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 September 30, 2018

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 every Interactive Data File required to be submitted 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 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, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging growth 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 October 31, 2018:

Registrant	Description	Shares
Duke Energy	Common stock, $0.001 par value	712,877,558

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 – Business Segments	43
	Note 3 – Regulatory Matters	47
	Note 4 – Commitments and Contingencies	59
	Note 5 – Debt and Credit Facilities	64
	Note 6 – Asset Retirement Obligations	66
	Note 7 – Goodwill	67
	Note 8 – Related Party Transactions	68
	Note 9 – Derivatives and Hedging	69
	Note 10 – Investments in Debt and Equity Securities	75
	Note 11 – Fair Value Measurements	81
	Note 12 – Variable Interest Entities	89
	Note 13 – Revenue	93
	Note 14 – Common Stock	98
	Note 15 – Stock-Based Compensation	100
	Note 16 – Employee Benefit Plans	100
	Note 17 – Income Taxes	104
	Note 18 – Subsequent Events	105
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	106
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	136
Item 4.	Controls and Procedures	136
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	137
Item 1A.	Risk Factors	137
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	137
Item 6.	Exhibits	138
	Signatures	141

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, including those related to 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 rate case proceedings and 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 sustained downturns of the economy and the economic health of our service territories or variations in customer usage patterns, including energy efficiency efforts and use of alternative energy sources, such as 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 obtain the necessary permits and approvals and to complete necessary or desirable pipeline expansion or infrastructure projects in our natural gas business;

◦ Operational interruptions to our natural 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 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, compliance with debt covenants and conditions and general market and 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;

◦ The impact of new U.S. tax legislation to our financial condition, results of operations or cash flows and our credit ratings;

◦ The impacts from potential impairments of goodwill or equity method investment carrying values; and

◦ The ability to implement our business strategy.

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 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						Nine Months Ended
	September 30,						September 30,
(in millions, except per-share amounts)	2018			2017			2018			2017
Operating Revenues
Regulated electric	$	6,216		$	6,091		$	16,678		$	16,122
Regulated natural gas	230			247			1,221			1,168
Nonregulated electric and other	182			144			507			476
Total operating revenues	6,628			6,482			18,406			17,766
Operating Expenses
Fuel used in electric generation and purchased power	1,931			1,863			5,181			4,853
Cost of natural gas	58			68			460			402
Operation, maintenance and other	1,584			1,476			4,592			4,385
Depreciation and amortization	1,039			900			2,979			2,594
Property and other taxes	323			313			954			924
Impairment charges	124			207			339			216
Total operating expenses	5,059			4,827			14,505			13,374
Gains (Losses) on Sales of Other Assets and Other, net	10			6			(87		)	24
Operating Income	1,579			1,661			3,814			4,416
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	37			36			49			101
Other income and expenses, net	131			122			327			358
Total other income and expenses	168			158			376			459
Interest Expense	517			498			1,550			1,475
Income From Continuing Operations Before Income Taxes	1,230			1,321			2,640			3,400
Income Tax Expense From Continuing Operations	168			364			449			1,035
Income From Continuing Operations	1,062			957			2,191			2,365
Income (Loss) From Discontinued Operations, net of tax	4			(2		)	(1		)	(4		)
Net Income	1,066			955			2,190			2,361
Less: Net (Loss) Income Attributable to Noncontrolling Interests	(16		)	1			(12		)	5
Net Income Attributable to Duke Energy Corporation	$	1,082		$	954		$	2,202		$	2,356
Earnings Per Share – Basic and Diluted
Income from continuing operations attributable to Duke Energy Corporation common stockholders
Basic	$	1.51		$	1.36		$	3.12		$	3.37
Diluted	$	1.51		$	1.36		$	3.11		$	3.37
Loss from discontinued operations attributable to Duke Energy Corporation common stockholders
Basic	$	—		$	—		$	—		$	(0.01	)
Diluted	$	—		$	—		$	—		$	(0.01	)
Net income attributable to Duke Energy Corporation common stockholders
Basic	$	1.51		$	1.36		$	3.12		$	3.36
Diluted	$	1.51		$	1.36		$	3.11		$	3.36
Weighted average shares outstanding
Basic	713			700			705			700
Diluted	714			700			706			700

See Notes to Condensed Consolidated Financial Statements

6

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Comprehensive Income

(Unaudited)

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
(in millions)	2018			2017			2018			2017
Net Income	$	1,066		$	955		$	2,190		$	2,361
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	1			—			3			2
Net unrealized (losses) gains on cash flow hedges	(3		)	2			10			(2		)
Reclassification into earnings from cash flow hedges	6			(2		)	5			3
Unrealized (losses) gains on available-for-sale securities	—			2			(5		)	10
Other Comprehensive Income, net of tax	4			2			13			13
Comprehensive Income	1,070			957			2,203			2,374
Less: Comprehensive (Loss) Income Attributable to Noncontrolling Interests	(16		)	1			(12		)	5
Comprehensive Income Attributable to Duke Energy Corporation	$	1,086		$	956		$	2,215		$	2,369

See Notes to Condensed Consolidated Financial Statements

7

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2018			December 31, 2017
ASSETS
Current Assets
Cash and cash equivalents	$	303		$	358
Receivables (net of allowance for doubtful accounts of $17 at 2018 and $14 at 2017)	682			779
Receivables of VIEs (net of allowance for doubtful accounts of $55 at 2018 and $54 at 2017)	2,397			1,995
Inventory	3,140			3,250
Regulatory assets (includes $52 at 2018 and $51 at 2017 related to VIEs)	1,906			1,437
Other	1,092			634
Total current assets	9,520			8,453
Property, Plant and Equipment
Cost	132,677			127,507
Accumulated depreciation and amortization	(43,200		)	(41,537		)
Generation facilities to be retired, net	388			421
Net property, plant and equipment	89,865			86,391
Other Noncurrent Assets
Goodwill	19,303			19,396
Regulatory assets (includes $1,055 at 2018 and $1,091 at 2017 related to VIEs)	12,616			12,442
Nuclear decommissioning trust funds	7,421			7,097
Investments in equity method unconsolidated affiliates	1,328			1,175
Other	3,112			2,960
Total other noncurrent assets	43,780			43,070
Total Assets	$	143,165		$	137,914
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	3,234		$	3,043
Notes payable and commercial paper	2,891			2,163
Taxes accrued	674			551
Interest accrued	557			525
Current maturities of long-term debt (includes $228 at 2018 and $225 at 2017 related to VIEs)	3,455			3,244
Asset retirement obligations	902			689
Regulatory liabilities	506			402
Other	1,703			1,865
Total current liabilities	13,922			12,482
Long-Term Debt (includes $4,015 at 2018 and $4,306 at 2017 related to VIEs)	50,507			49,035
Other Noncurrent Liabilities
Deferred income taxes	7,765			6,621
Asset retirement obligations	9,354			9,486
Regulatory liabilities	15,587			15,330
Accrued pension and other post-retirement benefit costs	1,001			1,103
Investment tax credits	539			539
Other	1,477			1,581
Total other noncurrent liabilities	35,723			34,660
Commitments and Contingencies
Equity
Common stock, $0.001 par value, 2 billion shares authorized; 713 million shares outstanding at 2018 and 700 million shares outstanding at 2017	1			1
Additional paid-in capital	39,747			38,792
Retained earnings	3,313			3,013
Accumulated other comprehensive loss	(66		)	(67		)
Total Duke Energy Corporation stockholders' equity	42,995			41,739
Noncontrolling interests	18			(2		)
Total equity	43,013			41,737
Total Liabilities and Equity	$	143,165		$	137,914

See Notes to Condensed Consolidated Financial Statements

8

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	2,190		$	2,361
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	3,447			2,990
Equity component of AFUDC	(175		)	(175		)
Losses (gains) on sales of other assets	87			(28		)
Impairment charges	339			216
Deferred income taxes	1,099			1,016
Equity in earnings of unconsolidated affiliates	(49		)	(101		)
Accrued pension and other post-retirement benefit costs	46			19
Contributions to qualified pension plans	(141		)	(8		)
Payments for asset retirement obligations	(389		)	(420		)
Payment for disposal of other assets	(105		)	—
Other rate case adjustments	37			—
Provision for rate refunds	375			—
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	15			4
Receivables	(288		)	80
Inventory	104			248
Other current assets	(648		)	(210		)
Increase (decrease) in
Accounts payable	389			(554		)
Taxes accrued	122			233
Other current liabilities	(180		)	(532		)
Other assets	(585		)	(159		)
Other liabilities	(23		)	(2		)
Net cash provided by operating activities	5,667			4,978
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(6,752		)	(5,841		)
Contributions to equity method investments	(298		)	(370		)
Purchases of debt and equity securities	(2,763		)	(3,170		)
Proceeds from sales and maturities of debt and equity securities	2,718			3,199
Other	(175		)	(149		)
Net cash used in investing activities	(7,270		)	(6,331		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	4,110			5,710
Issuance of common stock	834			—
Payments for the redemption of long-term debt	(2,278		)	(2,035		)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	243			265
Payments for the redemption of short-term debt with original maturities greater than 90 days	(207		)	(237		)
Notes payable and commercial paper	638			(647		)
Dividends paid	(1,835		)	(1,825		)
Other	42			8
Net cash provided by financing activities	1,547			1,239
Net decrease in cash, cash equivalents and restricted cash	(56		)	(114		)
Cash, cash equivalents and restricted cash at beginning of period	505			541
Cash, cash equivalents and restricted cash at end of period	$	449		$	427
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	1,016		$	740
Non-cash dividends	79			—

See Notes to Condensed Consolidated Financial Statements

9

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

									Accumulated Other Comprehensive Income (Loss)
												Net Unrealized						Total
									Net Gains			(Losses) Gains						Duke Energy
	Common			Additional					(Losses) on			on Available-			Pension and			Corporation
	Stock	Common		Paid-in		Retained			Cash Flow			for-Sale-			OPEB			Stockholders'			Noncontrolling			Total
(in millions)	Shares	Stock		Capital		Earnings			Hedges			Securities			Adjustments			Equity			Interests			Equity
Balance at December 31, 2016	700	$	1	$	38,741	$	2,384		$	(20	)	$	(1	)	$	(72	)	$	41,033		$	8		$	41,041
Net income	—	—		—		2,356			—			—			—			2,356			5			2,361
Other comprehensive income	—	—		—		—			1			10			2			13			—			13
Common stock issuances, including dividend reinvestment and employee benefits	—	—		33		—			—			—			—			33			—			33
Common stock dividends	—	—		—		(1,825		)	—			—			—			(1,825		)	—			(1,825		)
Distributions to noncontrolling interest in subsidiaries	—	—		—		—			—			—			—			—			(2		)	(2		)
Other(a)	—	—		—		21			—			—			—			21			—			21
Balance at September 30, 2017	700	$	1	$	38,774	$	2,936		$	(19	)	$	9		$	(70	)	$	41,631		$	11		$	41,642
Balance at December 31, 2017	700	$	1	$	38,792	$	3,013		$	(10	)	$	12		$	(69	)	$	41,739		$	(2	)	$	41,737
Net income (loss)	—	—		—		2,202			—			—			—			2,202			(12		)	2,190
Other comprehensive income (loss)	—	—		—		—			15			(5		)	3			13			—			13
Common stock issuances, including dividend reinvestment and employee benefits	13	—		955		—			—			—			—			955			—			955
Common stock dividends	—	—		—		(1,914		)	—			—			—			(1,914		)	—			(1,914		)
Distributions to noncontrolling interest in subsidiaries	—	—		—		—			—			—			—			—			(1		)	(1		)
Other(b)	—	—		—		12			—			(12		)	—			—			33			33
Balance at September 30, 2018	713	$	1	$	39,747	$	3,313		$	5		$	(5	)	$	(66	)	$	42,995		$	18		$	43,013

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

(b) Amounts in Retained Earnings and Accumulated Other Comprehensive Loss represent a cumulative-effect adjustment due to implementation of a new accounting standard related to Financial Instruments Classification and Measurement. See Note 1 for more information. Amount in Noncontrolling Interests relates to tax equity financing activity in the Commercial Renewables segment.

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				Nine Months Ended
	September 30,				September 30,
(in millions)	2018		2017		2018			2017
Operating Revenues	$	2,090	$	2,136	$	5,525		$	5,581
Operating Expenses
Fuel used in electric generation and purchased power	490		531		1,370			1,394
Operation, maintenance and other	514		494		1,464			1,472
Depreciation and amortization	305		281		866			804
Property and other taxes	67		67		214			206
Impairment charges	1		—		191			—
Total operating expenses	1,377		1,373		4,105			3,876
Losses on Sales of Other Assets and Other, net	—		—		(1		)	—
Operating Income	713		763		1,419			1,705
Other Income and Expenses, net	34		40		108			140
Interest Expense	106		108		323			314
Income Before Income Taxes	641		695		1,204			1,531
Income Tax Expense	145		229		268			522
Net Income	$	496	$	466	$	936		$	1,009
Other Comprehensive Income, net of tax
Reclassification into earnings from cash flow hedges	—		—		1			1
Comprehensive Income	$	496	$	466	$	937		$	1,010

See Notes to Condensed Consolidated Financial Statements

11

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2018			December 31, 2017
ASSETS
Current Assets
Cash and cash equivalents	$	27		$	16
Receivables (net of allowance for doubtful accounts of $2 at 2018 and 2017)	203			200
Receivables of VIEs (net of allowance for doubtful accounts of $7 at 2018 and 2017)	795			640
Receivables from affiliated companies	158			95
Inventory	976			971
Regulatory assets	435			299
Other	55			19
Total current assets	2,649			2,240
Property, Plant and Equipment
Cost	44,086			42,939
Accumulated depreciation and amortization	(15,536		)	(15,063		)
Net property, plant and equipment	28,550			27,876
Other Noncurrent Assets
Regulatory assets	3,188			2,853
Nuclear decommissioning trust funds	3,943			3,772
Other	1,009			979
Total other noncurrent assets	8,140			7,604
Total Assets	$	39,339		$	37,720
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	888		$	842
Accounts payable to affiliated companies	142			209
Notes payable to affiliated companies	804			104
Taxes accrued	189			234
Interest accrued	141			108
Current maturities of long-term debt	506			1,205
Asset retirement obligations	292			337
Regulatory liabilities	144			126
Other	419			486
Total current liabilities	3,525			3,651
Long-Term Debt	9,589			8,598
Long-Term Debt Payable to Affiliated Companies	300			300
Other Noncurrent Liabilities
Deferred income taxes	3,639			3,413
Asset retirement obligations	3,420			3,273
Regulatory liabilities	6,480			6,231
Accrued pension and other post-retirement benefit costs	97			95
Investment tax credits	233			232
Other	508			566
Total other noncurrent liabilities	14,377			13,810
Commitments and Contingencies
Equity
Member's equity	11,554			11,368
Accumulated other comprehensive loss	(6		)	(7		)
Total equity	11,548			11,361
Total Liabilities and Equity	$	39,339		$	37,720

See Notes to Condensed Consolidated Financial Statements

12

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	936		$	1,009
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	1,084			1,051
Equity component of AFUDC	(57		)	(79		)
Losses on sales of other assets	1			—
Impairment charges	191			—
Deferred income taxes	266			330
Accrued pension and other post-retirement benefit costs	3			—
Contributions to qualified pension plans	(46		)	—
Payments for asset retirement obligations	(174		)	(201		)
Provision for rate refunds	163			—
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	2			1
Receivables	(154		)	(40		)
Receivables from affiliated companies	(63		)	17
Inventory	(11		)	50
Other current assets	(54		)	8
Increase (decrease) in
Accounts payable	69			(78		)
Accounts payable to affiliated companies	(67		)	(88		)
Taxes accrued	(47		)	225
Other current liabilities	(129		)	(149		)
Other assets	18			(18		)
Other liabilities	(47		)	(26		)
Net cash provided by operating activities	1,884			2,012
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,006		)	(1,747		)
Purchases of debt and equity securities	(1,386		)	(1,660		)
Proceeds from sales and maturities of debt and equity securities	1,386			1,664
Notes receivable from affiliated companies	—			66
Other	(103		)	(58		)
Net cash used in investing activities	(2,109		)	(1,735		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	991			—
Payments for the redemption of long-term debt	(704		)	(115		)
Notes payable to affiliated companies	700			468
Distributions to parent	(750		)	(625		)
Other	(1		)	(1		)
Net cash provided by (used in) financing activities	236			(273		)
Net increase in cash and cash equivalents	11			4
Cash and cash equivalents at beginning of period	16			14
Cash and cash equivalents at end of period	$	27		$	18
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	299		$	292

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, 2016	$	10,781		$	(9	)	$	10,772
Net income	1,009			—			1,009
Other comprehensive income	—			1			1
Distributions to parent	(625		)	—			(625		)
Other	(1		)	—			(1		)
Balance at September 30, 2017	$	11,164		$	(8	)	$	11,156
Balance at December 31, 2017	$	11,368		$	(7	)	$	11,361
Net income	936			—			936
Other comprehensive income	—			1			1
Distributions to parent	(750		)	—			(750		)
Balance at September 30, 2018	$	11,554		$	(6	)	$	11,548

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					Nine Months Ended
	September 30,					September 30,
(in millions)	2018		2017			2018			2017
Operating Revenues	$	3,045	$	2,864		$	8,119		$	7,435
Operating Expenses
Fuel used in electric generation and purchased power	1,148		1,031			3,019			2,588
Operation, maintenance and other	680		588			1,913			1,697
Depreciation and amortization	419		334			1,183			958
Property and other taxes	145		140			399			386
Impairment charges	1		135			34			137
Total operating expenses	2,393		2,228			6,548			5,766
Gains on Sales of Other Assets and Other, net	11		5			23			19
Operating Income	663		641			1,594			1,688
Other Income and Expenses, net	51		36			128			112
Interest Expense	214		193			626			595
Income Before Income Taxes	500		484			1,096			1,205
Income Tax Expense	94		141			186			384
Net Income	406		343			910			821
Less: Net Income Attributable to Noncontrolling Interests	2		2			6			7
Net Income Attributable to Parent	$	404	$	341		$	904		$	814
Net Income	$	406	$	343		$	910		$	821
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	—		3			2			5
Net unrealized gains (losses) on cash flow hedges	2		(2		)	5			4
Unrealized (losses) gains on available-for-sale securities	—		1			(1		)	3
Other Comprehensive Income, net of tax	2		2			6			12
Comprehensive Income	408		345			916			833
Less: Comprehensive Income Attributable to Noncontrolling Interests	2		2			6			7
Comprehensive Income Attributable to Parent	$	406	$	343		$	910		$	826

See Notes to Condensed Consolidated Financial Statements

15

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2018			December 31, 2017
ASSETS
Current Assets
Cash and cash equivalents	$	43		$	40
Receivables (net of allowance for doubtful accounts of $5 at 2018 and $4 at 2017)	131			123
Receivables of VIEs (net of allowance for doubtful accounts of $8 at 2018 and $7 at 2017)	1,098			780
Receivables from affiliated companies	15			31
Notes receivable from affiliated companies	445			240
Inventory	1,473			1,592
Regulatory assets (includes $52 at 2018 and $51 at 2017 related to VIEs)	1,122			741
Other	256			334
Total current assets	4,583			3,881
Property, Plant and Equipment
Cost	49,822			47,323
Accumulated depreciation and amortization	(16,652		)	(15,857		)
Generation facilities to be retired, net	388			421
Net property, plant and equipment	33,558			31,887
Other Noncurrent Assets
Goodwill	3,655			3,655
Regulatory assets (includes $1,055 at 2018 and $1,091 at 2017 related to VIEs)	5,987			6,010
Nuclear decommissioning trust funds	3,477			3,324
Other	1,019			931
Total other noncurrent assets	14,138			13,920
Total Assets	$	52,279		$	49,688
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	1,301		$	1,006
Accounts payable to affiliated companies	327			251
Notes payable to affiliated companies	794			805
Taxes accrued	244			101
Interest accrued	228			212
Current maturities of long-term debt (includes $53 at 2018 and 2017 related to VIEs)	1,322			771
Asset retirement obligations	475			295
Regulatory liabilities	246			213
Other	672			729
Total current liabilities	5,609			4,383
Long-Term Debt (includes $1,636 at 2018 and $1,689 at 2017 related to VIEs)	17,440			16,916
Long-Term Debt Payable to Affiliated Companies	150			150
Other Noncurrent Liabilities
Deferred income taxes	3,947			3,502
Asset retirement obligations	4,960			5,119
Regulatory liabilities	5,275			5,306
Accrued pension and other post-retirement benefit costs	513			545
Other	255			302
Total other noncurrent liabilities	14,950			14,774
Commitments and Contingencies
Equity
Common stock, $0.01 par value, 100 shares authorized and outstanding at 2018 and 2017	—			—
Additional paid-in capital	9,143			9,143
Retained earnings	5,009			4,350
Accumulated other comprehensive loss	(24		)	(25		)
Total Progress Energy, Inc. stockholders' equity	14,128			13,468
Noncontrolling interests	2			(3		)
Total equity	14,130			13,465
Total Liabilities and Equity	$	52,279		$	49,688

See Notes to Condensed Consolidated Financial Statements

16

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	910		$	821
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,458			1,130
Equity component of AFUDC	(80		)	(68		)
Gains on sales of other assets	(23		)	(20		)
Impairment charges	34			137
Deferred income taxes	342			651
Accrued pension and other post-retirement benefit costs	18			(9		)
Contributions to qualified pension plans	(45		)	—
Payments for asset retirement obligations	(164		)	(190		)
Other rate case adjustments	37			—
Provision for rate refunds	101			—
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	14			1
Receivables	(316		)	(182		)
Receivables from affiliated companies	16			102
Inventory	119			126
Other current assets	(156		)	(312		)
Increase (decrease) in
Accounts payable	427			(281		)
Accounts payable to affiliated companies	76			(59		)
Taxes accrued	143			143
Other current liabilities	(28		)	(184		)
Other assets	(668		)	(100		)
Other liabilities	(34		)	(85		)
Net cash provided by operating activities	2,181			1,621
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,689		)	(2,419		)
Purchases of debt and equity securities	(1,216		)	(1,393		)
Proceeds from sales and maturities of debt and equity securities	1,225			1,411
Net proceeds from the sales of other assets	20			—
Notes receivable from affiliated companies	(205		)	(90		)
Other	(142		)	(36		)
Net cash used in investing activities	(3,007		)	(2,527		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,785			1,720
Payments for the redemption of long-term debt	(719		)	(611		)
Notes payable to affiliated companies	(11		)	(129		)
Dividends to parent	(250		)	(125		)
Other	(3		)	(3		)
Net cash provided by financing activities	802			852
Net decrease in cash, cash equivalents and restricted cash	(24		)	(54		)
Cash, cash equivalents and restricted cash at beginning of period	87			110
Cash, cash equivalents and restricted cash at end of period	$	63		$	56
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	441		$	174
Equitization of certain notes payable to affiliates	—			1,047
Dividend to parent related to a legal entity restructuring	—			547

See Notes to Condensed Consolidated Financial Statements

17

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

						Accumulated Other Comprehensive Income (Loss)
									Net Unrealized						Total Progress
	Additional					Net Losses on			Gains (losses) 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, 2016	$	8,094	$	3,764		$	(23	)	$	1		$	(16	)	$	11,820		$	(13	)	$	11,807
Net income	—		814			—			—			—			814			7			821
Other comprehensive income	—		—			4			3			5			12			—			12
Dividends to parent(a)	—		(672		)	—			—			—			(672		)	—			(672		)
Equitization of certain notes payable to affiliates	1,047		—			—			—			—			1,047			—			1,047
Other	2		—			—			—			—			2			—			2
Balance at September 30, 2017	$	9,143	$	3,906		$	(19	)	$	4		$	(11	)	$	13,023		$	(6	)	$	13,017
Balance at December 31, 2017	$	9,143	$	4,350		$	(18	)	$	5		$	(12	)	$	13,468		$	(3	)	$	13,465
Net income	—		904			—			—			—			904			6			910
Other comprehensive income (loss)	—		—			5			(1		)	2			6			—			6
Distributions to noncontrolling interests	—		—			—			—			—			—			(1		)	(1		)
Dividends to parent	—		(250		)	—			—			—			(250		)	—			(250		)
Other(b)	—		5			—			(5		)	—			—			—			—
Balance at September 30, 2018	$	9,143	$	5,009		$	(13	)	$	(1	)	$	(10	)	$	14,128		$	2		$	14,130

(a) Includes a $547 million non-cash dividend related to a legal entity restructuring.

(b) Amounts in Retained Earnings and Accumulated Other Comprehensive Loss represent a cumulative-effect adjustment due to implementation of a new accounting standard related to Financial Instruments Classification and Measurement. See Note 1 for more information.

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				Nine Months Ended
	September 30,				September 30,
(in millions)	2018		2017		2018		2017
Operating Revenues	$	1,582	$	1,460	$	4,333	$	3,878
Operating Expenses
Fuel used in electric generation and purchased power	535		475		1,452		1,214
Operation, maintenance and other	431		365		1,187		1,069
Depreciation and amortization	253		182		723		536
Property and other taxes	40		40		115		120
Impairment charges	—		—		33		—
Total operating expenses	1,259		1,062		3,510		2,939
Gains on Sales of Other Assets and Other, net	7		—		9		3
Operating Income	330		398		832		942
Other Income and Expenses, net	24		27		61		84
Interest Expense	82		65		241		217
Income Before Income Taxes	272		360		652		809
Income Tax Expense	56		114		120		262
Net Income and Comprehensive Income	$	216	$	246	$	532	$	547

See Notes to Condensed Consolidated Financial Statements

19

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2018			December 31, 2017
ASSETS
Current Assets
Cash and cash equivalents	$	17		$	20
Receivables (net of allowance for doubtful accounts of $2 at 2018 and $1 at 2017)	34			56
Receivables of VIEs (net of allowance for doubtful accounts of $5 at 2018 and 2017)	635			459
Receivables from affiliated companies	6			3
Notes receivable from affiliated companies	52			—
Inventory	956			1,017
Regulatory assets	677			352
Other	112			97
Total current assets	2,489			2,004
Property, Plant and Equipment
Cost	31,091			29,583
Accumulated depreciation and amortization	(11,484		)	(10,903		)
Generation facilities to be retired, net	388			421
Net property, plant and equipment	19,995			19,101
Other Noncurrent Assets
Regulatory assets	3,822			3,507
Nuclear decommissioning trust funds	2,744			2,588
Other	653			599
Total other noncurrent assets	7,219			6,694
Total Assets	$	29,703		$	27,799
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	808		$	402
Accounts payable to affiliated companies	252			179
Notes payable to affiliated companies	—			240
Taxes accrued	92			64
Interest accrued	100			102
Current maturities of long-term debt	603			3
Asset retirement obligations	470			295
Regulatory liabilities	162			139
Other	353			376
Total current liabilities	2,840			1,800
Long-Term Debt	7,401			7,204
Long-Term Debt Payable to Affiliated Companies	150			150
Other Noncurrent Liabilities
Deferred income taxes	2,076			1,883
Asset retirement obligations	4,371			4,378
Regulatory liabilities	4,128			3,999
Accrued pension and other post-retirement benefit costs	240			248
Investment tax credits	143			143
Other	48			45
Total other noncurrent liabilities	11,006			10,696
Commitments and Contingencies
Equity
Member's Equity	8,306			7,949
Total Liabilities and Equity	$	29,703		$	27,799

See Notes to Condensed Consolidated Financial Statements

20

PART I

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	532		$	547
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	869			691
Equity component of AFUDC	(41		)	(35		)
Gains on sales of other assets	(9		)	(4		)
Impairment charges	33			—
Deferred income taxes	187			287
Accrued pension and other post-retirement benefit costs	11			(15		)
Contributions to qualified pension plans	(25		)	—
Payments for asset retirement obligations	(133		)	(149		)
Other rate case adjustments	37			—
Provision for rate refunds	101			—
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3			(2		)
Receivables	(154		)	(47		)
Receivables from affiliated companies	(3		)	(3		)
Inventory	62			52
Other current assets	(239		)	(34		)
Increase (decrease) in
Accounts payable	325			(286		)
Accounts payable to affiliated companies	73			(20		)
Taxes accrued	28			33
Other current liabilities	(27		)	(139		)
Other assets	(358		)	(49		)
Other liabilities	11			(9		)
Net cash provided by operating activities	1,283			818
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,526		)	(1,247		)
Purchases of debt and equity securities	(831		)	(995		)
Proceeds from sales and maturities of debt and equity securities	807			974
Net proceeds from the sales of other assets	20			—
Notes receivable from affiliated companies	(52		)	64
Other	(82		)	(26		)
Net cash used in investing activities	(1,664		)	(1,230		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	796			812
Payments for the redemption of long-term debt	(2		)	(270		)
Notes payable to affiliated companies	(240		)	—
Distributions to parent	(175		)	(125		)
Other	(1		)	(1		)
Net cash provided by financing activities	378			416
Net (decrease) increase in cash and cash equivalents	(3		)	4
Cash and cash equivalents at beginning of period	20			11
Cash and cash equivalents at end of period	$	17		$	15
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	261		$	116

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, 2016	$	7,358
Net income	547
Distributions to parent	(125		)
Balance at September 30, 2017	$	7,780
Balance at December 31, 2017	$	7,949
Net income	532
Distributions to parent	(175		)
Balance at September 30, 2018	$	8,306

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				Nine Months Ended
	September 30,				September 30,
(in millions)	2018		2017		2018			2017
Operating Revenues	$	1,462	$	1,401	$	3,780		$	3,551
Operating Expenses
Fuel used in electric generation and purchased power	614		557		1,567			1,374
Operation, maintenance and other	245		220		719			623
Depreciation and amortization	166		154		460			423
Property and other taxes	105		99		284			265
Impairment charges	1		135		1			137
Total operating expenses	1,131		1,165		3,031			2,822
Operating Income	331		236		749			729
Other Income and Expenses, net	28		19		75			58
Interest Expense	73		71		210			211
Income Before Income Taxes	286		184		614			576
Income Tax Expense	43		64		100			208
Net Income	$	243	$	120	$	514		$	368
Other Comprehensive (Loss) Income, net of tax
Unrealized (losses) gains on available-for-sale securities	—		1		(1		)	3
Comprehensive Income	$	243	$	121	$	513		$	371

See Notes to Condensed Consolidated Financial Statements

23

PART I

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2018			December 31, 2017
ASSETS
Current Assets
Cash and cash equivalents	$	20		$	13
Receivables (net of allowance for doubtful accounts of $3 at 2018 and 2017)	95			65
Receivables of VIEs (net of allowance for doubtful accounts of $3 at 2018 and $2 at 2017)	463			321
Receivables from affiliated companies	20			2
Notes receivable from affiliated companies	393			313
Inventory	517			574
Regulatory assets (includes $52 at 2018 and $51 at 2017 related to VIEs)	445			389
Other (includes $14 at 2018 and $40 at 2017 related to VIEs)	27			86
Total current assets	1,980			1,763
Property, Plant and Equipment
Cost	18,722			17,730
Accumulated depreciation and amortization	(5,161		)	(4,947		)
Net property, plant and equipment	13,561			12,783
Other Noncurrent Assets
Regulatory assets (includes $1,055 at 2018 and $1,091 at 2017 related to VIEs)	2,165			2,503
Nuclear decommissioning trust funds	734			736
Other	315			284
Total other noncurrent assets	3,214			3,523
Total Assets	$	18,755		$	18,069
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	492		$	602
Accounts payable to affiliated companies	83			74
Taxes accrued	232			34
Interest accrued	74			56
Current maturities of long-term debt (includes $53 at 2018 and 2017 related to VIEs)	269			768
Asset retirement obligations	4			—
Regulatory liabilities	84			74
Other	315			334
Total current liabilities	1,553			1,942
Long-Term Debt (includes $1,336 at 2018 and $1,389 at 2017 related to VIEs)	7,102			6,327
Other Noncurrent Liabilities
Deferred income taxes	2,012			1,761
Asset retirement obligations	589			742
Regulatory liabilities	1,146			1,307
Accrued pension and other post-retirement benefit costs	241			264
Other	56			108
Total other noncurrent liabilities	4,044			4,182
Commitments and Contingencies
Equity
Member's equity	6,058			5,614
Accumulated other comprehensive (loss) income	(2		)	4
Total equity	6,056			5,618
Total Liabilities and Equity	$	18,755		$	18,069

See Notes to Condensed Consolidated Financial Statements

24

PART I

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	514		$	368
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	581			431
Equity component of AFUDC	(40		)	(33		)
Impairment charges	1			137
Deferred income taxes	169			366
Accrued pension and other post-retirement benefit costs	4			3
Contributions to qualified pension plans	(20		)	—
Payments for asset retirement obligations	(31		)	(41		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	7			3
Receivables	(163		)	(140		)
Receivables from affiliated companies	(18		)	1
Inventory	57			74
Other current assets	51			(195		)
Increase (decrease) in
Accounts payable	101			6
Accounts payable to affiliated companies	9			(35		)
Taxes accrued	198			109
Other current liabilities	1			(45		)
Other assets	(308		)	(35		)
Other liabilities	(58		)	(71		)
Net cash provided by operating activities	1,055			903
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,162		)	(1,172		)
Purchases of debt and equity securities	(385		)	(398		)
Proceeds from sales and maturities of debt and equity securities	418			437
Notes receivable from affiliated companies	(80		)	(70		)
Other	(61		)	(10		)
Net cash used in investing activities	(1,270		)	(1,213		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	989			908
Payments for the redemption of long-term debt	(717		)	(341		)
Notes payable to affiliated companies	—			(297		)
Distributions to parent	(75		)	—
Other	(1		)	(1		)
Net cash provided by financing activities	196			269
Net decrease in cash, cash equivalents and restricted cash	(19		)	(41		)
Cash, cash equivalents and restricted cash at beginning of period	53			69
Cash, cash equivalents and restricted cash at end of period	$	34		$	28
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	180		$	102

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 (Loss)
				Net Unrealized
				Gains (Losses) on
	Member's			Available-for-Sale			Total
(in millions)	Equity			Securities			Equity
Balance at December 31, 2016	$	4,899		$	1		$	4,900
Net income	368			—			368
Other comprehensive income	—			3			3
Other	3			—			3
Balance at September 30, 2017	$	5,270		$	4		$	5,274
Balance at December 31, 2017	$	5,614		$	4		$	5,618
Net income	514			—			514
Other comprehensive loss	—			(1		)	(1		)
Distributions to parent	(75		)	—			(75		)
Other(a)	5			(5		)	—
Balance at September 30, 2018	$	6,058		$	(2	)	$	6,056

(a) Amounts in Member's Equity and Accumulated Other Comprehensive Income (Loss) represent a cumulative-effect adjustment due to implementation of a new accounting standard related to Financial Instruments Classification and Measurement. See Note 1 for more information.

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					Nine Months Ended
	September 30,					September 30,
(in millions)	2018		2017			2018			2017
Operating Revenues
Regulated electric	$	373	$	371		$	1,055		$	1,036
Regulated natural gas	84		90			361			360
Nonregulated electric and other	12		10			36			30
Total operating revenues	469		471			1,452			1,426
Operating Expenses
Fuel used in electric generation and purchased power – regulated	99		100			284			283
Fuel used in electric generation and purchased power – nonregulated	14		13			43			42
Cost of natural gas	4		5			73			69
Operation, maintenance and other	76		125			337			388
Depreciation and amortization	64		63			196			193
Property and other taxes	73		65			218			204
Impairment charges	—		—			—			1
Total operating expenses	330		371			1,151			1,180
Gains (Losses) on Sales of Other Assets and Other, net	—		1			(106		)	1
Operating Income	139		101			195			247
Other Income and Expenses, net	3		5			17			15
Interest Expense	23		22			68			67
Income From Continuing Operations Before Income Taxes	119		84			144			195
Income Tax Expense From Continuing Operations	19		28			23			67
Income From Continuing Operations	100		56			121			128
Loss From Discontinued Operations, net of tax	—		(1		)	—			(1		)
Net Income and Comprehensive Income	$	100	$	55		$	121		$	127

See Notes to Condensed Consolidated Financial Statements

27

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2018			December 31, 2017
ASSETS
Current Assets
Cash and cash equivalents	$	7		$	12
Receivables (net of allowance for doubtful accounts of $3 at 2018 and 2017)	112			68
Receivables from affiliated companies	71			133
Notes receivable from affiliated companies	—			14
Inventory	135			133
Regulatory assets	41			49
Other	28			39
Total current assets	394			448
Property, Plant and Equipment
Cost	9,176			8,732
Accumulated depreciation and amortization	(2,683		)	(2,691		)
Net property, plant and equipment	6,493			6,041
Other Noncurrent Assets
Goodwill	920			920
Regulatory assets	427			445
Other	62			21
Total other noncurrent assets	1,409			1,386
Total Assets	$	8,296		$	7,875
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	251		$	313
Accounts payable to affiliated companies	54			62
Notes payable to affiliated companies	268			29
Taxes accrued	159			190
Interest accrued	34			21
Current maturities of long-term debt	452			3
Asset retirement obligations	7			3
Regulatory liabilities	57			36
Other	67			71
Total current liabilities	1,349			728
Long-Term Debt	1,589			2,039
Long-Term Debt Payable to Affiliated Companies	25			25
Other Noncurrent Liabilities
Deferred income taxes	790			781
Asset retirement obligations	91			81
Regulatory liabilities	865			891
Accrued pension and other post-retirement benefit costs	84			59
Other	113			108
Total other noncurrent liabilities	1,943			1,920
Commitments and Contingencies
Equity
Common stock, $8.50 par value, 120 million shares authorized; 90 million shares outstanding at 2018 and 2017	762			762
Additional paid-in capital	2,776			2,670
Accumulated deficit	(148		)	(269		)
Total equity	3,390			3,163
Total Liabilities and Equity	$	8,296		$	7,875

See Notes to Condensed Consolidated Financial Statements

28

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	121		$	127
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	199			196
Equity component of AFUDC	(10		)	(8		)
Losses (gains) on sales of other assets	106			(1		)
Impairment charges	—			1
Deferred income taxes	9			70
Accrued pension and other post-retirement benefit costs	3			3
Contributions to qualified pension plans	—			(4		)
Payments for asset retirement obligations	(3		)	(4		)
Provision for rate refunds	23			—
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	—			1
Receivables	(44		)	3
Receivables from affiliated companies	62			48
Inventory	(2		)	1
Other current assets	12			(8		)
Increase (decrease) in
Accounts payable	(47		)	(48		)
Accounts payable to affiliated companies	(8		)	(4		)
Taxes accrued	(31		)	(21		)
Other current liabilities	19			(6		)
Other assets	3			(13		)
Other liabilities	(17		)	(2		)
Net cash provided by operating activities	395			331
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(588		)	(457		)
Cost of removal, net of salvage	(63		)	(25		)
Notes receivable from affiliated companies	14			7
Other	1			—
Net cash used in investing activities	(636		)	(475		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			182
Payments for the redemption of long-term debt	(3		)	(2		)
Notes payable to affiliated companies	239			(16		)
Dividends to parent	—			(25		)
Other	—			(1		)
Net cash provided by financing activities	236			138
Net decrease in cash and cash equivalents	(5		)	(6		)
Cash and cash equivalents at beginning of period	12			13
Cash and cash equivalents at end of period	$	7		$	7
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	83		$	65
Non-cash equity contribution from parent	106			—

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, 2016	$	762	$	2,695		$	(461	)	$	2,996
Net income	—		—			127			127
Dividends to parent	—		(25		)	—			(25		)
Balance at September 30, 2017	$	762	$	2,670		$	(334	)	$	3,098
Balance at December 31, 2017	$	762	$	2,670		$	(269	)	$	3,163
Net income	—		—			121			121
Contribution from parent(a)	—		106			—			106
Balance at September 30, 2018	$	762	$	2,776		$	(148	)	$	3,390

(a) Represents a non-cash settlement through equity of an intercompany payable from Duke Energy Ohio to its parent.

