10,866	$	4,400	$	131,032	$	2,898		$	178		$	134,108

	Three Months Ended March 31, 2016
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,081	$	169	$	114	$	5,364	$	13		$	—		$	5,377
Intersegment revenues	8		1		—		9		16			(25		)	—
Total revenues	$	5,089	$	170	$	114	$	5,373	$	29		$	(25	)	$	5,377
Segment income (loss)(a)	$	664	$	32	$	26	$	722	$	(148	)	$	—		$	574
Add back noncontrolling interests															3
Income from discontinued operations, net of tax															122
Net income															$	699

(a) Other includes $74 million of after-tax costs to achieve mergers, including losses on forward-starting interest rate swaps related to the Piedmont acquisition financing. See Note 9 for additional information.

The following table summarizes the net loss of Other for each of these entities.

	Three Months Ended
	March 31,
(in millions)	2017			2016
Duke Energy Carolinas	$	(6	)	$	(17	)
Progress Energy	(43		)	(49		)
Duke Energy Progress	(3		)	(8		)
Duke Energy Florida	(2		)	(4		)
Duke Energy Indiana	(2		)	(2		)
Piedmont	(4		)	6

Duke Energy Ohio [Member]

Segment Reporting Information [Line Items]

Business Segment Data

	Three Months Ended March 31, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Consolidated
Total revenues	$	337	$	170	$	507	$	11		$	—		$	518
Segment income (loss)/Net Income	24		26		50		(8		)	—			42
Segment assets	4,856		2,696		7,552		71			(14		)	7,609

	Three Months Ended March 31, 2016
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Consolidated
Total revenues	$	340	$	170	$	510	$	6		$	—		$	516
Segment income (loss)	$	36	$	31	$	67	$	(9	)	$	(1	)	$	57
Income from discontinued operations, net of tax													2
Net income													$	59

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Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2017

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. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2017, and exclude capitalized asset retirement costs.

		Remaining Net
	Capacity	Book Value
	(in MW)	(in millions)
Duke Energy Carolinas
Allen Steam Station Units 1-3(a)	585	$	167
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2(b)	873	117
Duke Energy Indiana
Gallagher Units 2 and 4(c)	280	135
Total Duke Energy	1,738	$	419

(a) Duke Energy Carolinas will retire Allen Steam Station Units 1 through 3 by December 31, 2024, as part of the resolution of a lawsuit involving alleged New Source Review violations.

(b) Duke Energy Florida will likely retire these coal units by 2018 to comply with environmental regulations.

(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 settlement of Edwardsport IGCC matters.

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Commitments and Contingencies (Table)

3 Months Ended

Mar. 31, 2017

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	$	71
Duke Energy Carolinas	22
Duke Energy Ohio	36
Duke Energy Indiana	7
Piedmont	2

Reserve for Environmental Costs [Member]

Valuation and Qualifying Accounts Disclosure [Line Items]

Schedule of Legal Reserves

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 Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets.

	Three Months Ended March 31, 2017
				Duke					Duke		Duke			Duke			Duke
	Duke			Energy		Progress			Energy		Energy			Energy			Energy
(in millions)	Energy			Carolinas		Energy			Progress		Florida			Ohio			Indiana			Piedmont
Balance at beginning of period	$	98		$	10	$	18		$	3	$	14		$	59		$	10		$	1
Provisions/adjustments	6			1		—			—		1			4			(1		)	1
Cash reductions	(6		)	—		(1		)	—		(1		)	(4		)	—			—
Balance at end of period	$	98		$	11	$	17		$	3	$	14		$	59		$	9		$	2

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Balance at beginning of period	$	94		$	10		$	17		$	3		$	14		$	54	$	12	$	1
Provisions/adjustments	10			2			1			—			1			—		6		—
Cash reductions	(3		)	(1		)	(2		)	(1		)	(1		)	—		—		—
Balance at end of period	$	101		$	11		$	16		$	2		$	14		$	54	$	18	$	1

Legal Reserve [Member]

Valuation and Qualifying Accounts Disclosure [Line Items]

Schedule of Legal Reserves

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 Other Noncurrent 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)	March 31, 2017		December 31, 2016
Reserves for Legal Matters
Duke Energy	$	91	$	98
Duke Energy Carolinas	23		23
Progress Energy	57		59
Duke Energy Progress	13		14
Duke Energy Florida	27		28
Duke Energy Ohio	4		4
Piedmont	2		2

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Debt and Credit Facilities (Tables)

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments [Table Text Block]

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

				Three Months Ended March 31, 2017
						Duke		Duke
	Maturity	Interest		Duke		Energy		Energy
Issuance Date	Date	Rate		Energy		Florida		Ohio
Secured Debt
February 2017(a)	June 2034	4.120	%	$	587	$	—	$	—
First Mortgage Bonds
January 2017(b)	January 2020	1.850	%	250		250		—
January 2017(b)	January 2027	3.200	%	650		650		—
March 2017(c)	June 2046	3.700	%	100		—		100
Total issuances				$	1,587	$	900	$	100

(a) Portfolio financing of four Texas and Oklahoma wind facilities. Secured by substantially all of the assets of these wind facilities and nonrecourse to Duke Energy. Proceeds were used to reimburse Duke Energy for a portion of previously funded construction expenditures.

(b) Debt issued to fund capital expenditures for ongoing construction and capital maintenance, to repay at maturity a $250 million aggregate principal amount of bonds due September 2017 and for general corporate purposes.

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

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		March 31, 2017
Unsecured Debt
Duke Energy (Parent)	August 2017	1.625	%	$	700
Piedmont	September 2017	8.510	%	35
Secured Debt
Duke Energy	June 2017	2.605	%	45
Duke Energy	June 2017	2.455	%	34
First Mortgage Bonds
Duke Energy Florida	September 2017	5.800	%	250
Duke Energy Progress	November 2017	1.252	%	200
Duke Energy Carolinas	January 2018	5.250	%	400
Other(a)				313
Current maturities of long-term debt				$	1,977

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

Schedule Of Line Of Credit Facilities

The table below includes the current borrowing sublimits and available capacity under the Master Credit Facility.

	March 31, 2017
				Duke			Duke			Duke			Duke			Duke			Duke
	Duke			Energy			Energy			Energy			Energy			Energy			Energy
(in millions)	Energy			(Parent)			Carolinas			Progress			Florida			Ohio			Indiana			Piedmont
Facility size(a)	$	8,000		$	3,400		$	1,100		$	1,000		$	950		$	450		$	600		$	500
Reduction to backstop issuances
Commercial paper(b)	(3,134		)	(1,822		)	(469		)	(402		)	—			(30		)	(150		)	(261		)
Outstanding letters of credit	(71		)	(62		)	(4		)	(2		)	(1		)	—			—			(2		)
Tax-exempt bonds	(81		)	—			—			—			—			—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—			—
Available capacity	$	4,214		$	1,516		$	377		$	346		$	949		$	420		$	369		$	237

(a) Represents the sublimit of each borrower. Certain sublimits were reallocated in May 2017 to provide additional liquidity to certain borrowers in light of near-term funding needs.

(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.

XML

Goodwill and Intangible Assets (Tables)

3 Months Ended

Mar. 31, 2017

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill By Reportable Operating Segment

Duke Energy

The following table presents the goodwill by reportable operating segment on Duke Energy's Condensed Consolidated Balance Sheets at March 31, 2017 and December 31, 2016.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables		Total
Goodwill	$	17,379	$	1,924	$	122	$	19,425

XML

Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2017

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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

Piedmont Natural Gas [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 March 31,
(in millions)	2017		2016
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	199	$	217
Indemnification coverages(b)	6		5
JDA revenue(c)	16		9
JDA expense(c)	31		41
Intercompany natural gas purchases(d)	1		—
Progress Energy
Corporate governance and shared service expenses(a)	$	169	$	174
Indemnification coverages(b)	10		9
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	103	$	100
Indemnification coverages(b)	4		4
JDA revenue(c)	31		41
JDA expense(c)	16		9
Intercompany natural gas purchases(d)	19		—
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	66	$	74
Indemnification coverages(b)	6		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	90	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	90	$	94
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	6	$	—
Indemnification coverages(b)	1		—
Intercompany natural gas sales(d)	20		—

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, 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.

(d) Piedmont provides long-term natural gas delivery service to Duke Energy Carolinas and Duke Energy Progress' natural gas-fired generation facilities. Piedmont recorded the sales in Operating Revenues – Regulated natural gas, and Duke Energy Carolinas and Duke Energy Progress recorded the related purchases in Operating Expenses – Cost of natural gas on their Condensed Consolidated Statements of Operations and Comprehensive Income. The amounts are not eliminated in accordance with rate-based accounting regulations. For the three months ended March 31, 2016, which was prior to the Piedmont acquisition, Piedmont recorded $19 million and $1 million of natural gas sales with Duke Energy Progress and Duke Energy Carolinas, respectively.

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		Piedmont
March 31, 2017
Intercompany income tax receivable	$	19	$	139	$	47	$	48	$	8	$	—	$	—
Intercompany income tax payable	—		—		—		—		—		23		44
December 31, 2016
Intercompany income tax receivable	$	1	$	—	$	—	$	37	$	—	$	—	$	—
Intercompany income tax payable	—		37		90		—		1		3		38

Equity Method Investee [Member] | Piedmont Natural Gas [Member]

Related Party Transaction [Line Items]

Schedule of Related Party Transactions, Other Revenue and Expense

Below are expenses for the three months ended March 31, 2017 and 2016, which are included in Operating Expenses – Cost of natural gas on Piedmont's Condensed Consolidated Statement of Operations and Comprehensive Income.

		Three Months Ended March 31,
(in millions)	Type of expense	2017		2016
Cardinal	Transportation Costs	$	2	$	2
Pine Needle	Gas Storage Costs	2		3
Hardy Storage	Gas Storage Costs	2		2
Total		$	6	$	7

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Derivatives and Hedging (Tables)

3 Months Ended

Mar. 31, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Notional Amounts of Outstanding Derivative Positions

The following table shows notional amounts of outstanding derivatives related to interest rate risk as of March 31, 2017 and December 31, 2016.

			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	750	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	927		400		500		250		250		27
Total notional amount	$	1,677	$	400	$	500	$	250	$	250	$	27

(a)    Duke Energy includes amounts related to consolidated VIEs of $750 million as of March 31, 2017 and December 31, 2016.

The tables below include 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.

	March 31, 2017
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	184	—	—	—	—	184	—
Natural gas (millions of dekatherms)	817	85	228	105	123	—	504

	December 31, 2016
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	147	—	—	—	—	147	—
Natural gas (millions of dekatherms)	890	91	269	118	151	1	529

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	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	58	$	16	$	30	$	19	$	11	$	—	$	9	$	2
Noncurrent	5		1		2		1		1		1		—		—
Total Derivative Assets – Commodity Contracts	$	63	$	17	$	32	$	20	$	12	$	1	$	9	$	2
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	18	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	2		—		2		—		2		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	20	$	—	$	2	$	—	$	2	$	—	$	—	$	—
Total Derivative Assets	$	83	$	17	$	34	$	20	$	14	$	1	$	9	$	2

Derivative Liabilities	March 31, 2017
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	32	$	—	$	17	$	1	$	17	$	—	$	—	$	14
Noncurrent	145		4		11		4		1		—		—		131
Total Derivative Liabilities – Commodity Contracts	$	177	$	4	$	28	$	5	$	18	$	—	$	—	$	145
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	8	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	9		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		—		—		—		1		—		—
Noncurrent	21		10		6		5		1		4		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	39	$	10	$	6	$	5	$	1	$	5	$	—	$	—
Total Derivative Liabilities	$	216	$	14	$	34	$	10	$	19	$	5	$	—	$	145

Derivative Assets	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	108	$	23	$	61	$	35	$	26	$	4	$	16	$	3
Noncurrent	32		10		21		10		11		1		—		—
Total Derivative Assets – Commodity Contracts	$	140	$	33	$	82	$	45	$	37	$	5	$	16	$	3
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	$	19	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	3		—		3		1		2		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	22	$	—	$	3	$	1	$	2	$	—	$	—	$	—
Total Derivative Assets	$	162	$	33	$	85	$	46	$	39	$	5	$	16	$	3

Derivative Liabilities	December 31, 2016
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current	$	43	$	—	$	12	$	—	$	12	$	—	$	2	$	35
Noncurrent	166		1		7		1		—		—		—		152
Total Derivative Liabilities – Commodity Contracts	$	209	$	1	$	19	$	1	$	12	$	—	$	2	$	187
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	8	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	8		—		—		—		—		—		—		—
Not Designated as Hedging Instruments															—
Current	1		—		—		—		—		1		—		—
Noncurrent	26		15		6		6		—		5		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	43	$	15	$	6	$	6	$	—	$	6	$	—	$	—
Total Derivative Liabilities	$	252	$	16	$	25	$	7	$	12	$	6	$	2	$	187

Offsetting Assets

Derivative Assets	December 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	111		$	23		$	64		$	36		$	28		$	4	$	16	$	3
Gross amounts offset	(11		)	—			(11		)	—			(11		)	—		—		—
Net amounts presented in Current Assets: Other	$	100		$	23		$	53		$	36		$	17		$	4	$	16	$	3
Noncurrent
Gross amounts recognized	$	51		$	10		$	21		$	10		$	11		$	1	$	—	$	—
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	49		$	9		$	20		$	9		$	11		$	1	$	—	$	—

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	March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	60		$	16		$	32		$	19		$	13		$	—	$	9	$	2
Gross amounts offset	(7		)	—			(7		)	(1		)	(6		)	—		—		—
Net amounts presented in Current Assets: Other	$	53		$	16		$	25		$	18		$	7		$	—	$	9	$	2
Noncurrent
Gross amounts recognized	$	23		$	1		$	2		$	1		$	1		$	1	$	—	$	—
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	21		$	—		$	1		$	—		$	1		$	1	$	—	$	—

Offsetting Liabilities

Derivative Liabilities	December 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	52		$	—		$	12		$	—		$	12		$	1	$	2	$	35
Gross amounts offset	(11		)	—			(11		)	—			(11		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	41		$	—		$	1		$	—		$	1		$	1	$	2	$	35
Noncurrent
Gross amounts recognized	$	200		$	16		$	13		$	7		$	—		$	5	$	—	$	152
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	198		$	15		$	12		$	6		$	—		$	5	$	—	$	152

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 Liabilities	March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Current
Gross amounts recognized	$	41		$	—		$	17		$	1		$	17		$	1	$	—	$	14
Gross amounts offset	(7		)	—			(7		)	(1		)	(6		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	34		$	—		$	10		$	—		$	11		$	1	$	—	$	14
Noncurrent
Gross amounts recognized	$	175		$	14		$	17		$	9		$	2		$	4	$	—	$	131
Gross amounts offset	(2		)	(1		)	(1		)	(1		)	—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	173		$	13		$	16		$	8		$	2		$	4	$	—	$	131

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, Duke Energy Indiana and Piedmont were not material.