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				Nine Months Ended
	September 30,				September 30,
(in millions)	2018		2017		2018		2017
Operating Revenues	$	819	$	802	$	2,288	$	2,302
Operating Expenses
Fuel used in electric generation and purchased power	272		259		730		744
Operation, maintenance and other	198		177		576		546
Depreciation and amortization	130		120		386		336
Property and other taxes	16		19		56		56
Impairment charges	30		—		30		—
Total operating expenses	646		575		1,778		1,682
Gains on Sale of Other Assets and Other, net	—		1		—		1
Operating Income	173		228		510		621
Other Income and Expenses, net	23		12		36		32
Interest Expense	42		44		125		132
Income Before Income Taxes	154		196		421		521
Income Tax Expense	35		75		104		203
Net Income and Comprehensive Income	$	119	$	121	$	317	$	318

See Notes to Condensed Consolidated Financial Statements

31

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2018			December 31, 2017
ASSETS
Current Assets
Cash and cash equivalents	$	17		$	9
Receivables (net of allowance for doubtful accounts of $2 at 2018 and 2017)	56			57
Receivables from affiliated companies	98			125
Inventory	434			450
Regulatory assets	190			165
Other	64			30
Total current assets	859			836
Property, Plant and Equipment
Cost	15,298			14,948
Accumulated depreciation and amortization	(4,831		)	(4,662		)
Net property, plant and equipment	10,467			10,286
Other Noncurrent Assets
Regulatory assets	950			978
Other	233			189
Total other noncurrent assets	1,183			1,167
Total Assets	$	12,509		$	12,289
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	177		$	196
Accounts payable to affiliated companies	72			78
Notes payable to affiliated companies	201			161
Taxes accrued	44			95
Interest accrued	54			57
Current maturities of long-term debt	62			3
Asset retirement obligations	128			54
Regulatory liabilities	25			24
Other	109			104
Total current liabilities	872			772
Long-Term Debt	3,571			3,630
Long-Term Debt Payable to Affiliated Companies	150			150
Other Noncurrent Liabilities
Deferred income taxes	988			925
Asset retirement obligations	616			727
Regulatory liabilities	1,761			1,723
Accrued pension and other post-retirement benefit costs	110			76
Investment tax credits	147			147
Other	31			18
Total other noncurrent liabilities	3,653			3,616
Commitments and Contingencies
Equity
Member's Equity	4,263			4,121
Total Liabilities and Equity	$	12,509		$	12,289

See Notes to Condensed Consolidated Financial Statements

32

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	317		$	318
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	388			339
Equity component of AFUDC	(28		)	(20		)
Gain on sale of other assets and other, net	—			(1		)
Impairment charges	30			—
Deferred income taxes	94			101
Accrued pension and other post-retirement benefit costs	5			4
Contributions to qualified pension plans	(8		)	—
Payments for asset retirement obligations	(49		)	(26		)
Provision for rate refunds	58			—
(Increase) decrease in
Receivables	1			53
Receivables from affiliated companies	27			31
Inventory	16			54
Other current assets	(59		)	18
Increase (decrease) in
Accounts payable	28			(71		)
Accounts payable to affiliated companies	(6		)	(1		)
Taxes accrued	(51		)	115
Other current liabilities	6			(18		)
Other assets	29			(24		)
Other liabilities	(13		)	32
Net cash provided by operating activities	785			904
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(619		)	(603		)
Purchases of debt and equity securities	(42		)	(15		)
Proceeds from sales and maturities of debt and equity securities	18			6
Notes receivable from affiliated companies	—			57
Other	3			(40		)
Net cash used in investing activities	(640		)	(595		)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt	(1		)	(3		)
Notes payable to affiliated companies	40			—
Distributions to parent	(175		)	(300		)
Other	(1		)	(1		)
Net cash used in financing activities	(137		)	(304		)
Net increase in cash and cash equivalents	8			5
Cash and cash equivalents at beginning of period	9			17
Cash and cash equivalents at end of period	$	17		$	22
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	71		$	101

See Notes to Condensed Consolidated Financial Statements

33

PART I

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Member's
(in millions)	Equity
Balance at December 31, 2016	$	4,067
Net income	318
Distributions to parent	(300		)
Balance at September 30, 2017	$	4,085
Balance at December 31, 2017	$	4,121
Net income	317
Distributions to parent	(175		)
Balance at September 30, 2018	$	4,263

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						Nine Months Ended
	September 30,						September 30,
(in millions)	2018			2017			2018		2017
Operating Revenues	$	172		$	183		$	940	$	884
Operating Expenses
Cost of natural gas	54			63			387		333
Operation, maintenance and other	85			73			252		226
Depreciation and amortization	40			38			118		109
Property and other taxes	12			13			36		38
Impairment charges	—			—			—		7
Total operating expenses	191			187			793		713
Operating (Loss) Income	(19		)	(4		)	147		171
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	3			3			6		8
Other income and expenses, net	3			—			9		(1		)
Total other income and expenses	6			3			15		7
Interest Expense	19			20			60		59
(Loss) Income Before Income Taxes	(32		)	(21		)	102		119
Income Tax (Benefit) Expense	(11		)	(10		)	21		43
Net (Loss) Income and Comprehensive (Loss) Income	$	(21	)	$	(11	)	$	81	$	76

See Notes to Condensed Consolidated Financial Statements

35

PART I

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2018			December 31, 2017
ASSETS
Current Assets
Cash and cash equivalents	$	6		$	19
Receivables (net of allowance for doubtful accounts of $1 at 2018 and $2 at 2017)	83			275
Receivables from affiliated companies	10			7
Notes receivable from affiliated companies	11			—
Inventory	51			66
Regulatory assets	38			95
Other	48			52
Total current assets	247			514
Property, Plant and Equipment
Cost	7,265			6,725
Accumulated depreciation and amortization	(1,553		)	(1,479		)
Net property, plant and equipment	5,712			5,246
Other Noncurrent Assets
Goodwill	49			49
Regulatory assets	305			283
Investments in equity method unconsolidated affiliates	63			61
Other	65			65
Total other noncurrent assets	482			458
Total Assets	$	6,441		$	6,218
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	131		$	125
Accounts payable to affiliated companies	27			13
Notes payable to affiliated companies	—			364
Taxes accrued	31			19
Interest accrued	25			31
Current maturities of long-term debt	350			250
Regulatory liabilities	34			3
Other	51			69
Total current liabilities	649			874
Long-Term Debt	1,788			1,787
Other Noncurrent Liabilities
Deferred income taxes	586			564
Asset retirement obligations	15			15
Regulatory liabilities	1,171			1,141
Accrued pension and other post-retirement benefit costs	3			5
Other	186			170
Total other noncurrent liabilities	1,961			1,895
Commitments and Contingencies
Equity
Common stock, no par value: 100 shares authorized and outstanding at 2018 and 2017	1,160			860
Retained earnings	883			802
Total equity	2,043			1,662
Total Liabilities and Equity	$	6,441		$	6,218

See Notes to Condensed Consolidated Financial Statements

36

PART I

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	81		$	76
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	120			112
Impairment charges	—			7
Deferred income taxes	2			127
Equity in earnings from unconsolidated affiliates	(6		)	(8		)
Accrued pension and other post-retirement benefit costs	(3		)	9
Provision for rate refunds	31			—
(Increase) decrease in
Receivables	192			157
Receivables from affiliated companies	(3		)	(1		)
Inventory	16			13
Other current assets	58			(129		)
Increase (decrease) in
Accounts payable	(48		)	(52		)
Accounts payable to affiliated companies	14			(1		)
Taxes accrued	11			(37		)
Other current liabilities	8			(21		)
Other assets	(4		)	(9		)
Other liabilities	(5		)	(7		)
Net cash provided by operating activities	464			236
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(497		)	(407		)
Cost of removal, net of salvage	(8		)	—
Contributions to equity method investments	—			(12		)
Notes receivable from affiliated companies	(11		)	—
Other	3			2
Net cash used in investing activities	(513		)	(417		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	100			250
Payments for the redemption of long-term debt	—			(35		)
Notes payable and commercial paper	—			(330		)
Notes payable to affiliated companies	(364		)	284
Capital contributions from parent	300			—
Other	—			(1		)
Net cash provided by financing activities	36			168
Net decrease in cash and cash equivalents	(13		)	(13		)
Cash and cash equivalents at beginning of period	19			25
Cash and cash equivalents at end of period	$	6		$	12
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	89		$	47
Transfer of ownership interest of certain equity method investees to parent	—			149

See Notes to Condensed Consolidated Financial Statements

37

PART I

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Common		Retained			Total
(in millions)	Stock		Earnings			Equity
Balance at December 31, 2016	$	860	$	812		$	1,672
Net income	—		76			76
Transfer of ownership interest of certain equity method investees to parent	—		(149		)	(149		)
Balance at September 30, 2017	$	860	$	739		$	1,599
Balance at December 31, 2017	$	860	$	802		$	1,662
Net income	—		81			81
Contribution from parent	300		—			300
Balance at September 30, 2018	$	1,160	$	883		$	2,043

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

18

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 and (ii) subsidiaries that are not registrants but included in the consolidated Duke Energy balances.

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.

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 subject to the regulatory provisions of the NCUC, PSCSC, Tennessee Public Utility Commission (TPUC) 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)

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles in the U.S. (GAAP) 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 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/A for the year ended December 31, 2017.

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.

REVENUE

Duke Energy recognizes revenue as customers obtain control of promised goods and services in an amount that reflects consideration expected in exchange for those goods or services. Generally, the delivery of electricity and natural gas results in the transfer of control to customers at the time the commodity is delivered and the amount of revenue recognized is equal to the amount billed to each customer, including estimated volumes delivered when billings have not yet occurred. See Note 13 for further information.

OTHER CURRENT ASSETS

Duke Energy recorded a receivable related to the Tax Act in Other within Current Assets in September 2018. As a result, Income taxes receivable exceeds five percent of Total current assets on the Duke Energy Condensed Consolidated Balance Sheets and is $655 million and $260 million as of September 30, 2018, and December 31, 2017, respectively. See Note 17 for further information.

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

Duke Energy, Progress Energy and Duke Energy Florida have restricted cash balances related primarily to collateral assets, escrow deposits and variable interest entities (VIEs). See Note 12 for additional information. Restricted cash amounts are included in Other within Current Assets and Other Noncurrent Assets. The following table presents the components of cash, cash equivalents and restricted cash included in the Condensed Consolidated Balance Sheets.

	September 30, 2018						December 31, 2017
					Duke						Duke
	Duke		Progress		Energy		Duke		Progress		Energy
	Energy		Energy		Florida		Energy		Energy		Florida
Current Assets
Cash and cash equivalents	$	303	$	43	$	20	$	358	$	40	$	13
Other	139		14		14		138		40		40
Other Noncurrent Assets
Other	7		6		—		9		7		—
Total cash, cash equivalents and restricted cash	$	449	$	63	$	34	$	505	$	87	$	53

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)

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 at September 30, 2018, and December 31, 2017. The components of inventory are presented in the tables below.

	September 30, 2018
			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	$	2,283	$	758	$	1,071	$	748	$	323	$	87	$	294	$	1
Coal	515		176		187		99		88		14		138		—
Natural gas, oil and other fuel	342		42		215		109		106		34		2		50
Total inventory	$	3,140	$	976	$	1,473	$	956	$	517	$	135	$	434	$	51

	December 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	$	2,293	$	744	$	1,118	$	774	$	343	$	82	$	309	$	2
Coal	603		192		255		139		116		17		139		—
Natural gas, oil and other fuel	354		35		219		104		115		34		2		64
Total inventory	$	3,250	$	971	$	1,592	$	1,017	$	574	$	133	$	450	$	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 on a net basis.

Excise taxes accounted for on a gross basis within both Operating Revenues and Property and other taxes on the Condensed Consolidated Statements of Operations were as follows.

	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Duke Energy	$	114	$	107	$	308	$	289
Duke Energy Carolinas	10		9		27		27
Progress Energy	71		67		181		168
Duke Energy Progress	5		5		15		14
Duke Energy Florida	66		62		166		154
Duke Energy Ohio	26		24		81		75
Duke Energy Indiana	6		6		17		16
Piedmont	1		1		2		3

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2018 and 2017 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 standards had the most significant impact on the Duke Energy results of operations, cash flows and financial position for the nine months endedSeptember 30, 2018.

Revenue from Contracts with Customers. In May 2014, the Financial Accounting Standards Board (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 expected in exchange for those goods or services. The amendments also required 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. The majority of Duke Energy’s revenue is in scope of the new guidance. Other revenue arrangements, such as alternative revenue programs and certain purchase power agreements (PPAs) and lighting agreements accounted for as leases, are excluded from the scope of this guidance and, therefore, are accounted for and evaluated for separate presentation and disclosure under other relevant accounting guidance.

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)

Duke Energy elected the modified retrospective method of adoption effective January 1, 2018. Under the modified retrospective method of adoption, prior year reported results are not restated. Adoption of this standard did not result in a material change in the timing or pattern of revenue recognition and a cumulative-effect adjustment was not recorded at January 1, 2018. Duke Energy utilized certain practical expedients including applying this guidance to open contracts at the date of adoption, expensing costs to obtain a contract where the amortization period of the asset would have been one year or less, ignoring the effects of a significant financing when the period between transfer of the good or service and payment is one year or less and recognizing revenues for certain contracts under the invoice practical expedient, which allows revenue recognition to be consistent with invoiced amounts (including unbilled estimates) provided certain criteria are met, including consideration of whether the invoiced amounts reasonably represent the value provided to customers.

In preparation for adoption, Duke Energy identified material revenue streams and reviewed representative contracts and tariffs, including those associated with certain long-term customer contracts such as wholesale contracts, PPAs and other customer arrangements. Duke Energy also monitored the activities of the power and utilities industry revenue recognition task force and has reviewed published positions on specific industry issues to evaluate the impact, if any, on Duke Energy’s specific contracts and conclusions.

Duke Energy applied the available practical expedient to portfolios of tariffs and contracts with similar characteristics. The vast majority of sales, including energy provided to retail customers, are from tariff offerings that provide natural gas or electricity without a defined contractual term ("at-will"). In most circumstances, revenue from contracts with customers is equivalent to the electricity or natural gas supplied and billed in that period (including unbilled estimates). As such, adoption of the new rules did not result in a shift in the timing or pattern of revenue recognition for such sales. While there have been changes to the captions and descriptions of revenues in Duke Energy’s financial statements, the most significant impact as a result of adopting the standard are additional disclosures around the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers. See Note 13 for further information.

Financial Instruments Classification and Measurement. On January 1, 2018, Duke Energy adopted FASB guidance, which revised the classification and measurement of certain financial instruments. The adopted guidance changes the presentation of realized and unrealized gains and losses in certain equity securities that were previously recorded in accumulated other comprehensive income (AOCI). These gains and losses are now recorded in net income. 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. This guidance had a 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' equity securities are deferred as regulatory assets or liabilities pursuant to accounting guidance for regulated operations. The resulting adjustment of unrealized gains and losses in AOCI to retained earnings was immaterial. The primary impact to Duke Energy as a result of implementing this guidance is adding disclosure requirements to present separately the financial assets and financial liabilities by measurement category and form of financial asset. See Notes 10 and 11 for further information.

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 Condensed Consolidated Statements of Cash Flows. Under the updated guidance, restricted cash and restricted cash equivalents are included within beginning-of-period and end-of-period cash and cash equivalents on the Condensed Consolidated Statements of Cash Flows. Duke Energy adopted this guidance on January 1, 2018. The guidance has been applied using a retrospective transition method to each period presented. The adoption by Duke Energy of the revised guidance resulted in a change to the amount of Cash, cash equivalents and restricted cash explained when reconciling the beginning-of-period and end-of-period total amounts shown on the Condensed Consolidated Statements of Cash Flows. In addition, a reconciliation has been provided of Cash, cash equivalents and restricted cash reported within the Condensed Consolidated Balance Sheets that sums to the total of the same such amounts in the Condensed Consolidated Statements of Cash Flows. Prior to adoption, the Duke Energy Registrants reflected changes in noncurrent restricted cash within Cash Flows from Investing Activities and changes in current restricted cash within Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows.

In August 2016, the FASB issued accounting guidance addressing diversity in practice for eight separate cash flow issues. The guidance requires entities to classify distributions received from equity method investees using either the cumulative earnings approach or the nature of the distribution approach. Duke Energy adopted this guidance on January 1, 2018, and elected the nature of distribution approach. This approach requires all distributions received to be categorized based on legal documentation describing the nature of the activities generating the distribution. Cash inflows resulting in a return on investment (surplus) will be reflected in Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows, whereas cash inflows resulting in a return of investment (capital) will be reflected in Cash Flows from Investing Activities on the Condensed Consolidated Statements of Cash Flows. The guidance has been applied using the retrospective transition method to each period presented. There are no changes to the Condensed Consolidated Statements of Cash Flows for the periods presented as a result of this accounting change.

Retirement Benefits. In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic costs related to benefit plans. Previous guidance required the aggregation of all the components of net periodic costs on the Condensed Consolidated Statement of Operations and did 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 is included within Operating Income within the same line as other compensation expenses. All other components of net periodic costs are 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 previous guidance, which permitted all components of net periodic costs to be eligible for capitalization.

Duke Energy adopted this guidance on January 1, 2018. Under previous guidance, Duke Energy presented the total non-capitalized net periodic costs within Operation, maintenance and other on the Condensed Consolidated Statements of Operations. The adoption of this guidance resulted in a retrospective change to reclassify the presentation of the non-service cost (benefit) components of net periodic costs to Other income and expenses. Duke Energy utilized the practical expedient for retrospective presentation. The change in components of net periodic costs eligible for capitalization is applicable prospectively. Since Duke Energy’s service cost component is greater than the total net periodic costs, the change results in increased capitalization of net periodic costs, higher Operation, maintenance and other and higher Other income and expenses. The resulting prospective impact to Duke Energy is an immaterial increase in Net Income. See Note 15 for further information.

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)

For Duke Energy, the retrospective change resulted in higher Operation, maintenance and other and higher Other income and expenses, net, of $156 million, $131 million and $96 million for the years ended December 31, 2017, 2016 and 2015, respectively. There was no change to Net Income for these prior periods.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of September 30, 2018.

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. The guidance will be applied using a modified retrospective approach. Upon adoption, agreements considered leases for the use of certain aircraft, space on communication towers, industrial equipment, fleet vehicles, fuel transportation (barges and railcars), land and office space will be recognized on the balance sheet. Duke Energy expects to elect certain of the following practical expedients upon adoption:

Practical Expedient	Description	Election
Package of transition practical expedients (for leases commenced prior to adoption date and must be adopted as a package)	Do not need to 1) reassess whether any expired or existing contracts are/or contain leases, 2) reassess the lease classification for any expired or existing leases and 3) reassess initial direct costs for any existing leases.	Duke Energy plans to elect this practical expedient.
Short-term lease expedient (elect by class of underlying asset)	Elect as an accounting policy to not apply the recognition requirements to short-term leases by asset class.	Duke Energy plans to elect this practical expedient for all asset classes.
Lease and non-lease components (elect by class of underlying asset)	Elect as an accounting policy to not separate non-lease components from lease components and instead account for each lease and associated non-lease component as a single lease component by asset class.	Duke Energy is currently assessing the election of this practical expedient.
Hindsight expedient (when determining lease term)	Elect to use hindsight to determine the lease term.	Duke Energy plans to elect this practical expedient.
Existing and expired land easements not previously accounted for as leases	Elect to not evaluate existing or expired easements under the new guidance and carry forward current accounting treatment.	Duke Energy plans to elect this practical expedient.
Comparative reporting requirements for initial adoption	Elect to apply transition requirements at adoption date, recognize cumulative effect adjustment to retained earnings in period of adoption and not apply ASC 842 to comparative periods, including disclosures.	Duke Energy plans to elect this practical expedient.
Lessor expedient (elect by class of underlying asset)	Elect as an accounting policy to aggregate non-lease components with the related lease component when specified conditions are met by asset class. Account for the combined component based on its predominant characteristic (revenue or operating lease).	Duke Energy is currently assessing the election of this practical expedient.

Duke Energy is currently evaluating the financial statement impact of adopting this standard and is continuing to monitor industry implementation issues, including leases within asset retirement obligations, pipeline laterals and renewable energy PPAs. In arrangements where Duke Energy is the lessee, it expects an increase in assets and liabilities on its balance sheet along with the addition of required disclosures of key lease information. However, the ultimate lessee impact of the new standard has not yet been determined. Duke Energy does not expect a material change to its financial statements from adoption of the new standard for contracts where it is the lessor. System enhancements, including additional processes and controls, will be required to facilitate the identification, tracking and reporting of potential leases based upon requirements of the new lease standard. Duke Energy is implementing a third-party software tool to help with the adoption and ongoing accounting under the new standard.

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

Duke Energy

Duke Energy's segment structure includes the following segments: Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables.

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)

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 midstream 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 interest expense on holding company debt, unallocated corporate costs and Duke Energy’s wholly owned captive insurance company, Bison Insurance Company Limited (Bison). Other also includes Duke Energy's 17.5 percent interest in National Methanol Company (NMC), a large regional producer of methyl tertiary butyl ether 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 September 30, 2018
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	6,253	$	232	$	127		$	6,612	$	16		$	—		$	6,628
Intersegment revenues	7		24		—			31		18			(49		)	—
Total revenues	$	6,260	$	256	$	127		$	6,643	$	34		$	(49	)	$	6,628
Segment income (loss)(a)(b)(c)	$	1,167	$	17	$	(62	)	$	1,122	$	(44	)	$	—		$	1,078
Add back noncontrolling interests																(16		)
Income from discontinued operations, net of tax																4
Net income																$	1,066
Segment assets	$	123,847	$	11,806	$	4,212		$	139,865	$	3,115		$	185		$	143,165

	Three Months Ended September 30, 2017
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	6,122	$	249	$	95		$	6,466	$	16		$	—		$	6,482
Intersegment revenues	7		23		—			30		19			(49		)	—
Total revenues	$	6,129	$	272	$	95		$	6,496	$	35		$	(49	)	$	6,482
Segment income (loss)(b)(d)(e)	$	1,020	$	19	$	(49	)	$	990	$	(34	)	$	—		$	956
Add back noncontrolling interests																1
Loss from discontinued operations, net of tax																(2		)
Net income																$	955

(a) All segments include adjustments to the December 31, 2017 estimate of the income tax effects of the Tax Act. See Note 17 for additional information.

(b) Other includes costs to achieve the Piedmont acquisition.

(c) Commercial Renewables includes an impairment charge related to goodwill. See Note 7 for additional information.

(d) Electric Utilities and Infrastructure includes an impairment charge related to the unrecovered Levy Nuclear Project costs at Duke Energy Florida.

(e) Commercial Renewables includes impairment charges related to certain wind projects.

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)

	Nine Months Ended September 30, 2018
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	16,783	$	1,229	$	347		$	18,359	$	47		$	—		$	18,406
Intersegment revenues	23		72		—			95		54			(149		)	—
Total revenues	$	16,806	$	1,301	$	347		$	18,454	$	101		$	(149	)	$	18,406
Segment income (loss)(a)(b)(c)(d)(e)(f)	$	2,492	$	161	$	(4	)	$	2,649	$	(446	)	$	—		$	2,203
Add back noncontrolling interests																(12		)
Loss from discontinued operations, net of tax																(1		)
Net income																$	2,190

	Nine Months Ended September 30, 2017
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	16,211	$	1,175	$	333	$	17,719	$	47		$	—		$	17,766
Intersegment revenues	23		68		—		91		56			(147		)	—
Total revenues	$	16,234	$	1,243	$	333	$	17,810	$	103		$	(147	)	$	17,766
Segment income (loss)(c)(g)(h)	$	2,384	$	179	$	2	$	2,565	$	(205	)	$	—		$	2,360
Add back noncontrolling interests															5
Loss from discontinued operations, net of tax															(4		)
Net income															$	2,361

(a) All segments include adjustments to the December 31, 2017 estimate of the income tax effects of the Tax Act. See Note 17 for additional information.

(b) Electric Utilities and Infrastructure includes regulatory and legislative impairment charges related to rate case orders, settlements or other actions of regulators or legislative bodies. See Note 3 for additional information.

(c) Other includes costs to achieve the Piedmont acquisition.

(d) Gas Utilities and Infrastructure includes an impairment of the investment in Constitution Pipeline Company, LLC (Constitution). See Note 3 for additional information.

(e) Other includes the loss on the sale of the retired Beckjord Generating Station (Beckjord) described below and a valuation allowance recorded against the alternative minimum tax credits subject to sequestration. See Note 17 for additional information on the valuation allowance.

(f) Commercial Renewables includes an impairment charge related to goodwill. See Note 7 for additional information.

(g) Electric Utilities and Infrastructure includes an impairment charge related to the unrecovered Levy Nuclear Project costs at Duke Energy Florida.

(h) Commercial Renewables includes impairment charges related to certain wind projects.

In February 2018, Duke Energy sold Beckjord, a nonregulated facility retired during 2014, and recorded a pretax loss of $106 million within Gains (Losses) on Sales of Other Assets and Other, net and $1 million within Operation, maintenance and other on Duke Energy's Condensed Consolidated Statements of Operations for the nine months endedSeptember 30, 2018. The sale included the transfer of coal ash basins and other real property and indemnification from any and all potential future claims related to the property, whether arising under environmental laws or otherwise.

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 Northern Kentucky. Gas Utilities and Infrastructure transports and sells natural gas in portions of Ohio and Northern Kentucky. Both reportable operating segments conduct operations primarily through Duke Energy Ohio and its wholly owned subsidiary, Duke Energy Kentucky.

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 remainder of Duke Energy Ohio's operations is presented as Other, which 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 September 30, 2018
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations			Consolidated
Total revenues	$	373	$	84	$	457	$	12	$	—		$	469
Segment income/Net income	$	85	$	12	$	97	$	3	$	—		$	100
Segment assets	$	5,484	$	2,775	$	8,259	$	39	$	(2	)	$	8,296

	Three Months Ended September 30, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	371	$	90	$	461	$	10		$	471
Segment income (loss)	$	50	$	14	$	64	$	(8	)	$	56
Loss from discontinued operations, net of tax										(1		)
Net income										$	55

	Nine Months Ended September 30, 2018
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	1,055	$	361	$	1,416	$	36		$	1,452
Segment income (loss)/Net income(a)	$	157	$	64	$	221	$	(100	)	$	121

	Nine Months Ended September 30, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	1,036	$	360	$	1,396	$	30		$	1,426
Segment income (loss)	$	96	$	56	$	152	$	(24	)	$	128
Loss from discontinued operations, net of tax										(1		)
Net income										$	127

(a)    Other includes the loss on the sale of Beckjord.

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)

3. 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

Grid Improvement – South Carolina

On June 22, 2018, Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the PSCSC seeking an accounting order authorizing deferral of certain costs incurred in connection with grid reliability, resiliency and modernization work that is being performed under the companies’ grid improvement initiative. On October 3, 2018, the PSCSC granted Duke Energy Carolinas' and Duke Energy Progress' joint petition.

Hurricane Florence Storm Damage

In September 2018, Hurricane Florence made landfall and inflicted severe damage to the Duke Energy Carolinas and Duke Energy Progress territories in North Carolina and South Carolina. Approximately 1.8 million customers were impacted. The companies incurred approximately $455 million in operation and maintenance expenses ($35 million and $420 million for Duke Energy Carolinas and Duke Energy Progress, respectively,) and approximately $85 million in capital costs ($10 million and $75 million for Duke Energy Carolinas and Duke Energy Progress, respectively,) which are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of September 30, 2018, resulting from the hurricane restoration efforts. Most of the operation and maintenance expenses are deferred in Regulatory assets within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of September 30, 2018. The balance of operation and maintenance expenses are included in Operation, maintenance and other on the Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2018.

Given the magnitude of the storm, Duke Energy Progress intends to request approval in North Carolina and South Carolina to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate case. These requests are expected to be filed during the fourth quarter of 2018.

Duke Energy Carolinas

2017 North Carolina Rate Case

On August 25, 2017, Duke Energy Carolinas filed an application with the NCUC for a rate increase for retail customers of approximately $647 million, which represented an approximate 13.6 percent increase in annual base revenues. The rate increase was driven by capital investments subsequent to the previous base rate case, including the William States Lee Combined Cycle Facility discussed below, grid improvement projects, advanced metering infrastructure (AMI), investments in customer service technologies, costs of complying with coal combustion residuals (CCR) regulations and the North Carolina Coal Ash Management Act of 2014 (Coal Ash Act) and recovery of costs related to licensing and development of the William States Lee III Nuclear Station (Lee Nuclear Station) discussed below.

On February 28, 2018, Duke Energy Carolinas and the North Carolina Public Staff (Public Staff) filed an Agreement and Stipulation of Partial Settlement resolving certain portions of the proceeding. Terms of the settlement included a return on equity of 9.9 percent and a capital structure of 52 percent equity and 48 percent debt. As a result of the settlement, Duke Energy Carolinas recorded a pretax charge of approximately $4 million to Operation, maintenance and other on the Condensed Consolidated Statements of Operations.

On June 1, 2018, Duke Energy Carolinas and certain intervenors filed a Pilot Grid Rider Agreement and Stipulation (Grid Rider Stipulation) in which the parties agreed to the proposal Duke Energy Carolinas introduced in a post-hearing brief on April 27, 2018, along with additional commitments by Duke Energy Carolinas. Also on June 1, 2018, Duke Energy Carolinas and the Commercial Group filed a Partial Stipulation and Settlement Agreement to be considered in conjunction with the Stipulation.

Components of the Grid Rider Stipulation included:

• Duke Energy Carolinas would recover grid improvement costs through a pilot, three-year Grid Rider except for costs related to targeted undergrounding of power lines, cable and conduit replacement, and power pole replacement;

• Excluded costs were to be deferred with a return until Duke Energy Carolinas’ next base rate case proceeding; and

• Costs incurred during the three-year pilot, both rider recoverable and deferred, were subject to a 4.5 percent cumulative cap of total annual electric service revenue.

47

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)

On June 22, 2018, the NCUC issued an order approving the Stipulation of Partial Settlement and requiring a revenue reduction. The order also included the following material components not covered in the Stipulation:

• Recovery of $554 million of deferred coal ash basin closure costs over a five-year period with a return at Duke Energy Carolinas' weighted average cost of capital (WACC);

• Assessment of a $70 million management penalty ratably over a five-year period by reducing the annual recovery of the deferred coal ash costs;

• Denial of Duke Energy Carolinas' request for recovery of future estimated ongoing annual coal ash costs of $201 million with approval to defer such costs with a return at Duke Energy Carolinas' WACC, to be considered for recovery in the next rate case;

• Inclusion in rates of costs related to the Lee Combined Cycle Facility, two new solar facilities, and AMI deployment as requested;

• Recovery of Lee Nuclear Station licensing and development cost of $347 million over a 12-year period, but denial of a return on the deferred balance of costs;

• Reduction in revenue related to lower income tax expense resulting from the Federal Tax Cuts and Jobs Act (Tax Act), and a requirement to maintain all excess deferred income tax (EDIT) resulting from the Tax Act in a regulatory liability account pending flow back to customers as approved by the commission at the earlier of three years or Duke Energy Carolinas’ next general rate case proceeding; and

• Denial of the proposed Grid Rider Stipulation related to grid improvement costs and denial of deferral accounting treatment of the costs at this time. Duke Energy Carolinas may petition for deferral of grid modernization costs outside of a general rate case proceeding if it can show financial hardship or a stipulation that includes greater consensus among intervening parties on costs being classified as grid modernization.

As a result of the Order, Duke Energy Carolinas recorded a pretax charge of approximately $150 million to Impairment charges and Operation, maintenance and other on the Condensed Consolidated Statements of Operations. The charge is primarily related to the denial of a return on the Lee Nuclear Project and for previously recognized return impacted by the coal ash management penalty described above. On July 27, 2018, NCUC approved Duke Energy Carolinas' compliance filing. As a result, revised customer rates were effective on August 1, 2018.

On July 20, 2018, the North Carolina Attorney General filed a Notice of Appeal to the North Carolina Supreme Court from the June 22, 2018, Order Accepting Stipulation, Deciding Contested Issues and Requiring Revenue Reduction issued by the NCUC. The Attorney General contends the commission’s order should be reversed and remanded, as it is in excess of the commission’s statutory authority; affected by errors of law; unsupported by competent, material and substantial evidence in view of the entire record as submitted; and arbitrary or capricious. The Sierra Club, North Carolina Sustainable Energy Association, North Carolina Justice Center, North Carolina Housing Coalition, Natural Resource Defense Council and Southern Alliance for Clean Energy have also filed Notices of Appeal to the North Carolina Supreme Court from the June 22, 2018, Order Accepting Stipulation, Deciding Contested Issues and Requiring Revenue Reduction. On August 8, 2018, the Public Staff filed a Notice of Cross Appeal to the North Carolina Supreme Court from the June 22, 2018, Order Accepting Stipulation, Deciding Contested Issues and Requiring Revenue Reduction issued by the NCUC. The Public Staff contends the commission’s order should be reversed and remanded, as it is affected by errors of law, and is unsupported by substantial evidence with regard to the commission’s failure to consider substantial evidence of coal ash related environmental violations. The briefing will likely be delayed until the second quarter of 2019. Duke Energy Carolinas cannot predict the outcome of this matter.

2018 South Carolina Rate Case

On October 8, 2018, Duke Energy Carolinas filed a notice with the PSCSC of the company’s intent to file a base rate adjustment application no earlier than 30 days from the notice submittal date.

FERC Formula Rate Matter

On July 31, 2017, Piedmont Municipal Power Agency (PMPA) filed a complaint with FERC against Duke Energy Carolinas alleging that Duke Energy Carolinas misapplied the formula rate under the PPA between the parties by including in its rates amortization expense associated with regulatory assets and recorded in a certain account without FERC approval. On February 15, 2018, FERC issued an order ruling in favor of PMPA and ordered Duke Energy Carolinas to refund to PMPA all amounts improperly collected under the PPA. Duke Energy Carolinas has issued to PMPA and similarly situated wholesale customers refunds of approximately $25 million. FERC also set the matter for settlement and hearing. PMPA and other customers filed a protest to Duke Energy Carolinas' refund report claiming that the refunds are inadequate in that (1) Duke Energy Carolinas invoked the limitations periods in the contracts to limit the time period for which the refunds were paid and the customers disagree that this limitation applies, and (2) Duke Energy Carolinas refunded only amounts recovered through a certain account and the customers have asserted that the order applies to all regulatory assets. On July 3, 2018, FERC issued an order accepting Duke Energy Carolinas' refund report and ruling that these two claims are outside the scope of FERC's February order. Duke Energy Carolinas will file revised formula rates as well as settlement agreements which are subject to FERC approval. Duke Energy Carolinas cannot predict the outcome of this matter.

48

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)

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 for the construction and operation of a 750-megawatt (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 its share of the cost to build the facility was approximately $650 million, including allowance for funds used during construction (AFUDC). Approximately $600 million is being recovered through base rate or deferral filings in North Carolina and South Carolina. The remaining amount will be included in future rate filings. The project commenced commercial operation on April 5, 2018. NCEMC owns approximately 13 percent of the project.

Lee 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 concurred with the prudency of Duke Energy Carolinas incurring 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.

The Duke Energy Carolinas rate case filing discussed above included a request to cancel the development of the Lee Nuclear Station project, recover incurred licensing and development costs and maintain the license issued by the NRC as an option for potential future development. The cancellation request was due to the Westinghouse bankruptcy filing and other market activity. The NCUC Order issued on June 22, 2018, approved the cancellation of the Lee Nuclear Project, allowed Duke Energy Carolinas to continue to maintain the COLs, provided for recovery of the North Carolina retail allocation of project development costs, including AFUDC accrued through December 31, 2017, over 12 years and disallowed any return on the unamortized balance during the 12-year recovery period.

Given the recent repeal of certain sections of the Base Load Review Act in South Carolina combined with the cancellation of the project, Duke Energy Carolinas determined that it was no longer probable it would be allowed a return on its share of project development costs attributable to South Carolina. As a result, Duke Energy Carolinas recorded a pretax impairment in the second quarter of $29 million within Impairment charges on the Condensed Consolidated Statements of Operations and Comprehensive Income.

South Carolina Petition

On June 22, 2018, Duke Energy Carolinas filed a petition with the PSCSC requesting an accounting order to defer certain costs incurred in connection with the addition of the William States Lee Combined Cycle Facility, the ongoing deployment of Duke Energy Carolinas new billing and Customer Information System and the addition of the Carolinas West Primary Distribution Control Center. This request totaling approximately $33 million was approved on July 25, 2018.

Sale of Hydroelectric (Hydro) Plants

In May 2018, Duke Energy Carolinas entered an agreement for the sale of five hydro plants with a combined 18.7-MW generation capacity in the Western Carolinas region to Northbrook Energy. The completion of the transaction is subject to approval from FERC, as well as other state regulatory agencies and is contingent upon regulatory approval from the NCUC and PSCSC to defer the total estimated loss on the sale of approximately $40 million. On July 5, 2018, Duke Energy Carolinas filed with NCUC for approval of the sale of the five hydro plants to Northbrook, to transfer the Certificates of Public Convenience and Necessity (CPCN) for the four North Carolina hydro plants and to establish a regulatory asset for the North Carolina retail portion of the difference between sales proceeds and net book value. On September 4, 2018, the Public Staff filed comments supporting the CPCN transfer with conditions, specifically that the commission direct Duke Energy Carolinas and the Public Staff to further evaluate the reasonableness of Duke Energy Carolinas' expenditures at the facilities in the 36 months leading up to the agreement for the sale for consideration in the next rate case. On September 18, 2018, Duke Energy Carolinas filed reply comments opposing this condition. The Public Staff also recommended that the amortization period for the regulatory asset start in the month in which the asset transfer is completed, rather than be delayed until the next rate case. On August 28, 2018, Duke Energy Carolinas filed with PSCSC its Application for Approval of Transfer and Sale of Hydroelectric Generation Facilities, Acceptance for Filing of a Power Purchase Agreement and an Accounting Order to Establish a Regulatory Asset. On September 10, 2018, the South Carolina Office of Regulatory Staff (ORS) provided a letter to the commission stating its position on the application and on September 18, 2018, Duke Energy Carolinas requested this matter be carried over to allow Duke Energy Carolinas time to discuss certain accounting issues with the ORS. On October 9, 2018, Duke Energy Carolinas filed a Notice of Application for Transfer of Licenses with the FERC, which provides 30 days to file comments and motions to intervene.

If commission approvals are not received, Duke Energy Carolinas can cancel the sales agreement and retain the hydro facilities. If commission approvals are received, the closing is expected to occur during the first quarter of 2019. After closing, Duke Energy Carolinas will purchase all the capacity and energy generated by these facilities at the avoided cost for five years through power purchase agreements. Duke Energy Carolinas cannot predict the outcome of this matter.

49

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

2017 North Carolina Rate Case

On June 1, 2017, Duke Energy Progress filed an application with the NCUC for a rate increase for retail customers of approximately $477 million, which represented an approximate 14.9 percent increase in annual base revenues. Subsequent to the filing, Duke Energy Progress adjusted the requested amount to $420 million, representing an approximate 13 percent increase. The rate increase is driven by capital investments subsequent to the previous base rate case, costs of complying with CCR regulations and the Coal Ash Act, costs relating to storm recovery, investments in customer service technologies and recovery of costs associated with renewable purchased power.

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. The final estimate of incremental operation and maintenance and capital costs of $116 million was filed with the NCUC in September 2017. On July 10, 2017, the NCUC consolidated Duke Energy Progress' storm deferral request into the Duke Energy Progress rate case docket for decision.

On November 22, 2017, Duke Energy Progress and the Public Staff filed an Agreement and Stipulation of Partial Settlement resolving certain portions of the proceeding. Terms of the settlement included a return on equity of 9.9 percent and a capital structure of 52 percent equity and 48 percent debt. As a result of the settlement, in 2017 Duke Energy Progress recorded pretax charges totaling approximately $25 million to Impairment charges and Operation, maintenance and other on the Condensed Consolidated Statements of Operations, principally related to disallowances from rate base of certain projects at the Mayo and Sutton plants. On February 23, 2018, the NCUC issued an order approving the stipulation. The order also included the following material components not covered in the stipulation:

• Recovery of the remaining $234 million of deferred coal ash basin closure costs over a five-year period with a return at Duke Energy Progress' WACC, excluding $9.5 million of retail deferred coal ash basin costs related to ash hauling at Duke Energy Progress' Asheville Plant;

• Assessment of a $30 million management penalty ratably over a five-year period by reducing the annual recovery of the deferred coal ash costs;

• Denial of Duke Energy Progress' request for recovery of future estimated ongoing annual coal ash costs of $129 million with approval to defer such costs with a return at Duke Energy Progress' WACC, to be considered for recovery in the next rate case; and

• Approval to recover $51 million of the approximately $80 million deferred storm costs over a five-year period with amortization beginning in October 2016. The order did not allow the deferral of the associated capital costs or a return on the deferred balance during the deferral period.

The order also impacted certain amounts that were similarly recorded on Duke Energy Carolinas' Condensed Consolidated Balance Sheets. As a result of the order, Duke Energy Progress and Duke Energy Carolinas recorded pretax charges of $68 million and $14 million, respectively, in the first quarter of 2018 to Impairment charges, Operation, maintenance and other and Interest Expense on the Condensed Consolidated Statements of Operations. These charges primarily related to the coal ash basin disallowance and previously recognized return impacted by the coal ash management penalty and deferred storm cost adjustments. Revised customer rates became effective on March 16, 2018.