	March 31, 2017
			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	$	40	$	14	$	25	$	9	$	17
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	40		14		25		9		17

	December 31, 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	$	34	$	16	$	18	$	6	$	12
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	34		16		18		6		12

The Duke Energy Registrants have elected to offset cash collateral and fair values of derivatives. For amounts to be netted, the derivative and cash collateral must be executed with the same counterparty under the same master netting arrangement.

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Investments in Debt and Equity Securities (Tables)

3 Months Ended

Mar. 31, 2017

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.

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	114	$	—	$	—	$	111
Equity securities	2,250		32		4,284		2,092		54		4,106
Corporate debt securities	10		5		576		10		8		528
Municipal bonds	3		6		336		3		10		331
U.S. government bonds	10		8		949		10		8		984
Other debt securities	—		3		132		—		3		124
Total NDTF	$	2,273	$	54	$	6,391	$	2,115	$	83	$	6,184
Other Investments
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	25
Equity securities	44		—		106		38		—		104
Corporate debt securities	1		—		60		1		1		66
Municipal bonds	2		1		84		2		1		82
U.S. government bonds	—		—		43		—		1		51
Other debt securities	—		2		42		—		2		42
Total Other Investments(b)	$	47	$	3	$	353	$	41	$	5	$	370
Total Investments	$	2,320	$	57	$	6,744	$	2,156	$	88	$	6,554

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	82
Due after one through five years	640
Due after five through 10 years	514
Due after 10 years	986
Total	$	2,222

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
	March 31,
(in millions)	2017		2016
Realized gains	$	93	$	54
Realized losses	62		50

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.

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	20	$	—	$	—	$	18
Equity securities	1,229		15		2,366		1,157		28		2,245
Corporate debt securities	5		4		388		5		6		354
Municipal bonds	1		1		67		1		2		67
U.S. government bonds	3		5		431		2		5		458
Other debt securities	—		3		120		—		3		116
Total NDTF	$	1,238	$	28	$	3,392	$	1,165	$	44	$	3,258
Other Investments
Other debt securities	$	—	$	1	$	3	$	—	$	1	$	3
Total Other Investments(b)	$	—	$	1	$	3	$	—	$	1	$	3
Total Investments	$	1,238	$	29	$	3,395	$	1,165	$	45	$	3,261

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	2
Due after one through five years	221
Due after five through 10 years	269
Due after 10 years	517
Total	$	1,009

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
	March 31,
(in millions)	2017		2016
Realized gains	$	66	$	34
Realized losses	40		37

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.

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	94	$	—	$	—	$	93
Equity securities	1,021		17		1,918		935		26		1,861
Corporate debt securities	5		1		188		5		2		174
Municipal bonds	2		5		269		2		8		264
U.S. government bonds	7		3		518		8		3		526
Other debt securities	—		—		12		—		—		8
Total NDTF	$	1,035	$	26	$	2,999	$	950	$	39	$	2,926
Other Investments
Cash and cash equivalents	$	—	$	—	$	12	$	—	$	—	$	21
Municipal bonds	2		—		46		2		—		44
Total Other Investments(b)	$	2	$	—	$	58	$	2	$	—	$	65
Total Investments	$	1,037	$	26	$	3,057	$	952	$	39	$	2,991

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	72
Due after one through five years	355
Due after five through 10 years	189
Due after 10 years	417
Total	$	1,033

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
	March 31,
(in millions)	2017		2016
Realized gains	$	27	$	19
Realized losses	21		13

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.

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	43	$	—	$	—	$	45
Equity securities	772		13		1,541		704		21		1,505
Corporate debt securities	4		1		131		4		1		120
Municipal bonds	2		5		268		2		8		263
U.S. government bonds	5		2		284		5		2		275
Other debt securities	—		—		7		—		—		5
Total NDTF	$	783	$	21	$	2,274	$	715	$	32	$	2,213
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	1
Total Other Investments(b)	$	—	$	—	$	1	$	—	$	—	$	1
Total Investments	$	783	$	21	$	2,275	$	715	$	32	$	2,214

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	17
Due after one through five years	215
Due after five through 10 years	142
Due after 10 years	316
Total	$	690

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
	March 31,
(in millions)	2017		2016
Realized gains	$	24	$	15
Realized losses	19		11

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.

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	51	$	—	$	—	$	48
Equity securities	249		4		377		231		5		356
Corporate debt securities	1		—		57		1		1		54
Municipal bonds	—		—		1		—		—		1
U.S. government bonds	2		1		234		3		1		251
Other debt securities	—		—		5		—		—		3
Total NDTF(b)	$	252	$	5	$	725	$	235	$	7	$	713
Other Investments
Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	4
Municipal bonds	2		—		46		2		—		44
Total Other Investments(c)	$	2	$	—	$	47	$	2	$	—	$	48
Total Investments	$	254	$	5	$	772	$	237	$	7	$	761

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) During the three months endedMarch 31, 2017, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing commissioning activity of the Crystal River Unit 3 nuclear plant.

(c) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	55
Due after one through five years	140
Due after five through 10 years	47
Due after 10 years	101
Total	$	343

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
	March 31,
(in millions)	2017		2016
Realized gains	$	3	$	4
Realized losses	2		2

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.

	March 31, 2017						December 31, 2016
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses(a)		Value		Gains		Losses(a)		Value
Other Investments
Equity securities	$	38	$	—	$	84	$	33	$	—	$	79
Corporate debt securities	—		—		2		—		—		2
Municipal bonds	—		1		28		—		1		28
U.S. government bonds	—		—		1		—		—		1
Total Other Investments(b)	$	38	$	1	$	115	$	33	$	1	$	110
Total Investments	$	38	$	1	$	115	$	33	$	1	$	110

(a) Substantially all amounts are considered OTTIs on investments within Investment Trusts that have been recognized immediately as a regulatory asset.

(b) These amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	March 31, 2017
Due in one year or less	$	2
Due after one through five years	15
Due after five through 10 years	9
Due after 10 years	5
Total	$	31

XML

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2017

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3			Not categorized
Nuclear decommissioning trust fund equity securities	$	4,284		$	4,207	$	—		$	—		$	77
Nuclear decommissioning trust fund debt securities	2,107			602		1,505			—			—
Other trading and available-for-sale equity securities	110			110		—			—			—
Other trading and available-for-sale debt securities	248			61		182			5			—
Derivative assets	83			2		71			10			—
Total assets	6,832			4,982		1,758			15			77
Derivative liabilities	(216		)	—		(71		)	(145		)	—
Net assets (liabilities)	$	6,616		$	4,982	$	1,687		$	(130	)	$	77

	December 31, 2016
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not categorized
Nuclear decommissioning trust fund equity securities	$	4,106		$	4,029		$	—		$	—		$	77
Nuclear decommissioning trust fund debt securities	2,078			632			1,446			—			—
Other trading and available-for-sale equity securities	104			104			—			—			—
Other trading and available-for-sale debt securities	266			75			186			5			—
Derivative assets	162			5			136			21			—
Total assets	6,716			4,845			1,768			26			77
Derivative liabilities	(252		)	(2		)	(63		)	(187		)	—
Net assets (liabilities)	$	6,464		$	4,843		$	1,705		$	(161	)	$	77

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.

	Three Months Ended March 31, 2017
(in millions)	Investments		Derivatives (net)			Total
Balance at beginning of period	$	5	$	(166	)	$	(161	)
Purchases, sales, issuances and settlements:
Settlements	—		(9		)	(9		)
Total amount included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		40			40
Balance at end of period	$	5	$	(135	)	$	(130	)

	Three Months Ended March 31, 2016
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	5		$	10		$	15
Purchases, sales, issuances and settlements:
Sales	(1		)	—			(1		)
Settlements	—			(7		)	(7		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—			(1		)	(1		)
Balance at end of period	$	4		$	2		$	6

Quantitative Information Table - Level 3

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

	March 31, 2017
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
Financial Transmission Rights (FTRs)	$	1		RTO auction pricing	FTR price – per megawatt-hour (MWh)	$	0.23		-	$	2.02
Duke Energy Indiana
FTRs	9			RTO auction pricing	FTR price – per MWh	(1.08		)	-	5.33
Piedmont
Natural gas contracts	(145		)	Discounted cash flow	Forward natural gas curves – price per million British thermal unit (MMBtu)	2.08			-	3.57
Duke Energy
Total Level 3 derivatives	$	(135	)

	December 31, 2016
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
FTRs	$	5		RTO auction pricing	FTR price – per MWh	$	0.77		-	$	3.52
Duke Energy Indiana
FTRs	16			RTO auction pricing	FTR price – per MWh	(0.83		)	-	9.32
Piedmont
Natural gas contracts	(187		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	2.31			-	4.18
Duke Energy
Total Level 3 derivatives	$	(166	)

Schedule Of Long Term Debt Fair Value

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.

	March 31, 2017				December 31, 2016
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy	$	48,998	$	50,480	$	47,895	$	49,161
Duke Energy Carolinas	9,491		10,405		9,603		10,494
Progress Energy	18,148		19,742		17,541		19,107
Duke Energy Progress	6,761		7,103		7,011		7,357
Duke Energy Florida	6,981		7,596		6,125		6,728
Duke Energy Ohio	1,977		2,122		1,884		2,020
Duke Energy Indiana	3,784		4,292		3,786		4,260
Piedmont	1,821		1,954		1,821		1,933

Duke Energy Carolinas [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,366		$	2,289	$	—		$	—	$	77
Nuclear decommissioning trust fund debt securities	1,026			146		880			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	17			—		17			—		—
Total assets	3,412			2,435		897			3		77
Derivative liabilities	(14		)	—		(14		)	—		—
Net assets	$	3,398		$	2,435	$	883		$	3	$	77

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Not categorized
Nuclear decommissioning trust fund equity securities	$	2,245		$	2,168	$	—		$	—	$	77
Nuclear decommissioning trust fund debt securities	1,013			178		835			—		—
Other available-for-sale debt securities	3			—		—			3		—
Derivative assets	33			—		33			—		—
Total assets	3,294			2,346		868			3		77
Derivative liabilities	(16		)	—		(16		)	—		—
Net assets	$	3,278		$	2,346	$	852		$	3	$	77

Progress Energy [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,918		$	1,918	$	—
Nuclear decommissioning trust fund debt securities	1,081			456		625
Other available-for-sale debt securities	58			12		46
Derivative assets	34			—		34
Total assets	3,091			2,386		705
Derivative liabilities	(34		)	—		(34		)
Net assets	$	3,057		$	2,386	$	671

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,861		$	1,861	$	—
Nuclear decommissioning trust fund debt securities	1,065			454		611
Other available-for-sale debt securities	65			21		44
Derivative assets	85			—		85
Total assets	3,076			2,336		740
Derivative liabilities	(25		)	—		(25		)
Net assets	$	3,051		$	2,336	$	715

Duke Energy Progress [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,541		$	1,541	$	—
Nuclear decommissioning trust fund debt securities and other	733			221		512
Other available-for-sale debt securities and other	1			1		—
Derivative assets	20			—		20
Total assets	2,295			1,763		532
Derivative liabilities	(10		)	—		(10		)
Net assets	$	2,285		$	1,763	$	522

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	1,505		$	1,505	$	—
Nuclear decommissioning trust fund debt securities and other	708			207		501
Other available-for-sale debt securities and other	1			1		—
Derivative assets	46			—		46
Total assets	2,260			1,713		547
Derivative liabilities	(7		)	—		(7		)
Net assets	$	2,253		$	1,713	$	540

Duke Energy Florida [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	377		$	377	$	—
Nuclear decommissioning trust fund debt securities and other	348			235		113
Other available-for-sale debt securities and other	47			1		46
Derivative assets	14			—		14
Total assets	786			613		173
Derivative liabilities	(19		)	—		(19		)
Net assets	$	767		$	613	$	154

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2
Nuclear decommissioning trust fund equity securities	$	356		$	356	$	—
Nuclear decommissioning trust fund debt securities and other	357			247		110
Other available-for-sale debt securities and other	48			4		44
Derivative assets	39			—		39
Total assets	800			607		193
Derivative liabilities	(12		)	—		(12		)
Net assets	$	788		$	607	$	181

Duke Energy Ohio [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	1		$	—	$	—		$	1
Derivative liabilities	(5		)	—		(5		)	—
Net (liabilities) assets	$	(4	)	$	—	$	(5	)	$	1

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Derivative assets	$	5		$	—	$	—		$	5
Derivative liabilities	(6		)	—		(6		)	—
Net (liabilities) assets	$	(1	)	$	—	$	(6	)	$	5

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	5		$	3
Purchases, sales, issuances and settlements:
Settlements	(1		)	(2		)
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(3		)	(1		)
Balance at end of period	$	1		$	—

Duke Energy Indiana [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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.

	March 31, 2017
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Other available-for-sale equity securities	$	84	$	84	$	—	$	—
Other available-for-sale debt securities and other	31		—		31		—
Derivative assets	9		—		—		9
Net assets	$	124	$	84	$	31	$	9

	December 31, 2016
(in millions)	Total Fair Value			Level 1			Level 2		Level 3
Other available-for-sale equity securities	$	79		$	79		$	—	$	—
Other available-for-sale debt securities and other	31			—			31		—
Derivative assets	16			—			—		16
Total assets	126			79			31		16
Derivative liabilities	(2		)	(2		)	—		—
Net assets	$	124		$	77		$	31	$	16

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	16		$	7
Purchases, sales, issuances and settlements:
Settlements	(7		)	(5		)
Balance at end of period	$	9		$	2

Piedmont Natural Gas [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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. See Note 10 for additional information related to investments.