On May 15, 2018, the Public Staff filed a Notice of Cross Appeal to the North Carolina Supreme Court from the February 23, 2018, Order Accepting Stipulation, Deciding Contested Issues and Granting Partial Rate Increase issued by the NCUC. The Public Staff contend the commission’s order should be reversed and remanded, as it is affected by errors of law, and is unsupported by competent, material and substantial evidence in view of the entire record as submitted. The North Carolina Attorney General and Sierra Club have also filed Notices of Appeal to the North Carolina Supreme Court from the February 23, 2018, Order Accepting Stipulation, Deciding Contested Issues and Granting Partial Rate Increase. The briefing will likely be delayed until the second quarter of 2019. Duke Energy Progress cannot predict the outcome of this matter.

2016 South Carolina Rate Case

In December 2016, the PSCSC approved a rate case settlement agreement among the ORS, intervenors and Duke Energy Progress. Terms of the settlement agreement included an approximate $56 million increase in revenues over a two-year period. An increase of approximately $38 million in revenues was effective January 1, 2017, and an additional increase of approximately $18.5 million in revenues was effective January 1, 2018. Duke Energy Progress amortized approximately $18.5 million from the cost of removal reserve in 2017. Other settlement terms included a rate of return on equity of 10.1 percent, recovery of coal ash costs incurred from January 1, 2015, through June 30, 2016, over a 15‑year period and ongoing deferral of allocated ash basin closure costs from July 1, 2016, until the next base rate case. The settlement also provides that Duke Energy Progress will not seek an increase in rates in South Carolina to occur prior to 2019, with limited exceptions.

2018 South Carolina Rate Case

On October 8, 2018, Duke Energy Progress filed a notice with the PSCSC of the company’s intent to file a base rate adjustment application no earlier than 30 days from the notice submittal date.

50

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)

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 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, 2018, 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 complete and construction of these plants began in 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 $352 million and $385 million is included in Generation facilities to be retired, net on Duke Energy Progress' Condensed Consolidated Balance Sheets as of September 30, 2018, and December 31, 2017, respectively. Duke Energy Progress' request for a regulatory asset at the time of retirement with amortization over a 10-year period was approved by the NCUC on February 23, 2018.

Shearon Harris Nuclear Plant Expansion

In 2006, Duke Energy Progress selected a site at Harris to evaluate for possible future nuclear expansion. On February 19, 2008, Duke Energy Progress filed its COL application with the NRC for two Westinghouse AP1000 reactors at Harris, which the NRC docketed for review. On May 2, 2013, Duke Energy Progress filed a letter with the NRC requesting the NRC to suspend its review activities associated with the COL at the Harris site. The NCUC and PSCSC approved deferral of retail costs. Total deferred costs were approximately $47 million as of December 31, 2017, and are recorded in Regulatory assets on Duke Energy Progress’ Condensed Consolidated Balance Sheets. On November 17, 2016, the FERC approved Duke Energy Progress’ rate recovery request filing for the wholesale ratepayers’ share of the abandonment costs, including a debt-only return to be recovered through revised formula rates and amortized over a 15-year period beginning May 1, 2014. As part of the settlement agreement for the 2017 North Carolina Rate Case discussed above, Duke Energy Progress will amortize the regulatory asset over an eight-year period. NCUC approved the settlement on February 23, 2018.

South Carolina Petitions

On June 22, 2018, Duke Energy Progress filed a petition with the PSCSC seeking an accounting order authorizing Duke Energy Progress to adopt new depreciation rates, effective March 16, 2018, that reflect the results of Duke Energy Progress’ most recent depreciation study. Also on June 22, 2018, Duke Energy Progress filed a petition with the PSCSC requesting an accounting order to defer certain costs incurred in connection with the deployment of AMI, the ongoing deployment of Duke Energy Progress' new billing and Customer Information System, new depreciation rates and costs incurred in connection with the return of certain excess deferred state income taxes from North Carolina. These requests totaling approximately $20 million were approved on July 25, 2018.

FERC Form 1 Reporting Matter

On October 18, 2017, Fayetteville Public Works Commission (FPWC) filed with FERC a complaint against Duke Energy Progress. In the complaint, FPWC alleges that Duke Energy Progress’ change in its method of reporting materials and supplies inventory on FERC Form 1 for 2015 constituted a change in accounting practice that Duke Energy Progress was not permitted to implement without first obtaining FERC approval. On April 23, 2018, FERC issued an order finding that Duke Energy Progress’ new reporting methodology was not proper and required Duke Energy Progress to revise its FERC Form 1s beginning in 2014 and to issue refunds to formula rate customers. Duke Energy Progress estimates that these refunds will total approximately $14 million. On May 23, 2018, Duke Energy Progress filed a request for rehearing alleging that FERC’s order is incorrect. Duke Energy Progress revised its FERC Form 1 filings in June 2018. On August 31, 2018, Duke Energy Progress filed with FERC a refund report memorializing its payment of refunds to FPWC. Duke Energy Progress cannot predict the outcome of this matter.

Tax Act

As ordered by the NCUC on October 5, 2018, Duke Energy Progress filed a proposal on October 25, 2018, to adjust rates to reflect the reduction in federal corporate income tax rate from 35 to 21 percent for taxable years beginning after December 31, 2017, as outlined in the Tax Act. Duke Energy Progress proposes that this rate decrement be effective for service rendered on and after December 1, 2018. The Public Staff is requested to file comments on the proposal no later than November 14, 2018, and other parties may also file comments on the proposals no later than November 14, 2018. Duke Energy Progress cannot predict the outcome of this matter.

51

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

Storm Restoration Cost Recovery

In September 2017, Duke Energy Florida’s service territory suffered significant damage from Hurricane Irma, resulting in approximately 1.3 million customers experiencing outages. In the fourth quarter of 2017, Duke Energy Florida also incurred preparation costs related to Hurricane Nate. On December 28, 2017, Duke Energy Florida filed a petition with the FPSC to recover incremental storm restoration costs for hurricanes Irma and Nate and to replenish the storm reserve. On February 6, 2018, the FPSC approved a stipulation that would apply tax savings resulting from the Tax Act toward storm costs effective January 2018 in lieu of implementing a storm surcharge. Storm costs are currently expected to be fully recovered by approximately mid-2021. On May 31, 2018, Duke Energy Florida filed a petition for approval of actual storm restoration costs and associated recovery process related to Hurricanes Irma and Nate. The petition is seeking the approval for the recovery in the amount of $510 million in actual recoverable storm restoration costs, including the replenishment of Duke Energy Florida’s storm reserve of $132 million, and the process for recovering these recoverable storm costs. On August 20, 2018, the FPSC approved Duke Energy Florida's unopposed Motion for Continuance filed August 17, 2018, to allow for an evidentiary hearing in this matter. The commission has scheduled the hearing to begin on May 21, 2019. At September 30, 2018, Duke Energy Florida's Condensed Consolidated Balance Sheets included approximately $258 million of recoverable costs under the FPSC's storm rule in Regulatory assets within Current Assets and Other Noncurrent Assets related to storm recovery. Duke Energy Florida cannot predict the outcome of this matter.

Tax Act

Pursuant to Duke Energy Florida's 2017 Revised and Restated Settlement Agreement, on May 31, 2018, Duke Energy Florida filed a petition related to the Tax Act, which included annual tax savings of $84 million and annual amortization of EDIT of $67 million for a total of $151 million. The pretax revenue requirement impact is $201 million, of which $50 million will be offset with accelerated depreciation of Crystal River 4 and 5 coal units and $151 million will be offset by Hurricane Irma storm cost recovery as explained in the Storm Restoration Cost Recovery section above. The petition is subject to review and approval by the FPSC. Duke Energy Florida cannot predict the outcome of this matter.

Citrus County Combined Cycle Facility

On October 2, 2014, the FPSC granted Duke Energy Florida a Determination of Need for the construction of a 1,640-MW combined-cycle natural gas plant in Citrus County, Florida. On May 5, 2015, the Florida Department of Environmental Protection approved Duke Energy Florida's Site Certification Application. The project has received all required permits and approvals and construction began in October 2015. The facility is expected to be commercially available by the end of 2018 at an estimated cost of $1.5 billion, including AFUDC. Actual costs are expected to exceed this estimate by an immaterial amount after recoveries; therefore, an impairment is not expected. On April 2, 2018, Duke Energy Florida filed a petition seeking approval to include in base rates the revenue requirements associated with the new facility. The annual retail revenue requirement is approximately $200 million. On July 10, 2018, the FPSC voted to approve Duke Energy Florida's request to include the revenue requirements for the new Citrus County combined-cycle units in base rates. The first 820-MW power block came on line on October 26, 2018, and the rate increase for this unit will be effective in December 2018. The second 820-MW power block remains on track to start serving customers in December 2018. The rate increase for the second unit is expected to take place in January 2019. The plant will receive natural gas from the Sabal Trail pipeline discussed below.

Solar Base Rate Adjustment

On July 31, 2018, Duke Energy Florida petitioned the FPSC to include in base rates the revenue requirements for its first two solar generation projects, the Hamilton Project and the Columbia Project, as authorized by the 2017 Second Revised and Restated Stipulation and Settlement Agreement. The annual retail revenue requirement for the Hamilton Project is $15.2 million and the increase would take effect with the first billing cycle in January 2019. The Columbia Project has a projected annual revenue requirement of $14 million and a projected in-service date in early 2020; the associated rate increase would take place with the first month’s billing cycle after the Columbia Project goes into service. At its October 30, 2018, Agenda Conference, the FPSC approved the rate increase related to the Hamilton Project to go into effect beginning with the first billing cycle in January 2019 under its file and suspend authority. Rates are subject to true up pending the outcome of the final hearing, which is scheduled to take place on April 2, 2019.

Duke Energy Ohio

2017 Electric Security Plan Filing

On June 1, 2017, Duke Energy Ohio filed with the PUCO a request for a standard service offer in the form of an electric security plan (ESP). If approved by the PUCO, the term of the ESP would be from June 1, 2018, to May 31, 2025. Terms of the ESP include continuation of market-based customer rates through competitive procurement processes for generation, continuation and expansion of existing rider mechanisms and proposed new rider mechanisms relating to regulatory mandates, costs incurred to enhance the customer experience and transform the grid and a service reliability rider for vegetation management. On February 15, 2018, the procedural schedule was suspended to facilitate ongoing settlement discussions. On April 13, 2018, Duke Energy Ohio filed a Motion to consolidate this proceeding with several other cases currently pending before the PUCO, including, but not limited to, its Electric Base Rate Case. Additionally, on April 13, 2018, Duke Energy Ohio, along with certain intervenors, filed a Stipulation and Recommendation (Stipulation) with the PUCO resolving certain issues in this proceeding. The Stipulation establishes a regulatory model for the next seven years via the approval of the ESP and continues the current model for procuring supply for non-shopping customers, including recovery mechanisms. The Stipulation is subject to the review and approval of PUCO. An evidentiary hearing to review the Stipulation and other issues in the cases concluded on August 6, 2018. Initial briefs were filed on September 11, 2018. Reply briefs were filed October 2, 2018. Duke Energy Ohio cannot predict the outcome of this matter.

52

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)

Electric 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. On September 26, 2017, the PUCO staff filed a report recommending a revenue decrease between approximately $18 million and $29 million and a return on equity between 9.22 percent and 10.24 percent. On February 15, 2018, the procedural schedule was suspended to facilitate ongoing settlement discussions. On April 13, 2018, Duke Energy Ohio filed a Motion to consolidate this proceeding with several other cases currently pending before the PUCO. On April 13, 2018, Duke Energy Ohio, along with certain intervenors, filed the Stipulation with the PUCO resolving numerous issues including those in this base rate proceeding. Major components of the Stipulation related to the base distribution rate case include a $19 million decrease in annual base distribution revenue with a return on equity unchanged from the current rate of 9.84 percent based upon a capital structure of 50.75 percent equity and 49.25 percent debt. Upon approval of new rates, Duke Energy Ohio's rider for recovering its initial SmartGrid implementation ends as these costs will be recovered through base rates. The Stipulation also renews 14 existing riders, some of which were included in the company's ESP, and adds two new riders including the Enhanced Service Reliability Rider to recover vegetation management costs not included in base rates, up to $10 million per year (operation and maintenance only) and the PowerForward Rider to recover costs incurred to enhance the customer experience and further transform the grid (operation and maintenance and capital). The Stipulation is subject to the review and approval of the PUCO. An evidentiary hearing to review the Stipulation and other issues in the cases concluded on August 6, 2018. Initial briefs were filed on September 11, 2018. Reply briefs were filed October 2, 2018. In addition to the changes in revenue attributable to the Stipulation, Duke Energy Ohio’s capital-related riders, including the Distribution Capital Investments Rider, began to reflect the lower federal income tax rate associated with the Tax Act with updates to customers’ bills beginning April 1, 2018. This change reduces electric revenue by approximately $20 million on an annualized basis. Duke Energy Ohio cannot predict the outcome of this matter.

Ohio Valley Electric Corporation

On March 31, 2017, Duke Energy Ohio filed for approval to adjust its existing price stabilization rider (Rider PSR), which is currently set at zero dollars, to pass through net costs related to its contractual entitlement to capacity and energy from the generating assets owned by OVEC. 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. Various intervenors have filed motions to dismiss or stay the proceeding and Duke Energy Ohio has opposed these filings. On April 13, 2018, Duke Energy Ohio filed a Motion to consolidate this proceeding with several other cases currently pending before the PUCO. Also on April 13, 2018, Duke Energy Ohio, along with certain intervenors, filed a Stipulation with the PUCO resolving numerous issues including those related to Rider PSR. The Stipulation, if approved, would activate Rider PSR for recovery of net costs incurred since January 1, 2018. The Stipulation is subject to the review and approval of PUCO. An evidentiary hearing to review the Stipulation and other issues in the cases concluded on August 6, 2018. Initial briefs were filed on September 11, 2018. Reply briefs were filed October 2, 2018. See Note 12 for additional discussion of Duke Energy Ohio's ownership interest in OVEC. Duke Energy Ohio cannot predict the outcome of this matter.

Tax Act – Ohio

On July 25, 2018, Duke Energy Ohio filed an application to establish a new rider to implement the benefits of the Tax Act for electric distribution customers. Duke Energy Ohio requested commission approval to implement the rider effective October 1, 2018, as a credit to all distribution customers based upon a percent reduction to Duke Energy Ohio’s distribution rates. The new rider will flow through to customers the benefit of the lower statutory federal tax rate from 35 to 21 percent since January 1, 2018, all future benefits of the lower tax rates and a full refund of deferred income taxes collected at the higher tax rates in prior years. Deferred income taxes subject to normalization rules will be refunded consistent with federal law and deferred income taxes not subject to normalization rules will be refunded over a 10-year period. An order is expected during the fourth quarter of 2018. Duke Energy Ohio's transmission rates reflect lower federal income tax but guidance from FERC on amortization of both protected and unprotected transmission-related EDITs is still pending. On October 24, 2018, the PUCO issued a Finding and Order that, among other things, directed all rate-regulated utilities file an application not for an increase in rates to reflect the impact of the Tax Act on their current rates by January 1, 2019, unless otherwise exempted or directed by the PUCO. Duke Energy Ohio's July 25, 2018, filing for electric distribution operations is consistent with the commission's October 24, 2018, Finding and Order and no further action is needed. Options for Duke Energy Ohio gas customers are still being evaluated. Duke Energy Ohio cannot predict the outcome of this matter.

53

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)

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. In December 2016, the PUCO granted the intervenors request for rehearing for the purpose of further review. Duke Energy Ohio cannot predict the outcome of this matter.

On June 15, 2016, Duke Energy Ohio filed an application for approval of a three-year energy efficiency and peak demand reduction portfolio of programs. A stipulation and modified stipulation were filed on December 22, 2016, and January 27, 2017, respectively. Under the terms of the stipulations, which included support for deferral authority of all costs and a cap on shared savings incentives, Duke Energy Ohio has offered its energy efficiency and peak demand reduction programs throughout 2017. On February 3, 2017, Duke Energy Ohio filed for deferral authority of its costs incurred in 2017 in respect of its proposed energy efficiency and peak demand reduction portfolio. On September 27, 2017, the PUCO issued an order approving a modified stipulation. The modifications impose an annual cap of approximately $38 million on program costs and shared savings incentives combined, but allowed for Duke Energy Ohio to file for a waiver of costs in excess of the cap in 2017. The PUCO approved the waiver request up to a total cost of $56 million. On November 21, 2017, the PUCO granted Duke Energy Ohio's and intervenor's applications for rehearing of the September 27, 2017, order. On January 10, 2018, the PUCO denied the Ohio Consumers' Counsel’s application for rehearing of the PUCO order granting Duke Energy Ohio's waiver request; however, a decision on Duke Energy Ohio's application for rehearing remains pending. Duke Energy Ohio cannot predict the outcome of this matter.

2014 Electric Security Plan

In April 2015, the PUCO modified and approved Duke Energy Ohio's proposed ESP, with a three-year term and an effective date of June 1, 2015. The PUCO approved a competitive procurement process for SSO load, a distribution capital investment rider (Rider DCI) and a tracking mechanism for incremental distribution expenses caused by major storms. The PUCO also approved a placeholder tariff for a price stabilization rider, but denied Duke Energy Ohio's specific request to include Duke Energy Ohio's entitlement to generation from OVEC in the rider at this time; however, the order allows Duke Energy Ohio to submit additional information to request recovery in the future. On May 4, 2015, Duke Energy Ohio filed an application for rehearing requesting the PUCO to modify or amend certain aspects of the order. On May 28, 2015, the PUCO granted all applications for rehearing filed in the case for future consideration. On March 21, 2018, the PUCO issued an order denying Duke Energy Ohio's issues on rehearing. On April 20, 2018, Duke Energy Ohio filed a second application for rehearing based upon the commission’s March 21, 2018, Order. On May 16, 2018, the commission issued its third Entry on Rehearing granting in part, and denying in part, Duke Energy Ohio’s rehearing request.

On March 9, 2018, Duke Energy Ohio filed a motion to extend its then-current ESP, including all terms and conditions thereof, pending approval of a new ESP. On May 30, 2018, the PUCO granted the request, with modification. Specifically, the PUCO did not extend the cap applicable to Rider DCI beyond July 31, 2018. Duke Energy Ohio sought rehearing of this finding. On July 25, 2018, the PUCO granted the request and allowed a continuing cap on recovery under Rider DCI. On August 24, 2018, OMA and OCC filed an Application for Rehearing of the commission's decision. Duke Energy Ohio filed a Memorandum Contra OCC's request for rehearing of the commission's continuation of Rider DCI on September 4, 2018. On September 19, 2018, the PUCO issued an Order granting rehearing on the matter for further consideration. Duke Energy Ohio cannot predict the outcome of this matter.

On May 21, 2018, the Ohio Manufacturers' Association (OMA) filed a notice of appeal of PUCO's approval of Duke Energy Ohio’s ESP with the Ohio Supreme Court, challenging PUCO's approval of Duke Energy Ohio’s Price Stability Rider as a placeholder and its Rider DCI to recover incremental revenue requirement for distribution capital since Duke Energy Ohio’s last base rate case. On July 16, 2018, the Office of the Ohio Consumers' Counsel (OCC) filed its own appeal of Duke Energy Ohio’s ESP with the Ohio Supreme Court raising similar issues to that of the OMA. Duke Energy Ohio's Application for Rehearing was granted on July 25, 2018. Duke Energy Ohio filed a Motion to Intervene in the two Ohio Supreme Court appeals. OMA's Supreme Court brief was filed on August 20, 2018. PUCO submitted its brief on October 26, 2018, and Duke Energy Ohio filed its brief on October 29, 2018. 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 (the Central Corridor Project) in its Ohio service territory to increase system reliability and enable the retirement of older infrastructure. Duke Energy Ohio estimates the pipeline development costs and construction activities will range from $163 million to $245 million in direct costs (excluding overheads and AFUDC). Project construction activities, schedule and final costs are still subject to uncertainty due to potential additional permitting delays, construction productivity and other conditions and risks, which could result in additional project cost availability and a potential delay in the targeted in-service date. On January 20, 2017, Duke Energy Ohio filed an amended application with the Ohio Power Siting Board (OPSB) for approval of one of two proposed routes. A public hearing was held on June 15, 2017, and an adjudicatory hearing was scheduled to begin September 11, 2017. On August 24, 2017, an Attorney Examiner granted a request made by Duke Energy Ohio to delay the procedural schedule while it works through various issues related to the pipeline route. In April 2018, Duke Energy Ohio filed a motion with OPSB to establish a procedural schedule and filed supplemental information supporting its application. If approved, construction of the pipeline extension is expected to be completed before the 2021/2022 winter season. Duke Energy Ohio cannot predict the outcome of this matter.

54

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 Kentucky Electric Rate Case

On September 1, 2017, Duke Energy Kentucky filed a rate case with the KPSC requesting an increase in electric base rates of approximately $49 million, which represents an approximate 15 percent increase on the average customer bill. Subsequent to the filing, Duke Energy Kentucky adjusted the requested amount to $30.1 million, in part to reflect the benefits of the Tax Act, representing an approximate 9 percent increase on the average customer bill. The rate increase is driven by increased investment in utility plant, increased operations and maintenance expenses, and recovery of regulatory assets. The application also includes requests to implement an Environmental Surcharge Mechanism to recover environmental costs not recovered in base rates, to establish a Distribution Capital Investment Rider to recover incremental costs of specific programs, to establish a FERC Transmission Cost Reconciliation Rider to recover escalating transmission costs and to modify existing Profit Sharing Mechanism to increase customers' share of proceeds from the benefits of owning generation and to mitigate shareholder risks associated with that generation. An evidentiary hearing concluded on March 8, 2018, and the KPSC issued an order on April 13, 2018. Major components of the Order include approval of an $8.4 million increase in base rates with a return on equity at 9.725 percent based upon a capital structure of 49 percent equity on a total allocable capitalization of approximately $650 million. The Order approved the Environmental Surcharge Mechanism Rider and in June 2018 recovery began of capital-related environmental costs, including costs related to ash and ash disposal, and environmental operation and maintenance expenses formerly recovered in base rates, including expenses for environmental reagents and emission allowances. The incremental revenue from this rider will be approximately $13 million on an annualized basis. The order settles all issues associated with the Tax Act as it relates to the electric business by lowering the income tax component of the revenue requirement and refunding protected EDIT under allowable normalization rules and unprotected EDIT over 10 years. The Order denied requests to implement riders for certain transmission costs and distribution capital investments. Duke Energy Kentucky implemented new base rates on May 1, 2018. On May 3, 2018, Duke Energy Kentucky filed an application for rehearing on certain aspects of the order; on May 23, 2018, the KPSC granted a rehearing. On October 2, 2018, the KPSC issued its rehearing order correcting certain findings in its initial order and making additional changes that are immaterial to the company's earnings. Duke Energy Kentucky does not plan any further appeals.

Duke Energy Kentucky Natural Gas Base Rate Case

On August 31, 2018, Duke Energy Kentucky filed an application with the KPSC requesting an increase in natural gas base rates of approximately $10.5 million, an approximate 11.1 percent average increase across all customer classes. The increase is net of approximately $5.2 million in annual savings as a result of the Tax Act. The drivers for this case are capital invested since the Duke Energy Kentucky’s last rate case in 2009. Duke Energy Kentucky is also seeking implementation of a Weather Normalization Adjustment Mechanism, amortization of regulatory assets and to implement the impacts of the Tax Act, prospectively. The KPSC accepted Duke Energy Kentucky’s filing as of September 10, 2018, as meeting all filing requirements and issued its first round of discovery. A procedural schedule was set. A hearing is set to commence on February 5, 2019. A ruling is expected in late first quarter 2019. Duke Energy Kentucky cannot predict the outcome of this matter.

FERC 494 Refund of Regional Transmission Enhancement Projects

FERC Order No. 494 Settlement Agreement (FERC 494 Settlement Agreement) was entered into by most of the PJM Interconnection, LLC (PJM) transmission owners, including Duke Energy Ohio and Duke Energy Kentucky, and the PJM state regulatory commissions approximately two years ago and was planned to be effective on January 1, 2016; however, it was not approved by FERC until May 31, 2018. The FERC 494 Settlement Agreement was due to the Seventh Circuit Court of Appeals finding that FERC had failed to adequately justify the costs that the customers in the western part of PJM were being charged for high voltage transmission projects, or Regional Transmission Expansion Plan (RTEP) projects (500 kV and above) built in the east. These costs were being allocated to all PJM customers on a load-ratio share basis but the court determined that these costs were not justifiable to customers in the west, including Duke Energy Ohio and Duke Energy Kentucky, that did not benefit from the RTEP projects. Costs for the periods 2012 through 2015 are expected to be refunded to Duke Energy Ohio and Duke Energy Kentucky on a monthly basis through December 2025. The refund amount for similar costs incurred beginning in 2016 through June 30, 2018, prior to the change in cost allocation by PJM was determined in the third quarter of 2018 and these amounts will be refunded over a 12-month period beginning in July 2018. These refunds, totaling approximately $47 million for Duke Energy Ohio and Duke Energy Kentucky, have been recorded to Operation, maintenance and other on the Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2018.

Duke Energy Indiana

FERC Transmission Return on Equity Complaint

Customer groups have filed with the FERC complaints against Midcontinent Independent System Operator, Inc. (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 claim, among other things, 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. On October 16, 2018, FERC issued an order in response to the Emera remand proceeding proposing a new method for determining whether an existing return on equity is unjust and unreasonable, and a new process for determining a just and reasonable return on equity. The parties involved in the Emera proceeding are directed to file briefs by December 15, 2018. Duke Energy Indiana is in discussions with the other MISO Transmission Owners to determine strategy in light of this order. 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.

55

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)

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 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 it 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. Duke Energy Indiana recorded an obligation and a regulatory asset related to the settlement amount in fourth quarter 2016. On June 30, 2017, the parties finalized a settlement agreement. Terms of the settlement included Duke Energy Indiana paying $29 million for back damages. Additionally, the parties agreed on the method by which the contract will be bid into the market in the future. The settlement amount was paid in June 2017. The IURC issued an order on September 27, 2017, approving recovery of the settlement amount through Duke Energy Indiana's fuel clause. The IURC order has been appealed to the Indiana Court of Appeals. On May 21, 2018, the Indiana Court of Appeals upheld the commission's decision. The appellants have requested rehearing at the Indiana Court of Appeals. The Indiana Court of Appeals denied the request for rehearing. The appellants have requested transfer to the Indiana Supreme Court, including briefs in support from environmental groups. Duke Energy Indiana cannot predict the outcome of this matter.

Edwardsport Integrated Gasification Combined Cycle Plant

On September 20, 2018, Duke Energy Indiana, the Indiana Office of Utility Consumer Counselor (OUCC), the Duke Industrial Group and Nucor Steel – Indiana entered into a settlement agreement to resolve integrated gasification combined cycle (IGCC) ratemaking issues for calendar years 2018 and 2019. The agreement will remain in effect until new rates are established in Duke Energy Indiana's next base rate case, which is expected to be filed in mid-2019 with rates effective in mid-2020. It addresses the pending Edwardsport filing at the commission and eliminates the need for future filings until the overall rate case. This settlement includes caps on Duke Energy Indiana’s retail operating expenses for 2018 and 2019, reduces Duke Energy Indiana's regulatory asset by $30 million (with a corresponding reduction of the amount of amortization of the regulatory asset included in rates by $10 million annually beginning with the implementation of final IGCC 17 rates), and provides funding for low- income assistance and clean energy projects. Duke Energy Indiana recognized pretax impairment and related charges of $32 million in the third quarter of 2018. The settlement is subject to IURC approval. An evidentiary hearing is scheduled for December 2018. Duke Energy Indiana cannot predict the outcome of this matter.

Tax Act

On June 27, 2018, Duke Energy Indiana, the Indiana Office of Utility Consumer Counselor, the Indiana Industrial Group and Nucor Steel – Indiana filed testimony consistent with their Stipulation and Settlement Agreement (Settlement Agreement) in the federal tax act proceeding with the IURC. The Settlement Agreement outlines how Duke Energy Indiana will implement the impacts of the Tax Act. Material components of the Settlement Agreement were as follows:

• Riders to reflect the change in the statutory federal tax rate from 35 to 21 percent as they are filed in 2018;

• Base rates to reflect the change in the statutory federal tax rate from 35 to 21 percent upon IURC approval, but no later than September 1, 2018;

• Duke Energy Indiana to continue to defer protected federal EDIT until January 1, 2020, at which time it will be returned to customers according to the Average Rate Assumption Method (ARAM) required by the Internal Revenue Service over approximately 26 years; and

• Duke Energy Indiana to begin returning unprotected federal EDIT upon IURC approval, over 10 years. In order to mitigate the negative impacts to cash flow and credit metrics, the Settlement Agreement allows Duke Energy Indiana to return $7 million per year over the first five years, with a step up to $35 million per year in the following five years.

The settlement was subject to the review and approval of the IURC. An evidentiary hearing was held on July 13, 2018. On August 22, 2018, the IURC approved the settlement and rates have been adjusted effective September 1, 2018.

Piedmont

South Carolina Rate Stabilization Adjustment Filing

On June 15, 2018, Piedmont filed with the PSCSC under the South Carolina Rate Stabilization Act its quarterly monitoring report for the 12-month period ending March 31, 2018. The filing included a revenue deficiency calculation and tariff rates in order to permit Piedmont the opportunity to earn the rate of return on common equity established in its last general rate case. The filing also incorporated the impacts of the Tax Act by lowering the income tax component of the revenue requirement, refunding protected EDIT under allowable normalization rules, unprotected EDIT and amounts over collected from the customers from January 1, 2018, through the end of the review period for this proceeding. A settlement agreement reached between Piedmont and ORS was filed with the PSCSC on September 14, 2018, and approved by the PSCSC on October 3, 2018. Terms of the settlement include implementation of rates for the 12-month period beginning November 2018 with a return on equity of 10.2 percent.

56

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)

North Carolina Integrity Management Rider Filing

In October 2018, Piedmont filed a petition under the Integrity Management Rider (IMR) mechanism to collect an additional $9.5 million in annual revenues effective December 2018 based on the eligible capital investments closed to integrity and safety projects over the six-month period ended September 30, 2018. Piedmont cannot predict the outcome of this matter.

In May 2018, Piedmont filed, and the NCUC approved, a petition under the IMR mechanism to update rates, effective June 2018, based on the eligible capital investments closed to integrity and safety projects over the six-month period ending March 31, 2018, and the decrease in the corporate federal income tax rate effective January 1, 2018. The combined effect of the update was a reduction to annual revenues of approximately $5.7 million.

OTHER REGULATORY MATTERS

Progress Energy Merger FERC Mitigation

Since December 2014, the FERC Office of Enforcement has conducted an investigation of Duke Energy’s market power filings in its application for approval of the Progress Energy merger submitted in 2012. On June 8, 2018, the FERC issued an order approving a settlement agreement under which Duke Energy paid a penalty of $3.5 million. The FERC Office of Enforcement stated in its conclusion that Duke Energy violated FERC regulations by failing to fully and accurately describe certain specific matters in its market power filings. Duke neither admitted nor denied the alleged violations.

Atlantic Coast Pipeline, LLC

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, in part, the needs identified by Duke Energy Carolinas, Duke Energy Progress and Piedmont. 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, which is accounted for as an equity method investment 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.

In 2018, the FERC issued a series of Notices to Proceed, which authorized the project to begin certain construction-related activities along the pipeline route, including supply header and compressors. On May 11, 2018, and October 19, 2018, FERC issued Notices to Proceed allowing full construction activities in all areas of West Virginia except in the Monongahela National Forest. On July 24, 2018, FERC issued a Notice to Proceed allowing full construction activities along the project route in North Carolina. On October 19, 2018, the conditions to effectiveness of the Virginia 401 water quality certification were satisfied. Immediately following receipt of the Virginia 401 certification, ACP filed a request for FERC to issue a Notice to Proceed with full construction activities in Virginia, receipt of which is expected shortly. We appreciate the professional and collaborative process the permitting agencies have pursued to ensure that this critical energy infrastructure project will meet the stringent environmental standards required by law and regulation.

ACP is the subject of challenges in state and federal courts and agencies, including, among others, challenges of the project’s incidental take statement (ITS), crossings of the Blue Ridge Parkway, the Appalachian Trail, and the Monongahela and George Washington National Forests, the project’s U.S. Army Corps of Engineers (USACE) 404 permit, the Virginia conditional 401 water quality certification, the FERC Environmental Impact Statement order and the FERC order approving the Certificate of Public Convenience and Necessity. Each of these challenges alleges non-compliance on the part of federal and state permitting authorities and adverse ecological consequences if the project is permitted to proceed. ACP is vigorously defending these challenges and coordinating with the federal and state authorities which are the direct parties to the challenges. Since July 2018, notable developments in these challenges include a stay issued by the U.S. Court of Appeals for the Fourth Circuit (Fourth Circuit) on construction activities through the Monongahela and George Washington National Forests, a reissuance of the project’s ITS and Blue Ridge Parkway right-of-way and renewed challenges of these reissued permits and the USACE’s lifting of its administrative stay of ACP’s Huntington District 404 permit.

The FERC Stop Work Order following the Fourth Circuit's vacatur of the project's ITS and Blue Ridge Parkway right-of-way, together with delays in obtaining permits necessary for construction have impacted the cost and schedule for the project. As a result, project cost estimates have increased from a range of $6.0 billion to $6.5 billion to a range of $6.5 billion to $7.0 billion, excluding financing costs. ACP is pursuing a phased in-service approach with customers whereby it maintains a late 2019 in-service date for key segments of the project to meet peak winter demand in critically constrained regions served by the project. ACP will be pursuing a mid-2020 in-service date for the remaining segments. Abnormal weather, work delays (including delays due to judicial or regulatory action) and other conditions may result in cost or schedule modifications in the future.

Sabal Trail Transmission, LLC

On May 4, 2015, Duke Energy acquired a 7.5 percent ownership interest in Sabal Trail, which is accounted for as an equity method investment, 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 to construct 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 traverses 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. See Note 12 for additional information related to Duke Energy's ownership interest.

57

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)

On February 3, 2016, the FERC issued an order granting the request for a CPCN to construct and operate the pipeline. The Sabal Trail pipeline received other required regulatory approvals and the Phase 1 mainline was placed in service in July 2017. On October 12, 2017, Sabal Trail filed a request with FERC to place in service a lateral line to Duke Energy Florida's Citrus County Combined Cycle Facility. This request is required to support commissioning and testing activities at the facility. On March 16, 2018, FERC approved the Citrus lateral and it was placed in service.

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 (D.C. Circuit Court of Appeals). On August 22, 2017, the appeals court ruled against FERC in the case for failing to include enough information on the impact of greenhouse-gas emissions carried by the pipeline, vacated the CPCN order and remanded the case to FERC. In response to the August 2017 court decision, the FERC issued a draft Supplemental Environmental Impact Statement (SEIS) on September 27, 2017. On October 6, 2017, FERC and a group of industry intervenors, including Sabal Trail and Duke Energy Florida, filed separate petitions with the D.C. Circuit Court of Appeals requesting rehearing regarding the court's decision to vacate the CPCN order. On January 31, 2018, the D.C. Circuit Court of Appeals denied the requests for rehearing. On February 2, 2018, Sabal Trail filed a request with FERC for expedited issuance of its order on remand and reissuance of the CPCN. In the alternative, the pipeline requested that FERC issue a temporary emergency CPCN to allow for continued operations. On February 5, 2018, FERC issued the final SEIS. On February 6, 2018, FERC and the intervenors in this case each filed motions for stay with the D.C. Circuit Court to stay the court's mandate. On March 7, 2018, the D.C. Circuit Court of Appeals granted FERC and Sabal Trail’s stay request. On March 14, 2018, FERC issued its final order on remand, which recertified the project. On August 10, 2018, FERC denied requests for rehearing of the final order on remand.

Constitution Pipeline Company, LLC

Duke Energy owns a 24 percent ownership interest in Constitution, which is accounted for as an equity method investment. 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. Before the permitting delays discussed below, Duke Energy's total anticipated contributions were approximately $229 million. As a result of the permitting delays and project uncertainty, total anticipated contributions by Duke Energy can no longer be reasonably estimated. Since April 2016, with the actions of the New York State Department of Environmental Conservation (NYSDEC), Constitution stopped construction and discontinued capitalization of future development costs until the project's uncertainty is resolved.

In December 2014, Constitution received approval from the FERC to construct and operate the proposed pipeline. However, on April 22, 2016, the 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. Court of Appeals for the Second Circuit (U.S. Court of Appeals) challenging the legality and appropriateness of the NYSDEC’s decision and on August 18, 2017, the petition was denied in part and dismissed in part. In September 2017, Constitution filed a petition for a rehearing of portions of the decision unrelated to the water quality certification, which was denied by the U.S. Court of Appeals. In January 2018, Constitution petitioned the Supreme Court of the United States to review the U.S. Court of Appeals decision, and on April 30, 2018, the Supreme Court denied Constitution's petition. In October 2017, Constitution filed a petition for declaratory order requesting FERC to find that the NYSDEC waived its rights to issue a Section 401 water quality certification by not acting on Constitution's application within a reasonable period of time as required by statute. This petition was based on precedent established by another pipeline’s successful petition with FERC following a District of Columbia Circuit Court ruling. On January 11, 2018, FERC denied Constitution's petition. In February 2018, Constitution filed a rehearing request with FERC of its finding that the NYSDEC did not waive the Section 401 certification requirement. On July 19, 2018, FERC denied Constitution's rehearing request. Constitution is currently unable to approximate an in-service date for the project due to the NYSDEC's denial of the water quality certification. The Constitution partners remain committed to the project and are evaluating next steps to move the project forward. On June 25, 2018, Constitution filed with FERC a Request for Extension of Time until December 2, 2020, for construction of the project. Duke Energy cannot predict the outcome of this matter.

During the nine months ended September 30, 2018, Duke Energy recorded an other-than-temporary impairment (OTTI) of $55 million within Equity in earnings of unconsolidated affiliates on Duke Energy's Condensed Consolidated Statements of Operations. The charge represents the excess carrying value over the estimated fair value of the project, which was based on a Level 3 Fair Value measurement that was determined from the income approach using discounted cash flows. The impairment was primarily due to the recent actions taken by the courts and regulators to uphold the NYSDEC's denial of the certification and uncertainty associated with the remaining legal and regulatory challenges.

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. 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 U.S. Environmental Protection Agency (EPA) regulations recently approved or proposed.

58

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 contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement due to a lack of requisite environmental control equipment. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of September 30, 2018, 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	$	132
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2(b)	766	100
Duke Energy Indiana
Gallagher Units 2 and 4(c)	280	123
Total Duke Energy	1,631	$	355

(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 expects to retire these coal units by the end of 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 2016 settlement of Edwardsport IGCC matters.

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

4. 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 (ARO) 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 on the Condensed Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.

59

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 Accounts Payable within Current Liabilities and Other within Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets.

	Nine Months Ended September 30, 2018
				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	$	81		$	10		$	15		$	3		$	12		$	47		$	5		$	2
Provisions/adjustments	7			3			2			3			(1		)	3			1			—
Cash reductions	(20		)	(2		)	(5		)	(1		)	(4		)	(12		)	(1		)	—
Balance at end of period	$	68		$	11		$	12		$	5		$	7		$	38		$	5		$	2

	Nine Months Ended September 30, 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	(1		)	2			1			—		1			(3		)	(2		)	1
Cash reductions	(13		)	(2		)	(3		)	—		(3		)	(7		)	(1		)	—
Balance at end of period	$	84		$	10		$	16		$	3	$	12		$	49		$	7		$	2

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	$	57
Duke Energy Carolinas	17
Duke Energy Ohio	30
Piedmont	2

LITIGATION

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 Coal Ash Act and the EPA CCR rule at 15 coal-fired plants in North Carolina and South Carolina. The parties are engaged in discovery. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

NCDEQ State Enforcement Actions

In the first quarter of 2013, the Southern Environmental Law Center (SELC) sent notices of intent to sue Duke Energy Carolinas and Duke Energy Progress related to alleged Clean Water Act (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 in the North Carolina Superior Court.

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. On February 13, 2017, the court issued an order denying motions for partial summary judgment brought by both the environmental groups and Duke Energy Carolinas and Duke Energy Progress for the remaining seven plants. On March 15, 2017, Duke Energy Carolinas and Duke Energy Progress filed a Notice of Appeal with the North Carolina Court of Appeals to challenge the trial court’s order. The parties were unable to reach an agreement at mediation in April 2017 and submitted briefs to the trial court on remaining issues to be tried. On August 1, 2018, the Court of Appeals dismissed the appeal and the matter is proceeding before the trial court. No trial date has been scheduled. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

60

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)

Federal Citizens Suits

On June 13, 2016, the Roanoke River Basin Association (RRBA) 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 (NPDES) permit provisions survived the motion to dismiss, and Duke Energy Progress filed its response on May 10, 2017. Duke Energy Progress and RRBA each filed motions for summary judgment on March 23, 2018. The court has not yet ruled on these motions.

On May 16, 2017, RRBA filed a federal citizen suit in the U.S. District Court for the Middle District of North Carolina, which asserts two claims relating to alleged violations of NPDES permit provisions at the Roxboro Plant and one claim relating to the use of nearby water bodies. Duke Energy Progress and RRBA each filed motions for summary judgment on April 17, 2018, and the court has not yet ruled on these motions.

On May 8, 2018, on motion from Duke Energy Progress, the court ordered trial in both of the above matters to be consolidated. Trial is currently scheduled for July 15, 2019.

On June 20, 2017, RRBA filed a federal citizen suit in the U.S. District Court for the Middle District of North Carolina challenging the closure plans at the Mayo Plant under the EPA CCR Rule. Duke Energy Progress filed a motion to dismiss, which was granted by the court on March 30, 2018. RRBA had until April 30, 2018, to file an appeal to the Fourth Circuit but did not do so.

On August 2, 2017, RRBA filed a federal citizen suit in the U.S. District Court for the Middle District of North Carolina challenging the closure plans at the Roxboro Plant under the EPA CCR Rule. Duke Energy Progress filed a motion to dismiss on October 2, 2017, which was granted by the court on May 29, 2018. RRBA had until June 28, 2018, to file an appeal to the Fourth Circuit but did not do so.

On December 5, 2017, various parties filed a federal citizen suit in the U.S. District Court for the Middle District of North Carolina for alleged violations at Duke Energy Carolinas' Belews Creek Steam Station (Belews Creek) under the CWA. Duke Energy Carolinas filed a motion to dismiss on February 5, 2018, and on August 13, 2018, the court issued an order denying Duke Energy Carolinas’ motion to dismiss. Duke Energy Carolinas' answer to the complaint was filed on August 27, 2018. On October 10, 2018, Duke Energy Carolinas filed Motions to Dismiss for lack of standing, Motion for Judgment on the Pleadings and Motion to Stay Discovery. A hearing on the motion to stay is scheduled for December 12, 2018, and a scheduling conference has been set for January 2019.

Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of these matters.

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). Results of Comprehensive Site Assessments testing performed by Duke Energy under the Coal Ash Act 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 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 led 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 an 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. Settlement payments are being made, and, as of September 30, 2018, Duke Energy Carolinas and Duke Energy Progress have remaining reserves of $4 million and $2 million, respectively.

On August 23, 2017, a class-action suit was filed in Wake County Superior Court, North Carolina, against Duke Energy Carolinas and Duke Energy Progress on behalf of certain property owners living near coal ash impoundments at Allen, Asheville, Belews Creek, Buck, Cliffside, Lee, Marshall, Mayo and Roxboro. The class is defined as those who are “well-eligible” under the Coal Ash Act or those to whom Duke Energy has promised a permanent replacement water supply and seeks declaratory and injunctive relief, along with compensatory damages. Plaintiffs allege that Duke Energy’s improper maintenance of coal ash impoundments caused harm, particularly through groundwater contamination. Despite NCDEQ’s preliminary approval, Plaintiffs contend that Duke Energy’s proposed permanent water solutions plan fails to comply with the Coal Ash Act. On September 28, 2017, Duke Energy Carolinas and Duke Energy Progress filed a Motion to Dismiss and Motion to Strike the class designation. The parties entered into a Settlement Agreement on January 24, 2018, which resulted in the dismissal of the underlying class action on January 25, 2018.

61

PART I

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

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

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

On September 14, 2017, a complaint was filed against Duke Energy Progress in New Hanover County Superior Court by a group of homeowners residing approximately 1 mile from Duke Energy Progress' Sutton Steam Plant (Sutton). The homeowners allege that coal ash constituents have been migrating from ash impoundments at Sutton into their groundwater for decades and that in 2015, Duke Energy Progress discovered these releases of coal ash, but failed to notify any officials or neighbors and failed to take remedial action. The homeowners claim unspecified physical and mental injuries as a result of consuming their well water and seek actual damages for personal injury, medical monitoring and punitive damages. On March 6, 2018, Plaintiffs' counsel voluntarily dismissed the action without prejudice

It is not possible to estimate the maximum exposure of loss, if any, that may occur in connection with future claims that 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 September 30, 2018, there were 160 asserted claims for non-malignant cases with cumulative relief sought of up to $43 million, and 63 asserted claims for malignant cases with cumulative relief sought of up to $19 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 $461 million at September 30, 2018, and $489 million at December 31, 2017. 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 2037, 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 2037 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 $764 million in excess of the self-insured retention. Receivables for insurance recoveries were $553 million at September 30, 2018, and $585 million at December 31, 2017. These amounts are classified in Other within Other Noncurrent Assets and Receivables within Current Assets 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 Progress and Duke Energy Florida

Spent Nuclear Fuel Matters

On October 16, 2014, Duke Energy Progress and Duke Energy Florida sued the U.S. in the U.S. Court of Federal Claims. The lawsuit claimed the Department of Energy breached a contract in failing to accept spent nuclear fuel under the Nuclear Waste Policy Act of 1982 and asserted damages for the cost of on-site storage. Duke Energy Progress and Duke Energy Florida asserted damages for the period January 1, 2011, through December 31, 2013, of $48 million and $25 million, respectively. On November 17, 2017, the court awarded Duke Energy Progress and Duke Energy Florida $48 million and $21 million, respectively, subject to appeal. No appeals were filed and Duke Energy Progress and Duke Energy Florida recognized the recoveries in the first quarter of 2018. Claims for all periods through 2013 have been resolved. On June 22, 2018, Duke Energy Progress and Duke Energy Florida filed a complaint for damages incurred for 2014 through first quarter 2018.

Duke Energy Progress

Gypsum Supply Agreement Matter

On June 30, 2017, CertainTeed Gypsum NC, Inc. (CertainTeed) filed a declaratory judgment action against Duke Energy Progress in the North Carolina Business Court relating to a gypsum supply agreement. In its complaint, CertainTeed sought an order from the court declaring that the minimum amount of gypsum Duke Energy Progress must provide to CertainTeed under the supply agreement is 50,000 tons per month through 2029. Subsequently, CertainTeed also sought a preliminary injunction requiring Duke Energy Progress to provide 50,000 tons of gypsum per month through the trial date. The parties reached an agreement under which Duke Energy Progress delivered 50,000 tons of gypsum per month through August 2018. Trial in this matter was completed on July 16, 2018. On August 29, 2018, the court issued an order and opinion finding that Duke Energy Progress is required to supply 50,000 tons of gypsum/month, but that CertainTeed’s sole remedy for Duke Energy Progress’ long-term discontinuance under the agreement is liquidated damages. This ruling effectively limits CertainTeed’s remedies in the event that Duke Energy Progress elects to permanently discontinue gypsum supply at the Roxboro plant. The estimated maximum amount that would be owed under the liquidated damages provision is approximately $90 million. Both CertainTeed and Duke Energy Progress have filed cross-appeals, as they explore a possible resolution. Duke Energy Progress cannot predict the outcome of this matter.

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)

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 to the Eleventh Circuit U.S. Court of Appeals (Eleventh Circuit). On July 11, 2018, the Eleventh Circuit affirmed the U.S. District Court's dismissal of the lawsuit. The deadline to file a petition for cert was October 9, 2018, and no petition was filed; therefore, the dismissal of the lawsuit is final.

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 sought recovery of $54 million in milestone payments in excess of work performed under an Engineering, Procurement and Construction agreement (EPC) for Levy as well as a determination by the court of the amounts due to Westinghouse as a result of the termination of an EPC contract. Duke Energy Florida recognized an exit obligation as a result of the termination of the EPC. On March 31, 2014, Westinghouse filed a separate lawsuit against Duke Energy Florida in U.S. District Court for the Western District of Pennsylvania alleging damages under the same EPC contract 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 would 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, granting Westinghouse a $30 million termination fee claim and dismissing Duke Energy Florida's $54 million refund claim. Westinghouse's claim for termination costs continued to trial. Following a trial on the matter, the court issued an order in December 2016 denying Westinghouse’s claim for termination costs and reaffirming its earlier ruling in favor of Westinghouse on the $30 million termination fee. Judgment was entered against Duke Energy Florida in the amount of approximately $34 million, which includes prejudgment interest. Westinghouse appealed the trial court's order to the Fourth Circuit and Duke Energy Florida cross-appealed.

On March 29, 2017, Westinghouse filed Chapter 11 bankruptcy in the Southern District of New York, which automatically stayed the appeal. On May 23, 2017, the bankruptcy court entered an order lifting the stay with respect to the appeal. Briefing of the appeal concluded on October 20, 2017. Westinghouse and Duke Energy Florida executed a settlement agreement resolving this matter on April 5, 2018. The bankruptcy court approved the settlement and Duke Energy Florida paid approximately $34 million to Westinghouse in July 2018 pursuant to this agreement. At the request of the parties, the Fourth Circuit has dismissed the appeal.

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 Sixth Circuit, which affirmed the trial court's ruling on April 10, 2018. The dismissal of the lawsuit is therefore final.

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 related to the termination of an EPC contract discussed above. 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)	September 30, 2018		December 31, 2017
Reserves for Legal Matters
Duke Energy	$	63	$	88
Duke Energy Carolinas	11		30
Progress Energy	50		55
Duke Energy Progress	11		13
Duke Energy Florida	23		24
Piedmont	1		2

63

PART I

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

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

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

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.

5. DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

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

				Nine Months Ended September 30, 2018
						Duke		Duke		Duke		Duke
	Maturity	Interest		Duke		Energy		Energy		Energy		Energy
Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Progress		Florida
Unsecured Debt
March 2018(a)	April 2025	3.950	%	$	250	$	250	$	—	$	—	$	—
May 2018(b)	May 2021	2.819	%	500		500		—		—		—
September 2018(c)	September 2078	5.625	%	500		500		—		—		—
First Mortgage Bonds
March 2018(d)	March 2023	3.050	%	500		—		500		—		—
March 2018(d)	March 2048	3.950	%	500		—		500		—		—
June 2018(e)	July 2028	3.800	%	600		—		—		—		600
June 2018(e)	July 2048	4.200	%	400		—		—		—		400
August 2018(f)	September 2023	3.375	%	300		—		—		300		—
August 2018(f)	September 2028	3.700	%	500		—		—		500		—
Total issuances				$	4,050	$	1,250	$	1,000	$	800	$	1,000

(a) Debt issued to pay down short-term debt.

(b) Debt issued to pay down short-term debt. Debt issuance has a floating interest rate.

(c) Callable after September 2023 at par. Debt issued to pay down short-term debt and for general corporate purposes.

(d) Debt issued to repay at maturity a $300 million first mortgage bond due April 2018, pay down intercompany short-term debt and for general corporate purposes.

(e) Debt issued to repay a portion of intercompany short-term debt under money-pool borrowing arrangement and for general corporate purposes.

(f) Debt issued to repay short-term debt and for general corporate purposes.

64

PART I

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

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

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

CURRENT MATURITIES OF LONG-TERM DEBT

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

(in millions)	Maturity Date	Interest Rate			September 30, 2018
Unsecured Debt
Progress Energy	March 2019	7.050	%		$	450
Duke Energy (Parent)	September 2019	5.050	%		500
Piedmont	September 2019	2.848	%	(b)	350
First Mortgage Bonds
Duke Energy Carolinas	November 2018	7.000	%		500
Duke Energy Progress	January 2019	5.300	%		600
Duke Energy Ohio	April 2019	5.450	%		450
Other(a)					605
Current maturities of long-term debt					$	3,455

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

(b)    Debt issuance has a floating interest rate.

AVAILABLE CREDIT FACILITIES

Master Credit Facility

In January 2018, Duke Energy extended the termination date of substantially all of its existing $8 billion Master Credit Facility capacity from March 16, 2022, to March 16, 2023. In May 2018, Duke Energy completed the extension process with 100 percent of all commitments to the Master Credit Facility extending to March 16, 2023. 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.

	September 30, 2018
				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		$	2,650		$	1,750		$	1,400		$	650	$	450		$	600		$	500
Reduction to backstop issuances
Commercial paper(b)	(2,519		)	(988		)	(872		)	(150		)	—		(216		)	(293		)	—
Outstanding letters of credit	(55		)	(47		)	(4		)	(2		)	—		—			—			(2		)
Tax-exempt bonds	(81		)	—			—			—			—		—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—		—			—			—
Available capacity under the Master Credit Facility	$	4,845		$	1,615		$	624		$	998		$	650	$	234		$	226		$	498

(a) Represents the sublimit of each borrower.

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

Three-Year Revolving Credit Facility

Duke Energy (Parent) has a $1.0 billion revolving credit facility (the Three Year Revolver) through June 2020. As of September 30, 2018, $500 million has been drawn under the Three Year Revolver. This balance is classified as Long-Term Debt on Duke Energy's Condensed Consolidated Balance Sheets. Any undrawn commitments can be drawn and borrowings can be prepaid, at any time throughout the term of the facility. The terms and conditions of the Three Year Revolver are generally consistent with those governing Duke Energy's Master Credit Facility.

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)

Piedmont Term Loan Facility

In September 2018, Piedmont executed an amendment to its existing senior unsecured term loan (the Piedmont Term Loan). The amendment increased commitments from $250 million to $350 million and extended the maturity date to September 2019. As of September 30, 2018, the entire $350 million has been drawn under the Piedmont Term Loan. The balance is classified as Current maturities of long-term debt on Piedmont's Condensed Consolidated Balance Sheets.

6. ASSET RETIREMENT OBLIGATIONS

The Duke Energy Registrants record AROs when there is a legal obligation to incur retirement costs associated with the retirement of a long-lived asset and the obligation can be reasonably estimated. The following table presents the AROs recorded on the Condensed Consolidated Balance Sheets.

	September 30, 2018
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Decommissioning of Nuclear Power Facilities(a)	$	5,367	$	2,031	$	3,181	$	2,650	$	531	$	—	$	—	$	—
Closure of Ash Impoundments	4,575		1,623		2,175		2,154		20		52		725		—
Other	314		58		79		37		42		46		19		15
Total ARO	$	10,256	$	3,712	$	5,435	$	4,841	$	593	$	98	$	744	$	15
Less: current portion	902		292		475		470		4		7		128		—
Total noncurrent ARO	$	9,354	$	3,420	$	4,960	$	4,371	$	589	$	91	$	616	$	15

(a)    Duke Energy amount includes purchase accounting adjustments related to the merger with Progress Energy.

ARO Liability Rollforward

Actual closure costs incurred could be materially different from current estimates that form the basis of the recorded AROs. The following table presents the change in liability associated with AROs for the Duke Energy Registrants.

				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Balance at December 31, 2017(a)	$	10,175		$	3,610		$	5,414		$	4,673		$	742		$	84		$	781		$	15
Accretion expense(b)	319			133			168			145			23			3			22			—
Liabilities settled(c)	(431		)	(198		)	(186		)	(155		)	(31		)	(5		)	(42		)	—
Liabilities incurred in the current year	34			8			—			—			—			—			25			—
Revisions in estimates of cash flows(d)	159			159			39			178			(141		)	16			(42		)	—
Balance at September 30, 2018	$	10,256		$	3,712		$	5,435		$	4,841		$	593		$	98		$	744		$	15

(a) Primarily relates to decommissioning nuclear power facilities, closure of ash impoundments, asbestos removal, closure of landfills at fossil generation facilities, retirement of natural gas mains and removal of renewable energy generation assets.

(b) For the nine months ended September 30, 2018, substantially all accretion expense relates to Duke Energy's regulated operations and has been deferred in accordance with regulatory accounting treatment.

(c) Primarily relates to ash impoundment closures and nuclear decommissioning of Crystal River Unit 3.

(d) Primarily relates to increases in groundwater monitoring estimates for closure of ash impoundments, partially offset by modifications to the timing of expected cash flows and a reduction for nuclear decommissioning at Crystal River Unit 3 compared to original estimates.

Asset retirement costs associated with the AROs for operating plants and retired plants are included in Net property, plant and equipment and Regulatory assets within Other Noncurrent Assets, respectively, on the Condensed Consolidated Balance Sheets.

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)

7. GOODWILL

Duke Energy

The following table presents the goodwill by reportable operating segment included on Duke Energy's Condensed Consolidated Balance Sheets at September 30, 2018, and December 31, 2017.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables			Total
Goodwill balance at December 31, 2017	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(29		)	$	(29	)
Goodwill balance at December 31, 2017, adjusted for accumulated impairment charges	$	17,379	$	1,924	$	93		$	19,396
Goodwill balance at September 30, 2018	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(122		)	(122		)
Goodwill balance at September 30, 2018, adjusted for accumulated impairment charges	$	17,379	$	1,924	$	—		$	19,303

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 September 30, 2018, and December 31, 2017.

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.

Impairment Testing

Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont are required to perform an annual goodwill impairment test as of the same date each year and, accordingly, perform their annual impairment testing of goodwill as of August 31. Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont update their test between annual tests if events or circumstances occur that would more likely than not reduce the fair value of a reporting unit below its carrying value.

In the third quarter of 2018, based on the results of the annual quantitative goodwill impairment test, management determined that the fair value of the Commercial Renewables reporting unit was below its respective carrying value, including goodwill. Determination of the Commercial Renewables reporting unit fair value was based on an income approach, which estimates the fair value based on discounted future cash flows. The fair value of the Commercial Renewables reporting unit is impacted by several factors, including forecasted tax credit utilization, the cost of capital, current and forecasted solar and wind volumes, and legislative developments. Certain assumptions used in determining the fair value of the reporting unit in the 2018 impairment test changed from those used in the 2017 annual impairment test including the cost of capital as a result of rising interest rates and the timing of tax credit utilization due to the Tax Act and IRS (Internal Revenue Service) clarification on bonus depreciation in August 2018. Based on the quantitative impairment test, the estimated fair value of the Commercial Renewables reporting unit was below its carrying value by an immaterial amount but still more than the goodwill balance assigned to the reporting unit. As such, the entire remaining goodwill balance of approximately $93 million was impaired during the third quarter of 2018.

The fair value of all other reporting units for Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont exceeded their respective carrying values at the date of the annual impairment analysis. As such, no other impairment charges were recorded in the third quarter of 2018.

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)

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 on the Condensed Consolidated Statements of Operations and Comprehensive Income are presented in the following table.

	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	214	$	206	$	647	$	645
Indemnification coverages(b)	6		5		17		17
JDA revenue(c)	13		9		66		42
JDA expense(c)	61		39		134		91
Intercompany natural gas purchases(d)	3		3		11		5
Progress Energy
Corporate governance and shared service expenses(a)	$	216	$	207	$	613	$	555
Indemnification coverages(b)	8		10		25		29
JDA revenue(c)	61		39		134		91
JDA expense(c)	13		9		66		42
Intercompany natural gas purchases(d)	20		19		58		57
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	138	$	112	$	382	$	321
Indemnification coverages(b)	3		4		9		11
JDA revenue(c)	61		39		134		91
JDA expense(c)	13		9		66		42
Intercompany natural gas purchases(d)	20		19		58		57
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	78	$	95	$	231	$	234
Indemnification coverages(b)	5		6		16		18
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	85	$	90	$	264	$	275
Indemnification coverages(b)	1		1		3		3
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	105	$	94	$	302	$	281
Indemnification coverages(b)	2		2		6		6
Piedmont
Corporate governance and shared service expenses(a)	$	39	$	11	$	115	$	25
Indemnification coverages(b)	1		1		2		2
Intercompany natural gas sales(d)	23		22		69		62

(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 primarily 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 Joint Dispatch Agreement (JDA), which allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power and expenses from the purchase of power pursuant to the JDA are recorded in Operating Revenues and Fuel used in electric generation and purchased power, respectively, on the Condensed Consolidated Statements of Operations and Comprehensive Income.

(d) Piedmont provides long-term natural gas delivery service to certain Duke Energy Carolinas and Duke Energy Progress natural gas-fired generation facilities. Piedmont records the sales in Operating revenues, and Duke Energy Carolinas and Duke Energy Progress record the related purchases as a component of Fuel used in electric generation and purchased power on their respective Condensed Consolidated Statements of Operations and Comprehensive Income. These intercompany revenues and expenses are eliminated in consolidation.

In addition to the amounts presented above, the Subsidiary Registrants have 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. These transactions of the Subsidiary Registrants were not material for the three and nine months ended September 30, 2018, and 2017.

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)

As discussed in Note 12, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to Cinergy Receivables Company LLC (CRC), an indirect subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but also include a subordinated note from CRC 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. The following table presents expenses for the three and nine months ended September 30, 2018, and 2017, which are included in Cost of natural gas on Piedmont's Condensed Consolidated Statements of Operations and Comprehensive Income.

		Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	Type of expense	2018		2017		2018		2017
Cardinal	Transportation Costs	$	2	$	2	$	5	$	6
Pine Needle	Natural Gas Storage Costs	2		2		6		6
Hardy Storage	Natural Gas Storage Costs	2		2		7		7
Total		$	6	$	6	$	18	$	19

Piedmont had accounts payable to its equity method investments of $2 million at September 30, 2018, and December 31, 2017, related to these transactions. 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
September 30, 2018
Intercompany income tax receivable	$	32	$	196	$	80	$	—	$	—	$	22	$	11
Intercompany income tax payable	—		—		—		77		9		—		—
December 31, 2017
Intercompany income tax receivable	$	—	$	168	$	—	$	44	$	22	$	—	$	7
Intercompany income tax payable	44		—		21		—		—		35		—

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 natural gas supply contracts to provide diversification, reliability and natural gas cost benefits to its 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 or Treasury locks 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.

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)

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 and nine months ended September 30, 2018, and 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 primarily include contracts not designated as a hedge because they are accounted for under regulatory accounting or 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 on the Duke Energy Registrant's Condensed Consolidated Statements of Operations and Comprehensive Income.

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

	September 30, 2018
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	411	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,127		400		500		250		250		27
Total notional amount(a)	$	1,538	$	400	$	500	$	250	$	250	$	27

	December 31, 2017
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	660	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	927		400		500		250		250		27
Total notional amount	$	1,587	$	400	$	500	$	250	$	250	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $411 million in cash flow hedges and $200 million in undesignated contracts as of September 30, 2018, and $660 million in cash flow hedges as of December 31, 2017.

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 natural 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 natural gas costs volatility for customers.

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)

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.

	September 30, 2018
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	170	—	—	—	—	170	—
Natural gas (millions of dekatherms)	744	119	167	158	9	1	457

	December 31, 2017
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	34	—	—	—	—	34	—
Natural gas (millions of dekatherms)	770	105	183	133	50	2	480

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)

LOCATION AND FAIR VALUE OF DERIVATIVE ASSETS AND LIABILITIES RECOGNIZED ON 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	September 30, 2018
			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	$	46	$	2	$	3	$	2	$	1	$	8	$	29	$	4
Noncurrent	1		—		—		—		—		—		—		—
Total Derivative Assets – Commodity Contracts	$	47	$	2	$	3	$	2	$	1	$	8	$	29	$	4
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	6	$	5	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	6		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		—		—		—		—		—		—
Noncurrent	17		—		—		—		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	30	$	5	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Assets	$	77	$	7	$	3	$	2	$	1	$	8	$	29	$	4

Derivative Liabilities	September 30, 2018
			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	$	26	$	14	$	5	$	5	$	—	$	—	$	—	$	7
Noncurrent	177		14		17		8		—		—		—		146
Total Derivative Liabilities – Commodity Contracts	$	203	$	28	$	22	$	13	$	—	$	—	$	—	$	153
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	2	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	7		—		6		3		3		1		—		—
Noncurrent	13		—		9		8		2		3		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	22	$	—	$	15	$	11	$	5	$	4	$	—	$	—
Total Derivative Liabilities	$	225	$	28	$	37	$	24	$	5	$	4	$	—	$	153

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)

Derivative Assets	December 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	$	34	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Noncurrent	1		—		1		1		—		—		—		—
Total Derivative Assets – Commodity Contracts	$	35	$	2	$	3	$	2	$	1	$	1	$	27	$	2
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	1	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	15		—		—		—		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	16	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Assets	$	51	$	2	$	3	$	2	$	1	$	1	$	27	$	2

Derivative Liabilities	December 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	$	36	$	6	$	18	$	8	$	10	$	—	$	—	$	11
Noncurrent	146		4		10		4		—		—		—		131
Total Derivative Liabilities – Commodity Contracts	$	182	$	10	$	28	$	12	$	10	$	—	$	—	$	142
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	29	$	25	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	6		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		1		—		—		1		—		—
Noncurrent	12		—		7		6		2		4		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	48	$	25	$	8	$	6	$	2	$	5	$	—	$	—
Total Derivative Liabilities	$	230	$	35	$	36	$	18	$	12	$	5	$	—	$	142

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.

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)

Derivative Assets	September 30, 2018
				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	$	53		$	7		$	3		$	2		$	1	$	8	$	29	$	4
Gross amounts offset	(4		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Assets: Other	$	49		$	5		$	1		$	—		$	1	$	8	$	29	$	4
Noncurrent
Gross amounts recognized	$	24		$	—		$	—		$	—		$	—	$	—	$	—	$	—
Gross amounts offset	(1		)	—			—			—			—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	23		$	—		$	—		$	—		$	—	$	—	$	—	$	—

Derivative Liabilities	September 30, 2018
				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	$	35		$	14		$	11		$	8		$	3	$	1	$	—	$	7
Gross amounts offset	(4		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Liabilities: Other	$	31		$	12		$	9		$	6		$	3	$	1	$	—	$	7
Noncurrent
Gross amounts recognized	$	190		$	14		$	26		$	16		$	2	$	3	$	—	$	146
Gross amounts offset	(1		)	—			(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	189		$	14		$	25		$	15		$	2	$	3	$	—	$	146

Derivative Assets	December 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	$	35	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Gross amounts offset	—		—		—		—		—		—		—		—
Net amounts presented in Current Assets: Other	$	35	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Noncurrent
Gross amounts recognized	$	16	$	—	$	1	$	1	$	—	$	—	$	—	$	—
Gross amounts offset	—		—		—		—		—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	16	$	—	$	1	$	1	$	—	$	—	$	—	$	—

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)

Derivative Liabilities	December 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	$	66		$	31		$	19		$	8		$	10	$	1	$	—	$	11
Gross amounts offset	(3		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Liabilities: Other	$	63		$	29		$	17		$	6		$	10	$	1	$	—	$	11
Noncurrent
Gross amounts recognized	$	164		$	4		$	17		$	10		$	2	$	4	$	—	$	131
Gross amounts offset	(1		)	—			(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	163		$	4		$	16		$	9		$	2	$	4	$	—	$	131

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.

	September 30, 2018
			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	$	48	$	26	$	23	$	22	$	—
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	48		26		23		22		—

	December 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	$	59	$	35	$	25	$	15	$	10
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	59		35		25		15		10

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

Duke Energy’s investments in debt and equity securities are primarily comprised of investments held in (i) the nuclear decommissioning trust funds (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. The Duke Energy Registrants classify investments in debt securities as available-for-sale (AFS) and investments in equity securities as fair value through net income (FV-NI). 

For investments in debt securities classified as AFS, the unrealized gains and losses are included in other comprehensive income until realized, at which time, they are reported through net income. For investments in equity securities classified as FV-NI, both realized and unrealized gains and losses are reported through net income. Substantially all of Duke Energy’s investments in debt and equity securities qualify for regulatory accounting, and accordingly, all associated realized and unrealized gains and losses on these investments are deferred as a regulatory asset or liability.

Duke Energy classifies the majority of investments in debt and equity securities as long term, unless otherwise noted.

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)

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 securities within the Investment Trusts are considered OTTIs and are recognized immediately and deferred to regulatory accounts where appropriate.

Other AFS Securities

Unrealized gains and losses on all other AFS 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 September 30, 2018, and December 31, 2017.

Other Investments amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

DUKE ENERGY

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	75	$	—	$	—	$	115
Equity securities	3,117		48		5,272		2,805		27		4,914
Corporate debt securities	5		10		595		17		2		570
Municipal bonds	—		7		346		4		3		344
U.S. government bonds	5		25		974		11		7		1,027
Other debt securities	—		3		141		—		1		118
Total NDTF Investments	$	3,127	$	93	$	7,403	$	2,837	$	40	$	7,088
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	15
Equity securities	51		—		115		59		—		123
Corporate debt securities	—		1		64		1		—		57
Municipal bonds	1		1		85		2		1		83
U.S. government bonds	—		1		59		—		—		41
Other debt securities	—		1		43		—		1		44
Total Other Investments	$	52	$	4	$	387	$	62	$	2	$	363
Total Investments	$	3,179	$	97	$	7,790	$	2,899	$	42	$	7,451

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	100
Due after one through five years	492
Due after five through 10 years	561
Due after 10 years	1,154
Total	$	2,307

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)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	19	$	85
Realized losses	16		60
AFS:
Realized gains	4		14
Realized losses	7		32

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	37	$	170
Realized losses	25		124

DUKE ENERGY CAROLINAS

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	32
Equity securities	1,692		29		2,890		1,531		12		2,692
Corporate debt securities	2		7		372		9		2		359
Municipal bonds	—		2		80		—		1		60
U.S. government bonds	1		14		439		3		4		503
Other debt securities	—		3		137		—		1		112
Total NDTF Investments	$	1,695	$	55	$	3,936	$	1,543	$	20	$	3,758

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	12
Due after one through five years	161
Due after five through 10 years	289
Due after 10 years	566
Total	$	1,028

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)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	11	$	47
Realized losses	8		30
AFS:
Realized gains	4		13
Realized losses	6		24

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	20	$	110
Realized losses	13		76

PROGRESS ENERGY

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	57	$	—	$	—	$	83
Equity securities	1,425		19		2,382		1,274		15		2,222
Corporate debt securities	3		3		223		8		—		211
Municipal bonds	—		5		266		4		2		284
U.S. government bonds	4		11		535		8		3		524
Other debt securities	—		—		4		—		—		6
Total NDTF Investments	$	1,432	$	38	$	3,467	$	1,294	$	20	$	3,330
Other Investments
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	12
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	66	$	2	$	—	$	59
Total Investments	$	1,433	$	38	$	3,533	$	1,296	$	20	$	3,389

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	83
Due after one through five years	268
Due after five through 10 years	217
Due after 10 years	508
Total	$	1,076

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)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	8	$	38
Realized losses	8		30
AFS:
Realized gains	—		1
Realized losses	1		8

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	16	$	58
Realized losses	12		47

DUKE ENERGY PROGRESS

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	42	$	—	$	—	$	50
Equity securities	1,101		14		1,913		980		12		1,795
Corporate debt securities	2		2		162		6		—		149
Municipal bonds	—		5		265		4		2		283
U.S. government bonds	3		8		352		5		2		310
Other debt securities	—		—		2		—		—		4
Total NDTF Investments	$	1,106	$	29	$	2,736	$	995	$	16	$	2,591
Other Investments
Cash and cash equivalents	$	—	$	—	$	8	$	—	$	—	$	1
Total Other Investments	$	—	$	—	$	8	$	—	$	—	$	1
Total Investments	$	1,106	$	29	$	2,744	$	995	$	16	$	2,592

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	40
Due after one through five years	200
Due after five through 10 years	156
Due after 10 years	385
Total	$	781

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)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	7	$	32
Realized losses	7		27
AFS:
Realized gains	—		1
Realized losses	1		6

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	14	$	49
Realized losses	11		41

DUKE ENERGY FLORIDA

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	15	$	—	$	—	$	33
Equity securities	324		5		469		294		3		427
Corporate debt securities	1		1		61		2		—		62
Municipal bonds	—		—		1		—		—		1
U.S. government bonds	1		3		183		3		1		214
Other debt securities	—		—		2		—		—		2
Total NDTF Investments(b)	$	326	$	9	$	731	$	299	$	4	$	739
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	1
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	48	$	2	$	—	$	48
Total Investments	$	327	$	9	$	779	$	301	$	4	$	787

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

(b) During the nine months endedSeptember 30, 2018, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of the Crystal River Unit 3 nuclear plant.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	43
Due after one through five years	68
Due after five through 10 years	61
Due after 10 years	123
Total	$	295

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)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	1	$	6
Realized losses	1		3
AFS:
Realized gains	—		—
Realized losses	—		2

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	2	$	9
Realized losses	1		6

DUKE ENERGY INDIANA

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are measured at FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
Investments
Equity securities	$	40	$	—	$	78	$	49	$	—	$	97
Corporate debt securities	—		—		8		—		—		3
Municipal bonds	—		1		32		—		1		28
Total Investments	$	40	$	1	$	118	$	49	$	1	$	128

(a) Realized and unrealized gains and losses where regulatory accounting is applied are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	2
Due after one through five years	20
Due after five through 10 years	5
Due after 10 years	13
Total	$	40

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months ended September 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were insignificant.

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.

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)

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 and (iii) inputs other than quoted market prices that are observable for the asset or liability, such as interest rate curves and yield curves observable at commonly quoted intervals, volatilities 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 at fair value using the net asset value (NAV) per share practical expedient. The NAV is derived based on the investment cost, less any impairment, plus or minus changes resulting from observable price changes for an identical or similar investment of the same issuer.

Fair value accounting guidance permits entities to elect to measure certain financial instruments that are not required to be accounted for at fair value, such as equity method investments or the company’s own debt, at fair value. The Duke Energy Registrants have not elected to record any of these items at fair value.

Transfers between levels represent assets or liabilities that were previously (i) categorized at a higher level for which the inputs to the estimate became less observable or (ii) classified at a lower level for which the inputs became more observable during the period. The Duke Energy Registrant’s policy is to recognize transfers between levels of the fair value hierarchy at the end of the period. There were no transfers between levels during the three and nine months endedSeptember 30, 2018, and 2017.

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 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 natural 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 natural gas purchase contracts; and increases (decreases) in electricity forward prices result in unfavorable (favorable) fair value adjustments for electricity sales contracts. Duke Energy regularly evaluates and validates pricing inputs used to estimate the fair value of natural gas commodity contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.

Interest rate derivatives

Most over-the-counter interest rate contract derivatives are valued using financial models 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 11 in Duke Energy's Annual Report on Form 10-K/A for the year ended December 31, 2017, for a discussion of the valuation of goodwill and intangible assets.

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)

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 tables below for all Duke Energy Registrants exclude cash collateral, which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type for the Duke Energy Registrants.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 2			Level 3			Not Categorized
NDTF equity securities	$	5,272		$	5,203	$	—		$	—		$	69
NDTF debt securities	2,131			510		1,621			—			—
Other equity securities	115			115		—			—			—
Other debt securities	272			78		194			—			—
Derivative assets	77			4		36			37			—
Total assets	7,867			5,910		1,851			37			69
Derivative liabilities	(225		)	—		(72		)	(153		)	—
Net assets (liabilities)	$	7,642		$	5,910	$	1,779		$	(116	)	$	69

	December 31, 2017
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	4,914		$	4,840		$	—		$	—		$	74
NDTF debt securities	2,174			635			1,539			—			—
Other equity securities	123			123			—			—			—
Other debt securities	241			57			184			—			—
Derivative assets	51			3			20			28			—
Total assets	7,503			5,658			1,743			28			74
Derivative liabilities	(230		)	(2		)	(86		)	(142		)	—
Net assets (liabilities)	$	7,273		$	5,656		$	1,657		$	(114	)	$	74

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 Cost of natural gas on the Duke Energy Registrants' Condensed Consolidated Statements of Operations and Comprehensive Income. Amounts included in changes of net assets on the Duke Energy Registrants' Condensed Consolidated Balance Sheets are included in regulatory assets or liabilities. All derivative assets and liabilities are presented on a net basis.

	Three Months Ended September 30, 2018								Three Months Ended September 30, 2017
(in millions)	Investments		Derivatives (net)			Total			Investments		Derivatives (net)			Total
Balance at beginning of period	$	—	$	(97	)	$	(97	)	$	—	$	(91	)	$	(91	)
Purchases, sales, issuances and settlements:
Settlements	—		(14		)	(14		)	—		(12		)	(12		)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	—		(5		)	(5		)	—		10			10
Balance at end of period	$	—	$	(116	)	$	(116	)	$	—	$	(93	)	$	(93	)

	Nine Months Ended September 30, 2018								Nine Months Ended September 30, 2017
(in millions)	Investments		Derivatives (net)			Total			Investments			Derivatives (net)			Total
Balance at beginning of period	$	—	$	(114	)	$	(114	)	$	5		$	(166	)	$	(161	)
Total pretax realized or unrealized gains included in comprehensive income	—		—			—			1			—			1
Purchases, sales, issuances and settlements:
Purchases	—		56			56			—			55			55
Sales	—		—			—			(6		)	—			(6		)
Settlements	—		(43		)	(43		)	—			(30		)	(30		)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	—		(15		)	(15		)	—			48			48
Balance at end of period	$	—	$	(116	)	$	(116	)	$	—		$	(93	)	$	(93	)

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)

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.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	2,890		$	2,821	$	—		$	69
NDTF debt securities	1,046			122		924			—
Derivative assets	7			—		7			—
Total assets	3,943			2,943		931			69
Derivative liabilities	(28		)	—		(28		)	—
Net assets	$	3,915		$	2,943	$	903		$	69

	December 31, 2017
(in millions)	Total Fair Value			Level 1			Level 2			Not Categorized
NDTF equity securities	$	2,692		$	2,618		$	—		$	74
NDTF debt securities	1,066			204			862			—
Derivative assets	2			—			2			—
Total assets	3,760			2,822			864			74
Derivative liabilities	(35		)	(1		)	(34		)	—
Net assets	$	3,725		$	2,821		$	830		$	74

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

	Investments
	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Balance at beginning of period	$	—	$	—	$	—	$	3
Total pretax realized or unrealized gains included in comprehensive income	—		—		—		1
Purchases, sales, issuances and settlements:
Sales	—		—		—		(4		)
Balance at end of period	$	—	$	—	$	—	$	—

84

PART I

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

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

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

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1			Level 2
NDTF equity securities	$	2,382		$	2,382	$	—		$	2,222		$	2,222		$	—
NDTF debt securities	1,085			388		697			1,108			431			677
Other debt securities	66			18		48			59			12			47
Derivative assets	3			—		3			3			1			2
Total assets	3,536			2,788		748			3,392			2,666			726
Derivative liabilities	(37		)	—		(37		)	(36		)	(1		)	(35		)
Net assets	$	3,499		$	2,788	$	711		$	3,356		$	2,665		$	691

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1			Level 2
NDTF equity securities	$	1,913		$	1,913	$	—		$	1,795		$	1,795		$	—
NDTF debt securities	823			254		569			796			243			553
Other debt securities	8			8		—			1			1			—
Derivative assets	2			—		2			2			1			1
Total assets	2,746			2,175		571			2,594			2,040			554
Derivative liabilities	(24		)	—		(24		)	(18		)	(1		)	(17		)
Net assets	$	2,722		$	2,175	$	547		$	2,576		$	2,039		$	537

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	469		$	469	$	—		$	427		$	427	$	—
NDTF debt securities	262			134		128			312			188		124
Other debt securities	48			—		48			48			1		47
Derivative assets	1			—		1			1			—		1
Total assets	780			603		177			788			616		172
Derivative liabilities	(5		)	—		(5		)	(12		)	—		(12		)
Net assets	$	775		$	603	$	172		$	776		$	616	$	160

DUKE ENERGY OHIO

The following table provides recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 2			Level 3		Total Fair Value			Level 2			Level 3
Derivative assets	$	8		$	—		$	8	$	1		$	—		$	1
Derivative liabilities	(4		)	(4		)	—		(5		)	(5		)	—
Net assets (liabilities)	$	4		$	(4	)	$	8	$	(4	)	$	(5	)	$	1

85

PART I

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

DUKE ENERGY PROGRESS, LLC – DUKE ENERGY FLORIDA, LLC – DUKE ENERGY OHIO, INC. – DUKE ENERGY INDIANA, LLC – 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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	9		$	3		$	1		$	5
Purchases, sales, issuances and settlements:
Purchases	—			—			7			3
Settlements	(1		)	(1		)	(2		)	(3		)
Total gains (losses) included on the Condensed Consolidated Balance Sheet	—			—			2			(3		)
Balance at end of period	$	8		$	2		$	8		$	2

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Total Fair Value		Level 1		Level 2		Level 3
Other equity securities	$	78	$	78	$	—	$	—	$	97	$	97	$	—	$	—
Other debt securities	40		—		40		—		31		—		31		—
Derivative assets	29		—		—		29		27		—		—		27
Total assets	$	147	$	78	$	40	$	29	$	155	$	97	$	31	$	27

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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	44		$	51		$	27		$	16
Purchases, sales, issuances and settlements:
Purchases	—			—			49			52
Settlements	(13		)	(11		)	(41		)	(27		)
Total losses included on the Condensed Consolidated Balance Sheet	(2		)	(12		)	(6		)	(13		)
Balance at end of period	$	29		$	28		$	29		$	28

86

PART I

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

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

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

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.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 3
Derivative assets	$	4		$	4	$	—
Derivative liabilities	(153		)	—		(153		)
Net (liabilities) assets	$	(149	)	$	4	$	(153	)

	December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 3
Other debt securities	$	1		$	1	$	—
Derivative assets	2			2		—
Total assets	3			3		—
Derivative liabilities	(142		)	—		(142		)
Net (liabilities) assets	$	(139	)	$	3	$	(142	)

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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	(150	)	$	(145	)	$	(142	)	$	(187	)
Total (losses) gains and settlements	(3		)	22			(11		)	64
Balance at end of period	$	(153	)	$	(123	)	$	(153	)	$	(123	)

87

PART I

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

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

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

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

	September 30, 2018
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
Financial Transmission Rights (FTRs)	$	8		RTO auction pricing	FTR price – per megawatt-hour (MWh)	$	1.03		-	$	4.10
Duke Energy Indiana
FTRs	29			RTO auction pricing	FTR price – per MWh	(2.32		)	-	8.11
Piedmont
Natural gas contracts	(153		)	Discounted cash flow	Forward natural gas curves – price per million British thermal unit (MMBtu)	1.74			-	3.41
Duke Energy
Total Level 3 derivatives	$	(116	)

	December 31, 2017
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
FTRs	$	1		RTO auction pricing	FTR price – per MWh	$	0.07		-	$	1.41
Duke Energy Indiana
FTRs	27			RTO auction pricing	FTR price – per MWh	(0.77		)	-	7.44
Piedmont
Natural gas contracts	(142		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	2.10			-	2.88
Duke Energy
Total Level 3 derivatives	$	(114	)

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.