	March 31, 2017
(in millions)	Total Fair Value			Level 1		Level 3
Other trading equity securities	4			4		—
Other trading debt securities	1			1		—
Derivative assets	2			2		—
Total assets	7			7		—
Derivative liabilities	(145		)	—		(145		)
Net (liabilities) assets	$	(138	)	$	7	$	(145	)

	December 31, 2016
(in millions)	Total Fair Value			Level 1		Level 3
Other trading equity securities	$	4		$	4	$	—
Other trading debt securities	1			1		—
Derivative assets	3			3		—
Total assets	8			8		—
Derivative liabilities	(187		)	—		(187		)
Net (liabilities) assets	$	(179	)	$	8	$	(187	)

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 March 31,
(in millions)	2017			2016
Balance at beginning of period	$	(187	)	$	(149	)
Total gains and settlements	42			23
Balance at end of period	$	(145	)	$	(126	)

XML

Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2017

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.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
(in millions)	CRC		DERF		DEPR		DEFR
Expiration date	December 2018		December 2018		February 2019		April 2019
Credit facility amount	$	325	$	425	$	300	$	225
Amounts borrowed at March 31, 2017	325		425		300		225
Amounts borrowed at December 31, 2016	325		425		300		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.

	March 31, 2017
	Duke Energy										Duke		Duke
	Pipeline			Commercial		Other					Energy		Energy
(in millions)	Investments			Renewables		VIEs		Total			Ohio		Indiana		Piedmont
Receivables from affiliated companies	$	—		$	—	$	—	$	—		$	53	$	69	$	—
Investments in equity method unconsolidated affiliates	673			173		92		938			—		—		152
Other noncurrent assets	12			—		—		12			—		—		—
Total assets	$	685		$	173	$	92	$	950		$	53	$	69	$	152
Taxes accrued(a)	23			—		—		23			—		—		(1		)
Other current liabilities	—			—		2		2			—		—		—
Deferred income taxes(a)	(7		)	—		—		(7		)	—		—		4
Other noncurrent liabilities	—			—		13		13			—		—		—
Total liabilities	$	16		$	—	$	15	$	31		$	—	$	—	$	3
Net assets	$	669		$	173	$	77	$	919		$	53	$	69	$	149

(a) Taxes accrued and Deferred income taxes are netted by jurisdiction on a consolidated basis on the Condensed Consolidated Balance Sheets.

	December 31, 2016
	Duke Energy								Duke		Duke
	Pipeline		Commercial		Other				Energy		Energy
(in millions)	Investments		Renewables		VIEs		Total		Ohio		Indiana		Piedmont
Receivables from affiliated companies	$	—	$	—	$	—	$	—	$	82	$	101	$	—
Investments in equity method unconsolidated affiliates	487		174		90		751		—		—		139
Other noncurrent assets	12		—		—		12		—		—		—
Total assets	$	499	$	174	$	90	$	763	$	82	$	101	$	139
Other current liabilities	—		—		3		3		—		—		—
Other noncurrent liabilities	—		—		13		13		—		—		4
Total liabilities	$	—	$	—	$	16	$	16	$	—	$	—	4
Net assets	$	499	$	174	$	74	$	747	$	82	$	101	$	135

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)	March 31, 2017		December 31, 2016
Receivables of VIEs	$	4	$	6
Current Assets: Regulatory assets	53		50
Current Assets: Other	14		53
Other Noncurrent Assets: Regulatory assets	1,131		1,142
Current Liabilities: Other	3		17
Current maturities of long-term debt	55		62
Long-Term Debt	1,189		1,217

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)	March 31, 2017			December 31, 2016
Current Assets: Other	$	336		$	223
Property, plant and equipment, cost	3,671			3,419
Accumulated depreciation and amortization	(448		)	(453		)
Current maturities of long-term debt	227			198
Long-Term Debt	1,645			1,097
Deferred income taxes	321			275
Other Noncurrent Liabilities: Other	251			252

Pipeline Investments [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

The table below presents the ownership interest and investment balances in these joint ventures.

	Duke Energy						Piedmont
			Investment Amount (in millions)						Investment Amount (in millions)
	Ownership		March 31,		December 31,		Ownership		March 31,		December 31,
Entity Name	Interest		2017		2016		Interest(a)		2017		2016
ACP	47	%	$	403	$	265	7	%	$	59	$	46
Sabal Trail	7.5	%	188		140
Constitution(b)	24	%	82		82		24	%	93		93
Total			$	673	$	487			$	152	$	139

(a) On April 1, 2017, Piedmont transferred its ownership interests in ACP and Constitution to a wholly owned subsidiary of Duke Energy at Piedmont's book value.

(b) Duke Energy's investment amount includes purchase accounting adjustments not recorded at the Piedmont registrant.

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
	2017		2016		2017		2016
Anticipated credit loss ratio	0.5	%	0.5	%	0.3	%	0.3	%
Discount rate	1.8	%	1.5	%	1.8	%	1.5	%
Receivable turnover rate	13.4	%	13.3	%	10.7	%	10.6	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	March 31, 2017		December 31, 2016		March 31, 2017		December 31, 2016
Receivables sold	$	238	$	267	$	277	$	306
Less: Retained interests	53		82		69		101
Net receivables sold	$	185	$	185	$	208	$	205

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

	Duke Energy Ohio				Duke Energy Indiana
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(in millions)	2017		2016		2017		2016
Sales
Receivables sold	$	533	$	532	$	664	$	635
Loss recognized on sale	2		3		3		3
Cash flows
Cash proceeds from receivables sold	$	559	$	537	$	693	$	643
Return received on retained interests	1		1		2		1

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Common Stock (Tables)

3 Months Ended

Mar. 31, 2017

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 shares outstanding to the diluted weighted average number of common shares outstanding.

	Three Months Ended March 31,
(in millions, except per share amounts)	2017		2016
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	715	$	574
Weighted average shares outstanding – basic	700		689
Weighted average shares outstanding – diluted	700		689
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	1.02	$	0.83
Diluted	$	1.02	$	0.83
Potentially dilutive items excluded from the calculation(a)	2		2
Dividends declared per common share	$	0.855	$	0.825

(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)

3 Months Ended

Mar. 31, 2017

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
	March 31,
(in millions)	2017		2016
Restricted stock unit awards	$	8	$	7
Performance awards	7		5
Pretax stock-based compensation cost	$	15	$	12
Tax benefit associated with stock-based compensation expense	$	5	$	4
Stock-based compensation costs capitalized	1		1

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Employee Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2017

Defined Benefit Plan Disclosure [Line Items]

Defined Contribution Plan Disclosures

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		Piedmont
Three Months Ended March 31,
2017	$	65	$	22	$	18	$	13	$	5	$	1	$	3	$	2
2016	52		18		15		11		4		1		2		2

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 qualified pension plans.

	Three Months Ended March 31, 2017
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	40		$	12		$	12		$	6		$	5		$	1		$	2		$	3
Interest cost on projected benefit obligation	82			20			25			12			13			5			7			3
Expected return on plan assets	(136		)	(35		)	(43		)	(21		)	(21		)	(7		)	(11		)	(6		)
Amortization of actuarial loss	36			8			14			6			7			1			3			3
Amortization of prior service credit	(6		)	(2		)	(1		)	—			—			—			—			(1		)
Other	2			—			1			—			—			—			—			—
Net periodic pension costs	$	18		$	3		$	8		$	3		$	4		$	—		$	1		$	2

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	36		$	12		$	11		$	6		$	5		$	1		$	2		$	3
Interest cost on projected benefit obligation	83			21			26			12			14			5			7			2
Expected return on plan assets	(129		)	(35		)	(42		)	(21		)	(21		)	(7		)	(10		)	(6		)
Amortization of actuarial loss	33			8			14			6			7			1			3			2
Amortization of prior service credit	(4		)	(2		)	(1		)	—			—			—			—			—
Other	3			1			1			—			—			—			—			—
Net periodic pension costs	$	22		$	5		$	9		$	3		$	5		$	—		$	2		$	1

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 March 31, 2017
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana		Piedmont
Service cost	$	1		$	—		$	—		$	—		$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	9			2			4			2			2			—		—		—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—		—
Amortization of actuarial loss (gain)	2			(1		)	5			3			2			—		—		—
Amortization of prior service credit	(29		)	(2		)	(21		)	(14		)	(8		)	—		—		—
Net periodic other post-retirement benefit	$	(20	)	$	(3	)	$	(12	)	$	(9	)	$	(4	)	$	—	$	—	$	—

	Three Months Ended March 31, 2016
				Duke						Duke			Duke			Duke		Duke
	Duke			Energy			Progress			Energy			Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio		Indiana			Piedmont
Service cost	$	1		$	—		$	—		$	—		$	—		$	—	$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	8			2			4			2			2			—		1			—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—			—
Amortization of actuarial loss (gain)	1			(1		)	5			3			2			—		(1		)	—
Amortization of prior service credit	(35		)	(3		)	(26		)	(17		)	(9		)	—		—			—
Net periodic other post-retirement benefit	$	(28	)	$	(4	)	$	(17	)	$	(12	)	$	(5	)	$	—	$	—		$	—

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2017

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
	March 31,
	2017		2016
Duke Energy	32.4	%	30.4	%
Duke Energy Carolinas	35.4	%	34.1	%
Progress Energy	34.1	%	36.7	%
Duke Energy Progress	34.1	%	35.4	%
Duke Energy Florida	36.6	%	37.9	%
Duke Energy Ohio	35.4	%	26.9	%
Duke Energy Indiana	39.3	%	30.2	%
Piedmont	37.9	%	38.0	%

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Organization and Basis of Presentation (Schedule of Unbilled Revenues with Restricted Receivables) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	$ 724	$ 831
Duke Energy Carolinas [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	296	313
Progress Energy [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	151	161
Duke Energy Progress [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	84	102
Duke Energy Florida [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	67	59
Duke Energy Ohio [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	2	2
Duke Energy Indiana [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	27	32
Piedmont Natural Gas [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	38	77
Cinergy Receivables [Member] | Duke Energy Ohio [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	69	97
Cinergy Receivables [Member] | Duke Energy Indiana [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	$ 106	$ 123

XML

Organization and Basis of Presentation (Schedule of Net Income Attributable to Noncontrolling Interest) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Schedule of Net Income Attributable to Noncontrolling Interest [Abstract]
Income From Continuing Operations	$ 717	$ 577
Income From Continuing Operations Attributable to Noncontrolling Interests	1	3
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent	716	574
Income From Discontinued Operations, net of tax		122
Income From Discontinued Operations Attributable to Noncontrolling Interests, net of tax		2
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent		120
Net Income	717	699
Net Income (Loss) Attributable to Noncontrolling Interests	1	5
Net Income Attributable to Parent	$ 716	$ 694

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Organization and Basis of Presentation (Schedule of Inventory) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Public Utilities, Inventory [Line Items]
Inventory	$ 3,366	$ 3,522
Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	2,328	2,374
Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	724	774
Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	314	374
Duke Energy Carolinas [Member]
Public Utilities, Inventory [Line Items]
Inventory	1,051	1,055
Duke Energy Carolinas [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	766	767
Duke Energy Carolinas [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	248	251
Duke Energy Carolinas [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	37	37
Progress Energy [Member]
Public Utilities, Inventory [Line Items]
Inventory	1,652	1,717
Progress Energy [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	1,122	1,167
Progress Energy [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	297	314
Progress Energy [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	233	236
Duke Energy Progress [Member]
Public Utilities, Inventory [Line Items]
Inventory	1,053	1,076
Duke Energy Progress [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	780	813
Duke Energy Progress [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	162	148
Duke Energy Progress [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	111	115
Duke Energy Florida [Member]
Public Utilities, Inventory [Line Items]
Inventory	599	641
Duke Energy Florida [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	341	354
Duke Energy Florida [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	135	166
Duke Energy Florida [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	123	121
Duke Energy Ohio [Member]
Public Utilities, Inventory [Line Items]
Inventory	118	137
Duke Energy Ohio [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	85	84
Duke Energy Ohio [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	17	19
Duke Energy Ohio [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	16	34
Duke Energy Indiana [Member]
Public Utilities, Inventory [Line Items]
Inventory	478	504
Duke Energy Indiana [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	315	312
Duke Energy Indiana [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	161	190
Duke Energy Indiana [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	2	2
Piedmont Natural Gas [Member]
Public Utilities, Inventory [Line Items]
Inventory	29	66
Piedmont Natural Gas [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	2	1
Piedmont Natural Gas [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	$ 27	$ 65

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Organization and Basis of Presentation (Schedule of Excise Taxes) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	$ 91	$ 91
Duke Energy Carolinas [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	9	8
Progress Energy [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	46	47
Duke Energy Progress [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	5	5
Duke Energy Florida [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	41	42
Duke Energy Ohio [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	28	28
Duke Energy Indiana [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	7	8
Piedmont Natural Gas [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	$ 1	$ 1

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Acquisitions and Dispositions - Acquisitions (Narrative) (Details) - Piedmont Natural Gas [Member] - USD ($) $ in Millions		3 Months Ended
	Oct. 03, 2016	Mar. 31, 2017	Mar. 31, 2016
Business Acquisition [Line Items]
Payments to acquire businesses	$ 5,000
Long-term debt assumed	$ 2,002
Business Combination, Integration Related Costs		$ 16	$ 101
Unrealized Losses on Forward-Starting Interest Rate Swaps			93
Business Combination, After Tax Integration Related Costs			63
Interest Expense [Member]
Business Acquisition [Line Items]
Business Combination, Integration Related Costs			$ 100

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Acquisitions and Dispositions - Dispositions (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($)
International Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from Divestiture of Businesses	$ 1,900
DEI Brazil Holdings [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Enterprise Value	1,200
DEI Latin American [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Enterprise Value	1,200
Obligations [Member] | International Energy [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Tax obligations	$ 78

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Acquisitions and Dispositions (Purchase Price Allocation) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016	Oct. 03, 2016
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest [Abstract]
Goodwill	$ 19,425	$ 19,425
Piedmont Natural Gas [Member]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest [Abstract]
Current assets			$ 497
Property, plant and equipment, net			4,714
Goodwill			3,353
Other long-term assets			804
Total assets			9,368
Current liabilities, including current maturities of long-term debt			576
Long-term liabilities			1,790
Long-term debt			2,002
Total liabilities			4,368
Total purchase price			$ 5,000