	September 30, 2018				December 31, 2017
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy(a)	$	53,962	$	53,949	$	52,279	$	55,331
Duke Energy Carolinas	10,395		10,887		10,103		11,372
Progress Energy	18,912		19,825		17,837		20,000
Duke Energy Progress	8,154		8,231		7,357		7,992
Duke Energy Florida	7,371		7,749		7,095		7,953
Duke Energy Ohio	2,066		2,136		2,067		2,249
Duke Energy Indiana	3,783		4,178		3,783		4,464
Piedmont	2,138		2,175		2,037		2,209

(a) Book value of long-term debt includes $1.6 billion as of September 30, 2018, and $1.7 billion as of December 31, 2017, of unamortized debt discount and premium, net in purchase accounting adjustments related to the mergers with Progress Energy and Piedmont that are excluded from fair value of long-term debt.

At both September 30, 2018, and December 31, 2017, 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.

88

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)

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 re-evaluation, 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 nine months ended September 30, 2018, and the year ended December 31, 2017, 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 and associated restricted receivables described above.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
(in millions)	CRC		DERF		DEPR		DEFR
Expiration date	December 2020		December 2020		February 2021		April 2021
Credit facility amount	$	325	$	450	$	300	$	225
Amounts borrowed at September 30, 2018	325		450		300		225
Amounts borrowed at December 31, 2017	325		450		300		225
Restricted Receivables at September 30, 2018	504		795		635		456
Restricted Receivables at December 31, 2017	545		640		459		317

89

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 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.

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)	September 30, 2018		December 31, 2017
Receivables of VIEs	$	7	$	4
Regulatory Assets: Current	52		51
Current Assets: Other	14		40
Other Noncurrent Assets: Regulatory assets	1,055		1,091
Current Liabilities: Other	3		10
Current maturities of long-term debt	53		53
Long-Term Debt	1,111		1,164

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)	September 30, 2018			December 31, 2017
Current Assets: Other	$	203		$	174
Property, plant and equipment, cost	4,025			3,923
Accumulated depreciation and amortization	(695		)	(591		)
Other Noncurrent Assets: Other	268			50
Current maturities of long-term debt	175			170
Long-Term Debt	1,604			1,700
Other Noncurrent Liabilities: Deferred income taxes	—			(148		)
Other Noncurrent Liabilities: Other	225			241

90

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.

	September 30, 2018
	Duke Energy								Duke		Duke
	Pipeline		Commercial		Other				Energy		Energy
(in millions)	Investments(a)		Renewables		VIEs		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	—	$	56	$	94
Investments in equity method unconsolidated affiliates	729		190		47		966		—		—
Total assets	$	729	$	190	$	47	$	966	$	56	$	94
Other current liabilities	—		—		3		3		—		—
Deferred income taxes	14		—		—		14		—		—
Other noncurrent liabilities	—		—		11		11		—		—
Total liabilities	$	14	$	—	$	14	$	28	$	—	$	—
Net assets	$	715	$	190	$	33	$	938	$	56	$	94

(a) See Pipeline Investments table below for further details regarding Investments in equity method unconsolidated affiliates.

	December 31, 2017
	Duke Energy										Duke		Duke
	Pipeline			Commercial		Other					Energy		Energy
(in millions)	Investments			Renewables		VIEs		Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	—	$	—	$	—		$	87	$	106
Investments in equity method unconsolidated affiliates	697			180		42		919			—		—
Other noncurrent assets	17			—		—		17			—		—
Total assets	$	714		$	180	$	42	$	936		$	87	$	106
Taxes accrued	(29		)	—		—		(29		)	—		—
Other current liabilities	—			—		4		4			—		—
Deferred income taxes	42			—		—		42			—		—
Other noncurrent liabilities	—			—		12		12			—		—
Total liabilities	$	13		$	—	$	16	$	29		$	—	$	—
Net assets	$	701		$	180	$	26	$	907		$	87	$	106

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 4.

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 Duke Energy's ownership interest and investment balances in these joint ventures.

			VIE Investment Amount (in millions)
	Ownership		September 30,		December 31,
Entity Name	Interest		2018		2017
ACP	47	%	$	704	$	397
Sabal Trail(a)	7.5	%	—		219
Constitution(b)	24	%	25		81
Total			$	729	$	697

(a) At December 31, 2017, Sabal Trail was considered a VIE due to having insufficient equity to finance their own activities without subordinated financial support. However, Sabal Trail is now a fully operational, well capitalized entity. As a result, Sabal Trail has sufficient equity to finance its own activities, and therefore, is no longer considered a VIE. Duke Energy's investment in Sabal Trail was $112 million at September 30, 2018.

91

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)

(b) During the nine months ended September 30, 2018, Duke Energy recorded an OTTI of $55 million related to Constitution within Equity in earnings of unconsolidated affiliates on Duke Energy's Condensed Consolidated Statements of Income. See Note 3 for additional information.

In 2017, ACP executed a $3.4 billion revolving credit facility with a stated maturity date of October 2021. Duke Energy entered into a guarantee agreement to support its share of the ACP revolving credit facility. Duke Energy's maximum exposure to loss under the terms of the guarantee is $486 million, which represents 47 percent of the outstanding borrowings under the credit facility as of September 30, 2018.

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 Pioneer Transmission, LLC (Pioneer). Pioneer is considered a VIE due to having insufficient equity to finance its 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 OVEC having insufficient equity to finance its 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. On March 31, 2018, FirstEnergy Solutions (FES), a subsidiary of FirstEnergy and an ICPA counterparty with a power participation ratio of 4.85 percent, filed for Chapter 11 bankruptcy, which could increase costs allocated to the counterparties. On July 31, 2018, the bankruptcy court rejected the FES ICPA, which means OVEC is an unsecured creditor in the FES bankruptcy proceeding. Duke Energy Ohio cannot predict the impact of the bankruptcy filing on its OVEC interests. In addition, certain proposed environmental rulemaking could result in future increased OVEC 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
	2018		2017		2018		2017
Anticipated credit loss ratio	0.5	%	0.5	%	0.3	%	0.3	%
Discount rate	2.9	%	2.1	%	2.9	%	2.1	%
Receivable turnover rate	13.6	%	13.5	%	10.9	%	10.7	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Receivables sold	$	218	$	273	$	326	$	312
Less: Retained interests	56		87		94		106
Net receivables sold	$	162	$	186	$	232	$	206

92

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 shows sales and cash flows related to receivables sold.

	Duke Energy Ohio								Duke Energy Indiana
	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
(in millions)	2018		2017		2018		2017		2018		2017		2018		2017
Sales
Receivables sold	$	450	$	438	$	1,478	$	1,392	$	754	$	720	$	2,140	$	2,047
Loss recognized on sale	4		2		10		7		5		3		12		9
Cash flows
Cash proceeds from receivables sold	$	449	$	434	$	1,499	$	1,421	$	743	$	713	$	2,140	$	2,064
Collection fees received	—		1		1		1		—		—		1		1
Return received on retained interests	2		—		5		2		3		2		7		5

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

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

13. REVENUE

As described in Note 1, Duke Energy adopted Revenue from Contracts with Customers effective January 1, 2018, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. No cumulative effect adjustment was recorded as the vast majority of Duke Energy’s revenues are at-will and without a defined contractual term. Additionally, comparative disclosures for 2018 operating results with the previous revenue recognition rules are not applicable as Duke Energy’s revenue recognition has not materially changed as a result of the new standard.

Duke Energy recognizes revenue consistent with amounts billed under tariff offerings or at contractually agreed upon rates based on actual physical delivery of electric or natural gas service, including estimated volumes delivered when billings have not yet occurred. As such, the majority of Duke Energy’s revenues have fixed pricing based on the contractual terms of the published tariffs, with variability in expected cash flows attributable to the customer’s volumetric demand and ultimate quantities of energy or natural gas supplied and used during the billing period. The stand-alone selling price of related sales are designed to support recovery of prudently incurred costs and an appropriate return on invested assets and are primarily governed by published tariff rates or contractual agreements approved by relevant regulatory bodies. As described in Note 1, certain excise taxes and franchise fees 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 as part of revenues. Duke Energy elects to account for all other taxes net of revenues.

Performance obligations are satisfied over time as energy or natural gas is delivered and consumed with billings generally occurring monthly and related payments due within 30 days, depending on regulatory requirements. In no event does the timing between payment and delivery of the goods and services exceed one year. Using this output method for revenue recognition provides a faithful depiction of the transfer of electric and natural gas service as customers obtain control of the commodity and benefit from its use at delivery. Additionally, Duke Energy has an enforceable right to consideration for energy or natural gas delivered at any discrete point in time, and will recognize revenue at an amount that reflects the consideration to which Duke Energy is entitled for the energy or natural gas delivered.

As described above, the majority of Duke Energy’s tariff revenues are at-will and, as such, related contracts with customers have an expected duration of one year or less and will not have future performance obligations for disclosure. Additionally, other long-term revenue streams, including wholesale contracts, generally provide services that are part of a single performance obligation, the delivery of electricity or natural gas. As such, other than material fixed consideration under long-term contracts, related disclosures for future performance obligations are also not applicable.

Duke Energy earns substantially all of its revenues through its reportable segments, Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables.

93

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)

Electric Utilities and Infrastructure

Electric Utilities and Infrastructure earns the majority of its revenues through retail and wholesale electric service through the generation, transmission, distribution and sale of electricity. Duke Energy generally provides retail and wholesale electric service customers with their full electric load requirements or with supplemental load requirements when the customer has other sources of electricity.

Retail electric service is generally marketed throughout Duke Energy's electric service territory through standard service offers. The standard service offers are through tariffs determined by regulators in Duke Energy's regulated service territory. Each tariff, which is assigned to customers based on customer class, has multiple components such as an energy charge, a demand charge, a basic facilities charge and applicable riders. Duke Energy considers each of these components to be aggregated into a single performance obligation for providing electric service, or in the case of distribution only customers in Duke Energy Ohio, for delivering electricity. Electricity is considered a single performance obligation satisfied over time consistent with the series guidance and is provided and consumed over the billing period (generally one month). Retail electric service is typically provided to at-will customers that can cancel service at any time, without a substantive penalty. Additionally, Duke Energy adheres to applicable regulatory requirements in each jurisdiction to ensure the collectability of amounts billed and appropriate mitigating procedures are followed when necessary. As such, revenue from contracts with customers for such contracts is equivalent to the electricity supplied and billed in that period (including unbilled estimates).

Wholesale electric service is generally provided under long-term contracts using cost-based pricing. FERC regulates costs that may be recovered from customers and the amount of return companies are permitted to earn. Wholesale contracts include both energy and demand charges. For full requirements contracts, Duke Energy considers both charges as a single performance obligation for providing integrated electric service. For contracts where energy and demand charges are considered separate performance obligations, energy and demand are each a distinct performance obligation under the series guidance and are satisfied as energy is delivered and stand-ready service is provided on a monthly basis. This service represents consumption over the billing period and revenue is recognized consistent with billings and unbilled estimates, which generally occur monthly. Contractual amounts owed are typically trued up annually based upon incurred costs in accordance with FERC published filings and the specific customer’s actual peak demand. Estimates of variable consideration related to potential additional billings or refunds owed are updated quarterly.

The majority of wholesale revenues are full requirements contracts where the customers purchase the substantial majority of their energy needs and do not have a fixed quantity of contractually required energy or capacity. As such, related forecasted revenues are considered optional purchases. Supplemental requirements contracts that include contracted blocks of energy and capacity at contractually fixed prices have the following estimated remaining performance obligations:

	Remaining Performance Obligations
(in millions)	2018		2019		2020		2021		2022		Thereafter		Total
Progress Energy	$	24	$	112	$	121	$	80	$	82	$	81	$	500
Duke Energy Progress	2		9		9		9		9		18		56
Duke Energy Florida	22		103		112		71		73		63		444
Duke Energy Indiana	2		9		10		5		—		—		26

Revenues for block sales are recognized monthly as energy is delivered and stand-ready service is provided, consistent with invoiced amounts and unbilled estimates.

Gas Utilities and Infrastructure

Gas Utilities and Infrastructure earns its revenue through retail and wholesale natural gas service through the transportation, distribution and sale of natural gas. Duke Energy generally provides retail and wholesale natural gas service customers with all natural gas load requirements. Additionally, while natural gas can be stored, substantially all natural gas provided by Duke Energy is consumed by customers simultaneously with receipt of delivery.

Retail natural gas service is marketed throughout Duke Energy's natural gas service territory using published tariff rates. The tariff rates are established by regulators in Duke Energy's service territories. Each tariff, which is assigned to customers based on customer class, have multiple components, such as a commodity charge, demand charge, customer or monthly charge and transportation costs. Duke Energy considers each of these components to be aggregated into a single performance obligation for providing natural gas service. For contracts where Duke Energy provides all of the customer’s natural gas needs, the delivery of natural gas is considered a single performance obligation satisfied over time, and revenue is recognized monthly based on billings and unbilled estimates as service is provided and the commodity is consumed over the billing period. Additionally, natural gas service is typically at-will and customers can cancel service at any time, without a substantive penalty. Duke Energy also adheres to applicable regulatory requirements to ensure the collectability of amounts billed and receivable and appropriate mitigating procedures are followed when necessary.

Certain long-term individually negotiated contracts exist to provide natural gas service. These contracts are regulated and approved by state commissions. The negotiated contracts have multiple components, including a natural gas and a demand charge, similar to retail natural gas contracts. Duke Energy considers each of these components to be a single performance obligation for providing natural gas service. This service represents consumption over the billing period, generally one month.

94

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)

Fixed capacity payments under long-term contracts for the Gas segment include minimum margin contracts and supply arrangements with municipalities and power generation facilities. Revenues for related sales are recognized monthly as natural gas is delivered and stand-ready service is provided, consistent with invoiced amounts and unbilled estimates. Estimated remaining performance obligations are as follows:

	Remaining Performance Obligations
(in millions)	2018		2019		2020		2021		2022		Thereafter		Total
Piedmont	$	18	$	71	$	70	$	65	$	64	$	462	$	750

Commercial Renewables

Commercial Renewables earns the majority of its revenues through long-term PPAs and generally sells all of its wind and solar facility output, electricity and Renewable Energy Credits (RECs) to customers. The majority of these PPAs have historically been accounted for as leases. For PPAs that are not accounted for as leases, the delivery of electricity and the delivery of RECs are considered separate performance obligations.

The delivery of electricity is a performance obligation satisfied over time and represents generation and consumption of the electricity over the billing period, generally one month. The delivery of RECs is a performance obligation satisfied at a point in time and represents delivery of each REC generated by the wind or solar facility. The majority of self-generated RECs are bundled with energy in Duke Energy’s contracts and, as such, related revenues are recognized as energy is generated and delivered as that pattern is consistent with Duke Energy’s performance. Commercial Renewables recognizes revenue based on the energy generated and billed for the period, generally one month, at contractual rates (including unbilled estimates) according to the invoice practical expedient. Amounts are typically due within 30 days of invoice.

Other

The remainder of Duke Energy’s operations is presented as Other, which does not include material revenues from contracts with customers.

95

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)

Disaggregated Revenues

For the Electric and Gas segments, revenue by customer class is most meaningful to Duke Energy as each respective customer class collectively represents unique customer expectations of service, generally has different energy and demand requirements, and operates under tailored, regulatory approved pricing structures. Additionally, each customer class is impacted differently by weather and a variety of economic factors including the level of population growth, economic investment, employment levels, and regulatory activities in each of Duke Energy’s jurisdictions. As such, analyzing revenues disaggregated by customer class allows Duke Energy to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. For the Commercial Renewables segment, the majority of revenues from contracts with customers are from selling all of the unit-contingent output at contractually defined pricing under long-term PPAs with consistent expectations regarding the timing and certainty of cash flows. Disaggregated revenues are presented as follows:

	Three Months Ended September 30, 2018
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	2,729	$	823	$	1,425	$	572	$	853	$	203	$	279	$	—
General	1,763		635		800		373		427		112		218		—
Industrial	835		352		246		177		69		33		202		—
Wholesale	589		132		372		335		37		3		81		—
Other revenues	225		109		134		90		44		20		29		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	6,141	$	2,051	$	2,977	$	1,547	$	1,430	$	371	$	809	$	—
Gas Utilities and Infrastructure
Residential	$	116	$	—	$	—	$	—	$	—	$	59	$	—	$	57
Commercial	66		—		—		—		—		20		—		46
Industrial	28		—		—		—		—		3		—		24
Power Generation	—		—		—		—		—		—		—		13
Other revenues	23		—		—		—		—		1		—		22
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	233	$	—	$	—	$	—	$	—	$	83	$	—	$	162
Commercial Renewables
Revenue from contracts with customers	$	61	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	16	$	—	$	—	$	—	$	—	$	12	$	—	$	—
Total revenue from contracts with customers	$	6,451	$	2,051	$	2,977	$	1,547	$	1,430	$	466	$	809	$	162
Other revenue sources(a)	$	177	$	39	$	68	$	35	$	32	$	3	$	10	$	10
Total revenues	$	6,628	$	2,090	$	3,045	$	1,582	$	1,462	$	469	$	819	$	172

96

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)

	Nine Months Ended September 30, 2018
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	7,264	$	2,263	$	3,636	$	1,540	$	2,096	$	564	$	802	$	—
General	4,619		1,608		2,109		972		1,137		318		584		—
Industrial	2,235		893		678		481		197		96		567		—
Wholesale	1,737		366		1,140		1,019		121		5		226		—
Other revenues	558		261		359		222		137		57		66		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	16,413	$	5,391	$	7,922	$	4,234	$	3,688	$	1,040	$	2,245	$	—
Gas Utilities and Infrastructure
Residential	$	682	$	—	$	—	$	—	$	—	$	236	$	—	$	446
Commercial	354		—		—		—		—		97		—		257
Industrial	107		—		—		—		—		13		—		93
Power Generation	—		—		—		—		—		—		—		40
Other revenues	101		—		—		—		—		13		—		88
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	1,244	$	—	$	—	$	—	$	—	$	359	$	—	$	924
Commercial Renewables
Revenue from contracts with customers	$	141	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	47	$	—	$	—	$	—	$	—	$	36	$	—	$	—
Total Revenue from contracts with customers	$	17,845	$	5,391	$	7,922	$	4,234	$	3,688	$	1,435	$	2,245	$	924
Other revenue sources(a)	$	561	$	134	$	197	$	99	$	92	$	17	$	43	$	16
Total revenues	$	18,406	$	5,525	$	8,119	$	4,333	$	3,780	$	1,452	$	2,288	$	940

(a) Other revenue sources include revenues from leases, derivatives and alternative revenue programs that are not considered revenues from contracts with customers. Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over or under collection of related revenues.

IMPACT OF WEATHER AND THE TIMING OF BILLING PERIODS

Revenues and costs are influenced by seasonal weather patterns. Peak sales of electricity occur during the summer and winter months, which results in higher revenue and cash flows during these periods. By contrast, lower sales of electricity occur during the spring and fall, allowing for scheduled plant maintenance. Residential and general service customers are more impacted by weather than industrial customers. Estimated weather impacts are based on actual current period weather compared to normal weather conditions. Normal weather conditions are defined as the long-term average of actual historical weather conditions. Heating-degree days measure the variation in weather based on the extent the average daily temperature falls below a base temperature. Cooling-degree days measure the variation in weather based on the extent the average daily temperature rises above the base temperature. Each degree of temperature below the base temperature counts as one heating-degree day and each degree of temperature above the base temperature counts as one cooling-degree day.

The estimated impact of weather on earnings for Electric Utilities and Infrastructure is based on the temperature variances from a normal condition and customers' historic usage patterns. The methodology used to estimate the impact of weather does not consider all variables that may impact customer response to weather conditions, such as humidity in the summer or wind chill in the winter. The precision of this estimate may also be impacted by applying long-term weather trends to shorter-term periods.

97

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)

Gas Utilities and Infrastructure's costs and revenues are influenced by seasonal patterns due to peak natural gas sales occurring during the winter months as a result of space heating requirements. Residential customers are the most impacted by weather. There are certain regulatory mechanisms for the North Carolina, South Carolina, Tennessee and Ohio service territories that normalize the margins collected from certain customer classes during the winter. In North Carolina, rate design provides protection from both weather and other usage variations such as conservation, while South Carolina and Tennessee revenues are adjusted solely based on weather. Ohio primarily employs a fixed charge each month regardless of the season and usage.

UNBILLED REVENUE

Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy or 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 and meter reading schedules, and the impact of weather normalization or margin decoupling mechanisms.

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

(in millions)	September 30, 2018		December 31, 2017
Duke Energy	$	802	$	944
Duke Energy Carolinas	278		342
Progress Energy	283		228
Duke Energy Progress	163		143
Duke Energy Florida	120		85
Duke Energy Ohio	2		4
Duke Energy Indiana	25		21
Piedmont	3		86

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

(in millions)	September 30, 2018		December 31, 2017
Duke Energy Ohio	$	68	$	104
Duke Energy Indiana	121		132

14. COMMON STOCK

Basic Earnings Per Share (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 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.

98

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 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 September 30,				Nine Months Ended September 30,
(in millions, except per-share amounts)	2018		2017		2018		2017
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	1,077	$	954	$	2,199	$	2,356
Weighted average shares outstanding – basic	713		700		705		700
Equity Forwards	1		—		1		—
Weighted average shares outstanding – diluted	714		700		706		700
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	1.51	$	1.36	$	3.12	$	3.37
Diluted	$	1.51	$	1.36	$	3.11	$	3.37
Potentially dilutive items excluded from the calculation(a)	2		2		2		2
Dividends declared per common share	$	0.9275	$	0.89	$	2.7075	$	2.60

(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 Issuance

On February 20, 2018, Duke Energy filed a prospectus supplement and executed an Equity Distribution Agreement (the EDA) under which it may sell up to $1 billion of its common stock through an at-the-market (ATM) offering program, including an equity forward sales component. The EDA was entered into with Wells Fargo Securities, LLC, Citigroup Global Markets Inc., and J.P. Morgan Securities LLC (the Agents). Under the terms of the EDA, Duke Energy may issue and sell, through any of the Agents, shares of common stock through September 23, 2019. In June 2018, Duke Energy marketed two separate tranches, each for 1.3 million shares, of common stock. The first tranche was marketed with Wells Fargo Bank at an initial forward price of $72.02 per share and the second tranche was marketed with Citibank at an initial forward price of $78.71 per share through equity forward transactions under the ATM program. The Equity Forwards require Duke Energy to either physically settle the transactions by issuing 2.6 million shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreements or net settle in whole or in part through the delivery or receipt of cash or shares. The settlement alternative is at Duke Energy's election.

Separately, in March 2018, Duke Energy marketed an equity offering of 21.3 million shares of common stock through an Underwriting Agreement with Credit Suisse Securities (USA) LLC, J.P. Morgan Securities LLC, Barclays Capital Inc. and Goldman Sachs & Co. LLC, as representatives of several underwriters, Credit Suisse Capital LLC and J.P. Morgan Securities LLC as Forward Sellers, and Credit Suisse Capital LLC and JPMorgan Chase National Bank Associate, acting as forward purchasers. In connection with the offering, Duke Energy entered into equity forward sale agreements with Credit Suisse Securities (USA) LLC as Agent for Credit Suisse Capital LLC and J.P. Morgan Chase Bank, National Association. The sale price was $75 per share less certain net adjustments for an initial forward price of $74.07 per share. The Equity Forwards require Duke Energy to either physically settle the transactions by issuing 21.3 million shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreements, or net settle in whole or in part through the delivery or receipt of cash or shares. The settlement alternative is at Duke Energy's election. In June 2018, Duke Energy physically settled one-half of the equity forwards by delivering approximately 10.6 million shares of common stock in exchange for net cash proceeds of approximately $781 million.

For contracts that have not been settled, no amounts have or will be recorded in Duke Energy's Condensed Consolidated Financial Statements with respect to the equity or ATM offerings until settlements of the Equity Forwards occur, which is expected by December 31, 2018. If Duke Energy had elected to net share settle these contracts as of September 30, 2018, Duke Energy would have been required to deliver 1.1 million shares. The initial forward sale price will be subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the relevant forward sale agreement. Until settlement of the Equity Forwards, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Duke Energy's stock is higher than the average forward sales price.

For the nine months ended September 30, 2018, Duke Energy has issued 1.7 million shares through its Dividend Reinvestment Program (DRIP) with an increase in additional paid-in capital of approximately $134 million.

99

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)

15. STOCK-BASED COMPENSATION

Stock-based compensation awarded to employees or outside directors is measured at the service inception date or grant date. The fair value of the award is expensed or capitalized over the requisite service period. For awards with performance conditions, the probability of vesting is assessed at each reporting period and compensation cost is adjusted based upon that assessment.

The following table presents information related to Duke Energy's stock–based compensation.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2018		2017		2018		2017
Restricted stock unit awards	$	10	$	10	$	32	$	30
Performance awards	13		7		27		20
Pretax stock-based compensation cost	$	23	$	17	$	59	$	50
Stock-based compensation cost capitalized	$	1	$	1	$	3	$	2
Stock-based compensation expense	$	22	$	16	$	56	$	48
Tax benefit associated with stock-based compensation expense	$	5	$	6	$	13	$	18

16. 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. The following table presents contributions made by the Duke Energy Registrants to their qualified defined benefit pension plans during the nine months ended September 30, 2018.

			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana
Contributions	$	141	$	46	$	45	$	25	$	20	$	8

Duke Energy and Duke Energy Ohio made contributions of $8 million and $4 million, respectively, to their qualified defined benefit pension plans during the nine months ended September 30, 2017.

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

Components of Net Periodic Benefit Costs

The tables below present total net periodic benefit costs prior to capitalization of amounts reflected as Net property, plant and equipment on the Condensed Consolidated Balance Sheets. Only the service cost component of net periodic benefit costs is eligible to be capitalized. The remaining non-capitalized portions of net periodic benefit costs are classified as either: (1) service cost, which is recorded in Operations, maintenance and other on the Condensed Consolidated Statements of Operations; or as (2) components of non-service cost, which is recorded in Other income and expenses, net on the Condensed Consolidated Statements of Operations. See Note 1 for further information on impacts of the retirement benefits accounting standard adopted by Duke Energy on January 1, 2018.

Pension and other post-retirement benefit costs presented in the tables below for the Subsidiary Registrants are amounts allocated from Duke Energy for the employees of the respective Subsidiary Registrants. The Condensed Consolidated Statements of Operations of the Subsidiary Registrants also include allocated net periodic benefit costs for their proportionate share of pension and post-retirement benefit costs related to employees of the Duke Energy shared services affiliate. However, in the tables below these amounts are only presented in the Duke Energy column. For additional information on the corporate governance and shared service expenses allocated from the Duke Energy shared service affiliate, see Note 8.

100

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)

QUALIFIED PENSION PLANS

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

	Three Months Ended September 30, 2018
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	47		$	15		$	13		$	7		$	5		$	2		$	2		$	2
Interest cost on projected benefit obligation	74			18			24			10			13			4			6			3
Expected return on plan assets	(140		)	(37		)	(45		)	(21		)	(23		)	(7		)	(10		)	(6		)
Amortization of actuarial loss	33			7			11			6			6			1			2			3
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(3		)
Net periodic pension costs	$	6		$	1		$	2		$	2		$	1		$	—		$	—		$	(1	)

	Three Months Ended September 30, 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			4			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	)	$	1		$	2

	Nine Months Ended September 30, 2018
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	137		$	45		$	39		$	22		$	16		$	4		$	7		$	6
Interest cost on projected benefit obligation	224			54			70			31			38			13			18			9
Expected return on plan assets	(420		)	(111		)	(133		)	(63		)	(69		)	(21		)	(31		)	(18		)
Amortization of actuarial loss	99			21			33			16			18			3			6			9
Amortization of prior service credit	(24		)	(6		)	(3		)	(1		)	(1		)	—			—			(9		)
Net periodic pension costs	$	16		$	3		$	6		$	5		$	2		$	(1	)	$	—		$	(3	)

	Nine Months Ended September 30, 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	$	120		$	36		$	36		$	18		$	15		$	3		$	6		$	9
Interest cost on projected benefit obligation	246			60			75			36			39			14			21			9
Expected return on plan assets	(408		)	(106		)	(129		)	(63		)	(63		)	(21		)	(33		)	(18		)
Amortization of actuarial loss	108			24			42			18			21			3			9			9
Amortization of prior service credit	(18		)	(6		)	(3		)	—			—			—			—			(3		)
Other	6			—			3			1			—			—			—			1
Net periodic pension costs	$	54		$	8		$	24		$	10		$	12		$	(1	)	$	3		$	7

NON-QUALIFIED PENSION PLANS

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

101

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)

	Three Months Ended September 30, 2018
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	3	$	—	$	1	$	—	$	—
Amortization of actuarial loss	2		—		—		—		—
Net periodic pension costs	$	5	$	—	$	1	$	—	$	—

	Three Months Ended September 30, 2017
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	4	$	—	$	1	$	1	$	1
Amortization of actuarial loss	2		—		1		—		—
Net periodic pension costs	$	6	$	—	$	2	$	1	$	1

	Nine Months Ended September 30, 2018
				Duke				Duke		Duke
	Duke			Energy		Progress		Energy		Energy
(in millions)	Energy			Carolinas		Energy		Progress		Florida
Service cost	$	1		$	1	$	—	$	—	$	—
Interest cost on projected benefit obligation	9			—		3		1		1
Amortization of actuarial loss	6			—		—		—		—
Amortization of prior service (credit) cost	(1		)	—		1		—		—
Net periodic pension costs	$	15		$	1	$	4	$	1	$	1

	Nine Months Ended September 30, 2017
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	10	$	1	$	3	$	2	$	2
Amortization of actuarial loss	6		—		3		—		—
Net periodic pension costs	$	16	$	1	$	6	$	2	$	2

OTHER POST-RETIREMENT BENEFIT PLANS

Duke Energy provides, and the Subsidiary Registrants participate in, certain health care and life insurance benefits for retired employees on a contributory and non-contributory basis.

102

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

	Three Months Ended September 30, 2018
				Duke						Duke		Duke			Duke		Duke
	Duke			Energy			Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress		Florida			Ohio		Indiana		Piedmont
Service cost	$	2		$	—		$	—		$	—	$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	7			2			3			2		1			—		1		—
Expected return on plan assets	(4		)	(2		)	—			—		—			—		—		—
Amortization of actuarial loss	2			1			—			—		—			—		1		—
Amortization of prior service credit	(5		)	(1		)	(2		)	—		(1		)	—		—		—
Net periodic other post-retirement benefit costs	$	2		$	—		$	1		$	2	$	—		$	—	$	2	$	—

	Three Months Ended September 30, 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			—		1		—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—		—
Amortization of actuarial loss	2			—			5			3			2			—		—		—
Amortization of prior service credit	(29		)	(2		)	(21		)	(14		)	(8		)	—		—		—
Net periodic other post-retirement benefit costs	$	(20	)	$	(2	)	$	(12	)	$	(9	)	$	(4	)	$	—	$	1	$	—

	Nine Months Ended September 30, 2018
				Duke						Duke		Duke			Duke		Duke
	Duke			Energy			Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress		Florida			Ohio		Indiana		Piedmont
Service cost	$	5		$	1		$	—		$	—	$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	21			5			9			5		4			1		3		—
Expected return on plan assets	(10		)	(6		)	—			—		—			—		—		—
Amortization of actuarial loss	5			2			1			—		—			—		3		—
Amortization of prior service credit	(15		)	(3		)	(6		)	—		(4		)	—		—		(1		)
Net periodic other post-retirement benefit costs	$	6		$	(1	)	$	4		$	5	$	—		$	1	$	6	$	(1	)

	Nine Months Ended September 30, 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	$	3		$	—		$	—		$	—		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	27			6			11			6			6			—			1		—
Expected return on plan assets	(10		)	(6		)	—			—			—			—			—		—
Amortization of actuarial loss (gain)	6			(2		)	15			9			6			(1		)	—		—
Amortization of prior service credit	(87		)	(6		)	(63		)	(41		)	(23		)	—			—		—
Net periodic other post-retirement benefit costs	$	(61	)	$	(8	)	$	(37	)	$	(26	)	$	(11	)	$	(1	)	$	1	$	—

103

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)

EMPLOYEE SAVINGS PLAN

Duke Energy sponsors, and the Subsidiary Registrants participate in, an employee savings plan that covers substantially all employees. The following table includes 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 September 30,
2018	$	49	$	15	$	13	$	9	$	4	$	—	$	3	$	4
2017	43		14		12		9		4		1		2		2
Nine Months Ended September 30,
2018	$	167	$	53	$	45	$	31	$	14	$	2	$	8	$	10
2017	147		49		42		30		13		3		7		5

17. INCOME TAXES

Tax Act

On December 22, 2017, President Trump signed the Tax Act into law. Among other provisions, the Tax Act lowered the corporate federal income tax rate from 35 to 21 percent, limits interest deductions outside of regulated utility operations, requires the normalization of excess deferred taxes associated with property under ARAM as a prerequisite to qualifying for accelerated depreciation and repealed the federal manufacturing deduction. The Tax Act also repealed the corporate alternative minimum tax (AMT) and stipulates a refund of 50 percent of remaining AMT credit carryforwards (to the extent the credits exceed regular tax for the year) for tax years 2018, 2019 and 2020 with all remaining AMT credits to be refunded in tax year 2021. During the three months ended September 30, 2018, the company reclassified $573 million which is 50 percent of the remaining estimated AMT credit carryforwards from noncurrent deferred tax liability to a current federal income tax receivable as a result of the Tax Act. The company reclassified the estimated AMT credit carryforwards during the three months ended September 30, 2018, since the company expects to receive it as a refund from the IRS in the three months ended September 30, 2019, based on the expected filing of Duke Energy's 2018 income tax return in the second quarter of 2019.

At this time AMT credits, which are among the certain tax credits treated as refundable under the Tax Act, are subject to sequestration. In the first quarter of 2018, the company revised the December 31, 2017, estimate of the income tax effects of the Tax Act and recorded a $76 million valuation allowance against these AMT credits based on additional interpretative guidance from the Internal Revenue Service related to the Tax Act. See Note 22 to the Consolidated Financial Statements in the Annual Report on Form 10-K/A for the year ended December 31, 2017, for information on the U.S. Securities and Exchange Commission staff's guidance on accounting for the Tax Act (Staff Accounting Bulletin No. 118 (SAB 118), Income Tax Accounting Implications of the Tax Cuts and Jobs Act).

During the three months endedSeptember 30, 2018, the company revised the December 31, 2017 estimate of the income tax effects of the Tax Act, in accordance with SAB 118, by recording a $3 million benefit for the remeasurement of its deferred tax assets and deferred tax liabilities primarily related to the guidance on bonus depreciation issued by the Internal Revenue Service in August of 2018 affecting the computation of the company's 2017 Federal income tax liability. The majority of Duke Energy’s operations are regulated and it is expected that the Subsidiary Registrants will ultimately pass on the savings associated with the amount representing the remeasurement of deferred tax balances related to regulated operations to customers. For Duke Energy's regulated operations, where the reduction is expected to be returned to customers in future rates, the remeasurement has been deferred as a regulatory liability. For the three months ended September 30, 2018, Duke Energy recorded a regulatory liability of $57 million, representing the revaluation of those deferred tax balances. The Subsidiary Registrants continue to respond to requests from regulators in various jurisdictions to determine the timing and magnitude of savings they will pass on to customers.

For the nine months ended September 30, 2018, the company has revised the December 31, 2017, estimates of the income tax effects of the Tax Act, in accordance with SAB 118, by recording an expense of $73 million. Additional tax returns will be filed in the quarter ending December 31, 2018, and Duke Energy expects to make refinements of estimates recorded in the three months ending September 30, 2018. These refinements are not expected to be material to the financial statements. Duke Energy anticipates finalizing and recording any resulting adjustments within the measurement period allowed, which will be no later than the quarter ending December 31, 2018.

104

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)

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				Nine Months Ended
	September 30,				September 30,
	2018		2017		2018		2017
Duke Energy	13.7	%	27.6	%	17.0	%	30.4	%
Duke Energy Carolinas	22.6	%	32.9	%	22.3	%	34.1	%
Progress Energy	18.8	%	29.1	%	17.0	%	31.9	%
Duke Energy Progress	20.6	%	31.7	%	18.4	%	32.4	%
Duke Energy Florida	15.0	%	34.8	%	16.3	%	36.1	%
Duke Energy Ohio	16.0	%	33.3	%	16.0	%	34.4	%
Duke Energy Indiana	22.7	%	38.3	%	24.7	%	39.0	%
Piedmont	34.4	%	47.6	%	20.6	%	36.1	%

The decrease in the effective tax rate (ETR) for Duke Energy and the Subsidiary Registrants for the three months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act. The decrease in the ETR for Duke Energy and the Subsidiary Registrants for the nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal and state excess deferred taxes, partially offset by a valuation allowance against AMT credits discussed above.

The decrease in the ETR for Duke Energy Carolinas for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and amortization of state excess deferred taxes partially offset by favorable tax return true ups in the prior year.

The decrease in the ETR for Progress Energy for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal and state excess deferred taxes.

The decrease in the ETR for Duke Energy Progress for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and amortization of state excess deferred taxes.

The decrease in the ETR for Duke Energy Florida for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal excess deferred taxes.

The decrease in the ETR for Duke Energy Ohio for the three and nine months ended September 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal excess deferred taxes.

The decrease in the ETR for Duke Energy Indiana for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act.

The decrease in the ETR for Piedmont for the three months ended September 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act partially offset by favorable research credits in relation to pretax losses. The decrease in the ETR for Piedmont for the nine months ended September 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act.

18. SUBSEQUENT EVENTS

For information on subsequent events related to regulatory matters and commitments and contingencies see Notes 3 and 4, respectively.

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 4 hurricane, the most powerful storm to hit the Florida Panhandle in recorded history. The storm caused significant damage and more than a million power outages within the service territories of Duke Energy Florida, Duke Energy Carolinas and Duke Energy Progress. Duke Energy has not completed the final accumulation of total estimated storm restoration costs incurred; however, the preliminary estimate is approximately$235 million of operation and maintenance expenses and approximately $185 million in capital costs. Given the magnitude of the storm, Duke Energy Carolinas and Duke Energy Progress intend to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate cases, and Duke Energy Florida will recover these storm costs consistent with the provisions in its 2017 Second Revised and Restated Settlement Agreement.

105

PART I

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

The following combined Management’s Discussion and Analysis of Financial Condition and Results of Operations is separately filed by Duke Energy Corporation (collectively with its subsidiaries, Duke Energy) and Duke Energy Carolinas, LLC (Duke Energy Carolinas), Progress Energy, Inc. (Progress Energy), Duke Energy Progress, LLC (Duke Energy Progress), Duke Energy Florida, LLC (Duke Energy Florida), Duke Energy Ohio, Inc. (Duke Energy Ohio), 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.

Management’s Discussion and Analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2018, and with Duke Energy’s Annual Report on Form 10-K/A for the year ended December 31, 2017.

Executive Overview

Hurricane Florence

In the third quarter of 2018, Hurricane Florence caused historic flooding, extensive damage and widespread power outages within the Duke Energy Progress and Duke Energy Carolinas service territories. Approximately 1.8 million customers were impacted. Current estimated restoration costs are approximately $540 million. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

Hurricane Michael

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 4 hurricane, the most powerful storm to hit the Florida Panhandle in recorded history. The storm caused significant damage and more than a million power outages within the service territories of Duke Energy Florida, Duke Energy Carolinas and Duke Energy Progress. Duke Energy has not completed the final accumulation of total estimated storm restoration costs incurred; however, the preliminary estimate is approximately $235 million of operation and maintenance expenses and approximately $185 million in capital costs. Given the magnitude of the storm, Duke Energy Carolinas and Duke Energy Progress intend to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate cases, and Duke Energy Florida will recover these storm costs consistent with the provisions in its 2017 Second Revised and Restated Settlement Agreement.

Regulatory Activity

In 2018, Duke Energy advanced regulatory activity underway in multiple jurisdictions, as follows:

Duke Energy Carolinas received an order on its rate case from the North Carolina Utilities Commission (NCUC) on June 22, 2018. Major components of the order included: a return on equity of 9.9 percent, recovery of past coal ash remediation costs, recovery of Lee Nuclear Project development costs, and partial clarity on the treatment of recent federal tax reform legislation. On July 27, 2018, the NCUC approved Duke Energy Carolinas' compliance filing. As a result, revised customer rates were effective on August 1, 2018.

Duke Energy Progress received an order on its rate case from the NCUC on February 23, 2018. Major components of the order included: a return on equity of 9.9 percent; recovery of past coal ash remediation costs; recovery of deferred storm costs from 2016; and new rates in effect mid-March 2018.

Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the Public Service Commission of South Carolina (PSCSC) seeking an order to defer certain costs associated with grid reliability, resiliency, and modernization work that is being performed under the grid improvement initiative. On October 3, 2018, the PSCSC granted Duke Energy Carolinas' and Duke Energy Progress' joint petition.

Duke Energy Carolinas also petitioned the PSCSC seeking an order to defer certain costs associated with the William States Lee Combined Cycle Facility, the new billing and customer information system and the addition of the Carolinas West Primary Distribution Control Center. Duke Energy Progress also petitioned the PSCSC seeking an order to adopt the new depreciation rates and to defer certain costs associated with the deployment of advanced metering infrastructure, the new billing and customer information system and the costs incurred in connection with the return of certain excess deferred state income taxes from North Carolina. These petitions were approved on July 25, 2018.

Duke Energy Florida filed a petition with the Florida Public Service Commission (FPSC) on May 31, 2018, related to approximately $200 million of customer savings associated with the Federal Tax Cuts and Jobs Act (Tax Act). The tax savings will offset accelerated depreciation of Crystal River Units 4 and 5 and Hurricane Irma storm cost recovery. The petition is subject to review and approval by the FPSC.

Duke Energy Ohio along with the Public Utilities Commission of Ohio (PUCO) Staff and certain intervenors filed a Stipulation and Recommendation (Stipulation) with PUCO on April 13, 2018, and the evidentiary hearing concluded on August 6, 2018. The Stipulation, subject to approval by the PUCO, is in connection with Duke Energy Ohio's electric rate case and other regulatory matters.

On July 25, 2018, Duke Energy Ohio filed an application to establish a new rider to implement the benefits of the Tax Act for electric distribution customers. If approved, the new rider will flow through to customers the benefit of the lower statutory federal tax rate since January 1, 2018, all future benefits of the lower tax rates and a full refund of deferred income taxes collected at the higher tax rates in prior years. Deferred income taxes subject to normalization rules will be refunded consistent with federal law and deferred income taxes not subject to normalization rules will be refunded over a 10-year period. An order is expected before the end of the year. Duke Energy Ohio's transmission rates reflect lower federal

106

PART I

income tax but guidance from FERC on amortization of both protected and unprotected transmission-related EDITs is still pending. On October 24, 2018, the PUCO issued a Finding and Order that, among other things, directed all rate-regulated utilities file an application not for an increase in rates to reflect the impact of the Tax Act on their current rates by January 1, 2019, unless otherwise exempted or directed by the PUCO. Duke Energy Ohio's July 25, 2018, filing for electric distribution operations is consistent with the commission's October 24, 2018, Finding and Order and no further action is needed. Options for Duke Energy Ohio gas customers are still being evaluated.

Duke Energy Kentucky received an order on its electric rate case from the Kentucky Public Service Commission (KPSC) on April 13, 2018. The order granted an annual revenue increase of $21 million, incorporating customer benefits from the Tax Act as well as rider recovery of environmental costs, including coal ash. Duke Energy Kentucky implemented new base rates on May 1, 2018.

On August 31, 2018, Duke Energy Kentucky filed an application with the KPSC requesting an increase in gas base rates of approximately $10.5 million. The KPSC accepted the filing as of September 10, 2018, and a procedural schedule was set.

On June 27, 2018, Duke Energy Indiana, the Indiana Office of Utility Consumers Counselor and others filed testimony consistent with their Stipulation and Settlement Agreement in the federal tax proceedings with the Indiana Utility Regulatory Commission (IURC). Major components include riders to reflect the lower federal tax rate as they are filed in 2018, base rates to reflect the lower federal tax rate upon approval, but no later than September 1, 2018, and a timeline for returning federal excess deferred income taxes to customers. On August 22, 2018, the IURC approved the settlement and rates have been adjusted effective September 1, 2018.

See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters" 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.

Management evaluates financial performance in part based on non-GAAP financial measures, including adjusted earnings and adjusted diluted earnings per share (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.

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 Piedmont Merger represents charges that result from the Piedmont acquisition.

• Regulatory and Legislative Impacts represents charges related to rate case orders, settlements or other actions of regulators or legislative bodies.

• Sale of Retired Plant represents the loss associated with selling Beckjord Generating Station (Beckjord), a nonregulated generating facility in Ohio.

• Impairment Charges represents an other-than-temporary impairment (OTTI) of an investment in Constitution Pipeline Company, LLC (Constitution) and Commercial Renewables impairments.

• Impacts of the Tax Act represents an alternative minimum tax (AMT) valuation allowance recognized and a true up of prior year tax estimates related to the Tax Act.

107

PART I

Three Months Ended September 30, 2018, as compared to September 30, 2017

GAAP Reported EPS was $1.51 for the third quarter of 2018 compared to $1.36 for the third quarter of 2017. The increase in GAAP Reported EPS was primarily due to favorable weather-normal retail sales volumes, higher income tax benefits, a FERC approved settlement refund of certain transmission costs previously billed by PJM Interconnection, LLC (PJM), and lower regulatory settlement charges compared to the prior year. These drivers were partially offset by increased operations and maintenance expense primarily related to Hurricane Florence and share dilution.

As discussed above, management also evaluates financial performance based on adjusted diluted EPS. Duke Energy’s third quarter 2018 adjusted diluted EPS was $1.65 compared to $1.59 for the third quarter of 2017. The increase in adjusted earnings was primarily due to favorable weather-normal retail sales volumes, higher income tax benefits, and a FERC approved settlement refund of certain transmission costs previously billed by PJM Interconnection, LLC (PJM). These drivers were partially offset by increased operations and maintenance expense primarily related to Hurricane Florence and share dilution.

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

	Three Months Ended September 30,
	2018					2017
(in millions, except per-share amounts)	Earnings			EPS		Earnings		EPS
GAAP Reported Earnings/GAAP Reported EPS	$	1,082		$	1.51	$	954	$	1.36
Adjustments:
Impairment Charges(a)	91			0.12		56		0.08
Costs to Achieve Piedmont Merger(b)	13			0.02		14		0.03
Impacts of the Tax Act(c)	(3		)	—		—		—
Florida Settlement(d)	—			—		84		0.12
Discontinued Operations	(4		)	—		2		—
Adjusted Earnings/Adjusted Diluted EPS	$	1,179		$	1.65	$	1,110	$	1.59

(a) Net of $2 million Noncontrolling Interests in 2018 and $28 million tax benefit in 2017.

(b) Net of $3 million tax benefit in 2018 and $9 million tax benefit in 2017.

(c) Represents a true up of prior year tax estimates related to the Tax Act.

(d) Net of $51 million tax benefit in 2017.

Nine Months Ended September 30, 2018, as compared to September 30, 2017

Duke Energy's GAAP Reported EPS was $3.11 for the nine months ended September 30, 2018, compared to $3.36 for the nine months ended September 30, 2017. The decrease in GAAP Reported EPS was driven by regulatory and legislative charges related to the Duke Energy Carolinas North Carolina rate case order and the repeal of the South Carolina Base Load Review Act, a goodwill impairment at Commercial Renewables, and higher depreciation expense due to growing asset base. These drivers were partially offset by favorable weather at Electric Utilities and Infrastructure and higher income tax benefits.

As discussed above, management also evaluates financial performance based on adjusted diluted EPS. Duke Energy's adjusted diluted EPS for the nine months ended September 30, 2018, was $3.87 compared to $3.63 for the nine months ended September 30, 2017. The increase in adjusted earnings for the nine months ended September 30, 2018, compared to the same period in 2017, was primarily due to favorable weather at Electric Utilities and Infrastructure and higher income tax benefits partially offset by higher depreciation expense due to growing asset base.

108

PART I

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

	Nine Months Ended September 30,
	2018				2017
(in millions, except per-share amounts)	Earnings		EPS		Earnings		EPS
GAAP Reported Earnings/GAAP Reported EPS	$	2,202	$	3.11	$	2,356	$	3.36
Adjustments:
Regulatory and Legislative Impacts(a)	202		0.29		—		—
Impairment Charges(b)	133		0.19		56		0.08
Sale of Retired Plant(c)	82		0.12		—		—
Impacts of the Tax Act(d)	73		0.10		—		—
Costs to Achieve Piedmont Merger(e)	41		0.06		43		0.06
Florida Settlement(f)	—		—		84		0.12
Discontinued Operations	1		—		4		0.01
Adjusted Earnings/Adjusted Diluted EPS	$	2,734	$	3.87	$	2,543	$	3.63

(a) Net of $63 million tax benefit.

(b) Net of $13 million tax benefit and $2 million Noncontrolling Interest in 2018 and $28 million tax benefit in 2017.

(c) Net of $25 million tax benefit.

(d) Represents a recognition of AMT valuation allowance and true up of prior year tax estimates related to the Tax Act.

(e) Net of $12 million tax benefit in 2018 and $26 million tax benefit in 2017.

(f) Net of $51 million tax benefit in 2017.

SEGMENT RESULTS

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

Duke Energy's segment structure includes 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. See Note 2 to the Condensed Consolidated Financial Statements, “Business Segments,” for additional information on Duke Energy’s segment structure.

Tax Act

On December 22, 2017, President Trump signed the Tax Act into law. Among other provisions, the Tax Act lowered the corporate federal income tax rate from 35 to 21 percent, limits interest deductions outside of regulated utility operations, requires the normalization of excess deferred taxes associated with property under the average rate assumption method as a prerequisite to qualifying for accelerated depreciation and repealed the federal manufacturing deduction. The Tax Act also repealed the corporate AMT and stipulates a refund of 50 percent of remaining AMT credit carryforwards (to the extent the credits exceed regular tax for the year) for tax years 2018, 2019 and 2020 with all remaining AMT credits to be refunded in tax year 2021. The Tax Act also could be amended or subject to technical correction, which could change the financial impacts that were recorded since December 31, 2017, or are expected to be recorded in future periods. The Federal Energy Regulatory Commission (FERC) and state utility commissions will determine the regulatory treatment of the impacts of the Tax Act for the Subsidiary Registrants. Duke Energy's segments’ future results of operations, financial condition and cash flows could be adversely impacted by the Tax Act, subsequent amendments or corrections, or the actions of the FERC, state utility commissions or credit rating agencies related to the Tax Act. Duke Energy is addressing the rate treatment of the Tax Act by each state utility commission in which the Subsidiary Registrants operate. In January 2018, the Subsidiary Registrants began deferring the estimated ongoing impacts of the Tax Act that are expected to be returned to customers. See Notes 3 and 17 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and “Income Taxes,” respectively, for additional information on the Tax Act.

109

PART I

Electric Utilities and Infrastructure

	Three Months Ended September 30,							Nine Months Ended September 30,
(in millions)	2018		2017		Variance			2018		2017		Variance
Operating Revenues	$	6,260	$	6,129	$	131		$	16,806	$	16,234	$	572
Operating Expenses
Fuel used in electric generation and purchased power	1,935		1,872		63			5,202		4,875		327
Operation, maintenance and other	1,431		1,332		99			4,151		3,935		216
Depreciation and amortization	897		777		120			2,570		2,228		342
Property and other taxes	289		277		12			842		808		34
Impairment charges	31		132		(101		)	246		134		112
Total operating expenses	4,583		4,390		193			13,011		11,980		1,031
Gains on Sales of Other Assets and Other, net	8		—		8			9		4		5
Operating Income	1,685		1,739		(54		)	3,804		4,258		(454		)
Other Income and Expenses, net	107		102		5			286		324		(38		)
Interest Expense	322		305		17			955		925		30
Income Before Income Taxes	1,470		1,536		(66		)	3,135		3,657		(522		)
Income Tax Expense	303		516		(213		)	643		1,273		(630		)
Segment Income	$	1,167	$	1,020	$	147		$	2,492	$	2,384	$	108
Duke Energy Carolinas gigawatt-hours (GWh) sales	25,607		24,135		1,472			70,506		66,159		4,347
Duke Energy Progress GWh sales	19,625		18,827		798			52,747		50,026		2,721
Duke Energy Florida GWh sales	12,375		12,132		243			31,798		31,177		621
Duke Energy Ohio GWh sales	6,964		6,672		292			19,183		18,632		551
Duke Energy Indiana GWh sales	9,114		8,795		319			25,900		24,975		925
Total Electric Utilities and Infrastructure GWh sales	73,685		70,561		3,124			200,134		190,969		9,165
Net proportional megawatt (MW) capacity in operation								48,757		48,909		(152		)

Three Months Ended September 30, 2018, as Compared to September 30, 2017

Electric Utilities and Infrastructure’s results were impacted by favorable weather-normal retail sales volumes, favorable weather in the current year, a positive net contribution from the Duke Energy Progress and Duke Energy Carolinas North Carolina rate cases, a FERC approved settlement refund of certain transmission costs previously billed by PJM, lower income tax expense and lower regulatory charges compared to the prior year related to the unrecovered Levy Nuclear Project costs at Duke Energy Florida.

These drivers were partially offset by higher operation and maintenance expenses primarily due to the impacts of Hurricane Florence and increased depreciation and amortization. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• a $90 million increase in fuel related revenues due to higher sales volumes and increases in fuel rates billed to customers;

• a $54 million increase in weather-normal retail sales volumes;

• a $59 million increase in retail pricing primarily due to the Duke Energy Progress and Duke Energy Carolinas North Carolina rate cases;

• a $38 million increase in retail sales, net of fuel revenues, due to favorable weather in the current year; and

• a $23 million increase in Joint Asset Agency Rider (JAAR) revenues at Duke Energy Progress in conjunction with implementation of new base rates.

Partially offset by:

• a $143 million decrease in retail revenues associated with the lower statutory federal corporate tax rate under the Tax Act.

Operating Expenses. The variance was driven primarily by:

• a $120 million increase in depreciation and amortization expense primarily due to higher amortization of deferred coal ash costs, additional plant in service and new depreciation rates associated with the Duke Energy Progress and Duke Energy Carolinas North Carolina rate cases;

• a $99 million increase in operation, maintenance and other expense primarily due to higher storm costs due to Hurricane Florence and higher operational costs that are recoverable in rates, partially offset by a FERC approved settlement refund of certain transmission costs previously billed by PJM; and

110

PART I

• a $63 million increase in fuel used in electric generation and purchased power primarily due to higher sales and higher deferred fuel expenses.

Partially offset by:

• a $101 million decrease in impairment charges primarily due to the write-off of remaining unrecovered Levy Nuclear Project costs in 2017.

Income Tax Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act and a decrease in pretax income. The effective tax rates (ETRs) for the three months endedSeptember 30, 2018, and 2017 were 20.6 percent and 33.6 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of excess deferred taxes partially offset by favorable tax return true ups in the prior year. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Electric Utilities and Infrastructure’s results were impacted by favorable weather in the current year and a positive net contribution from the Duke Energy Progress and Duke Energy Carolinas North Carolina rate cases, partially offset by higher legislative and regulatory charges compared to the prior year. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• a $398 million increase in fuel related revenues due to higher sales volumes, changes in generation mix and increases in fuel rates billed to customers;

• a $288 million increase in retail sales, net of fuel revenues, due to favorable weather in the current year;

• a $125 million increase in retail pricing primarily due to the Duke Energy Progress and Duke Energy Carolinas North Carolina rate cases and Duke Energy Florida base rate adjustments for the Osprey acquisition and the completion of the Hines Energy Complex Chiller Uprate Project;

• an $80 million increase in weather-normal retail sales volumes; and

• a $52 million increase in JAAR revenues at Duke Energy Progress in conjunction with implementation of new base rates.

Partially offset by:

• a $401 million decrease in retail revenues associated with the lower statutory federal corporate tax rate under the Tax Act.

Operating Expenses. The variance was driven primarily by:

• a $342 million increase in depreciation and amortization expense primarily due to higher amortization of deferred coal ash costs, additional plant in service and new depreciation rates per the Duke Energy Progress and Duke Energy Carolinas North Carolina rate cases;

• a $327 million increase in fuel used in electric generation and purchased power, due to higher sales and higher deferred fuel expenses;

• a $216 million increase in operation, maintenance and other expense primarily due to impacts associated with the Duke Energy Progress North Carolina rate case, the impacts of Hurricane Florence and higher storm cost amortization at Duke Energy Florida, partially offset by a FERC approved settlement refund of certain transmission costs previously billed by PJM; and

• a $112 million increase in impairment charges primarily due to the impacts associated with the Duke Energy Carolinas and Duke Energy Progress North Carolina rate cases, offset by the write-off of remaining unrecovered Levy Nuclear project costs at Duke Energy Florida in the prior year.

Other Income and Expenses, net. The decrease was primarily due to lower post in-service equity returns for projects that had been completed prior to being reflected in customer rates at Duke Energy Carolinas and lower income from non-service components of employee benefit costs in the current year at Duke Energy Progress. For additional information on employee benefit costs, see Note 16 to the Condensed Consolidated Financial Statements, "Employee Benefit Plans."

Income Tax Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act and a decrease in pretax income. The ETRs for the nine months endedSeptember 30, 2018, and 2017 were 20.5 percent and 34.8 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of excess deferred taxes partially offset by favorable tax return true ups in the prior year.

111

PART I

Matters Impacting Future Electric Utilities and Infrastructure Results

On May 18, 2016, the North Carolina Department of Environmental Quality (NCDEQ) issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the North Carolina Coal Ash Management Act of 2014 (Coal Ash Act) were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation enacted 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. On October 12, 2018, NCDEQ announced that Duke Energy had satisfied the permanent replacement water supply requirements by the October 15, 2018, deadline set out in the Coal Ash Management Act. However, NCDEQ has not yet issued final classifications for these impoundments. 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 results of operations, financial position and cash flows.

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. In addition, the orders issued in the Duke Energy Carolinas and Duke Energy Progress North Carolinas rate cases supporting recovery of past coal ash remediation costs have been appealed by various parties. The outcome of these appeals, lawsuits and potential fines and penalties could have an adverse impact on Electric Utilities and Infrastructure's results of operations, financial position and cash flows. See Notes 3 and 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and “Commitments and Contingencies,” respectively, for additional information.

On June 22, 2018, Duke Energy Carolinas received an order from the NCUC, which denied the Grid Rider Stipulation and deferral treatment of grid improvement costs. Duke Energy Carolinas may petition for deferral of grid modernization costs outside of a general rate case proceeding if it can show financial hardship or a stipulation that includes greater consensus among intervening parties on costs being classified as grid modernization. While Duke Energy Progress did not request recovery of these costs in its most recent case with the NCUC, Duke Energy Progress may request recovery of certain grid modernization costs in future regulatory proceedings. Electric Utilities and Infrastructure's results of operations, financial position and cash flows could be adversely impacted if grid modernization costs are not ultimately approved for recovery and/or deferral treatment. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On June 30, 2017, CertainTeed Gypsum NC, Inc. (CertainTeed) filed a declaratory judgment action against Duke Energy Progress in the North Carolina Business Court relating to a gypsum supply agreement. In its complaint, CertainTeed sought an order from the court declaring that the minimum amount of gypsum Duke Energy Progress must provide to CertainTeed under the supply agreement is 50,000 tons per month through 2029. The trial for this matter concluded on July 16, 2018. On August 29, 2018, the court issued an order and opinion finding that Duke Energy Progress is required to supply 50,000 tons of gypsum per month, but that CertainTeed's sole remedy for Duke Energy Progress' long-term discontinuance under the agreement is liquidated damages. The estimated maximum amount that would be owed under the liquidated damages provision is approximately $90 million. Both CertainTeed and Duke Energy Progress have filed cross-appeals. The outcome of the cross-appeals could have an adverse impact on Electric Utilities and Infrastructure's results of operations, financial position and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

In the third quarter of 2018, Hurricane Florence caused historic flooding, extensive damage and widespread power outages within the Duke Energy Progress and Duke Energy Carolinas service territories. Approximately 1.8 million customers were impacted. Current estimated restoration costs are approximately $540 million. Most of the operation and maintenance expenses are deferred as of September 30, 2018. Given the magnitude of the storm, Duke Energy Progress intends to request approval in North Carolina and South Carolina to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate case. These requests are expected to be filed during the fourth quarter of 2018. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration costs could have an adverse impact on Electric Utilities and Infrastructure’s financial position, results of operations and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 4 hurricane, the most powerful storm to hit the Florida Panhandle in recorded history. The storm caused significant damage and more than a million power outages within the service territories of Duke Energy Florida, Duke Energy Carolinas and Duke Energy Progress. Duke Energy has not completed the final accumulation of total estimated storm restoration costs incurred; however, the preliminary estimate is approximately $235 million of operation and maintenance expenses and approximately $185 million in capital costs. Given the magnitude of the storm, Duke Energy Carolinas and Duke Energy Progress intend to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate cases, and Duke Energy Florida will recover these storm costs consistent with the provisions in its 2017 Second Revised and Restated Settlement Agreement. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration costs could have an adverse impact on Electric Utilities and Infrastructure's results of operations, financial position and cash flows.

Duke Energy Florida is constructing the 1,640-MW combined-cycle natural gas plant in Citrus County, Florida, and expects it to be commercially available in 2018. Actual costs are expected to exceed estimated costs by an immaterial amount after recoveries; therefore, an impairment is not expected. Failure to complete the construction and achieve commercial operations by the end of 2018 or failure to obtain recoveries from customers or vendors could materially impact Electric Utilities and Infrastructure's results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On February 6, 2018, the FPSC approved a stipulation that would apply tax savings resulting from the Tax Act toward storm costs effective January 2018 in lieu of implementing a storm surcharge. On May 31, 2018, Duke Energy Florida filed for recovery of the storm costs. Storm costs are currently expected to be fully recovered by approximately mid-2021. The commission has scheduled the hearing to begin on May 21, 2019. An order disallowing recovery of these costs could have an adverse impact on Electric Utilities and Infrastructure's results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

112

PART I

In March 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. On April 13, 2018, Duke Energy Ohio filed a Stipulation with the PUCO to resolve issues in the electric distribution base rate case and other regulatory matters. If approved by PUCO, the Stipulation would allow for Duke Energy Ohio to recover gains and losses incurred on and after January 1, 2018, related to the Ohio Valley Electric Corporation (OVEC), through the Price Stabilization Rider. Hearings concluded on August 6, 2018. Initial briefs were filed on September 11, 2018, and reply briefs on October 2, 2018. Electric Utilities and Infrastructure's results of operations, financial position and cash flows could be adversely impacted if the Stipulation is denied by the PUCO. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

Gas Utilities and Infrastructure

	Three Months Ended September 30,								Nine Months Ended September 30,
(in millions)	2018			2017		Variance			2018		2017		Variance
Operating Revenues	$	256		$	272	$	(16	)	$	1,301	$	1,243	$	58
Operating Expenses
Cost of natural gas	58			68		(10		)	460		402		58
Operation, maintenance and other	101			94		7			312		293		19
Depreciation and amortization	61			57		4			182		171		11
Property and other taxes	24			25		(1		)	81		81		—
Total operating expenses	244			244		—			1,035		947		88
Operating Income	12			28		(16		)	266		296		(30		)
Other Income and Expenses, net	29			23		6			16		62		(46		)
Interest Expense	25			26		(1		)	78		78		—
Income Before Income Taxes	16			25		(9		)	204		280		(76		)
Income Tax (Benefit) Expense	(1		)	6		(7		)	43		101		(58		)
Segment Income	$	17		$	19	$	(2	)	$	161	$	179	$	(18	)
Piedmont local distribution company (LDC) throughput (dekatherms)	135,403,188			107,490,775		27,912,413			407,144,529		334,781,316		72,363,213
Duke Energy Midwest LDC throughput (Mcf)	9,370,743			9,904,644		(533,901		)	62,111,858		52,940,410		9,171,448

Three Months Ended September 30, 2018, as Compared to September 30, 2017

Gas Utilities and Infrastructure’s results were primarily impacted by lower revenues. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues.The variance was driven by:

• an $11 million decrease due to revenues subject to refund to customers associated with the lower statutory federal corporate tax rate under the Tax Act; and

• a $10 million decrease primarily due to lower natural gas costs passed through to customers from lower retail volumes sold, partially offset by higher natural gas prices.

Partially offset by:

• a $6 million increase primarily due to residential and commercial customer revenue, net of natural gas costs passed through to customers, due to customer growth and Integrity Management Rider (IMR) rate adjustments at Piedmont.

Operating Expenses.The variance was driven by:

• a $10 million decrease in cost of natural gas primarily due to lower retail volumes sold, partially offset by slightly higher natural gas prices.

Partially offset by:

• a $7 million increase in operations, maintenance and other primarily due to increased shared services and customer operations expense.

Other Income and Expenses, net. The increase was primarily due to higher income from non-service components of employee benefit costs in the current year. For additional information on employee benefit costs, see Note 16 to the Condensed Consolidated Financial Statements, "Employee Benefit Plans."

113

PART I

Income Tax (Benefit) Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the three months endedSeptember 30, 2018, and 2017 were (6.3) percent and 24.0 percent, respectively. The decrease in the ETR was primarily due to the lower statutory corporate tax rate under the Tax Act and research credits. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Gas Utilities and Infrastructure’s results were primarily impacted by the OTTI recorded on the Constitution investment; partially offset by favorable price adjustments and customer growth. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues.The variance was driven by:

• a $58 million increase primarily due to higher natural gas costs passed through to customers due to higher retail volumes sold and higher natural gas prices;

• a $37 million increase primarily due to residential and commercial customer revenue, net of natural gas costs passed through to customers, due to customer growth and IMR rate adjustments and new power generation customers at Piedmont; and

• a $10 million increase primarily due to favorable weather in the current year and higher volumes sold in the Midwest.

Partially offset by:

• a $49 million decrease due to revenues subject to refund to customers associated with the lower statutory federal corporate tax rate under the Tax Act.

Operating Expenses.The variance was driven by:

• a $58 million increase in cost of natural gas primarily due to higher retail volumes sold and higher natural gas prices;

• a $19 million increase in operations, maintenance and other primarily due to increased shared services and gas operations expense; and

• an $11 million increase in depreciation and amortization due to additional plant in service.

Other Income and Expenses, net. The decrease was primarily due to the OTTI recorded for the investment in Constitution in the current year, partially offset by higher income from non-service components of employee benefit costs in the current year. For additional information on employee benefit costs, see Note 16 to the Condensed Consolidated Financial Statements, "Employee Benefit Plans."

Income Tax (Benefit) Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the nine months ended September 30, 2018, and 2017 were 21.1 percent and 36.1 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act.

Matters Impacting Future Gas Utilities and Infrastructure Results

Gas Utilities and Infrastructure has a 47 percent ownership interest in Atlantic Coast Pipeline, LLC (ACP), which is building an approximately 600-mile interstate natural gas pipeline intended to transport diverse natural gas supplies into southeastern markets. Affected states (West Virginia, Virginia and North Carolina) have issued certain necessary permits; the project remains subject to other pending federal and state approvals, which will allow full construction activities to begin. In 2018, FERC issued a series of Notices to Proceed, which authorized the project to begin certain construction-related activities along the pipeline route. Project cost estimates have increased from a range of $6.0 billion to $6.5 billion to a range of $6.5 billion to $7.0 billion, excluding financing costs. The project has a targeted in-service date of late 2019 for key portions of the project, with the remaining segments targeted to be in-service in mid-2020. Project construction activities, schedule and final costs are subject to uncertainty due to abnormal weather, work delays (including delays due to judicial or regulatory action) and other conditions and risks that could result in potential higher project costs, a potential delay in the targeted in-service dates and potential impairment charges. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

114

PART I

Commercial Renewables

	Three Months Ended September 30,									Nine Months Ended September 30,
(in millions)	2018			2017			Variance			2018			2017			Variance
Operating Revenues	$	127		$	95		$	32		$	347		$	333		$	14
Operating Expenses
Operation, maintenance and other	85			55			30			209			191			18
Depreciation and amortization	40			39			1			116			116			—
Property and other taxes	6			9			(3		)	19			26			(7		)
Impairment charges	93			76			17			93			76			17
Total operating expenses	224			179			45			437			409			28
Gains on Sales of Other Assets and Other, net	—			1			(1		)	—			5			(5		)
Operating Loss	(97		)	(83		)	(14		)	(90		)	(71		)	(19		)
Other Income and Expenses, net	2			(11		)	13			22			(12		)	34
Interest Expense	21			22			(1		)	66			64			2
Loss Before Income Taxes	(116		)	(116		)	—			(134		)	(147		)	13
Income Tax Benefit	(37		)	(65		)	28			(112		)	(146		)	34
Less: Loss Attributable to Noncontrolling Interests	(17		)	(2		)	(15		)	(18		)	(3		)	(15		)
Segment (Loss) Income	$	(62	)	$	(49	)	$	(13	)	$	(4	)	$	2		$	(6	)
Renewable plant production, GWh	1,897			1,760			137			6,548			6,276			272
Net proportional MW capacity in operation										2,976			2,908			68

Three Months Ended September 30, 2018, as Compared to September 30, 2017

Commercial Renewables' results were unfavorably impacted by the higher tax benefit in 2017 from cost and property, plant and equipment impairments, partially offset by the minority interest loss associated with a third-party tax equity partnership arrangement. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The increase in revenues was primarily due to an increase in the number of Engineering, Procurement and Construction (EPC) agreements at REC Solar, a California based provider of solar installations.

Operating Expenses. The increase was primarily due to an increase in the number of EPC agreements at REC Solar, higher development expenses and higher goodwill impairment charges in the current year.

Other Income and Expenses, net. The favorable variance in other income and expenses was primarily a result of the impairment of certain cost investments in the prior year.

Income Tax Benefit. The lower tax benefits in 2018 were due to the lower statutory federal corporate tax rate under the Tax Act and higher tax benefit in 2017 from cost and property, plant and equipment impairments.

Loss Attributable to Noncontrolling Interests. The variance is primarily attributable to the entering into a third-party tax equity partnership arrangement during the third quarter.

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Commercial Renewables' results were unfavorably impacted by the higher tax benefit in 2017 from cost and property, plant and equipment impairments, primarily offset by the entering into a third-party tax equity partnership arrangement, the bankruptcy court approval of the North Allegheny Wind, LLC (NAW) and FirstEnergy Solutions (FES) settlement agreement and the minority interest loss associated with a third-party tax equity partnership arrangement. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The increase in revenues was primarily due to an increase in the number of EPC agreements at REC Solar and favorable solar portfolio revenue.

Operating Expenses. The increase was primarily due to higher development expenses and goodwill impairment charges in the current year, partially offset by lower property taxes due to non-recurring property tax payments made in the prior year.

Other Income and Expenses, net. The favorable variance in other income and expenses was primarily due to the bankruptcy court approved NAW and FES settlement agreement, which allowed retention of previously collected cash collateral under the Purchase Power Agreements (PPAs), mark-to-market gains on interest rate swaps, the impairment of certain cost investments in the prior year and lower equity losses in the current year.

Income Tax Benefit.The lower tax benefits in 2018 were due to the lower statutory federal corporate tax rate under the Tax Act and higher tax benefit in 2017 from cost and property, plant and equipment impairments.

Loss Attributable to Noncontrolling Interests. The variance is primarily attributable to the entering into a third-party tax equity partnership arrangement.

115

PART I

Matters Impacting Future Commercial Renewables Results

Persistently low market pricing for wind resources, primarily in the Electric Reliability Council of Texas West market and PJM west and the future expiration of tax incentives including investment tax credits and production tax credits could result in adverse impacts to the future results of operations, financial position and cash flows of Commercial Renewables.

Deterioration in credit quality resulting in bankruptcy of an offtaker of power from contracted wind or solar assets could result in adverse impacts to the future results of operations, financial position and cash flows of Commercial Renewables. On March 31, 2018, FES, a subsidiary of FirstEnergy and counterparty to two PPAs with NAW, filed for Chapter 11 bankruptcy. On June 18, 2018, The United States Bankruptcy Court’s Northern District of Ohio Eastern Division approved the Stipulation between FES and NAW. The Stipulation resulted in, among other items, the termination of the two PPAs between FES and NAW, as a result, NAW is subject to market pricing in the PJM west market.

On September 26, 2018, Duke Energy announced it is seeking a minority investor for the commercial renewables business. Duke Energy will continue to develop projects, grow its portfolio and manage its renewables assets. Duke Energy Renewable Services, an operations and maintenance business for third-party customers, and REC Solar are not included in the potential transaction. A sale of a minority interest is dependent on a number of factors and cannot be predicted at this time.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

Other

	Three Months Ended September 30,									Nine Months Ended September 30,
(in millions)	2018			2017			Variance			2018			2017			Variance
Operating Revenues	$	34		$	35		$	(1	)	$	101		$	103		$	(2	)
Operating Expenses
Fuel used in electric generation and purchased power	14			13			1			43			42			1
Operation, maintenance and other	(8		)	20			(28		)	(2		)	47			(49		)
Depreciation and amortization	43			27			16			113			79			34
Property and other taxes	5			3			2			13			10			3
Impairment charges	—			—			—			—			7			(7		)
Total operating expenses	54			63			(9		)	167			185			(18		)
Gains (Losses) on Sales of Other Assets and Other, net	3			4			(1		)	(96		)	15			(111		)
Operating Loss	(17		)	(24		)	7			(162		)	(67		)	(95		)
Other Income and Expenses, net	40			50			(10		)	81			100			(19		)
Interest Expense	163			150			13			484			423			61
Loss Before Income Taxes	(140		)	(124		)	(16		)	(565		)	(390		)	(175		)
Income Tax Benefit	(98		)	(93		)	(5		)	(125		)	(193		)	68
Less: Income Attributable to Noncontrolling Interests	2			3			(1		)	6			8			(2		)
Net Loss	$	(44	)	$	(34	)	$	(10	)	$	(446	)	$	(205	)	$	(241	)

Three Months Ended September 30, 2018, as Compared to September 30, 2017

Other's higher net loss was primarily driven by insurance proceeds received in the prior year. The following is a detailed discussion of the variance drivers by line item.

Operating Expenses. The variance was primarily driven by the reclassification of certain immaterial current year costs to the Electric Utilities and Infrastructure segment.

Other Income and Expenses, net. The variance was primarily due to insurance proceeds received in the prior year resulting from settlement of the shareholder litigation related to the Progress Energy merger.

Interest Expense. The variance was primarily due to an increase in long-term debt as well as higher interest rates on short-term debt.

Income Tax Benefit. The variance was primarily driven by an increase in pretax losses and favorable tax return true ups, partially offset by the lower statutory corporate federal income tax rate under the Tax Act. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Other's higher net loss was driven by the loss on sale of the retired Beckjord station, higher interest expense and lower tax benefit due to the Tax Act. The following is a detailed discussion of the variance drivers by line item.

Operating Expenses. The variance was primarily driven by the reclassification of certain immaterial current year costs to the Electric Utilities and Infrastructure segment.

Other Income and Expenses, net. The variance was primarily due to insurance proceeds received in the prior year resulting from settlement of the shareholder litigation related to the Progress Energy merger.

116

PART I

Gains (Losses) on Sales of Other Assets and Other, net. The variance was driven by the loss on sale of the retired Beckjord station, a nonregulated facility retired during 2014, including the transfer of coal ash basins and other real property and indemnification from all potential future claims related to the property, whether arising under environmental laws or otherwise.

Interest Expense. The variance was primarily due to an increase in long-term debt as well as higher interest rates on short-term debt.

Income Tax Benefit. The variance was primarily due to the valuation allowance against AMT credits and the lower statutory corporate federal income tax rate under the Tax Act, partially offset by an increase in pretax losses. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Matters Impacting Future Other Results

Included in Other is Duke Energy Ohio's 9 percent ownership interest in the 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. On March 31, 2018, FES, a subsidiary of FirstEnergy and an ICPA counterparty with a power participation ratio of 4.85 percent, filed for Chapter 11 bankruptcy, which could increase costs allocated to the counterparties. On July 31, 2018, the bankruptcy court rejected the FES ICPA, which means OVEC is an unsecured creditor in the FES bankruptcy proceeding. Duke Energy cannot predict the impact of the bankruptcy filing on its OVEC interests. In addition, certain proposed environmental rulemaking costs could result in future increased OVEC cost allocations.

In March 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. On April 13, 2018, Duke Energy Ohio filed a Stipulation with the PUCO to resolve issues in the electric distribution base rate case and other regulatory matters. If approved by PUCO, the Stipulation would allow for Duke Energy Ohio to recover gains and losses incurred on and after January 1, 2018, related to OVEC, through the Price Stabilization Rider and, as a result, Duke Energy Ohio may move its ownership interest to the Electric Utilities and Infrastructure segment. Hearings concluded on August 6, 2018. Initial briefs were filed on September 11, 2018, and reply briefs on October 2, 2018. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters” for additional information.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

DUKE ENERGY CAROLINAS

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2018, and 2017 and the Annual Report on Form 10-K/A for the year ended December 31, 2017.

Results of Operations

	Nine Months Ended September 30,
(in millions)	2018			2017		Variance
Operating Revenues	$	5,525		$	5,581	$	(56	)
Operating Expenses
Fuel used in electric generation and purchased power	1,370			1,394		(24		)
Operation, maintenance and other	1,464			1,472		(8		)
Depreciation and amortization	866			804		62
Property and other taxes	214			206		8
Impairment charges	191			—		191
Total operating expenses	4,105			3,876		229
Losses on Sales of Other Assets and Other, net	(1		)	—		(1		)
Operating Income	1,419			1,705		(286		)
Other Income and Expenses, net	108			140		(32		)
Interest Expense	323			314		9
Income Before Income Taxes	1,204			1,531		(327		)
Income Tax Expense	268			522		(254		)
Net Income	$	936		$	1,009	$	(73	)

117

PART I

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	2018
Residential sales	12.3	%
General service sales	6.1	%
Industrial sales	2.2	%
Wholesale power sales	13.5	%
Joint dispatch sales	7.4	%
Total sales	6.6	%
Average number of customers	1.4	%

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Operating Revenues.The variance was driven primarily by:

• a $197 million decrease in retail sales due to revenues subject to refund to customers associated with the lower statutory federal corporate tax rate under the Tax Act;

• a $48 million decrease in rider revenues primarily related to energy efficiency programs; and

• a $25 million decrease in wholesale power revenues, net of sharing and fuel, primarily due to wholesale customer refunds in the current year related to a FERC order on a complaint filed by Piedmont Municipal Power Agency (PMPA), partially offset by higher revenues related to recovery of coal ash costs.

Partially offset by:

• a $141 million increase in retail sales, net of fuel revenues, due to favorable weather in the current year;

• a $39 million increase in weather-normal retail sales volumes; and

• a $29 million increase in retail pricing due to the impacts of the North Carolina rate case.