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Acquisitions and Dispositions (Pro Forma Information) (Details) - Piedmont Natural Gas [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Operating Revenues	$ 5,840
Net income attributable to Duke Energy Corporation	$ 832

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Acquisitions and Dispositions (Discontinued Operations) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income From Discontinued Operations, net of tax	$ 122
International Energy [Member] | Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating Revenues	246
Fuel used in electric generation and purchased power	47
Cost of natural gas	11
Operation, maintenance and other	71
Deprecation and amortization	22
Property and other taxes	3
Other Income and Expenses, net	10
Interest Expense	22
Income before income taxes	80
Income tax benefit	(39)
Income From Discontinued Operations, net of tax	119
Other Disposal Groups [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income From Discontinued Operations, net of tax	3
Previously Remitted Earnings [Member] | International Energy [Member] | Discontinued Operations, Disposed of by Sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income tax benefit	$ (95)

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Acquisitions and Dispositions (Cash Flow Statement) (Details) - International Energy [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)
Operating Activities	$ 85
Investing Activities	$ (9)

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Business Segments (Narrative) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017 USD ($) segment	Mar. 31, 2016 USD ($)	Dec. 31, 2016
Segment Reporting Information [Line Items]
Net Income Attributable to Parent	$ 716	$ 694
Interest Expense	$ 491	489
Duke Energy Carolinas [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | segment	1
Net Income Attributable to Parent	$ 270	271
Interest Expense	$ 103	107
Progress Energy [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | segment	1
Net Income Attributable to Parent	$ 199	209
Interest Expense	$ 206	160
Duke Energy Progress [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | segment	1
Net Income Attributable to Parent	$ 147	137
Interest Expense	$ 82	63
Duke Energy Florida [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | segment	1
Net Income Attributable to Parent	$ 90	110
Interest Expense	$ 70	41
Duke Energy Ohio [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | segment	2
Net Income Attributable to Parent	$ 42	59
Interest Expense	$ 22	20
Duke Energy Indiana [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | segment	1
Net Income Attributable to Parent	$ 91	95
Interest Expense	$ 44	44
Piedmont Natural Gas [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | segment	1
Net Income Attributable to Parent	$ 95	103
Interest Expense	20	17
Other [Member] | Progress Energy [Member]
Segment Reporting Information [Line Items]
Interest Expense	$ 55	56
National Methanol Company [Member] | Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Equity Method Investment, Ownership Percentage	25.00%
SouthStar [Member] | Piedmont Natural Gas [Member]
Segment Reporting Information [Line Items]
Equity Method Investment, Ownership Percentage			15.00%
Net Income Attributable to Parent		$ 7

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Business Segments (Business Segment Data) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Segment Reporting Information [Line Items]
Operating revenues	$ 5,729	$ 5,377
Segment income	716	574
Add back noncontrolling interests	1	3
Income From Discontinued Operations, net of tax		122
Net Income	717	699
Net Income Attributable to Parent	716	694
Segment assets	134,108		$ 132,761
Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	4,939	5,081
Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	648	169
Commercial Renewables [Member]
Segment Reporting Information [Line Items]
Operating revenues	128	114
Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	14	13
Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	5,715	5,364
Operating Segments [Member] | Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	4,947	5,089
Segment income	635	664
Segment assets	115,766
Operating Segments [Member] | Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	670	170
Segment income	133	32
Segment assets	10,866
Operating Segments [Member] | Commercial Renewables [Member]
Segment Reporting Information [Line Items]
Operating revenues	128	114
Segment income	25	26
Segment assets	4,400
Operating Segments [Member] | Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	5,745	5,373
Segment income	793	722
Segment assets	131,032
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	(49)	(25)
Segment assets	178
Intersegment Eliminations [Member] | Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	(8)	(8)
Intersegment Eliminations [Member] | Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	(22)	(1)
Intersegment Eliminations [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	(19)	(16)
Intersegment Eliminations [Member] | Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	(30)	(9)
Corporate, Non-Segment [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	33	29
Segment income	(77)	(148)
Segment assets	2,898
Costs to achieve mergers		74
Duke Energy Ohio [Member]
Segment Reporting Information [Line Items]
Operating revenues	518	516
Segment income	42	57
Income From Discontinued Operations, net of tax		2
Net Income Attributable to Parent	42	59
Segment assets	7,609		$ 7,528
Duke Energy Ohio [Member] | Operating Segments [Member] | Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	337	340
Segment income	24	36
Segment assets	4,856
Duke Energy Ohio [Member] | Operating Segments [Member] | Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	170	170
Segment income	26	31
Segment assets	2,696
Duke Energy Ohio [Member] | Operating Segments [Member] | Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	507	510
Segment income	50	67
Segment assets	7,552
Duke Energy Ohio [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Segment income		(1)
Segment assets	(14)
Duke Energy Ohio [Member] | Corporate, Non-Segment [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	11	6
Segment income	(8)	$ (9)
Segment assets	$ 71

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Business Segments (Schedule of Segment Reporting Information, by Segment) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting Information [Line Items]
Segment income	$ 716	$ 574
Duke Energy Carolinas [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(6)	(17)
Progress Energy [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(43)	(49)
Duke Energy Progress [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(3)	(8)
Duke Energy Florida [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(2)	(4)
Duke Energy Ohio [Member]
Segment Reporting Information [Line Items]
Segment income	42	57
Duke Energy Indiana [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	(2)	(2)
Piedmont Natural Gas [Member] | Other [Member]
Segment Reporting Information [Line Items]
Segment income	$ (4)	$ 6

XML

Regulatory Matters (Narrative) (Details) $ in Millions		1 Months Ended	3 Months Ended
	May 01, 2017 USD ($)	Dec. 31, 2015 USD ($)	Mar. 31, 2017 USD ($) MW	Mar. 31, 2016 USD ($)	Dec. 31, 2016 USD ($)
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net			$ 83,516.0		$ 82,520.0
Generation Facilities To Be Retired Net			508.0		529.0
Electric Domestic Regulated Revenue			$ 4,913.0	$ 5,053.0
Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW			1,738
Public Utilities, Property, Plant and Equipment, Net			$ 419.0
Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			47.00%
Long-term Purchase Commitment, Period			20 years
Sabal Trail Transmission Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			7.50%
Estimated capital cost			$ 3,200.0
Long-term Purchase Commitment, Period			25 years
Constitution Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			24.00%
Estimated Contributions			$ 229.0
Minimum [Member] | Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			5,000.0
Maximum [Member] | Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			$ 5,500.0
Dominion Resources [Member] | Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			48.00%
Southern Company Gas [Member] | Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			5.00%
Spectra Energy [Member] | Sabal Trail Transmission Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			50.00%
NextEra [Member] | Sabal Trail Transmission Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			42.50%
Williams Partners L.P. [Member] | Constitution Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			41.00%
Duke Energy Carolinas [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net			$ 26,951.0		26,762.0
Duke Energy Carolinas [Member] | William States Lee Combined Cycle Facility [Member] | NCEMC [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost of new utility plant, including AFUDC			$ 600.0
Joint owner ownership percentage			13.00%
Progress Energy [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net			$ 30,792.0		30,181.0
Generation Facilities To Be Retired Net			508.0		529.0
Duke Energy Progress [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net			18,561.0		18,387.0
Generation Facilities To Be Retired Net			$ 508.0		529.0
Duke Energy Progress [Member] | Asheville Plant [Member] | Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW			376
Generation Facilities To Be Retired Net			$ 471.0		492.0
Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net			12,228.0		11,790.0
Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net			5,625.0		5,547.0
Electric Domestic Regulated Revenue			337.0	$ 340.0
Duke Energy Ohio [Member] | Regional Transmission Organization Realignment [Member]
Public Utilities, General Disclosures [Line Items]
Exit obligation			90.0		90.0
Regulatory Assets			$ 71.0		71.0
Approved MVP Proposals			17
MISO estimate of Duke Energy Ohio's MVP obligation			$ 2,700.0
Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net			9,985.0		9,924.0
Piedmont Natural Gas [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net			4,907.0		$ 4,814.0
Storm Cost Deferrals [Member] | NCUC [Member] | Duke Energy Progress [Member]
Public Utilities, General Disclosures [Line Items]
Amount of Regulatory Costs Not yet Approved			116.0
Western Carolinas Modernization Plan [Member] | NCUC [Member] | Duke Energy Progress [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			893.0
Hines Chiller Uprate Project [Member] | Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			150.0
Hines Chiller Uprate Project [Member] | FPSC [Member] | Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Approved Rate Increase (Decrease), Amount			19.0
Levy Nuclear Project [Member] | FPSC [Member] | Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Requested Rate Increase (Decrease), Amount			82.0
East Bend Coal Ash Basin Filing [Member] | KPSC [Member] | Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			93.0
2017 Base Rate Case [Member] | PUCO [Member] | Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Requested Rate Increase (Decrease), Amount			$ 15.0
Requested Return on Equity, Percentage			10.40%
Natural Gas Pipeline Extension [Member] | PUCO [Member] | Duke Energy Ohio [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Capital Cost Excluding AFUDC			$ 86.0
Natural Gas Pipeline Extension [Member] | PUCO [Member] | Duke Energy Ohio [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Capital Cost Excluding AFUDC			110.0
Advanced Metering Infrastructure Project [Member] | KPSC [Member] | Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Amount of Regulatory Costs Not yet Approved			10.0
Estimated capital cost			49.0
Accelerated Natural Gas Service Line Replacement Rider [Member] | PUCO [Member] | Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Amount of Regulatory Costs Not yet Approved			240.0
Energy Efficiency and Peak Demand Reduction Program [Member] | PUCO [Member] | Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Electric Domestic Regulated Revenue		$ 20.0
MGP Remediation [Member] | PUCO [Member] | Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets			100.0
Coal Combustion Residual Plan [Member] | IURC [Member] | Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Requested Rate Increase (Decrease), Amount			$ 380.0
Federal Mandate Costs Recovered Through Tracker Mechanism			80.00%
Federally Mandated Costs Recovered In Future Rate Case			20.00%
Percentage of Costs Recovered through Existing Rider			60.00%
Percentage Recovered Through Future Rate Case			40.00%
Interest Rate on Intermediary Debt for Electric Utility Plant Construction			4.73%
Requested Rate Increase (Decrease), Amended, Amount			$ 365.0
FERC Transmission Rates [Member] | Federal Energy Regulatory Commission [Member] | Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage			12.38%
Approved Return on Equity Percentage Adder			0.50%
FERC Complaint [Member] | Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity, Percentage			8.67%
FERC Complaint 1 [Member] | Federal Energy Regulatory Commission [Member] | Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage			10.32%
FERC Complaint 2 [Member] | Federal Energy Regulatory Commission [Member] | Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity, Percentage			9.70%
NCUC IMR Petition Filed October 2016 [Member] | NCUC [Member] | Piedmont Natural Gas [Member]
Public Utilities, General Disclosures [Line Items]
Approved Rate Increase (Decrease), Amount			$ 8.0
NCUC IMR Petition Filed May 2017 [Member] | NCUC [Member] | Piedmont Natural Gas [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Requested Rate Increase (Decrease), Amount	$ 11.6
TPUC Petition Filed IMR November 2016 [Member] | TPUC [Member] | Piedmont Natural Gas [Member]
Public Utilities, General Disclosures [Line Items]
Approved Rate Increase (Decrease), Amount			$ 1.7

XML

Regulatory Matters (Schedule of Net Carrying Value Of Facilities and Megawatt Capacity) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017 USD ($) MW	Dec. 31, 2016 USD ($)
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net	$ 83,516	$ 82,520
Duke Energy Carolinas [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net	26,951	26,762
Progress Energy [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net	30,792	30,181
Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net	12,228	11,790
Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Property, Plant and Equipment, Net	$ 9,985	$ 9,924
Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	1,738
Public Utilities, Property, Plant and Equipment, Net	$ 419
Allen Steam Station Units 1-3 [Member] | Generation Facilities To Be Retired [Member] | Duke Energy Carolinas [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	585
Public Utilities, Property, Plant and Equipment, Net	$ 167
Crystal River Units 1 and 2 [Member] | Generation Facilities To Be Retired [Member] | Progress Energy [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	873
Public Utilities, Property, Plant and Equipment, Net	$ 117
Crystal River Units 1 and 2 [Member] | Generation Facilities To Be Retired [Member] | Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	873
Public Utilities, Property, Plant and Equipment, Net	$ 117
Gallagher Units 2 and 4 [Member] | Generation Facilities To Be Retired [Member] | Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	280
Public Utilities, Property, Plant and Equipment, Net	$ 135

XML

Commitments and Contingencies (Narrative) (Details) gal in Millions	1 Months Ended	3 Months Ended
	Feb. 28, 2014 T gal	Mar. 31, 2017 USD ($) plant Claims	Dec. 31, 2016 USD ($)	Mar. 31, 2014 USD ($)
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual		$ 91,000,000	$ 98,000,000
Progress Energy Merger Shareholder Litigation [Member]
Valuation and Qualifying Accounts [Abstract]
Gain contingency, unrecorded amount		$ 27,000,000
Coal Ash Insurance Coverage Litigation [Member]
Valuation and Qualifying Accounts [Abstract]
Number of NC and SC Plants with Ash Basins | plant		15
NCDEQ State Enforcement Actions [Member]
Valuation and Qualifying Accounts [Abstract]
Number of Plants with No Disputed Facts | plant		7
Number of NC Plants with Ash Basins | plant		14
Number of Plants with Disputed Facts | plant		7
Potential Groundwater Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Number of NC Plants with Ash Basins | plant		14
Goodwill Payment		$ 5,000
Water Bill Stipend Period		25 years
Duke Energy Carolinas [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual		$ 23,000,000	23,000,000
Duke Energy Carolinas [Member] | Potential Groundwater Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual		18,000,000
Duke Energy Carolinas [Member] | Asbestos-related Injuries and Damages Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Asbestos-related injuries and damages reserves		506,000,000	512,000,000
Reinsurance retention policy, excess retention, amount reinsured		814,000,000
Probable insurance recoveries		$ 587,000,000	587,000,000
Duke Energy Carolinas [Member] | Asbestos-related Injuries and Damages Claims [Member] | Non-Malignant Asbestos Claim [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency, pending claims, number | Claims		111
Asbestos-related injuries and damages reserves		$ 29,000,000
Duke Energy Carolinas [Member] | Asbestos-related Injuries and Damages Claims [Member] | Malignant Asbestos Claim [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency, pending claims, number | Claims		58
Asbestos-related injuries and damages reserves		$ 16,000,000
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
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
Progress Energy [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual		57,000,000	59,000,000
Duke Energy Progress [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual		13,000,000	14,000,000
Duke Energy Progress [Member] | Potential Groundwater Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual		4,000,000
Duke Energy Florida [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual		27,000,000	28,000,000
Duke Energy Florida [Member] | Westinghouse Electric Company Litigation [Member]
Valuation and Qualifying Accounts [Abstract]
Gain contingency, unrecorded amount		54,000,000
Loss Contingency, Damages Sought, Original Amount		482,000,000		$ 510,000,000
Loss Contingency, Damages Awarded, Value		30,000,000
Gain Contingency, Dismissed Amount		54,000,000
Loss contingency, damages sought, value		424,000,000
Loss Contingency Damages Awarded and Interest, Value		34,000,000
Duke Energy Florida [Member] | MGP Cost Recovery Action [Member]
Valuation and Qualifying Accounts [Abstract]
Gain contingency, unrecorded amount		43,000,000
Duke Energy Ohio [Member]
Valuation and Qualifying Accounts [Abstract]
Loss Contingency Accrual		4,000,000	$ 4,000,000
Duke Energy Indiana [Member] | Benton County Wind Farm Dispute [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency, damages sought, value		$ 16,000,000