Operating Expenses. The variance was driven primarily by:

• a $191 million increase in impairment charges, primarily due to the impacts of the North Carolina rate order and charges related to coal ash costs in South Carolina; and

• a $62 million increase in depreciation and amortization primarily due to additional plant in service and higher amortization of deferred coal ash costs, partially offset by lower amortization of certain regulatory assets.

Partially offset by:

• a $24 million decrease in fuel used in electric generation and purchased power primarily due to decreased coal ash beneficial reuse costs, partially offset by higher sales volumes.

Other Income and Expenses. The variance was primarily due to lower AFUDC equity and a decrease in recognition of post in-service equity returns for projects that were completed prior to being reflected in customer rates.

Income Tax Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the nine months ended September 30, 2018, and 2017 were 22.3 percent and 34.1 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of state excess deferred taxes partially offset by favorable tax return true ups in the prior year. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Matters Impacting Future Results

On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation enacted 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. On October 12, 2018, NCDEQ announced that Duke Energy had satisfied the permanent replacement water supply requirements by the October 15, 2018, deadline set out in the Coal Ash Management Act. However, NCDEQ has not yet issued final classifications for these impoundments. 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' results of operations, financial position and cash flows.

118

PART I

On June 22, 2018, Duke Energy Carolinas received an order from the NCUC, which denied the Grid Rider Stipulation and deferral treatment of grid improvement costs. Duke Energy Carolinas may petition for deferral of grid modernization costs outside of a general rate case proceeding if it can show financial hardship or a stipulation that includes greater consensus among intervening parties on costs being classified as grid modernization. Duke Energy Carolinas' results of operations, financial position and cash flows could be adversely impacted if grid modernization costs are not ultimately approved for recovery and/or deferral treatment. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 4 hurricane, the most powerful storm to hit the Florida Panhandle in recorded history. The storm caused damage within the service territory of Duke Energy Carolinas. Duke Energy Carolinas has not completed the final accumulation of total estimated storm restoration costs incurred; however, the preliminary estimate is approximately $70 million of operation and maintenance expenses. Given the magnitude of the storm, Duke Energy Carolinas intends to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate case. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration costs could have an adverse impact on Duke Energy Carolinas' financial position, results of operations and cash flows.

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. In addition, the order issued in the Duke Energy Carolinas North Carolinas rate case supporting recovery of past coal ash remediation costs has been appealed by various parties. The outcome of these appeals, lawsuits, fines and penalties could have an adverse impact on Duke Energy Carolinas’ results of operations, financial position and cash flows. See Notes 3 and 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and “Commitments and Contingencies,” respectively, for additional information.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

PROGRESS ENERGY

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2018, and 2017 and the Annual Report on Form 10-K/A for the year ended December 31, 2017.

Results of Operations

	Nine Months Ended September 30,
(in millions)	2018		2017		Variance
Operating Revenues	$	8,119	$	7,435	$	684
Operating Expenses
Fuel used in electric generation and purchased power	3,019		2,588		431
Operation, maintenance and other	1,913		1,697		216
Depreciation and amortization	1,183		958		225
Property and other taxes	399		386		13
Impairment charges	34		137		(103		)
Total operating expenses	6,548		5,766		782
Gains on Sales of Other Assets and Other, net	23		19		4
Operating Income	1,594		1,688		(94		)
Other Income and Expenses, net	128		112		16
Interest Expense	626		595		31
Income Before Income Taxes	1,096		1,205		(109		)
Income Tax Expense	186		384		(198		)
Net Income	910		821		89
Less: Net Income Attributable to Noncontrolling Interests	6		7		(1		)
Net Income Attributable to Parent	$	904	$	814	$	90

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Operating Revenues. The variance was driven primarily by:

• a $467 million increase in fuel related revenues due to higher sales volumes, increases in fuel and capacity rates billed to customers and increased demand at Duke Energy Florida;

• a $103 million increase in retail sales, net of fuel revenues, due to favorable weather in the current year and impacts of lost revenue resulting from Hurricane Irma in the prior year at Duke Energy Florida;

• an $89 million increase in JAAR revenues, primarily due to the implementation of new base rates and weather normalized volumes at Duke Energy Progress;

• a $79 million increase in retail pricing due to the impacts of the Duke Energy Progress North Carolina and South Carolina rate cases; and

119

PART I

• a $73 million increase in wholesale power revenues, net of fuel, primarily due to the recovery of coal ash costs and higher peak demand at Duke Energy Progress.

Partially offset by:

• a $98 million decrease in retail sales due to revenues subject to refund to customers associated with the lower statutory federal corporate tax rate under the Tax Act at Duke Energy Progress; and

• a $35 million decrease in rider revenues in conjunction with implementation of new base rate and impacts of Hurricane Florence at Duke Energy Progress.

Operating Expenses. The variance was driven primarily by:

• a $431 million increase in fuel used in electric generation and purchased power primarily due to higher sales, higher deferred fuel and capacity expenses, and increased purchased power;

• a $225 million increase in depreciation and amortization primarily due to higher amortization of deferred coal ash costs and new depreciation rates associated with the North Carolina rate case at Duke Energy Progress, and accelerated depreciation of Crystal River Units 4 and 5 and additional plant in service at Duke Energy Florida;

• a $216 million increase in operation, maintenance and other primarily due to impacts associated with the North Carolina rate case at Duke Energy Progress and storm cost amortization at Duke Energy Florida; and

• a $13 million increase in property and other taxes primarily due to higher revenue related taxes.

Partially offset by:

• a $103 million decrease in impairment charges primarily due to the write-off of remaining unrecovered Levy Nuclear Project costs in the prior year at Duke Energy Florida.

Income Tax Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the nine months ended September 30, 2018, and 2017 were 17.0 percent and 31.9 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act and levelization for annual amortization of federal and state excess deferred taxes. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Matters Impacting Future Results

On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation enacted 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. On October 12, 2018, NCDEQ announced that Duke Energy had satisfied the permanent replacement water supply requirements by the October 15, 2018, deadline set out in the Coal Ash Management Act. However, NCDEQ has not yet issued final classifications for these impoundments. 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 results of operations, financial position and cash flows.

In the third quarter of 2018, Hurricane Florence caused historic flooding, extensive damage and widespread power outages within the Duke Energy Progress service territory. Current estimated restoration costs are approximately $420 million of operations and maintenance expense and approximately $75 million in capital costs. Most of the operation and maintenance expenses are deferred as of September 30, 2018. Given the magnitude of the storm, Duke Energy Progress intends to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate case. The request is expected to be filed during the fourth quarter of 2018. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration costs could have an adverse impact on Progress Energy's financial position, results of operations and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 4 hurricane, the most powerful storm to hit the Florida Panhandle in recorded history. The storm caused significant damage within the service territories of Duke Energy Florida and Duke Energy Progress. Progress Energy has not completed the final accumulation of total estimated storm restoration costs incurred; however, the preliminary estimate is approximately $165 million of operation and maintenance expenses and approximately $175 million of capital costs. Given the magnitude of the storm, Duke Energy Progress intends to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate case, and Duke Energy Florida will recover these storm costs consistent with the provisions in its 2017 Second Revised and Restated Settlement Agreement. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration costs could have an adverse impact on Progress Energy's financial position, results of operations and cash flows.

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. As noted above, the order issued in the Duke Energy Progress North Carolinas rate case supporting recovery of past coal ash remediation costs has been appealed by various parties. The outcome of these appeals, lawsuits, fines and penalties could have an adverse impact on Progress Energy’s results of operations, financial position and cash flows. See Notes 3 and 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and “Commitments and Contingencies,” respectively, for additional information.

120

PART I

Duke Energy Carolinas received an order from the NCUC, which denied the Grid Rider Stipulation and deferral treatment of grid improvement costs. The NCUC did allow Duke Energy Carolinas to petition for deferral of grid modernization costs outside of a general rate case proceeding if it can show financial hardship or a stipulation that includes greater consensus among intervening parties on costs being classified as grid modernization. While Duke Energy Progress did not request recovery of these costs in its most recent case with the NCUC, Duke Energy Progress may request recovery of certain grid modernization costs in future regulatory proceedings. If the NCUC were to rule similarly, Progress Energy's results of operations, financial position and cash flows could be adversely impacted if grid modernization costs are not ultimately approved for recovery and/or deferral treatment. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On June 30, 2017, CertainTeed filed a declaratory judgment action against Duke Energy Progress in the North Carolina Business Court relating to a gypsum supply agreement. In its complaint, CertainTeed sought an order from the court declaring that the minimum amount of gypsum Duke Energy Progress must provide to CertainTeed under the supply agreement is 50,000 tons per month through 2029. The trial for this matter concluded on July 16, 2018. On August 29, 2018, the court issued an order and opinion finding that Duke Energy Progress is required to supply 50,000 tons of gypsum per month, but that CertainTeed's sole remedy for Duke Energy Progress' long-term discontinuance under the agreement is liquidated damages. The estimated maximum amount that would be owed under the liquidated damages provision is approximately $90 million. Both CertainTeed and Duke Energy Progress have filed cross-appeals. The outcome of the cross-appeals could have an adverse impact on Progress Energy's results of operations, financial position and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

Duke Energy Florida is constructing the 1,640-MW combined-cycle natural gas plant in Citrus County, Florida, and expects it to be commercially available in 2018. Actual costs are expected to exceed estimated costs by an immaterial amount after recoveries; therefore, an impairment is not expected. Failure to complete the construction and achieve commercial operations by the end of 2018 or failure to obtain recoveries from customers or vendors could materially impact Progress Energy's results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On February 6, 2018, the FPSC approved a stipulation that would apply tax savings resulting from the Tax Act toward storm costs effective January 2018 in lieu of implementing a storm surcharge. On May 31, 2018, Duke Energy Florida filed for recovery of the storm costs. Storm costs are currently expected to be fully recovered by approximately mid-2021. The commission has scheduled the hearing to begin on May 21, 2019. An order disallowing recovery of these costs could have an adverse impact on Progress Energy's results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

DUKE ENERGY PROGRESS

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2018, and 2017 and the Annual Report on Form 10-K/A for the year ended December 31, 2017.

Results of Operations

	Nine Months Ended September 30,
(in millions)	2018		2017		Variance
Operating Revenues	$	4,333	$	3,878	$	455
Operating Expenses
Fuel used in electric generation and purchased power	1,452		1,214		238
Operation, maintenance and other	1,187		1,069		118
Depreciation and amortization	723		536		187
Property and other taxes	115		120		(5		)
Impairment charges	33		—		33
Total operating expenses	3,510		2,939		571
Gains on Sales of Other Assets and Other, net	9		3		6
Operating Income	832		942		(110		)
Other Income and Expenses, net	61		84		(23		)
Interest Expense	241		217		24
Income Before Income Taxes	652		809		(157		)
Income Tax Expense	120		262		(142		)
Net Income	$	532	$	547	$	(15	)

121

PART I

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	2018
Residential sales	10.1	%
General service sales	2.1	%
Industrial sales	0.7	%
Wholesale power sales	7.2	%
Joint dispatch sales	2.9	%
Total sales	5.4	%
Average number of customers	1.6	%

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Operating Revenues. The variance was driven primarily by:

• a $268 million increase in fuel related revenues due to higher retail sales and changes in generation mix;

• a $79 million increase in pricing due to the impacts of the North Carolina and South Carolina rate cases;

• a $73 million increase in wholesale power revenues, net of fuel, primarily due to recovery of coal ash costs and higher peak demand;

• a $72 million increase in retail sales due to favorable weather conditions;

• a $52 million increase in JAAR revenues in conjunction with implementation of new base rates; and

• a $37 million increase in weather normalized volumes.

Partially offset by:

• a $98 million decrease in retail sales due to revenues subject to refund to customers associated with the lower statutory federal corporate tax rate under the Tax Act;

• a $25 million decrease in certain rider revenues in conjunction with implementation of new base rates; and

• a $10 million decrease in revenues due to the impacts of Hurricane Florence.

Operating Expenses. The variance was driven primarily by:

• a $238 million increase in fuel used in electric generation and purchased power primarily due higher retail sales and changes in generation mix;

• a $187 million increase in depreciation and amortization primarily due to higher amortization of deferred coal ash costs and new depreciation rates per the North Carolina rate case;

• a $118 million increase in operation, maintenance and other expense primarily due to higher storm contingency costs, impacts associated with the North Carolina rate case and higher operational costs that are recoverable in rates; and

• a $33 million increase in impairment charges associated with the North Carolina rate case.

Other Income and Expenses. The variance was primarily driven by lower income from non-service components of employment benefit costs. For additional information on employee benefit costs, see Note 16 to the Condensed Consolidated Financial Statements, "Employee Benefit Plans."

Income Tax Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the nine months ended September 30, 2018, and 2017 were 18.4 percent and 32.4 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of state excess deferred taxes. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

122

PART I

Matters Impacting Future Results

On May 18, 2016, the NCDEQ issued proposed risk classifications for all coal ash surface impoundments in North Carolina. All ash impoundments not previously designated as high priority by the Coal Ash Act were designated as intermediate risk. Certain impoundments classified as intermediate risk, however, may be reassessed in the future as low risk pursuant to legislation enacted 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. On October 12, 2018, NCDEQ announced that Duke Energy had satisfied the permanent replacement water supply requirements by the October 15, 2018, deadline set out in the Coal Ash Management Act. However, NCDEQ has not yet issued final classifications for these impoundments. 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' results of operations, financial position and cash flows.

In the third quarter of 2018, Hurricane Florence caused historic flooding, extensive damage and widespread power outages within the Duke Energy Progress service territory. Current estimated restoration costs are approximately $420 million of operations and maintenance expense and approximately $75 million in capital costs. Most of the operation and maintenance expenses are deferred as of September 30, 2018. Given the magnitude of the storm, Duke Energy Progress intends to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate case. The request is expected to be filed during the fourth quarter of 2018. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration costs could have an adverse impact on Duke Energy Progress' financial position, results of operations and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 4 hurricane, the most powerful storm to hit the Florida Panhandle in recorded history. The storm caused damage within the service territory of Duke Energy Progress. Duke Energy Progress has not completed the final accumulation of total estimated storm restoration costs incurred; however, the preliminary estimate is approximately $25 million of operation and maintenance expenses. Given the magnitude of the storm, Duke Energy Progress intends to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate case. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration costs could have an adverse impact on Duke Energy Progress' financial position, results of operations and cash flows.

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. As noted above, the order issued in the Duke Energy Progress North Carolinas rate case supporting recovery of past coal ash remediation costs has been appealed by various parties. The outcome of these appeals, lawsuits, fines and penalties could have an adverse impact on Duke Energy Progress’ results of operations, financial position and cash flows. See Notes 3 and 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and “Commitments and Contingencies,” respectively, for additional information.

Duke Energy Carolinas received an order from the NCUC, which denied the Grid Rider Stipulation and deferral treatment of grid improvement costs. The NCUC did allow Duke Energy Carolinas to petition for deferral of grid modernization costs outside of a general rate case proceeding if it can show financial hardship or a stipulation that includes greater consensus among intervening parties on costs being classified as grid modernization. While Duke Energy Progress did not request recovery of these costs in its most recent case with the NCUC, Duke Energy Progress may request recovery of certain grid modernization costs in future regulatory proceedings. If the NCUC were to rule similarly, Duke Energy Progress' results of operations, financial position and cash flows could be adversely impacted if grid modernization costs are not ultimately approved for recovery and/or deferral treatment. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On June 30, 2017, CertainTeed filed a declaratory judgment action against Duke Energy Progress in the North Carolina Business Court relating to a gypsum supply agreement. In its complaint, CertainTeed sought an order from the court declaring that the minimum amount of gypsum Duke Energy Progress must provide to CertainTeed under the supply agreement is 50,000 tons per month through 2029. The trial for this matter concluded on July 16, 2018. On August 29, 2018, the court issued an order and opinion finding that Duke Energy Progress is required to supply 50,000 tons of gypsum per month, but that CertainTeed's sole remedy for Duke Energy Progress' long-term discontinuance under the agreement is liquidated damages. The estimated maximum amount that would be owed under the liquidated damages provision is approximately $90 million. Both CertainTeed and Duke Energy Progress have filed cross-appeals. The outcome of the cross-appeals could have an adverse impact on Duke Energy's Progress results of operations, financial position and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

123

PART I

DUKE ENERGY FLORIDA

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2018, and 2017 and the Annual Report on Form 10-K/A for the year ended December 31, 2017.

Results of Operations

	Nine Months Ended September 30,
(in millions)	2018		2017		Variance
Operating Revenues	$	3,780	$	3,551	$	229
Operating Expenses
Fuel used in electric generation and purchased power	1,567		1,374		193
Operation, maintenance and other	719		623		96
Depreciation and amortization	460		423		37
Property and other taxes	284		265		19
Impairment charges	1		137		(136		)
Total operating expenses	3,031		2,822		209
Operating Income	749		729		20
Other Income and Expenses, net	75		58		17
Interest Expense	210		211		(1		)
Income Before Income Taxes	614		576		38
Income Tax Expense	100		208		(108		)
Net Income	$	514	$	368	$	146

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	2018
Residential sales	2.7	%
General service sales	1.1	%
Industrial sales	0.2	%
Wholesale and other	4.4	%
Total sales	2.0	%
Average number of customers	1.6	%

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Operating Revenues. The variance was driven primarily by:

• a $199 million increase in fuel and capacity revenues primarily due to an increase in fuel and capacity rates billed to retail customers, as well as increased demand; and

• a $31 million increase in retail sales, net of fuel revenues, due to favorable weather in the current year and impacts of lost revenue resulting from Hurricane Irma in the prior year.

Operating Expenses. The variance was driven primarily by:

• a $193 million increase in fuel used in electric generation and purchased power primarily due to higher deferred fuel and capacity expenses, increased purchased power and increased demand;

• a $96 million increase in operations, maintenance and other expense primarily due to storm cost amortizations, partially offset by lower storm restoration costs in the current year;

• a $37 million increase in depreciation and amortization primarily due to accelerated depreciation of Crystal River Units 4 and 5 and additional plant in service, partially offset by decreased ARO depreciation due to the updated Crystal River Unit 3 nuclear decommissioning cost study; and

• a $19 million increase in property and other taxes primarily due to higher revenue related taxes.

Partially offset by:

• a $136 million decrease in impairment charges primarily due to the write-off of remaining unrecovered Levy Nuclear Project costs in the prior year.

Other Income and Expenses. The variance was driven primarily by higher AFUDC equity return on the Citrus County Combined Cycle project in the current year.

124

PART I

Income Tax Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the nine months ended September 30, 2018, and 2017 were 16.3 percent and 36.1 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal excess deferred taxes. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Matters Impacting Future Results

Duke Energy Florida is constructing the 1,640-MW combined-cycle natural gas plant in Citrus County, Florida, and expects it to be commercially available in 2018. Actual costs are expected to exceed estimated costs by an immaterial amount after recoveries; therefore, an impairment is not expected. Failure to complete the construction and achieve commercial operations by the end of 2018 or failure to obtain recoveries from customers or vendors could materially impact Duke Energy Florida’s results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On February 6, 2018, the FPSC approved a stipulation that would apply tax savings resulting from the Tax Act toward storm costs effective January 2018 in lieu of implementing a storm surcharge. On May 31, 2018, Duke Energy Florida filed for recovery of the storm costs. Storm costs are currently expected to be fully recovered by approximately mid-2021. The commission has scheduled the hearing to begin on May 21, 2019. An order disallowing recovery of these costs could have an adverse impact on Duke Energy Florida's results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 4 hurricane, the most powerful storm to hit the Florida Panhandle in recorded history. The storm caused significant damage within the service territory of Duke Energy Florida. Duke Energy Florida has not completed the final accumulation of total estimated storm restoration costs incurred; however, the preliminary estimate is approximately $140 million of operation and maintenance expenses and approximately $175 million in capital costs. Given the magnitude of the storm, Duke Energy Florida will recover these storm costs consistent with the provisions in its 2017 Second Revised and Restated Settlement Agreement. An order from regulatory authorities disallowing the future recovery of storm restoration costs could have an adverse impact on Duke Energy Florida's financial position, results of operations and cash flows.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

DUKE ENERGY OHIO

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2018, and 2017 and the Annual Report on Form 10-K/A for the year ended December 31, 2017.

Results of Operations

	Nine Months Ended September 30,
(in millions)	2018			2017			Variance
Operating Revenues
Regulated electric	$	1,055		$	1,036		$	19
Regulated natural gas	361			360			1
Nonregulated electric and other	36			30			6
Total operating revenues	1,452			1,426			26
Operating Expenses
Fuel used in electric generation and purchased power – regulated	284			283			1
Fuel used in electric generation and purchased power – nonregulated	43			42			1
Cost of natural gas	73			69			4
Operation, maintenance and other	337			388			(51		)
Depreciation and amortization	196			193			3
Property and other taxes	218			204			14
Impairment charges	—			1			(1		)
Total operating expenses	1,151			1,180			(29		)
(Losses) Gains on Sales of Other Assets and Other, net	(106		)	1			(107		)
Operating Income	195			247			(52		)
Other Income and Expenses, net	17			15			2
Interest Expense	68			67			1
Income From Continuing Operations Before Income Taxes	144			195			(51		)
Income Tax Expense From Continuing Operations	23			67			(44		)
Income From Continuing Operations	121			128			(7		)
Loss From Discontinued Operations, net of tax	—			(1		)	1
Net Income	$	121		$	127		$	(6	)

125

PART I

The following table shows the percent changes in GWh sales of electricity, dekatherms of natural gas delivered and average number of electric and natural gas 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.

	Electric		Natural Gas
Increase (Decrease) over prior year	2018		2018
Residential sales	13.4	%	28.6	%
General service sales	3.6	%	24.7	%
Industrial sales	(1.0	)%	9.6	%
Wholesale electric power sales	(58.3	)%	n/a
Other natural gas sales	n/a		0.3	%
Total sales	3.0	%	17.3	%
Average number of customers	0.8	%	0.8	%

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Operating Revenues. The variance was driven primarily by:

• a $39 million increase in electric and natural gas retail sales, net of fuel revenues, due to favorable weather in the current year;

• a $16 million increase in financial transmission rights revenues;

• a $5 million increase in other revenues related to OVEC;

• a $5 million increase in fuel revenues due to higher natural gas costs; and

• a $4 million increase in rider revenue primarily due to increased rates.

Partially offset by:

• a $38 million decrease in regulated revenues due to revenues subject to refund to customers associated with the lower statutory federal corporate tax rate under the Tax Act; and

•a $5 million decrease in bulk power marketing sales.

Operating Expenses. The variance was driven primarily by:

• a $51 million decrease in operations, maintenance and other expense primarily due to the FERC approved settlement refund of certain transmission costs previously billed by PJM.

Partially offset by:

•a $14 million increase in property and other taxes primarily due to higher property taxes due to higher plant balances; and

•a $6 million increase in fuel costs primarily due to increased natural gas sales volumes.

Other Income and Expenses. The variance was driven primarily by an increase in AFUDC equity due to higher base spending for transmission and fossil plants and an increase due to the impairment of meters in 2017.

Gains (Losses) on Sales of Other Assets and Other, net. The decrease was driven by the loss on the sale of Beckjord, a nonregulated facility retired during 2014, including the transfer of coal ash basins and other real property and indemnification from any and all potential future claims related to the property, whether arising under environmental laws or otherwise.

Income Tax Expense. The variance was primarily due to a decrease in pretax income and the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the nine months ended September 30, 2018, and 2017 were 16.0 percent and 34.4 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal excess deferred taxes. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Matters Impacting Future Results

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. On March 31, 2018, FES, a subsidiary of FirstEnergy and an ICPA counterparty with a power participation ratio of 4.85 percent, filed for Chapter 11 bankruptcy, which could increase costs allocated to the counterparties. On July 31, 2018, the bankruptcy court rejected the FES ICPA, which means OVEC is an unsecured creditor in the FES bankruptcy proceeding. Duke Energy Ohio cannot predict the impact of the bankruptcy filing on its OVEC interests. In addition, certain proposed environmental rulemaking costs could result in future increased OVEC cost allocations.

126

PART I

In March 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. On April 13, 2018, Duke Energy Ohio filed a Stipulation with the PUCO to resolve issues in the electric distribution base rate case and other regulatory matters. If approved by PUCO, the Stipulation would allow for Duke Energy Ohio to recover gains and losses incurred on and after January 1, 2018, related to OVEC, through the Price Stabilization Rider. Hearings concluded on August 6, 2018. Initial briefs were filed on September 11, 2018, and reply briefs on October 2, 2018. Duke Energy Ohio's results of operations, financial position and cash flows could be adversely impacted if the Stipulation is denied by the PUCO. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

DUKE ENERGY INDIANA

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2018, and 2017 and the Annual Report on Form 10-K/A for the year ended December 31, 2017.

Results of Operations

	Nine Months Ended September 30,
(in millions)	2018		2017		Variance
Operating Revenues	$	2,288	$	2,302	$	(14	)
Operating Expenses
Fuel used in electric generation and purchased power	730		744		(14		)
Operation, maintenance and other	576		546		30
Depreciation and amortization	386		336		50
Property and other taxes	56		56		—
Impairment charges	30		—		30
Total operating expenses	1,778		1,682		96
Gains on Sales of Other Assets and Other, net	—		1		(1		)
Operating Income	510		621		(111		)
Other Income and Expenses, net	36		32		4
Interest Expense	125		132		(7		)
Income Before Income Taxes	421		521		(100		)
Income Tax Expense	104		203		(99		)
Net Income	$	317	$	318	$	(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	2018
Residential sales	14.0	%
General service sales	3.1	%
Industrial sales	0.4	%
Wholesale power sales	(0.9	)%
Total sales	3.7	%
Average number of customers	1.2	%

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Operating Revenues.The variance was driven primarily by:

• an $83 million decrease due to revenues subject to refund to customers associated with the lower statutory federal corporate tax rate under the Tax Act; and

• a $22 million decrease in wholesale power revenues, net of fuel, primarily due to contracts that expired in the prior year.

127

PART I

Partially offset by:

• a $53 million increase in rate rider revenues primarily related to the Edwardsport Integrated Gasification Combined Cycle (IGCC) plant and the Transmission, Distribution and Storage System Improvement Charge rider;

• a $24 million increase in electric sales to retail customers due to favorable weather in the current year;

• a $7 million increase in weather-normal sales volumes to retail customers in the current year; and

• a $6 million increase in fuel and other revenues primarily due to higher Midcontinent Independent System Operator rider revenue, partially offset by a decrease in retail and wholesale fuel revenues.

Operating Expenses.The variance was driven primarily by:

• a $50 million increase in depreciation and amortization primarily due to additional plant in service and the deferral of certain asset retirement obligations in the prior year;

• a $30 million increase in operation, maintenance and other expense primarily due to higher amortizations of previously deferred expenses, higher transmission and customer related costs; and

• a $30 million increase in impairment charges primarily due to the reduction of a regulatory asset pertaining to the Edwardsport IGCC settlement agreement.

Partially offset by:

• a $14 million decrease in fuel used in electric generation and purchased power primarily due to the net benefit to expense of lower purchased power and an increase in internal generation, and lower fuel prices.

Other Income and Expenses. The increase was primarily due to higher AFUDC equity resulting from recognition of the equity portion of rider specific post-in-service carrying costs under the tax settlement approved by the IURC.

Income Tax Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the nine months ended September 30, 2018, and 2017 were 24.7 percent and 39.0 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Matters Impacting Future Results

On April 17, 2015, the U.S. Environmental Protection Agency (EPA) published in the Federal Register a rule to regulate the disposal of Coal Combustion Residuals (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. Additionally, Duke Energy Indiana has retired facilities that are not subject to the CCR rule. Duke Energy Indiana may incur costs at these facilities to comply with environmental regulations or to mitigate risks associated with on-site storage of coal ash. 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 results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

128

PART I

PIEDMONT

Management’s Discussion and Analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2018, and 2017 and the Annual Report on Form 10-K/A for the year ended December 31, 2017.

Results of Operations

	Nine Months Ended September 30,
(in millions)	2018		2017			Variance
Operating Revenues	$	940	$	884		$	56
Operating Expenses
Cost of natural gas	387		333			54
Operation, maintenance and other	252		226			26
Depreciation and amortization	118		109			9
Property and other taxes	36		38			(2		)
Impairment charges	—		7			(7		)
Total operating expenses	793		713			80
Operating Income	147		171			(24		)
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	6		8			(2		)
Other income and expenses, net	9		(1		)	10
Total other income and expenses	15		7			8
Interest Expense	60		59			1
Income Before Income Taxes	102		119			(17		)
Income Tax Expense	21		43			(22		)
Net Income	$	81	$	76		$	5

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	2018
Residential deliveries	34.2	%
Commercial deliveries	20.1	%
Industrial deliveries	3.3	%
Power generation deliveries	25.9	%
For resale	21.8	%
Total throughput deliveries	21.6	%
Secondary market volumes	(9.8	)%
Average number of customers	1.5	%

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 precise recovery of approved margin during periods when winter weather is significantly warmer or colder than normal.

Nine Months Ended September 30, 2018, as Compared to September 30, 2017

Operating Revenues.The variance was driven primarily by:

• a $54 million increase primarily due to higher natural gas costs passed through to customers due to higher retail volumes sold and higher natural gas prices; and

• a $37 million increase primarily due to residential and commercial customer revenue, net of natural gas costs passed through to customers, due to customer growth and IMR rate adjustments; and new power generation customers.

Partially offset by:

• a $34 million decrease due to revenues subject to refund to customers associated with the lower statutory federal corporate tax rate under the Tax Act.

129

PART I

Operating Expenses.The variance was driven by:

• a $54 million increase in cost of natural gas primarily due to higher retail volumes sold and higher natural gas prices;

• a $26 million increase in operation, maintenance and other primarily due to increased shared services, costs to achieve merger expenses and natural gas operations; and

• a $9 million increase in depreciation and amortization due to additional plant in service.

Partially offset by:

• a $7 million decrease due to an impairment of software recorded in the prior year.

Other Income and Expense.The increase was primarily due to higher income from non-service components of employee benefit costs in the current year. For additional information on employee benefit costs, see Note 16 to the Condensed Consolidated Financial Statements, "Employee Benefit Plans."

Income Tax Expense. The variance was primarily due to the lower statutory federal corporate tax rate under the Tax Act. The ETRs for the nine months ended September 30, 2018, and 2017 were 20.6 percent and 36.1 percent, respectively. The decrease in the ETR was primarily due to the lower statutory federal corporate tax rate under the Tax Act. For additional information, see Note 17 to the Condensed Consolidated Financial Statements, "Income Taxes."

Matters Impacting Future Results

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K/A for the year ended December 31, 2017, for discussion of risks associated with the Tax Act.

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/A for the year ended December 31, 2017, for a summary and detailed discussion of projected primary sources and uses of cash for 2018 to 2020.

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.

Equity Issuance

Refer to Note 14 to the CondensedConsolidated Financial Statements, "Common Stock," for further information regarding Duke Energy's equity issuance.

CREDIT FACILITIES AND REGISTRATION STATEMENTS

Refer to Note 5 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities," for further information regarding Duke Energy's available credit facilities, including the Master Credit Facility.

Shelf Registration

In September 2016, Duke Energy filed a registration statement (Form S-3) with the U.S. Securities and Exchange Commission. Under this Form S-3, which is uncapped, the Duke Energy Registrants, excluding Progress Energy (Parent), 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.

130

PART I

DEBT MATURITIES

Refer to Note 5 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities," for further information regarding significant components of Current Maturities of Long-Term Debt on the Condensed Consolidated Balance Sheets.

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, and regulatory orders 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 and Revolving Facilities, to support these operations, including storm restoration costs from Hurricanes Florence and Michael. 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/A for the year ended December 31, 2017, 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, and 70 percent for Piedmont. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements or sublimits thereto. As of September 30, 2018, each of the Duke Energy Registrants was 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.

Moody’s Investors Service, Inc. (Moody’s), Standard & Poor’s Rating Services and Fitch Ratings, Inc. provide credit ratings for various Duke Energy Registrants.

On August 1, 2018, Moody’s revised its ratings outlook for Duke Energy Corporation and Piedmont from negative to stable and for Duke Energy Ohio from positive to stable. Moody’s also revised its ratings as follows: Progress Energy is upgraded from Baa2 to Baa1; Piedmont is downgraded from A2 to A3. On September 6, 2018, Fitch revised its ratings outlook for Duke Energy Corporation from negative to stable.

Cash Flow Information

The following table summarizes Duke Energy’s cash flows.

	Nine Months Ended
	September 30,
(in millions)	2018			2017
Cash flows provided by (used in):
Operating activities	$	5,667		$	4,978
Investing activities	(7,270		)	(6,331		)
Financing activities	1,547			1,239
Net decrease in cash, cash equivalents and restricted cash	(56		)	(114		)
Cash, cash equivalents and restricted cash at beginning of period	505			541
Cash, cash equivalents and restricted cash at end of period	$	449		$	427

131

PART I

OPERATING CASH FLOWS

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

	Nine Months Ended
	September 30,
(in millions)	2018			2017			Variance
Net income	$	2,190		$	2,361		$	(171	)
Non-cash adjustments to net income	5,206			3,937			1,269
Contributions to qualified pension plans	(141		)	(8		)	(133		)
Payments for asset retirement obligations	(389		)	(420		)	31
Payment for disposal of other assets	(105		)	—			(105		)
Working capital	(1,094		)	(892		)	(202		)
Net cash provided by operating activities	$	5,667		$	4,978		$	689

The variance was primarily due to:

• a $1,098 million increase in net income after adjustment for non-cash items primarily due to favorable weather and increased pricing and volumes in the current period.

Partially offset by:

• a $133 million increase in contributions to qualified pension plans; and

• a $105 million payment for disposal of Beckjord.

INVESTING CASH FLOWS

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

	Nine Months Ended
	September 30,
(in millions)	2018			2017			Variance
Capital, investment and acquisition expenditures	$	(7,050	)	$	(6,211	)	$	(839	)
Other investing items	(220		)	(120		)	(100		)
Net cash used in investing activities	$	(7,270	)	$	(6,331	)	$	(939	)

The variance relates primarily to an increase in capital expenditures due to higher overall investments in regulated generation, natural gas and commercial renewables.

FINANCING CASH FLOWS

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

	Nine Months Ended
	September 30,
(in millions)	2018			2017			Variance
Issuances of long-term debt, net	$	1,832		$	3,675		$	(1,843	)
Issuances of common stock	834			—			834
Notes payable and commercial paper	674			(619		)	1,293
Dividends paid	(1,835		)	(1,825		)	(10		)
Other financing items	42			8			34
Net cash provided by financing activities	$	1,547		$	1,239		$	308

The variance was primarily due to:

• an $834 million increase in proceeds from the issuance of common stock; and

• a $1,293 million increase in net proceeds from issuances of notes payable and commercial paper primarily due to increased capital expenditures and the timing of debt and common stock issuances.

Partially offset by:

• a $1,843 million decrease in proceeds from net issuances of long-term debt primarily due to prior year financings of $820 million in the Commercial Renewables segment and the timing of issuances and redemptions of long-term debt.

132

PART I

Summary of Significant Debt Issuances

Refer to Note 5 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities," for further information regarding significant debt issuances.

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 statutes and regulations that may impact the Duke Energy Registrants. Refer to Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for further information regarding potential plant retirements and regulatory filings related to the Duke Energy Registrants.

Coal Combustion Residuals

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. 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. Duke Energy does not expect a material impact from the settlement or that it will result in additional ARO adjustments. On September 13, 2017, EPA responded to a petition by the Utility Solid Waste Activities Group that the agency would reconsider certain provisions of the final rule, and asked the D.C. Circuit Court to suspend the litigation. The D.C. Circuit Court denied EPA’s petition to suspend the litigation and oral argument was held on November 20, 2017. On August 21, 2018, the D.C. Circuit issued its decision in the CCR rule litigation denying relief for industry petitioners' remaining claims and ruling in favor of environmental petitioners on a number of their challenges, including the regulation of inactive CCR surface impoundments at retired plants and the continued operation of unlined impoundments.

On March 15, 2018, EPA published proposed amendments to the federal CCR rule, including revisions that were required as part of a CCR litigation settlement, as well as changes that the agency considers warranted due to the passage of the Water Infrastructure Improvements for the Nation Act, which provides statutory authority for state and federal permit programs. On July 17, 2018, EPA issued a rule finalizing certain, but not all, elements included in the agency's March 15, 2018, proposal. The final rule revises certain closure deadlines and groundwater protection standards in the CCR rule. It does not change the primary requirements for groundwater monitoring, corrective action, inspections and maintenance, and closure, and thus does not materially affect Duke Energy’s coal ash basin closure plans or compliance obligations under the CCR rule.

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/A for the year ended December 31, 2017.

Coal Ash Management Act of 2014

Asset retirement obligations recorded on the Duke Energy Carolinas and Duke Energy Progress Condensed Consolidated Balance Sheets at September 30, 2018, and December 31, 2017, 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. The Coal Ash Act requires Duke Energy to undertake dam improvement projects and to provide access to a permanent alternative drinking water source to certain residents within a half-mile of coal ash basin compliance boundaries and to certain other potentially impacted residents. The legislation requires excavation of the Sutton, Riverbend and Dan River basins by August 1, 2019, and Asheville basins by August 1, 2022. Excavation at these sites may include a combination of transfer of coal ash to an engineered landfill or conversion for beneficial use. Basins at the H.F. Lee, Cape Fear and Weatherspoon sites are required to be closed through excavation no later than August 1, 2028. Excavation at these sites can include conversion of the basin to a lined industrial landfill, transfer of ash to an engineered landfill or conversion for beneficial use. The remaining basins are required to be closed no later than December 31, 2024, through conversion to a lined industrial landfill, transfer to an engineered landfill or conversion for beneficial use, unless certain dam improvement projects and alternative drinking water source projects are completed by October 15, 2018. Upon satisfactory completion of these projects, the closure deadline would be extended to December 31, 2029, and could include closure through the combination of a cap system and a groundwater monitoring. On October 12, 2018, NCDEQ announced that Duke Energy had satisfied the permanent replacement water supply requirements by the October 15, 2018, deadline set out in the Coal Ash Management Act. NCDEQ has until November 14, 2018, to issue final basin classifications.

Additionally, the Coal Ash Act requires the installation and operation of three large-scale coal ash beneficiation projects to produce reprocessed ash for use in the concrete industry. Duke Energy selected the Buck, H.F. Lee and Cape Fear plants for these projects. Closure at these sites is required to be completed no later than December 31, 2029.

133

PART I

The Coal Ash Act includes a variance procedure for compliance deadlines and other issues surrounding the management of CCR and CCR surface impoundments and prohibits 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. NCDEQ requested that Duke Energy submit options analyses, groundwater modeling and net environmental benefits analyses for six sites potentially eligible for closure by cap in place by November 15, 2018. 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/A for the year ended December 31, 2017.

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 2023 time frame. Petitions challenging the rule have been filed by several groups. Oral argument was held on September 14, 2017. On July 23, 2018, the U.S. Court of Appeals for the Second Circuit announced their decision to uphold the 316(b) rule. Duke Energy continues to work with the state environmental permitting agency to implement the rule.

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. As originally written, affected facilities were required to comply between 2018 and 2023, depending on the timing of Clean Water Act (CWA) discharge permits. Most of the steam electric generating facilities the Duke Energy Registrants own are 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 rule focused on the limits imposed on IGCC facilities (gasification wastewater). All challenges to the rule were consolidated in the Fifth Circuit Court of Appeals. On August 22, 2017, the Fifth Circuit Court of Appeals granted EPA’s Motion to Govern Further Proceedings, thereby severing and suspending the claims related to flue gas desulfurization wastewater, bottom ash transport water and gasification wastewater. Claims regarding gasification wastewater were stayed, pending the issuance of the variance to Duke Energy Indiana. Duke Energy Indiana’s federal court challenge to EPA’s Effluent Limitations Guidelines and Standards for the Steam Electric Power Generating Point Source Category remains in abeyance. After a long delay, EPA issued a variance for discharges at Edwardsport of wastewater associated with the gasification process. The variance was incorporated by the state agency into a revised wastewater discharge permit, and Duke Energy Indiana has voluntarily dismissed the federal court challenge. The litigation will continue as to claims related to other waste streams.

Separate from the litigation, EPA finalized a rule on September 18, 2017, postponing the earliest applicability date for bottom ash transport water and flue gas desulfurization wastewater from 2018 to 2020 and retaining the end applicability date of 2023. Also, as part of the rule, EPA reiterated its intent to conduct a new rulemaking to review the effluent limitation guidelines for bottom ash transport water and flue gas desulfurization wastewater. EPA projects that a new rule on these two issues will be finalized by the end of 2019.

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, 2022. 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/A for the year ended December 31, 2017.

(in millions)	Estimated Cost
Duke Energy	$	950
Duke Energy Carolinas	440
Progress Energy	370
Duke Energy Progress	270
Duke Energy Florida	100
Duke Energy Ohio	90
Duke Energy Indiana	50

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.