XML

Commitments and Contingencies (Schedule of Environmental Loss Contingencies) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Environmental Matters Details [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	$ 71
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	98	$ 94
Provisions/adjustments	6	10
Cash reductions	(6)	(3)
Ending balance	98	101
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	1	2
Cash reductions	0	(1)
Ending balance	11	11
Progress Energy [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	18	17
Provisions/adjustments		1
Cash reductions	(1)	(2)
Ending balance	17	16
Duke Energy Progress [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	3	3
Cash reductions	0	(1)
Ending balance	3	2
Duke Energy Florida [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	14	14
Provisions/adjustments	1	1
Cash reductions	(1)	(1)
Ending balance	14	14
Duke Energy Ohio [Member]
Environmental Matters Details [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	36
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	59	54
Provisions/adjustments	4
Cash reductions	(4)
Ending balance	59	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	10	12
Provisions/adjustments	(1)	6
Cash reductions	0
Ending balance	9	18
Piedmont Natural Gas [Member]
Environmental Matters Details [Line Items]
Environmental Exit Costs, Reasonably Possible Additional Loss	2
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning balance	1	1
Provisions/adjustments	1
Cash reductions	0
Ending balance	$ 2	$ 1

XML

Commitments and Contingencies (Schedule of Legal Reserves) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Loss Contingencies [Line Items]
Reserves for legal matters	$ 91	$ 98
Duke Energy Carolinas [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	23	23
Progress Energy [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	57	59
Duke Energy Progress [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	13	14
Duke Energy Florida [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	27	28
Duke Energy Ohio [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	4	4
Piedmont Natural Gas [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	$ 2	$ 2

XML

Debt and Credit Facilities (Narrative) (Details) - USD ($)	3 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Debt issuances		$ 1,587,000,000
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size		8,000,000,000	$ 7,500,000,000.0
Parent Company [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size		3,400,000,000
Piedmont Natural Gas [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size		500,000,000	$ 850,000,000
Duke Energy Carolinas [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size		1,100,000,000
Duke Energy Carolinas [Member] | USDOJ [Member] | North Carolina Ash Basins [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Minimum Master Credit Facility Balance Required		250,000,000
Duke Energy Progress [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size		1,000,000,000
Duke Energy Progress [Member] | USDOJ [Member] | North Carolina Ash Basins [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Minimum Master Credit Facility Balance Required		$ 250,000,000
April 2017 Debt Issuance, 3.364% Coupon [Member] | Subsequent Event [Member] | Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt issuances	$ 420,000,000
Interest rate	3.364%
April 2017 Debt Issuance, 3.364% Coupon [Member] | Parent Company [Member] | Subsequent Event [Member] | Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt issuances	$ 420,000,000
Interest rate	3.364%
April 2017 Maturity [Member] | Subsequent Event [Member] | Unsecured Debt [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 400,000,000
April 2017 Maturity [Member] | Parent Company [Member] | Subsequent Event [Member] | Unsecured Debt [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 400,000,000

XML

Debt and Credit Facilities (Summary of Debt Issuances) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Debt issuances	$ 1,587
Current maturities of long-term debt	1,977	$ 2,319
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	404	116
Duke Energy Progress [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	202	452
Duke Energy Florida [Member]
Debt Instrument [Line Items]
Debt issuances	900
Current maturities of long-term debt	319	326
Duke Energy Ohio [Member]
Debt Instrument [Line Items]
Debt issuances	100
Current maturities of long-term debt	1	1
Duke Energy Indiana [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	3	$ 3
Secured Debt [Member] | February 2017 Debt Issuance, 4.120% Coupon [Member]
Debt Instrument [Line Items]
Debt issuances	$ 587
Interest rate	4.12%
First Mortgage [Member] | January 2017 Debt Issuance, 1.850% Coupon [Member]
Debt Instrument [Line Items]
Debt issuances	$ 250
Interest rate	1.85%
First Mortgage [Member] | January 2017 Debt Issuance, 3.200% Coupon [Member]
Debt Instrument [Line Items]
Debt issuances	$ 650
Interest rate	3.20%
First Mortgage [Member] | March 2017 Debt Issuance, 3.700% Coupon [Member]
Debt Instrument [Line Items]
Debt issuances	$ 100
Interest rate	3.70%
First Mortgage [Member] | Duke Energy Florida [Member] | January 2017 Debt Issuance, 1.850% Coupon [Member]
Debt Instrument [Line Items]
Debt issuances	$ 250
Interest rate	1.85%
First Mortgage [Member] | Duke Energy Florida [Member] | January 2017 Debt Issuance, 3.200% Coupon [Member]
Debt Instrument [Line Items]
Debt issuances	$ 650
Interest rate	3.20%
First Mortgage [Member] | Duke Energy Florida [Member] | First Mortgage Bonds Maturing September 2017, 5.800% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	5.80%
Current maturities of long-term debt	$ 250
First Mortgage [Member] | Duke Energy Ohio [Member] | March 2017 Debt Issuance, 3.700% Coupon [Member]
Debt Instrument [Line Items]
Debt issuances	$ 100
Interest rate	3.70%

XML

Debt and Credit Facilities (Summary of Current Maturities of Long-term Debt)(Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 1,977	$ 2,319
Secured Debt [Member] | Secured Debt Maturing June 2017, 2.605% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	2.605%
Current maturities of long-term debt	$ 45
Secured Debt [Member] | Secured Debt Maturing June 2017, 2.455% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	2.455%
Current maturities of long-term debt	$ 34
Other Debt Obligations [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 313
Parent Company [Member] | Unsecured Debt [Member] | Unsecured Debt Maturing August 2017, 1.625% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	1.625%
Current maturities of long-term debt	$ 700
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 404	116
Duke Energy Carolinas [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Maturing January 2018, 5.250% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	5.25%
Current maturities of long-term debt	$ 400
Duke Energy Progress [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 202	452
Duke Energy Progress [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Maturing November 2017, 1.252% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	1.252%
Current maturities of long-term debt	$ 200
Duke Energy Florida [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 319	326
Duke Energy Florida [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Maturing September 2017, 5.800% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	5.80%
Current maturities of long-term debt	$ 250
Duke Energy Ohio [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	1	1
Duke Energy Indiana [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	3	3
Piedmont Natural Gas [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 35	$ 35
Piedmont Natural Gas [Member] | Unsecured Debt [Member] | Unsecured Debt Maturing September 2017, 8.510% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	8.51%
Current maturities of long-term debt	$ 35

XML

Debt and Credit Facilities (Schedule of Line of Credit Facilities) (Details) - Revolving Credit Facility [Member] - USD ($)	Mar. 31, 2017	Dec. 31, 2016
Line of Credit Facility [Line Items]
Facility size	$ 8,000,000,000	$ 7,500,000,000.0
Commercial paper	(3,134,000,000)
Outstanding letters of credit	(71,000,000)
Tax exempt bonds	(81,000,000)
Coal ash set-aside	(500,000,000)
Available capacity	4,214,000,000
Parent Company [Member]
Line of Credit Facility [Line Items]
Facility size	3,400,000,000
Commercial paper	(1,822,000,000)
Outstanding letters of credit	(62,000,000)
Available capacity	1,516,000,000
Duke Energy Carolinas [Member]
Line of Credit Facility [Line Items]
Facility size	1,100,000,000
Commercial paper	(469,000,000)
Outstanding letters of credit	(4,000,000)
Coal ash set-aside	(250,000,000)
Available capacity	377,000,000
Duke Energy Progress [Member]
Line of Credit Facility [Line Items]
Facility size	1,000,000,000
Commercial paper	(402,000,000)
Outstanding letters of credit	(2,000,000)
Coal ash set-aside	(250,000,000)
Available capacity	346,000,000
Duke Energy Florida [Member]
Line of Credit Facility [Line Items]
Facility size	950,000,000
Outstanding letters of credit	(1,000,000)
Available capacity	949,000,000
Duke Energy Ohio [Member]
Line of Credit Facility [Line Items]
Facility size	450,000,000
Commercial paper	(30,000,000)
Available capacity	420,000,000
Duke Energy Indiana [Member]
Line of Credit Facility [Line Items]
Facility size	600,000,000
Commercial paper	(150,000,000)
Tax exempt bonds	(81,000,000)
Available capacity	369,000,000
Piedmont Natural Gas [Member]
Line of Credit Facility [Line Items]
Facility size	500,000,000	$ 850,000,000
Commercial paper	(261,000,000)
Outstanding letters of credit	(2,000,000)
Available capacity	237,000,000
Proceeds Loaned To Subsidiary Registrants [Member] | Parent Company [Member]
Line of Credit Facility [Line Items]
Commercial paper	$ (625,000,000)

XML

Goodwill and Intangible Assets (Details) - USD ($)	Mar. 31, 2017	Dec. 31, 2016
Goodwill [Roll Forward]
Goodwill	$ 19,425,000,000	$ 19,425,000,000
Electric Utilities and Infrastructure [Member]
Goodwill [Roll Forward]
Goodwill	17,379,000,000	17,379,000,000
Gas Utilities and Infrastructure [Member]
Goodwill [Roll Forward]
Goodwill	1,924,000,000	1,924,000,000
Commercial Renewables [Member]
Goodwill [Roll Forward]
Goodwill	122,000,000	122,000,000
Duke Energy Ohio [Member]
Goodwill [Roll Forward]
Goodwill	920,000,000	920,000,000
Accumulated impairment charges	216,000,000	216,000,000
Duke Energy Ohio [Member] | Electric Utilities and Infrastructure [Member]
Goodwill [Roll Forward]
Goodwill	596,000,000	596,000,000
Duke Energy Ohio [Member] | Gas Utilities and Infrastructure [Member]
Goodwill [Roll Forward]
Goodwill	324,000,000	324,000,000
Progress Energy [Member]
Goodwill [Roll Forward]
Goodwill	3,655,000,000	3,655,000,000
Accumulated impairment charges	0	0
Piedmont Natural Gas [Member]
Goodwill [Roll Forward]
Goodwill	49,000,000	49,000,000
Accumulated impairment charges	$ 0	$ 0

XML

Related Party Transactions (Other Revenue and Expense) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Duke Energy Carolinas [Member] | Corporate Governance And Shared Service Expenses [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 199	$ 217
Duke Energy Carolinas [Member] | Indemnification Coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	6	5
Duke Energy Carolinas [Member] | Joint Dispatch Agreement [Member] | Duke Energy Progress [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	16	9
Related party transaction, expenses from transactions with related party	31	41
Duke Energy Carolinas [Member] | Intercompany Natural Gas Transactions [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	1
Progress Energy [Member] | Corporate Governance And Shared Service Expenses [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	169	174
Progress Energy [Member] | Indemnification Coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	10	9
Progress Energy [Member] | Joint Dispatch Agreement [Member] | Duke Energy Carolinas [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	31	41
Related party transaction, expenses from transactions with related party	16	9
Progress Energy [Member] | Intercompany Natural Gas Transactions [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	19
Duke Energy Progress [Member] | Corporate Governance And Shared Service Expenses [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	103	100
Duke Energy Progress [Member] | Indemnification Coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	4	4
Duke Energy Progress [Member] | Joint Dispatch Agreement [Member] | Duke Energy Carolinas [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	31	41
Related party transaction, expenses from transactions with related party	16	9
Duke Energy Progress [Member] | Intercompany Natural Gas Transactions [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	19
Duke Energy Florida [Member] | Corporate Governance And Shared Service Expenses [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	66	74
Duke Energy Florida [Member] | Indemnification Coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	6	5
Duke Energy Ohio [Member] | Corporate Governance And Shared Service Expenses [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	90	85
Duke Energy Ohio [Member] | Indemnification Coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	1	1
Duke Energy Indiana [Member] | Corporate Governance And Shared Service Expenses [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	90	94
Duke Energy Indiana [Member] | Indemnification Coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	2	2
Piedmont Natural Gas [Member] | Corporate Governance And Shared Service Expenses [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	6
Piedmont Natural Gas [Member] | Indemnification Coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	1
Piedmont Natural Gas [Member] | Intercompany Natural Gas Transactions [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	$ 20
Piedmont Natural Gas [Member] | Intercompany Natural Gas Transactions [Member] | Duke Energy Carolinas [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party		1
Piedmont Natural Gas [Member] | Intercompany Natural Gas Transactions [Member] | Duke Energy Progress [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party		$ 19

XML

Related Party Transactions (Equity Method Investments) (Details) - Piedmont Natural Gas [Member] - Equity Method Investee [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	$ 2		$ 2
Related party transaction, expenses from transactions with related party	6	$ 7
Cardinal Pipeline Company, LLC [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	2	2
Pine Needle LNG Company, LLC [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	2	3
Hardy Storage Company, LLC [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 2	$ 2

XML

Related Party Transactions (Intercompany Income Taxes) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Duke Energy Carolinas [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	$ 109	$ 163
Intercompany income tax payable	250	247
Progress Energy [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	2	106
Intercompany income tax payable	316	348
Duke Energy Progress [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	6	5
Intercompany income tax payable	244	227
Duke Energy Florida [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	2	5
Intercompany income tax payable	77	125
Duke Energy Ohio [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	88	129
Intercompany income tax payable	64	63
Duke Energy Indiana [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	88	114
Intercompany income tax payable	75	74
Piedmont Natural Gas [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	7	7
Intercompany income tax payable	3	8
Income Taxes [Member] | Affiliated Entity [Member] | Duke Energy Carolinas [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	19	1
Income Taxes [Member] | Affiliated Entity [Member] | Progress Energy [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	139
Intercompany income tax payable		37
Income Taxes [Member] | Affiliated Entity [Member] | Duke Energy Progress [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	47
Intercompany income tax payable		90
Income Taxes [Member] | Affiliated Entity [Member] | Duke Energy Florida [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	48	37
Income Taxes [Member] | Affiliated Entity [Member] | Duke Energy Ohio [Member]
Related Party Transaction [Line Items]
Intercompany income tax receivable	8
Intercompany income tax payable		1
Income Taxes [Member] | Affiliated Entity [Member] | Duke Energy Indiana [Member]
Related Party Transaction [Line Items]
Intercompany income tax payable	23	3
Income Taxes [Member] | Affiliated Entity [Member] | Piedmont Natural Gas [Member]
Related Party Transaction [Line Items]
Intercompany income tax payable	$ 44	$ 38

XML

Derivatives and Hedging (Notional Amounts of Derivative Instruments) (Details) Mcf in Millions, $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2017 USD ($) GWh Mcf	Mar. 31, 2016 USD ($)	Dec. 31, 2016 USD ($) GWh Mcf
Commodity Contracts [Member] | Electricity [Member]
Derivative [Line Items]
Notional amount, energy measure, in gigawatt-hours | GWh	184		147
Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Mcf	817		890
Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 1,677
Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	750
Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	927
Variable Interest Entity, Primary Beneficiary [Member] | Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 750		$ 750
Piedmont Natural Gas [Member]
Derivative [Line Items]
Notional amount		$ 1,400
Gain (Loss) on Interest Rate Derivative Instruments Not Designated as Hedging Instruments		$ 93
Duke Energy Carolinas [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Mcf	85		91
Duke Energy Carolinas [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 400
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 400
Progress Energy [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Mcf	228		269
Progress Energy [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 500
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 500
Duke Energy Progress [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Mcf	105		118
Duke Energy Progress [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 250
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 250
Duke Energy Florida [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Mcf	123		151
Duke Energy Florida [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 250
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	250
Duke Energy Ohio [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	27
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 27
Duke Energy Indiana [Member] | Commodity Contracts [Member] | Electricity [Member]
Derivative [Line Items]
Notional amount, energy measure, in gigawatt-hours | GWh	184		147
Duke Energy Indiana [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Mcf			1
Piedmont Natural Gas [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume, in millions of decatherms | Mcf	504		529

XML

Derivatives and Hedging (Location and Fair Value Amounts of Derivatives Reflected in the Condensed Consolidated Balance Sheets) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	$ 83	$ 162
Location and fair value amounts of derivatives (Liability)	216	252
Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	60	111
Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	23	51
Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	41	52
Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	175	200
Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	63	140
Location and fair value amounts of derivatives (Liability)	177	209
Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	22
Location and fair value amounts of derivatives (Liability)	39	43
Designated As Hedging Instrument [Member] | Interest Rate Contracts [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	18	19
Designated As Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	8	8
Designated As Hedging Instrument [Member] | Interest Rate Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	9	8
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	58	108
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	5	32
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	32	43
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	145	166
Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	3
Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1	1
Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	21	26
Duke Energy Carolinas [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	17	33
Location and fair value amounts of derivatives (Liability)	14	16
Duke Energy Carolinas [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	16	23
Duke Energy Carolinas [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	10
Duke Energy Carolinas [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	14	16
Duke Energy Carolinas [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	17	33
Location and fair value amounts of derivatives (Liability)	4	1
Duke Energy Carolinas [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	10	15
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	16	23
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	10
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	4	1
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	10	15
Progress Energy [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	34	85
Location and fair value amounts of derivatives (Liability)	34	25
Progress Energy [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	32	64
Progress Energy [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	21
Progress Energy [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	17	12
Progress Energy [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	17	13
Progress Energy [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	32	82
Location and fair value amounts of derivatives (Liability)	28	19
Progress Energy [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	3
Location and fair value amounts of derivatives (Liability)	6	6
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	30	61
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	21
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	17	12
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	11	7
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	3
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	6	6
Duke Energy Progress [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	46
Location and fair value amounts of derivatives (Liability)	10	7
Duke Energy Progress [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	19	36
Duke Energy Progress [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	10
Duke Energy Progress [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1
Duke Energy Progress [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	9	7
Duke Energy Progress [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	45
Location and fair value amounts of derivatives (Liability)	5	1
Duke Energy Progress [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		1
Location and fair value amounts of derivatives (Liability)	5	6
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	19	35
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	10
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	4	1
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		1
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	5	6
Duke Energy Florida [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	14	39
Location and fair value amounts of derivatives (Liability)	19	12
Duke Energy Florida [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	13	28
Duke Energy Florida [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	11
Duke Energy Florida [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	17	12
Duke Energy Florida [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	2
Duke Energy Florida [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	12	37
Location and fair value amounts of derivatives (Liability)	18	12
Duke Energy Florida [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	2
Location and fair value amounts of derivatives (Liability)	1
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	11	26
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	11
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	17	12
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	2
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1
Duke Energy Ohio [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	5
Location and fair value amounts of derivatives (Liability)	5	6
Duke Energy Ohio [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		4
Duke Energy Ohio [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	1
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] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	4	5
Duke Energy Ohio [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	5
Duke Energy Ohio [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	5	6
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		4
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	1
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1	1
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	4	5
Duke Energy Indiana [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	9	16
Location and fair value amounts of derivatives (Liability)		2
Duke Energy Indiana [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	9	16
Duke Energy Indiana [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		2
Duke Energy Indiana [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	9	16
Location and fair value amounts of derivatives (Liability)		2
Duke Energy Indiana [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	9	16
Duke Energy Indiana [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		2
Piedmont Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	3
Location and fair value amounts of derivatives (Liability)	145	187
Piedmont Natural Gas [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	3
Piedmont Natural Gas [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	14	35
Piedmont Natural Gas [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	131	152
Piedmont Natural Gas [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	3
Location and fair value amounts of derivatives (Liability)	145	187
Piedmont Natural Gas [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	3
Piedmont Natural Gas [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	14	35
Piedmont Natural Gas [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	$ 131	$ 152

XML

Derivatives and Hedging (Schedule of Offsetting Assets) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	$ 83	$ 162
Net amounts recognized on the Condensed Consolidated Balance Sheet	83	162
Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	60	111
Gross amounts offset	(7)	(11)
Net amounts recognized on the Condensed Consolidated Balance Sheet	53	100
Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	23	51
Gross amounts offset	(2)	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	21	49
Duke Energy Carolinas [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	17	33
Net amounts recognized on the Condensed Consolidated Balance Sheet	17	33
Duke Energy Carolinas [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	16	23
Net amounts recognized on the Condensed Consolidated Balance Sheet	16	23
Duke Energy Carolinas [Member] | Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	1	10
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet		9
Progress Energy [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	34	85
Net amounts recognized on the Condensed Consolidated Balance Sheet	34	85
Progress Energy [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	32	64
Gross amounts offset	(7)	(11)
Net amounts recognized on the Condensed Consolidated Balance Sheet	25	53
Progress Energy [Member] | Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2	21
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	20
Duke Energy Progress [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	20	46
Net amounts recognized on the Condensed Consolidated Balance Sheet	20	46
Duke Energy Progress [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	19	36
Gross amounts offset	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	18	36
Duke Energy Progress [Member] | Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	1	10
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet		9
Duke Energy Florida [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	14	39
Net amounts recognized on the Condensed Consolidated Balance Sheet	14	39
Duke Energy Florida [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	13	28
Gross amounts offset	(6)	(11)
Net amounts recognized on the Condensed Consolidated Balance Sheet	7	17
Duke Energy Florida [Member] | Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	1	11
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	11
Duke Energy Ohio [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	1	5
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	5
Duke Energy Ohio [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized		4
Net amounts recognized on the Condensed Consolidated Balance Sheet		4
Duke Energy Ohio [Member] | Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	1	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	1
Duke Energy Indiana [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	9	16
Net amounts recognized on the Condensed Consolidated Balance Sheet	9	16
Duke Energy Indiana [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	9	16
Net amounts recognized on the Condensed Consolidated Balance Sheet	9	16
Piedmont Natural Gas [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2	3
Net amounts recognized on the Condensed Consolidated Balance Sheet	2	3
Piedmont Natural Gas [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2	3
Net amounts recognized on the Condensed Consolidated Balance Sheet	$ 2	$ 3

XML

Derivatives and Hedging (Schedule of Offsetting Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	$ 216	$ 252
Net amounts recognized on the Condensed Consolidated Balance Sheet	216	252
Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	41	52
Gross amounts offset	(7)	(11)
Net amounts recognized on the Condensed Consolidated Balance Sheet	34	41
Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	175	200
Gross amounts offset	(2)	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	173	198
Duke Energy Carolinas [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	14	16
Net amounts recognized on the Condensed Consolidated Balance Sheet	14	16
Duke Energy Carolinas [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	14	16
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	13	15
Progress Energy [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	34	25
Net amounts recognized on the Condensed Consolidated Balance Sheet	34	25
Progress Energy [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	17	12
Gross amounts offset	(7)	(11)
Net amounts recognized on the Condensed Consolidated Balance Sheet	10	1
Progress Energy [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	17	13
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	16	12
Duke Energy Progress [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	10	7
Net amounts recognized on the Condensed Consolidated Balance Sheet	10	7
Duke Energy Progress [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	1
Gross amounts offset	(1)
Duke Energy Progress [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	9	7
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	8	6
Duke Energy Florida [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	19	12
Net amounts recognized on the Condensed Consolidated Balance Sheet	19	12
Duke Energy Florida [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	17	12
Gross amounts offset	(6)	(11)
Net amounts recognized on the Condensed Consolidated Balance Sheet	11	1
Duke Energy Florida [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	2
Net amounts recognized on the Condensed Consolidated Balance Sheet	2
Duke Energy Ohio [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	5	6
Net amounts recognized on the Condensed Consolidated Balance Sheet	5	6
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	4	5
Net amounts recognized on the Condensed Consolidated Balance Sheet	4	5
Duke Energy Indiana [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized		2
Net amounts recognized on the Condensed Consolidated Balance Sheet		2
Duke Energy Indiana [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized		2
Net amounts recognized on the Condensed Consolidated Balance Sheet		2
Piedmont Natural Gas [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	145	187
Net amounts recognized on the Condensed Consolidated Balance Sheet	145	187
Piedmont Natural Gas [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	14	35
Net amounts recognized on the Condensed Consolidated Balance Sheet	14	35
Piedmont Natural Gas [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	131	152
Net amounts recognized on the Condensed Consolidated Balance Sheet	$ 131	$ 152

XML

Derivatives and Hedging (Derivative Instruments with Credit-Risk Related Contingent Features and Cash Collateral) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
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	$ 40	$ 34
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	40	34
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	14	16
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	14	16
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	25	18
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	25	18
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	9	6
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	9	6
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	17	12
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	$ 17	$ 12

XML

Investments in Debt and Equity Securities (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Schedule of Trading Securities and Other Trading Assets [Line Items]
Trading Securities	$ 5	$ 5
Piedmont Natural Gas [Member]
Schedule of Trading Securities and Other Trading Assets [Line Items]
Trading Securities	$ 5	$ 5

XML

Investments in Debt and Equity Securities (Available-For-Sale Investments) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	$ 2,320	$ 2,156
Gross Unrealized Holding Losses	57	88
Estimated Fair Value	6,744	6,554
Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2,273	2,115
Gross Unrealized Holding Losses	54	83
Estimated Fair Value	6,391	6,184
Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	114	111
Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2,250	2,092
Gross Unrealized Holding Losses	32	54
Estimated Fair Value	4,284	4,106
Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	10	10
Gross Unrealized Holding Losses	5	8
Estimated Fair Value	576	528
Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	3	3
Gross Unrealized Holding Losses	6	10
Estimated Fair Value	336	331
Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	10	10
Gross Unrealized Holding Losses	8	8
Estimated Fair Value	949	984
Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Losses	3	3
Estimated Fair Value	132	124
Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	47	41
Gross Unrealized Holding Losses	3	5
Estimated Fair Value	353	370
Other Classification [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	18	25
Other Classification [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	44	38
Estimated Fair Value	106	104
Other Classification [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1	1
Gross Unrealized Holding Losses		1
Estimated Fair Value	60	66
Other Classification [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	2
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	84	82
Other Classification [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Losses		1
Estimated Fair Value	43	51
Other Classification [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Losses	2	2
Estimated Fair Value	42	42
Duke Energy Carolinas [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,238	1,165
Gross Unrealized Holding Losses	29	45
Estimated Fair Value	3,395	3,261
Duke Energy Carolinas [Member] | Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,238	1,165
Gross Unrealized Holding Losses	28	44
Estimated Fair Value	3,392	3,258
Duke Energy Carolinas [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	20	18
Duke Energy Carolinas [Member] | Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,229	1,157
Gross Unrealized Holding Losses	15	28
Estimated Fair Value	2,366	2,245
Duke Energy Carolinas [Member] | Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	5	5
Gross Unrealized Holding Losses	4	6
Estimated Fair Value	388	354
Duke Energy Carolinas [Member] | Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1	1
Gross Unrealized Holding Losses	1	2
Estimated Fair Value	67	67
Duke Energy Carolinas [Member] | Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	3	2
Gross Unrealized Holding Losses	5	5
Estimated Fair Value	431	458
Duke Energy Carolinas [Member] | Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Losses	3	3
Estimated Fair Value	120	116
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	1,037	952
Gross Unrealized Holding Losses	26	39
Estimated Fair Value	3,057	2,991
Progress Energy [Member] | Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,035	950
Gross Unrealized Holding Losses	26	39
Estimated Fair Value	2,999	2,926
Progress Energy [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	94	93
Progress Energy [Member] | Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1,021	935
Gross Unrealized Holding Losses	17	26
Estimated Fair Value	1,918	1,861
Progress Energy [Member] | Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	5	5
Gross Unrealized Holding Losses	1	2
Estimated Fair Value	188	174
Progress Energy [Member] | Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	2
Gross Unrealized Holding Losses	5	8
Estimated Fair Value	269	264
Progress Energy [Member] | Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	7	8
Gross Unrealized Holding Losses	3	3
Estimated Fair Value	518	526
Progress Energy [Member] | Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	12	8
Progress Energy [Member] | Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	2
Estimated Fair Value	58	65
Progress Energy [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	12	21
Progress Energy [Member] | Other Classification [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	2
Estimated Fair Value	46	44
Duke Energy Progress [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	783	715
Gross Unrealized Holding Losses	21	32
Estimated Fair Value	2,275	2,214
Duke Energy Progress [Member] | Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	783	715
Gross Unrealized Holding Losses	21	32
Estimated Fair Value	2,274	2,213
Duke Energy Progress [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	43	45
Duke Energy Progress [Member] | Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	772	704
Gross Unrealized Holding Losses	13	21
Estimated Fair Value	1,541	1,505
Duke Energy Progress [Member] | Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	4	4
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	131	120
Duke Energy Progress [Member] | Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	2
Gross Unrealized Holding Losses	5	8
Estimated Fair Value	268	263
Duke Energy Progress [Member] | Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	5	5
Gross Unrealized Holding Losses	2	2
Estimated Fair Value	284	275
Duke Energy Progress [Member] | Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	7	5
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	254	237
Gross Unrealized Holding Losses	5	7
Estimated Fair Value	772	761
Duke Energy Florida [Member] | Ndtf [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	252	235
Gross Unrealized Holding Losses	5	7
Estimated Fair Value	725	713
Duke Energy Florida [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	51	48
Duke Energy Florida [Member] | Ndtf [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	249	231
Gross Unrealized Holding Losses	4	5
Estimated Fair Value	377	356
Duke Energy Florida [Member] | Ndtf [Member] | Corporate Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	1	1
Gross Unrealized Holding Losses		1
Estimated Fair Value	57	54
Duke Energy Florida [Member] | Ndtf [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	1	1
Duke Energy Florida [Member] | Ndtf [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	3
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	234	251
Duke Energy Florida [Member] | Ndtf [Member] | Other Debt Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	5	3
Duke Energy Florida [Member] | Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	2
Estimated Fair Value	47	48
Duke Energy Florida [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	1	4
Duke Energy Florida [Member] | Other Classification [Member] | Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	2	2
Estimated Fair Value	46	44
Duke Energy Indiana [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	38	33
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	115	110
Duke Energy Indiana [Member] | Other Classification [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	38	33
Gross Unrealized Holding Losses	1	1
Estimated Fair Value	115	110
Duke Energy Indiana [Member] | Other Classification [Member] | Equity Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Gross Unrealized Holding Gains	38	33
Estimated Fair Value	84	79
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 Losses	1	1
Estimated Fair Value	28	28
Duke Energy Indiana [Member] | Other Classification [Member] | US Treasury and Government [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated Fair Value	$ 1	$ 1

XML

Investments in Debt and Equity Securities (Maturities) (Details) $ in Millions	Mar. 31, 2017 USD ($)
Debt Instrument [Line Items]
Due in one year or less	$ 82
Due after one through five years	640
Due after five through 10 years	514
Due after 10 years	986
Total	2,222
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Due in one year or less	2
Due after one through five years	221
Due after five through 10 years	269
Due after 10 years	517
Total	1,009
Progress Energy [Member]
Debt Instrument [Line Items]
Due in one year or less	72
Due after one through five years	355
Due after five through 10 years	189
Due after 10 years	417
Total	1,033
Duke Energy Progress [Member]
Debt Instrument [Line Items]
Due in one year or less	17
Due after one through five years	215
Due after five through 10 years	142
Due after 10 years	316
Total	690
Duke Energy Florida [Member]
Debt Instrument [Line Items]
Due in one year or less	55
Due after one through five years	140
Due after five through 10 years	47
Due after 10 years	101
Total	343
Duke Energy Indiana [Member]
Debt Instrument [Line Items]
Due in one year or less	2
Due after one through five years	15
Due after five through 10 years	9
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
	Mar. 31, 2017	Mar. 31, 2016
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	$ 93	$ 54
Realized losses	62	50
Duke Energy Carolinas [Member]
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	66	34
Realized losses	40	37
Progress Energy [Member]
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	27	19
Realized losses	21	13
Duke Energy Progress [Member]
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	24	15
Realized losses	19	11
Duke Energy Florida [Member]
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]
Realized gains	3	4
Realized losses	$ 2	$ 2

XML

Fair Value Measurements (Fair Value Measurement Amounts for Assets and Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	$ 83	$ 162
Total assets	6,832	6,716
Derivative liabilities	(216)	(252)
Net assets (liabilities)	6,616	6,464
Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	2	5
Total assets	4,982	4,845
Derivative liabilities	0	(2)
Net assets (liabilities)	4,982	4,843
Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	71	136
Total assets	1,758	1,768
Derivative liabilities	(71)	(63)
Net assets (liabilities)	1,687	1,705
Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	10	21
Total assets	15	26
Derivative liabilities	(145)	(187)
Net assets (liabilities)	(130)	(161)
Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Alternative Investments, Fair Value Disclosure	77	77
Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Alternative Investments, Fair Value Disclosure	77	77
Investments	4,284	4,106
Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	4,207	4,029
Equity Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	110	104
Equity Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	110	104
Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	2,107	2,078
Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	602	632
Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,505	1,446
Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	248	266
Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	61	75
Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	182	186
Debt Securities [Member] | Other Classification [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	5	5
Duke Energy Carolinas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	17	33
Total assets	3,412	3,294
Derivative liabilities	(14)	(16)
Net assets (liabilities)	3,398	3,278
Duke Energy Carolinas [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	0
Total assets	2,435	2,346
Net assets (liabilities)	2,435	2,346
Duke Energy Carolinas [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	17	33
Total assets	897	868
Derivative liabilities	(14)	(16)
Net assets (liabilities)	883	852
Duke Energy Carolinas [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	3	3
Net assets (liabilities)	3	3
Duke Energy Carolinas [Member] | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Alternative Investments, Fair Value Disclosure	77	77
Duke Energy Carolinas [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Alternative Investments, Fair Value Disclosure	77	77
Investments	2,366	2,245
Duke Energy Carolinas [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	2,289	2,168
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,026	1,013
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	146	178
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	880	835
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	34	85
Total assets	3,091	3,076
Derivative liabilities	(34)	(25)
Net assets (liabilities)	3,057	3,051
Progress Energy [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	0
Total assets	2,386	2,336
Net assets (liabilities)	2,386	2,336
Progress Energy [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	34	85
Total assets	705	740
Derivative liabilities	(34)	(25)
Net assets (liabilities)	671	715
Progress Energy [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,918	1,861
Progress Energy [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,918	1,861
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,081	1,065
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	456	454
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	625	611
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	58	65
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	12	21
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	46	44
Duke Energy Progress [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	20	46
Total assets	2,295	2,260
Derivative liabilities	(10)	(7)
Net assets (liabilities)	2,285	2,253
Duke Energy Progress [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	0
Total assets	1,763	1,713
Net assets (liabilities)	1,763	1,713
Duke Energy Progress [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	20	46
Total assets	532	547
Derivative liabilities	(10)	(7)
Net assets (liabilities)	522	540
Duke Energy Progress [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,541	1,505
Duke Energy Progress [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1,541	1,505
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	733	708
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	221	207
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	512	501
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	14	39
Total assets	786	800
Derivative liabilities	(19)	(12)
Net assets (liabilities)	767	788
Duke Energy Florida [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	613	607
Net assets (liabilities)	613	607
Duke Energy Florida [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	14	39
Total assets	173	193
Derivative liabilities	(19)	(12)
Net assets (liabilities)	154	181
Duke Energy Florida [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	377	356
Duke Energy Florida [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	377	356
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	348	357
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	235	247
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	113	110
Duke Energy Florida [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	47	48
Duke Energy Florida [Member] | Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1	4
Duke Energy Florida [Member] | Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	46	44
Duke Energy Ohio [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	1	5
Derivative liabilities	(5)	(6)
Net assets (liabilities)	(4)	(1)
Duke Energy Ohio [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative liabilities	(5)	(6)
Net assets (liabilities)	(5)	(6)
Duke Energy Ohio [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	1	5
Net assets (liabilities)	1	5
Duke Energy Indiana [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	9	16
Total assets		126
Derivative liabilities		(2)
Net assets (liabilities)	124	124
Duke Energy Indiana [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	0
Total assets		79
Derivative liabilities		(2)
Net assets (liabilities)	84	77
Duke Energy Indiana [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets		31
Net assets (liabilities)	31	31
Duke Energy Indiana [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	9	16
Total assets		16
Net assets (liabilities)	9	16
Duke Energy Indiana [Member] | Equity Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	84	79
Duke Energy Indiana [Member] | Equity Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	84	79
Duke Energy Indiana [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	31	31
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	31
Piedmont Natural Gas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	2	3
Total assets	7	8
Derivative liabilities	(145)	(187)
Net assets (liabilities)	(138)	(179)
Piedmont Natural Gas [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	2	3
Total assets	7	8
Net assets (liabilities)	7	8
Piedmont Natural Gas [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative liabilities	(145)	(187)
Net assets (liabilities)	(145)	(187)
Piedmont Natural Gas [Member] | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	4	4
Piedmont Natural Gas [Member] | Equity Securities [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	4	4
Piedmont Natural Gas [Member] | Debt Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	1	1
Piedmont Natural Gas [Member] | Debt Securities [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments	$ 1	$ 1

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
	Mar. 31, 2017	Mar. 31, 2016
Derivatives (net)
Beginning balance	$ (166)	$ 10
Settlements	(9)	(7)
Total amount included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	40	(1)
Ending balance	(135)	2
Investments and Derivatives, Net
Beginning balance	(161)	15
Sales		(1)
Settlements	(9)	(7)
Total amount included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	40	(1)
Ending balance	(130)	6
Investments [Member]
Investments
Beginning balance	5	5
Sales		(1)
Ending balance	5	4
Duke Energy Ohio [Member]
Derivatives (net)
Beginning balance	5	3
Settlements	(1)	(2)
Total amount included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(3)	(1)
Ending balance	1
Duke Energy Indiana [Member]
Derivatives (net)
Beginning balance	16	7
Settlements	(7)	(5)
Ending balance	9	2
Piedmont Natural Gas [Member]
Derivatives (net)
Beginning balance	(187)	(149)
Total gains and settlements	42	23
Ending balance	$ (145)	$ (126)

XML

Fair Value Measurements (Quantitative Level 3 Fair Value Disclosure - Assets) (Details) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2017 USD ($) $ / MWh	Dec. 31, 2016 USD ($) $ / MWh	Mar. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net derivative asset (liability)	$ (135)	$ (166)	$ 2	$ 10
Duke Energy Ohio [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net derivative asset (liability)	1	5		3
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | Market Approach Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net derivative asset (liability)	$ 1	$ 5
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | Minimum [Member] | Market Approach Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Input Price Per Unit | $ / MWh	0.23	0.77
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | Maximum [Member] | Market Approach Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Input Price Per Unit | $ / MWh	2.02	3.52
Duke Energy Indiana [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net derivative asset (liability)	$ 9	$ 16	$ 2	$ 7
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | Market Approach Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net derivative asset (liability)	$ 9	$ 16
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | Minimum [Member] | Market Approach Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Input Price Per Unit | $ / MWh	(1.08)	(0.83)
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | Maximum [Member] | Market Approach Valuation Technique [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair Value Input Price Per Unit | $ / MWh	5.33	9.32

XML

Fair Value Measurements (Quantitative Level 3 Fair Value Disclosure - Liabilities) (Details) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2017 USD ($) $ / MMBTU	Dec. 31, 2016 USD ($) $ / MMBTU	Mar. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Net derivative asset (liability)	$ (135)	$ (166)	$ 2	$ 10
Piedmont Natural Gas [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Net derivative asset (liability)	(145)	(187)	$ (126)	$ (149)
Derivative Financial Instruments, Liabilities [Member] | Discounted Cash Flow [Member] | Piedmont Natural Gas [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Net derivative asset (liability)	$ (145)	$ (187)
Derivative Financial Instruments, Liabilities [Member] | Minimum [Member] | Discounted Cash Flow [Member] | Piedmont Natural Gas [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair Value Input Price Per Unit | $ / MMBTU	2.08	2.31
Derivative Financial Instruments, Liabilities [Member] | Maximum [Member] | Discounted Cash Flow [Member] | Piedmont Natural Gas [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair Value Input Price Per Unit | $ / MMBTU	3.57	4.18

XML

Fair Value Measurements (Additional Fair Value Disclosure) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 48,998	$ 47,895
Long-term debt, fair value	50,480	49,161
Duke Energy Carolinas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	9,491	9,603
Long-term debt, fair value	10,405	10,494
Progress Energy [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	18,148	17,541
Long-term debt, fair value	19,742	19,107
Duke Energy Progress [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	6,761	7,011
Long-term debt, fair value	7,103	7,357
Duke Energy Florida [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	6,981	6,125
Long-term debt, fair value	7,596	6,728
Duke Energy Ohio [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	1,977	1,884
Long-term debt, fair value	2,122	2,020
Duke Energy Indiana [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	3,784	3,786
Long-term debt, fair value	4,292	4,260
Piedmont Natural Gas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	1,821	1,821
Long-term debt, fair value	$ 1,954	$ 1,933

XML

Variable Interest Entities (Narrative) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017 USD ($)
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	$ 1,587
Cinergy Receivables [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Percent of proceeds received as cash	75.00%
Percent of proceeds received as subordinated note	25.00%
Minimum equity balance required by Cinergy Receivables	$ 3
Duke American Transmission Company [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	50.00%
Pioneer Transmission [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	50.00%
OVEC [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	9.00%
Duke Energy Florida [Member]
Variable Interest Entities [Line Items]
Debt Instrument, Face Amount	$ 900
Duke Energy Florida [Member] | DEFPF [Member] | Variable Interest Entity, Primary Beneficiary [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	$ 100
Duke Energy Ohio [Member] | Cinergy Receivables [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Fixed interest rate added to LIBOR to compute variable rate	1.00%
Duke Energy Indiana [Member] | Cinergy Receivables [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Fixed interest rate added to LIBOR to compute variable rate	1.00%

XML

Variable Interest Entities (Schedule of Accounts Receivable Securitizations) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Variable Interest Entities [Line Items]
Long-Term Debt	$ 47,021	$ 45,576
Duke Energy Carolinas [Member]
Variable Interest Entities [Line Items]
Long-Term Debt	8,787	9,187
Duke Energy Progress [Member]
Variable Interest Entities [Line Items]
Long-Term Debt	6,409	6,409
Duke Energy Florida [Member]
Variable Interest Entities [Line Items]
Long-Term Debt	$ 6,662	5,799
Cinergy Receivables [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Line of Credit Facility, Expiration Date	Dec. 01, 2018
Facility size	$ 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
Facility size	$ 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
Facility size	$ 300
Long-Term Debt	$ 300	300
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
Facility size	$ 225
Long-Term Debt	$ 225	$ 225

XML

Variable Interest Entities (Schedule of Consolidated VIEs) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current Assets: Regulatory assets	$ 1,031	$ 1,023
Current Assets: Other	425	458
Other Noncurrent Assets: Regulatory assets	12,838	12,878
Property, plant and equipment, cost	123,301	121,397
Accumulated depreciation and amortization	(40,293)	(39,406)
Current Liabilities: Other	1,570	2,044
Current maturities of long-term debt	1,977	2,319
Long-Term Debt	47,021	45,576
Deferred income taxes	14,443	14,155
Noncurrent Liabilities: Other	1,707	1,753
Duke Energy Carolinas [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current Assets: Regulatory assets	233	238
Current Assets: Other	65	37
Other Noncurrent Assets: Regulatory assets	3,098	3,159
Property, plant and equipment, cost	41,600	41,127
Accumulated depreciation and amortization	(14,649)	(14,365)
Current Liabilities: Other	345	468
Current maturities of long-term debt	404	116
Long-Term Debt	8,787	9,187
Deferred income taxes	6,668	6,544
Noncurrent Liabilities: Other	595	607
Duke Energy Progress [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current Assets: Regulatory assets	187	188
Current Assets: Other	102	57
Other Noncurrent Assets: Regulatory assets	3,338	3,243
Property, plant and equipment, cost	28,769	28,419
Accumulated depreciation and amortization	(10,716)	(10,561)
Current Liabilities: Other	294	365
Current maturities of long-term debt	202	452
Long-Term Debt	6,409	6,409
Deferred income taxes	3,453	3,323
Noncurrent Liabilities: Other	49	51
Duke Energy Florida [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current Assets: Regulatory assets	260	213
Current Assets: Other	104	125
Other Noncurrent Assets: Regulatory assets	2,476	2,480
Property, plant and equipment, cost	17,122	16,434
Accumulated depreciation and amortization	(4,894)	(4,644)
Current Liabilities: Other	309	352
Current maturities of long-term debt	319	326
Long-Term Debt	6,662	5,799
Deferred income taxes	2,800	2,694
Noncurrent Liabilities: Other	104	105
DEFPF [Member] | Duke Energy Florida [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Receivables of VIEs	4	6
Current Assets: Regulatory assets	53	50
Current Assets: Other	14	53
Other Noncurrent Assets: Regulatory assets	1,131	1,142
Current Liabilities: Other	3	17
Current maturities of long-term debt	55	62
Long-Term Debt	1,189	1,217
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	300
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]
Current Assets: Other	336	223
Property, plant and equipment, cost	3,671	3,419
Accumulated depreciation and amortization	(448)	(453)
Current maturities of long-term debt	227	198
Long-Term Debt	1,645	1,097
Deferred income taxes	321	275
Noncurrent Liabilities: Other	$ 251	$ 252

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Variable Interest Entities (Schedule of Non-Consolidated VIEs) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Variable Interest Entities [Line Items]
Other noncurrent assets	$ 2,754	$ 2,769
Taxes accrued	363	384
Current Liabilities: Other	1,570	2,044
Deferred income taxes	14,443	14,155
Noncurrent Liabilities: Other	1,707	1,753
Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	938	751
Other noncurrent assets	12	12
Total assets	950	763
Taxes accrued	23
Current Liabilities: Other	2	3
Deferred income taxes	(7)
Noncurrent Liabilities: Other	13	13
Total liabilities	31	16
Net assets	919	747
Pipeline Investments [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	673	487
Other noncurrent assets	12	12
Total assets	685	499
Taxes accrued	23
Deferred income taxes	(7)
Total liabilities	16
Net assets	669	499
Renewables [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	173	174
Total assets	173	174
Net assets	173	174
Other VIEs [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	92	90
Total assets	92	90
Current Liabilities: Other	2	3
Noncurrent Liabilities: Other	13	13
Total liabilities	15	16
Net assets	77	74
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	88	129
Other noncurrent assets	23	23
Taxes accrued	127	178
Current Liabilities: Other	83	91
Deferred income taxes	1,472	1,443
Noncurrent Liabilities: Other	166	166
Duke Energy Ohio [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	53	82
Total assets	53	82
Net assets	53	82
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	88	114
Other noncurrent assets	156	147
Taxes accrued	72	31
Current Liabilities: Other	75	93
Deferred income taxes	1,921	1,900
Noncurrent Liabilities: Other	24	27
Duke Energy Indiana [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	69	101
Total assets	69	101
Net assets	69	101
Piedmont Natural Gas [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	7	7
Other noncurrent assets	19	21
Taxes accrued	69	67
Current Liabilities: Other	70	102
Deferred income taxes	981	931
Noncurrent Liabilities: Other	169	189
Piedmont Natural Gas [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	152	139
Total assets	152	139
Taxes accrued	(1)
Deferred income taxes	4
Noncurrent Liabilities: Other		4
Total liabilities	3	4
Net assets	149	135
Piedmont Natural Gas [Member] | Pipeline Investments [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	$ 152	$ 139

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Variable Interest Entities (Pipeline Investments) (Details) - Variable Interest Entity, Not Primary Beneficiary [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Variable Interest Entities [Line Items]
Investments in Joint Ventures	$ 938	$ 751
Atlantic Coast Pipeline [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	47.00%
Investments in Joint Ventures	$ 403	265
Sabal Trail Transmission Pipeline [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	7.50%
Investments in Joint Ventures	$ 188	140
Constitution Pipeline [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	24.00%
Investments in Joint Ventures	$ 82	82
Pipeline Investments [Member]
Variable Interest Entities [Line Items]
Investments in Joint Ventures	673	487
Piedmont Natural Gas [Member]
Variable Interest Entities [Line Items]
Investments in Joint Ventures	$ 152	139
Piedmont Natural Gas [Member] | Atlantic Coast Pipeline [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	7.00%
Investments in Joint Ventures	$ 59	46
Piedmont Natural Gas [Member] | Constitution Pipeline [Member]
Variable Interest Entities [Line Items]
Variable Interest Entity Ownership Interest	24.00%
Investments in Joint Ventures	$ 93	93
Piedmont Natural Gas [Member] | Pipeline Investments [Member]
Variable Interest Entities [Line Items]
Investments in Joint Ventures	$ 152	$ 139

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Variable Interest Entities (Fair Value Assumptions)(Details) - Cinergy Receivables [Member]	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Anticipated credit loss ratio	0.50%	0.50%
Discount rate	1.80%	1.50%
Receivable turnover rate	13.40%	13.30%
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Anticipated credit loss ratio	0.30%	0.30%
Discount rate	1.80%	1.50%
Receivable turnover rate	10.70%	10.60%

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Variable Interest Entities (Receivables Sold)(Details) - Cinergy Receivables [Member] - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables sold	$ 238	$ 267
Less: Retained interests	53	82
Net receivables sold	185	185
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables sold	277	306
Less: Retained interests	69	101
Net receivables sold	$ 208	$ 205

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Variable Interest Entities (Sales and Cash Flows)(Details) - Cinergy Receivables [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables sold	$ 533	$ 532
Loss recognized on sale	2	3
Cash proceeds from receivables sold	559	537
Return received on retained interests	1	1
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables sold	664	635
Loss recognized on sale	3	3
Cash proceeds from receivables sold	693	643
Return received on retained interests	$ 2	$ 1

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Common Stock (Earnings Per Share Data)(Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Common Stock [Line Items]
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$ 715	$ 574
Average shares, basic	700	689
Average shares, diluted	700	689
EPS, basic (usd per share)	$ 1.02	$ 0.83
EPS, diluted (usd per share)	$ 1.02	$ 0.83
Number of stock options and performance and unvested stock awards excluded from the dilutive securities calculation	2	2
Dividends declared per share (usd per share)	$ 0.855	$ 0.825

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Common Stock (Equity Securities Offering) (Details) shares in Millions	Mar. 31, 2016 shares
Piedmont Natural Gas [Member]
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares offered	10.6

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Stock-Based Compensation (Schedule of Stock-Based Compensation Expense) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation cost	$ 15	$ 12
Tax benefit associated with stock-based compensation expense	5	4
Stock-based compensation costs capitalized	1	1
Restricted Stock Units Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation cost	8	7
Performance Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation cost	$ 7	5
Piedmont Natural Gas [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation cost		$ 2

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Employee Benefit Plans (Plan Contributions) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Qualified Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	$ 0	$ 0

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Employee Benefit Plans (Components of Net Periodic Pension Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Qualified Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	$ 40	$ 36
Interest cost on projected benefit obligation	82	83
Expected return on plan assets	(136)	(129)
Amortization of actuarial loss (gain)	36	33
Amortization of prior service credit	(6)	(4)
Other	2	3
Net periodic costs	18	22
Qualified Pension Plan [Member] | Duke Energy Carolinas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	12	12
Interest cost on projected benefit obligation	20	21
Expected return on plan assets	(35)	(35)
Amortization of actuarial loss (gain)	8	8
Amortization of prior service credit	(2)	(2)
Other		1
Net periodic costs	3	5
Qualified Pension Plan [Member] | Progress Energy [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	12	11
Interest cost on projected benefit obligation	25	26
Expected return on plan assets	(43)	(42)
Amortization of actuarial loss (gain)	14	14
Amortization of prior service credit	(1)	(1)
Other	1	1
Net periodic costs	8	9
Qualified Pension Plan [Member] | Duke Energy Progress [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	6	6
Interest cost on projected benefit obligation	12	12
Expected return on plan assets	(21)	(21)
Amortization of actuarial loss (gain)	6	6
Net periodic costs	3	3
Qualified Pension Plan [Member] | Duke Energy Florida [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	5	5
Interest cost on projected benefit obligation	13	14
Expected return on plan assets	(21)	(21)
Amortization of actuarial loss (gain)	7	7
Net periodic costs	4	5
Qualified Pension Plan [Member] | Duke Energy Ohio [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	1	1
Interest cost on projected benefit obligation	5	5
Expected return on plan assets	(7)	(7)
Amortization of actuarial loss (gain)	1	1
Qualified Pension Plan [Member] | Duke Energy Indiana [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	2	2
Interest cost on projected benefit obligation	7	7
Expected return on plan assets	(11)	(10)
Amortization of actuarial loss (gain)	3	3
Net periodic costs	1	2
Qualified Pension Plan [Member] | Piedmont Natural Gas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	3	3
Interest cost on projected benefit obligation	3	2
Expected return on plan assets	(6)	(6)
Amortization of actuarial loss (gain)	3	2
Amortization of prior service credit	(1)
Net periodic costs	2	1
Other Post-Retirement Benefit Plans [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	1	1
Interest cost on projected benefit obligation	9	8
Expected return on plan assets	(3)	(3)
Amortization of actuarial loss (gain)	2	1
Amortization of prior service credit	(29)	(35)
Net periodic costs	(20)	(28)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Carolinas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	2	2
Expected return on plan assets	(2)	(2)
Amortization of actuarial loss (gain)	(1)	(1)
Amortization of prior service credit	(2)	(3)
Net periodic costs	(3)	(4)
Other Post-Retirement Benefit Plans [Member] | Progress Energy [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	4	4
Amortization of actuarial loss (gain)	5	5
Amortization of prior service credit	(21)	(26)
Net periodic costs	(12)	(17)
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
Amortization of actuarial loss (gain)	3	3
Amortization of prior service credit	(14)	(17)
Net periodic costs	(9)	(12)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Florida [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Interest cost on projected benefit obligation	2	2
Amortization of actuarial loss (gain)	2	2
Amortization of prior service credit	(8)	(9)
Net periodic costs	$ (4)	(5)
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
Amortization of actuarial loss (gain)		$ (1)

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Employee Benefit Plans (Employee Savings Plans) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Employee Savings Plan [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	$ 65	$ 52
Employee Savings Plan [Member] | Duke Energy Carolinas [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	22	18
Employee Savings Plan [Member] | Progress Energy [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	18	15
Employee Savings Plan [Member] | Duke Energy Progress [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	13	11
Employee Savings Plan [Member] | Duke Energy Florida [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	5	4
Employee Savings Plan [Member] | Duke Energy Ohio [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	1	1
Employee Savings Plan [Member] | Duke Energy Indiana [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	3	2
Employee Savings Plan [Member] | Piedmont Natural Gas [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	2	$ 2
Pension Plan [Member] | Piedmont Natural Gas [Member]
Defined Contribution Plan Disclosure [Line Items]
Pension Contributions	$ 2

XML

Income Taxes (Effective Tax Rates) (Details)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
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	32.40%	30.40%
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	35.40%	34.10%
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	34.10%	36.70%
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	34.10%	35.40%
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	36.60%	37.90%
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	35.40%	26.90%
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	39.30%	30.20%
Piedmont Natural Gas [Member]
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]
Effective tax rate	37.90%	38.00%

XML

Income Taxes Income Taxes (Taxes on Foreign Earnings) (Details) - Discontinued Operations, Disposed of by Sale [Member] - International Energy [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income tax benefit	$ (39)
Previously Remitted Earnings [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income tax benefit	$ (95)