134

PART I

Cross-State Air Pollution Rule

On September 7, 2016, EPA finalized a revision to the Cross-State Air Pollution Rule (CSAPR); the revised rule is known as the CSAPR Update Rule. The CSAPR Update Rule 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, near-term responses 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. The Indiana Utility Group and the Indiana Energy Association jointly filed a petition for reconsideration asking that the EPA correct errors it made in calculating the Indiana budget and increase the budget accordingly. EPA has yet to act on the petition. Numerous parties have filed petitions with the D.C. Circuit Court challenging various aspects of the CSAPR Update Rule. Final briefs in the case were due April 9, 2018. Oral argument was heard on October 3, 2018. The Duke Energy Registrants cannot predict the outcome of these matters.

Carbon Pollution Standards for New, Modified and Reconstructed Power Plants

On October 23, 2015, 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. 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. EPA set a final standard of 1,000 pounds of CO2 per gross MWh for new natural gas combined-cycle units.

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. On August 10, 2017, the court ordered that the litigation be suspended indefinitely. The rule remains in effect pending the outcome of litigation and EPA’s review. On July 24, 2018, EPA reported to the court that it plans to send a proposed revised rule to the Office of Management and Budget (OMB) for review. EPA has stated that it expects to release the proposed rule in November. 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 to regulate 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 were filed by numerous 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 the 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 required EPA to file status reports with the court every 30 days. The court has issued subsequent orders, most recently on June 26, 2018, maintaining the case in abeyance. On October 16, 2017, EPA issued a Notice of Proposed Rulemaking (NPRM) to repeal the CPP based on a change to EPA’s legal interpretation of the section of the Clean Air Act on which the CPP was based. The comment period on EPA's NPRM ended April 26, 2018. On December 28, 2017, EPA issued an Advance Notice of Proposed Rulemaking (ANPRM) in which it sought public comment on various aspects of a potential CPP replacement rule. The comment period on the ANPRM ended February 26, 2018. On August 31, 2018, EPA published a proposed rule to replace the CPP, the Affordable Clean Energy (ACE) rule. The proposed ACE rule is based on an “inside the fence” approach under which states develop CO₂ reduction plans based on efficiency (heat rate) improvements at coal-fired power plants. The rule proposes a list of “candidate technologies” from which the states develop unit-specific emission standards. State compliance plans will be due three years after the rule is finalized. The proposal also revises EPA’s New Source Review (NSR) permitting program to remove impediments to the kinds of efficiency improvements the ACE rule would require. The Duke Energy Registrants cannot predict the outcome of these matters.

Section 126 Petitions

On November 16, 2016, the state of Maryland filed a petition with EPA under Section 126 of the Clean Air Act alleging that 19 power plants, including two that Duke Energy Registrants own and operate, contribute to violations of EPA’s National Ambient Air Quality Standards (NAAQS) for ozone in the state of Maryland. On March 12, 2018, the state of New York filed a petition with EPA, also under Section 126 of the Clean Air Act alleging that over 60 power plants, including four that Duke Energy Registrants own and operate, contribute to violations of EPA’s ozone NAAQS in the state of New York. Both Maryland and New York seek EPA orders requiring the states in which the named power plants operate impose more stringent nitrogen oxide (NO_x) emission limitations on the plants. On October 5, 2018, EPA published a final rule denying the Maryland petition. That same day, Maryland appealed EPA's denial of their Section 126 petition. Duke Energy has three units named in the petition. Any other petition to challenge this final rule must be filed within 60 days from EPA's denial. The impact of these petitions could be more stringent requirements for the operation of NO_x emission controls at these plants. 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/A for the year ended December 31, 2017.

135

PART I

North Carolina Legislation

For other information on North Carolina legislation 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/A for the year ended December 31, 2017.

Liquefied Natural Gas Facility

Piedmont Natural Gas plans to build a liquefied natural gas facility in Robeson County, North Carolina. The project is expected to be completed in the summer of 2021 at a cost of $250 million. Construction will begin in the summer of 2019.

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/A for the year ended December 31, 2017.

New Accounting Standards

See Note 1 to the Condensed Consolidated Financial Statements, “Organization and Basis of Presentation,” for a discussion of the impact of new accounting standards.

Off-Balance Sheet Arrangements

During the three and nine months ended September 30, 2018, there were no material changes to Duke Energy’s off-balance sheet arrangements. See Note 12 to the Condensed Consolidated Financial Statements, "Variable Interest Entities," for a discussion of off-balance sheet arrangements regarding ACP. For additional 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/A for the year ended December 31, 2017.

Contractual Obligations

Duke Energy enters into contracts that require payment of cash at certain specified periods, based on certain specified minimum quantities and prices. During the three and nine months ended September 30, 2018, 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/A for the year ended December 31, 2017.

Subsequent Events

See Note 18 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 and nine months ended September 30, 2018, 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/A 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 U.S. Securities and Exchange Commission rules and forms.

Disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Duke Energy Registrants in the reports they file or submit under the Exchange Act 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 September 30, 2018, 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

On August 2, 2018, Duke Energy and Ernst and Young LLP (EY) announced a strategic tax relationship which resulted in approximately 45 tax team employees joining EY as part of an outsourced arrangement for managed tax services. In connection with this new strategic relationship, management will continue to enhance the design and documentation of our internal control processes to ensure suitable controls over financial reporting. During the three months ended September 30, 2018, except as noted above, there were no changes in Duke Energy’s internal control over financial reporting, as defined in Rule 13a-15(f) under the Exchange Act, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

136

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

For information regarding material legal proceedings, including regulatory and environmental matters, see Note 3, "Regulatory Matters," and Note 4, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements.

Methyl tertiary butyl ether (MTBE) Litigation

On June 19, 2014, the Commonwealth of Pennsylvania filed suit against, among others, Duke Energy Merchants, 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 lawsuit was moved to federal court and consolidated into an existing multidistrict litigation docket of pending MTBE cases. This suit was settled for an immaterial amount in December 2017 and dismissed in January 2018.

In December 2017, the state of Maryland filed a lawsuit in Baltimore City Circuit Court against Duke Energy Merchants and other defendants alleging contamination of its water supplies from MTBE. The case was removed to the U.S. District Court in Baltimore. Duke Energy cannot predict the outcome of this matter.

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

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

None.

137

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	Twentieth Supplemental Indenture (incorporated by reference to Exhibit 4.2 to Registrant's Registration Statement on Form 8-A filed on September 17, 2018, File no. 001-32853).	X
*10.1	Amendment No. 1 to the Term Loan Credit Agreement, dated as of September 13, 2018, among Piedmont Natural Gas Company, Inc., the lenders listed therein, U.S. Bank National Association, as Administrative Agent, and PNC Bank, National Association, Bank of New York Mellon and KeyBank, National Association, as Co-Documentation Agents.	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
*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

138

PART II

*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
*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

139

PART II

*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.

140

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:	November 2, 2018	/s/ STEVEN K. YOUNG
		Steven K. Young Executive Vice President and Chief Financial Officer (Principal Financial Officer)
Date:	November 2, 2018	/s/ DWIGHT L. JACOBS
		Dwight L. Jacobs Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)

141

EX-10.1

Exhibit 10.1

AMENDMENT NO. 1 TO THE TERM LOAN CREDIT AGREEMENT, dated as of September 13, 2018 (this “Agreement”), among, PIEDMONT NATURAL GAS COMPANY, INC. (the “Borrower”), the LENDERS party hereto (the “Lenders”), PNC BANK, NATIONAL ASSOCIATION, BANK OF NEW YORK MELLON and KEYBANK, NATIONAL ASSOCIATION as Co-Documentation Agents and U.S. BANK NATIONAL ASSOCIATION, as Administrative Agent.

A.    Reference is made to the Term Loan Credit Agreement dated as of June 14, 2017, (the “Existing Credit Agreement”), among, the Borrower, the Lenders party thereto (the “Existing Lenders”) and U.S. Bank National Association as administrative agent for the Lenders (in such capacity, the “Administrative Agent”).

B.    The Borrower has requested that certain amendments be made to the Existing Credit Agreement, as more fully set forth herein (the “Amendments”).

C.    The Lenders party hereto have agreed to the amendments of the Existing Credit Agreement as set forth herein and as amended hereby (the Existing Credit Agreement as so amended, the “Amended Credit Agreement”).

Accordingly, in consideration of the mutual agreements herein contained in this Agreement and for other good and valuable consideration, the sufficiency and receipt of which are hereby acknowledged, the parties hereto agree as follows:

SECTION 1. Terms Generally. (a) The rules of construction set forth in Article 1 of the Amended Credit Agreement shall apply mutatis mutandis to this Agreement. Capitalized terms used but not defined herein have the meanings assigned thereto in the Amended Credit Agreement.

(b) As used in this Agreement, the following terms have the meanings specified below:

“Amendment Effective Date” shall have the meaning assigned to such term in Section 5.

SECTION 2. Amendments to Existing Credit Agreement. Effective as of the Amendment Effective Date immediately after giving effect to the Assigned Interests in Section 3 of this Agreement, the Existing Credit Agreement is hereby amended to delete the stricken text (indicated textually in the same manner as the following example: stricken text) and to add the bold and double-underlined text (indicated textually in the same manner as the following example: double underlined text) as set forth in the pages of the Amended Credit Agreement attached as Annex A hereto.

SECTION 3. Confirmation of Commitments.(a) Each Lender, by executing this Agreement confirms that on the Amendment Effective Date after giving effect to this Agreement (including this Section 3) the Commitment of such Lender under the Amended Credit Agreement shall be as set forth on such Lender’s executed signature page to this Agreement.

(b) The Borrower agrees to execute and deliver a Note, if required by a Lender, payable to the order of such Lender reflecting the Commitments set forth on the Commitment Schedule to the Amended Credit Agreement pursuant to Sections 2.04(b) and 9.06(c) of the Amended Credit Agreement.

SECTION 4. Representations and Warranties. To induce the other parties hereto to enter into this Agreement, the Borrower party hereto represents and warrants to the Administrative Agent and each of the Lenders that:

(a) The execution, delivery and performance by the Borrower of this Agreement and the Notes are within the Borrower’s powers, have been duly authorized by all necessary company action, require no action by or in respect of, or filing with, any Governmental Authority (except for consents, authorizations or filings which have been obtained or made, as the case may be, and are in full force and effect) and do not contravene, or constitute a default under, any provision of applicable law or regulation or of the articles of incorporation, by laws or certificate of formation of the Borrower or of any material agreement, judgment, injunction, order, decree or other instrument binding upon the Borrower or result in the creation or imposition of any Lien on any asset of the Borrower or any of its Material Subsidiaries.

(b) This Agreement constitutes a valid and binding agreement of the Borrower and each Note, if and when executed and delivered by it in accordance with this Agreement, will constitute a valid and binding obligation of the Borrower, in each case enforceable in accordance with its terms, except as the same may be limited by bankruptcy, insolvency or similar laws affecting creditors’ rights generally and by general principles of equity.

(c) Each of the representations and warranties made by the Borrower in Article 4 of the Amended Credit Agreement is true and correct in all material respects on and as of the date hereof, except to the extent such representations and warranties expressly relate to an earlier date (in which case they shall be true and correct on and as of such earlier date); provided that any representation and warranty that is qualified by materiality or material adverse effect shall be true and correct in all respects on and as of the date hereof, except to the extent such representations and warranties expressly relate to an earlier date (in which case they shall be true and correct on and as of such earlier date).

(d) No Event of Default or Default has occurred and is continuing as of the date hereof.

SECTION 5. Effectiveness. This Agreement shall become effective as of the date (the “Amendment Effective Date”) on which each of the following conditions precedent shall have been satisfied:

(a) The Administrative Agent shall have received duly executed counterparts of this Agreement from the Borrower and the Lenders with Commitments as shown on the Commitment Schedule to the Amended Credit Agreement attached as Annex A hereto consenting to this Agreement.

(b) The Administrative Agent shall have received an opinion of internal counsel of the Borrower covering such additional matters relating to the transactions contemplated hereby as the Administrative Agent may reasonably request;

(c) The Administrative Agent shall have received a certificate signed by a Vice President, the Treasurer, an Assistant Treasurer or the Controller of the Borrower, dated the Amendment Effective Date, to the effect set forth in clauses (c) and (d) of Section 4 above;

(d) The Administrative Agent shall have received all documents it may have reasonably requested prior to the Amendment Effective Date relating to the existence of the

Borrowers, the corporate authority for and the validity of this Agreement, and any other matters relevant hereto, all in form and substance satisfactory to the Administrative Agent;

(e) The Administrative Agent shall have received all Fees and other amounts due and payable on or prior to the Amendment Effective Date, fees and expenses required to be paid or delivered by the Company on the Amendment Effective Date pursuant to that certain fee letter dated as of the date hereof between the Administrative Agent and the Company, and to the extent invoiced, reimbursement or payment of all out of pocket expenses required to be reimbursed or paid by the Company hereunder;

(f) The Administrative Agent shall have received, at least three Domestic Business Days prior to the Amendment Effective Date, all documentation and other information about the Borrowers that shall have been reasonably requested by the Administrative Agent (on behalf of the Additional Lenders (as defined in Exhibit A hereto) in writing at least 10 Domestic Business Days prior to the Amendment Effective Date and that the Administrative Agent reasonably determines is required by United States regulatory authorities under applicable “know your customer” and anti-money laundering rules and regulations, including without limitation the Patriot Act.

SECTION 6. Effect of Amendments. Except as expressly set forth herein, this Agreement shall not by implication or otherwise limit, impair, constitute a waiver of, or otherwise affect the rights and remedies of the Administrative Agent or each of the Lenders under the Existing Credit Agreement and shall not alter, modify, amend or in any way affect any of the terms, conditions, obligations, covenants or agreements contained in the Existing Credit Agreement, all of which are ratified and affirmed in all respects and shall continue in full force and effect. Nothing herein shall be deemed to entitle the Borrower to a consent to, or a waiver, amendment, modification or other change of, any of the terms, conditions, obligations, covenants or agreements contained in the Existing Credit Agreement in similar or different circumstances. This Agreement shall apply and be effective only with respect to the provisions of the Existing Credit Agreement specifically referred to herein.

SECTION 7. Notices. All notices hereunder shall be given in accordance with the provisions of Section 9.01 of the Amended Credit Agreement.

SECTION 8. Counterparts.This Agreement may be executed in counterparts (and by different parties hereto on different counterparts), each of which shall constitute an original but all of which when taken together shall constitute a single contract. Delivery of an executed signature page to this Agreement by facsimile or other means of electronic transmission shall be as effective as delivery of a manually signed counterpart of this Agreement.

SECTION 9. APPLICABLE LAW, SUBMISSION TO JURISDICTION.THIS AGREEMENT SHALL BE CONSTRUED IN ACCORDANCE WITH AND GOVERNED BY THE LAW OF THE STATE OF NEW YORK. THE BORROWER AND EACH LENDER PARTY HEREBY SUBMITS TO THE EXCLUSIVE JURISDICTION OF THE UNITED STATES DISTRICT COURT FOR THE SOUTHERN DISTRICT OF NEW YORK AND OF ANY NEW YORK STATE COURT SITTING IN NEW YORK COUNTY FOR PURPOSES OF ALL LEGAL PROCEEDINGS ARISING OUT OF OR RELATING TO THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED HEREBY. THE BORROWER AND EACH LENDER PARTY IRREVOCABLY WAIVES, TO THE FULLEST EXTENT PERMITTED BY LAW, ANY OBJECTION WHICH IT MAY NOW OR HEREAFTER HAVE TO THE LAYING OF THE VENUE OF ANY SUCH PROCEEDING BROUGHT IN SUCH A COURT AND ANY CLAIM THAT ANY SUCH PROCEEDING BROUGHT IN SUCH A COURT HAS BEEN BROUGHT IN AN INCONVENIENT FORUM.

SECTION 10. WAIVER OF JURY TRIAL.THE BORROWER, THE AGENTS, THE ISSUING LENDERS AND THE LENDERS, TO THE FULLEST EXTENT IT MAY EFFECTIVELY DO SO UNDER APPLICABLE LAW, HEREBY IRREVOCABLY WAIVES ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED HEREBY.

SECTION 11. Headings.The headings used herein are for convenience of reference only, are not part of this Agreement and are not to affect the construction of, or to be taken into consideration in interpreting, this Agreement.

[Remainder of this page intentionally left blank]

IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed by their respective authorized officers as of the date and year first above written.

PIEDMONT NATURAL GAS COMPANY,

INC., as Borrower

/s/ John L. Sullivan, III        

Name: John L. Sullivan, III

Title: Assistant Treasurer

[Signature Page to Amendment No. 1]

U.S. BANK NATIONAL ASSOCIATION, as a

Lender and as Administrative Agent

By: /s/ James O’Shaughnessy        

Name: James O’Shaughnessy

Title: Vice President

Commitment under Amended Credit Agreement:

$ 70,000,000

[Signature Page to Amendment No. 1]

BRANCH BANKING AND TRUST

COMPANY, as a Lender

By: /s/ Stuart M. Jones        

Name: Stuart M. Jones

Title: Senior Vice President

Commitment under Amended Credit Agreement:

$ 70,000,000

[Signature Page to Amendment No. 1]

REGIONS BANK, as a Lender

By: /s/ Brian Walsh        

Name: Brian Walsh

Title: Director

Commitment under Amended Credit Agreement:

$ 70,000,000

[Signature Page to Amendment No. 1]

PNC BANK, NATIONAL ASSOCIATION, as

a Lender

By: /s/ Brittany Manski        

Name: Brittany Manski

Title: Assistant Vice President

Commitment under Amended Credit Agreement:

$ 40,000,000

[Signature Page to Amendment No. 1]

THE BANK OF NEW YORK MELLON, as

a Lender

By: /s/ Richard K. Fronapfel, Jr.        

Name: Richard K. Fronapfel, Jr.

Title: Director

Commitment under Amended Credit Agreement:

$ 50,000,000

[Signature Page to Amendment No. 1]

KEYBANK, NATIONAL ASSOCIATION, as

a Lender

By: /s/ Lisa A. Ryder        

Name: Lisa A. Ryder

Title: Senior Vice President

Commitment under Amended Credit Agreement:

$ 50,000,000

[Signature Page to Amendment No. 1]

ANNEX A

AMENDED CREDIT AGREEMENT

EXECUTION VERSION

$250,000,000350,000,000

TERM LOAN CREDIT AGREEMENT

dated as of

June 14September 13, 20172018

among

Piedmont Natural Gas Company, Inc.,

as Borrower,

The Lenders Listed Herein,

U.S. Bank National Association,

as Administrative Agent,

Branch Banking and Trust Company

and

Regions Bank,

as Co-Syndication Agents

PNC Bank, National Association,

as Documentation Agent

and

BB&T Capital Markets,

Regions Capital Markets, a division of Regions Bank

and

U.S. Bank National Association,

as Joint Lead Arrangers and Bookrunners

TABLE OF CONTENTS

PAGE

ARTICLE 1DEFINITIONS
Section 1.01.	Definitions	1
Section 1.02.	Accounting Terms and Determinations	11
Section 1.03.	Types of Borrowings	12
ARTICLE 2 THE CREDIT
Section 2.01.	Commitments to Lend	12
Section 2.02.	Notice of Borrowings	12
Section 2.03.	Notice to Lenders; Funding of Loans	13
Section 2.04.	Registry; Notes	13
Section 2.05.	Maturity of Loans	14
Section 2.06.	Interest Rates	14
Section 2.07.	Ticking Fee.	15
Section 2.08.	[Reserved].	15
Section 2.09.	Method of Electing Interest Rates	15
Section 2.10.	[Reserved]	16
Section 2.11.	Optional Prepayments	17
Section 2.12.	General Provisions as to Payments	17
Section 2.13.	Funding Losses	17
Section 2.14.	Computation of Interest and Fees	18
Section 2.15.	[Reserved]	18
Section 2.16.	Regulation D Compensation	18
Section 2.17.	[Reserved]	18
Section 2.18.	[Reserved]	18
Section 2.19.	Defaulting Lenders	19
ARTICLE 3 CONDITIONS
Section 3.01.	Effective Date	20
Section 3.02.	[Reserved].	21
Section 3.03.	Borrowings	21
ARTICLE 4 REPRESENTATIONS AND WARRANTIES
Section 4.01.	Organization and Power	21
Section 4.02.	Corporate and Governmental Authorization; No Contravention	21
Section 4.03.	Binding Effect	22
Section 4.04.	Financial Information	22

i

Section 4.05.	Regulation U	22
Section 4.06.	Litigation	23
Section 4.07.	Compliance with Laws	23
Section 4.08.	Taxes	23
Section 4.09.	Anti-corruption Law and Sanctions	23
ARTICLE 5 COVENANTS
Section 5.01.	Information	23
Section 5.02.	Payment of Taxes	25
Section 5.03.	Maintenance of Property; Insurance	25
Section 5.04.	Maintenance of Existence	26
Section 5.05.	Compliance with Laws	26
Section 5.06.	Books and Records	26
Section 5.07.	Negative Pledge	26
Section 5.08.	Consolidations, Mergers and Sales of Assets	28
Section 5.09.	Use of Proceeds	28
Section 5.10.	Indebtedness/Capitalization Ratio	28
ARTICLE 6 DEFAULTS
Section 6.01.	Events of Default	28
Section 6.02.	Notice of Default	30
ARTICLE 7 THE ADMINISTRATIVE AGENT
Section 7.01.	Appointment and Authorization	30
Section 7.02.	Administrative Agent and Affiliates	30
Section 7.03.	Action by Administrative Agent	30
Section 7.04.	Consultation with Experts	31
Section 7.05.	Liability of Administrative Agent	31
Section 7.06.	Indemnification	31
Section 7.07.	Credit Decision	31
Section 7.08.	Successor Administrative Agent	31
Section 7.09.	Administrative Agent’s Fee	32
ARTICLE 8 CHANGE IN CIRCUMSTANCES
Section 8.01.	Basis for Determining Interest Rate Inadequate or Unfair	32
Section 8.02.	Illegality	33
Section 8.03.	Increased Cost and Reduced Return	33
Section 8.04.	Taxes	34
Section 8.05.	Base Rate Loans Substituted for Affected Euro-Dollar Loans	37

ii

Section 8.06.	Substitution of Lender; Termination Option	38
ARTICLE 9 MISCELLANEOUS
Section 9.01.	Notices	38
Section 9.02.	No Waivers	39
Section 9.03.	Expenses; Indemnification	39
Section 9.04.	Sharing of Set-offs	40
Section 9.05.	Amendments and Waivers	40
Section 9.06.	Successors and Assigns	41
Section 9.07.	Collateral	43
Section 9.08.	Confidentiality	43
Section 9.09.	Governing Law; Submission to Jurisdiction	44
Section 9.10.	Counterparts; Integration	44
Section 9.11.	WAIVER OF JURY TRIAL	44
Section 9.12.	USA Patriot Act	44
Section 9.13.	[Reserved]	44
Section 9.14.	No Fiduciary Duty	44
Section 9.15.	Survival	45
Section 9.16.	Acknowledgment and Consent to Bail-In of EEA Financial
	Institutions	45

COMMITMENT SCHEDULE

EXHIBIT A -    Note

EXHIBIT B -    [Reserved]

EXHIBIT C -    [Reserved]

EXHIBIT D -    Assignment and Assumption Agreement

iii

TERM LOAN CREDIT AGREEMENT

TERM LOAN CREDIT AGREEMENT dated as of June 14, 2017, as amended by Amendment No. 1 dated as of September 13, 2018 (“Amendment No. 1”), among PIEDMONT NATURAL GAS COMPANY, INC., a North Carolina corporation, as Borrower, the Lenders from time to time party hereto and U.S. BANK NATIONAL ASSOCIATION, as Administrative Agent.

The parties hereto agree as follows:

ARTICLE 1Definitions

Section 1.01,Definitions. The following terms, as used herein, have the following meanings:

“Additional Lender” means each Lender party to this Agreement on and after the Amendment Effective Date that was not party to this Agreement prior to the Amendment Effective Date.

“Administrative Agent” means U.S. Bank National Association in its capacity as administrative agent for the Lenders hereunder, and its successors in such capacity.

“Administrative Questionnaire” means, with respect to each Lender, the administrative questionnaire in the form submitted to such Lender by the Administrative Agent and submitted to the Administrative Agent (with a copy to the Borrower) duly completed by such Lender.

“Affiliate” means, as to any Person (the “specified Person”) (i) any Person that directly, or indirectly through one or more intermediaries, controls the specified Person (a “Controlling Person”) or (ii) any Person (other than the specified Person or a Subsidiary of the specified Person) which is controlled by or is under common control with a Controlling Person. As used herein, the term “control” means possession, directly or indirectly, of the power to direct or cause the direction of the management or policies of a Person, whether through the ownership of voting securities, by contract or otherwise.

“Agreement”means this Term Loan Credit Agreement as the same may be amended from time to time.

“Amendment Effective Date” has the meaning set forth in Amendment No. 1.

“Amendment No. 1” has the meaning set forth in the preamble to this Agreement.

“Anti-Corruption Laws” means the United States Foreign Corrupt Practices Act of 1977 and all other laws, rules, and regulations of any jurisdiction concerning or relating to bribery, corruption or money laundering.

“Applicable Lending Office” means, with respect to any Lender, (i) in the case of its Base Rate Loans, its Domestic Lending Office and (ii) in the case of its Euro-Dollar Loans, its Euro‑Dollar Lending Office.

“Applicable Margin” means, with respect to Euro-Dollar Loans to the Borrower, 0.750.70% per annum.

“Approved Fund” means any Fund that is administered or managed by (i) a Lender, (ii) an Affiliate of a Lender or (iii) an entity or an Affiliate of an entity that administers or manages a Lender.

“Approved Officer” means the president, the chief financial officer, a vice president, the treasurer, an assistant treasurer or the controller of the Borrower or such other representative of the Borrower as may be designated by any one of the foregoing with the consent of the Administrative Agent.

“Assignee” has the meaning set forth in ‎Section 9.06(c).

“Bail-In Action” means the exercise of any Write-Down and Conversion Powers by the applicable EEA Resolution Authority in respect of any liability of an EEA Financial Institution.

“Bail-In Legislation” means, with respect to any EEA Member Country implementing Article 55 of Directive 2014/59/EU of the European Parliament and of the Council of the European Union, the implementing law for such EEA Member Country from time to time which is described in the EU Bail-In Legislation Schedule.

“Bankruptcy Event” means, with respect to any Person, such Person becomes the subject of a bankruptcy or insolvency proceeding (or any similar proceeding), or generally fails to pay its debts as such debts become due, or admits in writing its inability to pay its debts generally, or has had a receiver, conservator, trustee, administrator, custodian, assignee for the benefit of creditors or similar Person charged with the reorganization or liquidation of its business or assets appointed for it, or, in the good faith determination of the Administrative Agent (or, if the Administrative Agent is the subject of the Bankruptcy Event, the Required Lenders), has taken any action in furtherance of, or indicating its consent to, approval of, or acquiescence in, any such proceeding or appointment, provided that (except with respect to a Lender that is subject to a Bail-In Action) a Bankruptcy Event shall not result solely by virtue of any ownership interest, or the acquisition of any ownership interest, in such Person by a Governmental Authority or instrumentality thereof so long as such ownership interest does not result in or provide such Person with immunity from the jurisdiction of courts within the United States or from the enforcement of judgments or writs of attachment on its assets or permit such Person (or such Governmental Authority or instrumentality) to reject, repudiate, disavow or disaffirm any contracts or agreements made by such Person.

“Base Rate” means, for any day for which the same is to be calculated, the highest of (a) the Prime Rate, (b) the Federal Funds Rate plus 1/2 of 1% and (c) the LIBOR Market Index Rate plus 1%; provided, that, if the Base Rate shall be less than zero, such rate shall be deemed to be zero for purposes of this Agreement. Each change in the Base Rate shall take effect simultaneously with the corresponding change in the rates described in clauses (a), (b) or (c) above, as the case may be.

“Base Rate Loan” means (i) a Loan which bears interest at the Base Rate pursuant to the applicable Notice of Borrowing or Notice of Interest Rate Election or the provisions of ‎Article 8 or (ii) an overdue amount which was a Base Rate Loan immediately before it became overdue.

“Borrower” means Piedmont Natural Gas Company, Inc., a North Carolina Corporation.

“Borrowing” means a borrowing made on a single date and for a single Interest Period.

“Change” has the meaning set forth in Section 9.05(b).

2

“Change in Law” means the occurrence of any of the following after the date of this Agreement: (a) the adoption or taking effect of any law, rule, regulation or treaty, (b) any change in any law, rule, regulation or treaty or in the administration, interpretation or application thereof by any Governmental Authority, or (c) the making or issuance of any request, rules, guideline, requirement or directive (whether or not having the force of law) by any Governmental Authority; provided however, that notwithstanding anything herein to the contrary, (i) the Dodd-Frank Wall Street Reform and Consumer Protection Act and all requests, rules, guidelines, requirements and directives thereunder, issued in connection therewith or in implementation thereof, and (ii) all requests, rules, guidelines, requirements and directives promulgated by the Bank for International Settlements, the Basel Committee on Banking Supervision (or any successor or similar authority) or the United States or foreign regulatory authorities, in each case pursuant to Basel III, shall in each case be deemed to be a “Change in Law” after the date hereof regardless of the date enacted, adopted, issued or implemented.

“Commitment” means (i) with respect to any Lender listed on the signature pages hereof, the amount set forth opposite its name on the Commitment Schedule, and (ii) with respect to each Assignee which becomes a Lender pursuant to Sections ‎8.06 or ‎9.06(c), the amount of the Commitment thereby assumed by it, in each case as such amount may from time to time be reduced pursuant to Sections ‎8.06 or ‎9.06(c) or increased pursuant to Sections ‎8.06 or ‎9.06(c).

“Commitment Schedule” means the Commitment Schedule attached hereto.

“Commitment Termination Date” means the date that is 90 days after the Effective Date.

“Connection Income Taxes” means, with respect to any Lender or Agent, taxes that are imposed on or measured by net income (however denominated), franchise taxes or branch profits taxes, in each case, imposed as a result of a connection (including any former connection) between such Lender or Agent and the jurisdiction imposing such tax (other than connections arising from such Lender or Agent having executed, delivered, become a party to, performed its obligations under, received payments under, received or perfected a security interest under, engaged in any other transaction pursuant to or enforced this Agreement or any Note, or sold or assigned an interest in any Loan, this Agreement or any Note).

“Consolidated Capitalization” means, with respect to the Borrower, the sum, without duplication, of (i) Consolidated Indebtedness of the Borrower, (ii) consolidated common equityholdersequity holders’ equity as would appear on a consolidated balance sheet of the Borrower and its Consolidated Subsidiaries prepared in accordance with generally accepted accounting principles, (iii) the aggregate liquidation preference of preferred or priority equity interests (other than preferred or priority equity interests subject to mandatory redemption or repurchase) of the Borrower and its Consolidated Subsidiaries upon involuntary liquidation, (iv) the aggregate outstanding amount of all Equity Preferred Securities of the Borrower and (v) minority interests as would appear on a consolidated balance sheet of the Borrower and its Consolidated Subsidiaries prepared in accordance with generally accepted accounting principles.

“Consolidated Indebtedness” means, at any date, with respect to the Borrower, all Indebtedness of the Borrower and its Consolidated Subsidiaries determined on a consolidated basis in accordance with generally accepted accounting principles; provided that Consolidated Indebtedness shall exclude, to the extent otherwise reflected therein, Equity Preferred Securities of the Borrower and

3

its Consolidated Subsidiaries up to a maximum excluded amount equal to 15% of Consolidated Capitalization of the Borrower.

“Consolidated Net Assets” means, at any date with respect to the Borrower, (a) total assets of the Borrower and its Subsidiaries (minus applicable reserves) determined on a consolidated basis in accordance with GAAP minus (b) total liabilities of the Borrower and its Subsidiaries, in each case determined on a consolidated basis in accordance with GAAP, all as reflected in the consolidated financial statements of the Borrower most recently delivered to the Administrative Agent and the Lenders pursuant to ‎Section 5.01(a) or ‎5.01(b).

“Consolidated Subsidiary” means, for any Person, at any date any Subsidiary or other entity the accounts of which would be consolidated with those of such Person in its consolidated financial statements if such statements were prepared as of such date.

“Default” means any condition or event which constitutes an Event of Default or which with the giving of notice or lapse of time or both would, unless cured or waived, become an Event of Default.

“Defaulting Lender” means any Lender that (a) has failed to (i) fund any portion of its Loans within two Domestic Business Days of the date required to be funded or (ii) pay over to any Lender Party any other amount required to be paid by it hereunder within two Domestic Business Days of the date required to be paid, unless, in the case of clause (i) or (ii) above, such Lender notifies the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) in writing that such failure is the result of such Lender’s good faith determination that a condition precedent to funding (specifically identified and including the particular default, if any) has not been satisfied, (b) has notified the Borrower or the Administrative Agent in writing, or has made a public statement to the effect, that it does not intend or expect to comply with any of its funding obligations under this Agreement (unless such writing or public statement indicates that such position is based on such Lender’s good faith determination that a condition precedent (specifically identified and including the particular default, if any) to funding under this Agreement cannot be satisfied) or generally under other agreements in which it commits to extend credit, (c) has failed, within three Domestic Business Days after written request by the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) or the Borrower, acting in good faith, to provide a certification in writing from an authorized officer of such Lender that it will comply with its obligations to fund prospective Loans under this Agreement unless such Lender notifies the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) in writing that such failure is the result of such Lender’s good faith determination that one or more conditions precedent to funding (specifically identified and including the particular default, if any) has not been satisfied, provided that such Lender shall cease to be a Defaulting Lender pursuant to this clause (c) upon receipt by the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) and the Borrower of such certification in form and substance satisfactory to the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) and the Borrower, or (d) has become (or has a direct or indirect Parent that has become) the subject of a Bankruptcy Event or a Bail-In Action. Any determination by the Administrative Agent (or, if the Administrative Agent is the Defaulting Lender, the Required Lenders) that a Lender is a Defaulting Lender shall be conclusive and binding absent manifest error, and such Lender shall be deemed to be a Defaulting Lender upon delivery of written notice of such determination to the Borrower and each Lender.

4

“Domestic Business Day” means any day except a Saturday, Sunday or other day on which commercial banks in New York City or in the State of North Carolina are authorized by law to close.

“Domestic Lending Office” means, as to each Lender, its office located at its address set forth in its Administrative Questionnaire (or identified in its Administrative Questionnaire as its Domestic Lending Office) or such other office as such Lender may hereafter designate as its Domestic Lending Office by notice to the Borrower and the Administrative Agent.

“EEA Financial Institution” means (a) any credit institution or investment firm established in any EEA Member Country which is subject to the supervision of an EEA Resolution Authority, (b) any entity established in an EEA Member Country which is a parent of an institution described in clause (a) of this definition, or (c) any financial institution established in an EEA Member Country which is a subsidiary of an institution described in clauses (a) or (b) of this definition and is subject to consolidated supervision with its parent.

“EEA Member Country” means any of the member states of the European Union, Iceland, Liechtenstein, and Norway.

“EEA Resolution Authority” means any public administrative authority or any person entrusted with public administrative authority of any EEA Member Country (including any delegee) having responsibility for the resolution of any EEA Financial Institution.

“Effective Date” means the date on which all the conditions precedent in ‎Section 3.01 are satisfied or waived in accordance Section 9.05.

“Environmental Laws” means any and all federal, state, local and foreign statutes, laws, regulations, ordinances, rules, judgments, orders, decrees, permits, concessions, grants, franchises, licenses, agreements or other governmental restrictions relating to the environment or to emissions, discharges, releases of pollutants, contaminants, chemicals, or industrial, toxic or hazardous substances or wastes into the environment including, without limitation, ambient air, surface water, ground water, or land, or otherwise relating to the manufacture, processing, distribution, use, treatment, storage, disposal, transport, or handling of pollutants, contaminants, chemicals, or industrial, toxic or hazardous substances or wastes.

“Equity Preferred Securities” means, with respect to the Borrower, any trust preferred securities or deferrable interest subordinated debt securities issued by the Borrower or any Subsidiary or other financing vehicle of the Borrower that (i) have an original maturity of at least twenty years and (ii) require no repayments or prepayments and no mandatory redemptions or repurchases, in each case, prior to the first anniversary of the Maturity Date.

“ERISA” means the Employee Retirement Income Security Act of 1974, as amended.

“ERISA Group” means, with respect to the Borrower, the Borrower and all other members of a controlled group of corporations and all trades or businesses (whether or not incorporated) under common control which, together with the Borrower, are treated as a single employer under Section 414 of the Internal Revenue Code.

“EU Bail-In Legislation Schedule” means the EU Bail-In Legislation Schedule published by the Loan Market Association (or any successor person), as in effect from time to time.

5

“Euro-Dollar Business Day” means any Domestic Business Day on which commercial banks are open for international business (including dealings in dollar deposits) in London.

“Euro‑Dollar Lending Office” means, as to each Lender, its office, branch or affiliate located at its address set forth in its Administrative Questionnaire (or identified in its Administrative Questionnaire as its Euro‑Dollar Lending Office) or such other office, branch or affiliate of such Lender as it may hereafter designate as its Euro‑Dollar Lending Office by notice to the Borrower and the Administrative Agent.

“Euro‑Dollar Loan” means (i) a Loan which bears interest at a Euro-Dollar Rate pursuant to the applicable Notice of Borrowing or Notice of Interest Rate Election or (ii) an overdue amount which was a Euro-Dollar Loan immediately before it became overdue.

“Euro-Dollar Rate” means a rate of interest determined pursuant to ‎Section 2.06(b) on the basis of a London Interbank Offered Rateand if the Euro-Dollar Rate shall be less than zero, such rate shall be deemed zero for purposes of this Agreement.

“Euro‑Dollar Reserve Percentage” has the meaning set forth in ‎Section 2.16.

“Event of Default” has the meaning set forth in ‎Section 6.01.

“FATCA” has the meaning set forth in ‎Section 8.04(a).

“Federal Funds Rate” means, for any day, the rate per annum (rounded upwards, if necessary, to the nearest 1/100th of 1%) equal to the weighted average of the rates on overnight Federal funds transactions with members of the Federal Reserve System, as published by the Federal Reserve Bank of New York on the Domestic Business Day next succeeding such day; provided that (i) if such day is not a Domestic Business Day, the Federal Funds Rate for such day shall be such rate on such transactions on the next preceding Domestic Business Day as so published on the next succeeding Domestic Business Day and (ii) if no such rate is so published on such next succeeding Domestic Business Day, the Federal Funds Rate for such day shall be the average rate quoted to U.S. Bank National Association on such day on such transactions as determined by the Administrative Agent; provided further, that, if the Federal Funds Rate shall be less than zero, such rate shall be deemed to be zero for purposes of this Agreement.

“Fund” means any Person (other than a natural Person) that is (or will be) engaged in making, purchasing, holding or otherwise investing in commercial loans and similar extensions of credit in the ordinary course of its business.

“Funding Date” means each of (a) the Effective Date and (b) the Second Funding Date.

“Governmental Authority” means any international, foreign, federal, state, regional, county, local or other governmental or quasi-governmental authority.

“Group of Loans” means at any time a group of Loans consisting of (i) all Loans to the Borrower which are Base Rate Loans at such time or (ii) all Euro-Dollar Loans to the Borrower having the same Interest Period at such time; provided that, if a Loan of any particular Lender is converted to or made as a Base Rate Loan pursuant to ‎Article 8, such Loan shall be included in the same Group or Groups of Loans from time to time as it would have been if it had not been so converted or made.

6

“Hedging Agreement” means for any Person, any and all agreements, devices or arrangements designed to protect such Person or any of its Subsidiaries from the fluctuations of interest rates, exchange rates applicable to such party’s assets, liabilities or exchange transactions, including, but not limited to, dollar-denominated or cross-currency interest rate exchange agreements, forward currency exchange agreements, interest rate cap or collar protection agreements, commodity swap agreements, forward rate currency or interest rate options, puts and warrants. Notwithstanding anything herein to the contrary, “Hedging Agreements” shall also include fixed-for-floating interest rate swap agreements and similar instruments.

“Indebtedness” of any Person means at any date, without duplication, (i) all obligations of such Person for borrowed money, (ii) all indebtedness of such Person for the deferred purchase price of property or services purchased (excluding current accounts payable incurred in the ordinary course of business), (iii) all indebtedness created or arising under any conditional sale or other title retention agreement with respect to property acquired, (iv) all indebtedness under leases which shall have been or should be, in accordance with generally accepted accounting principles, recorded as capital leases in respect of which such Person is liable as lessee, (v) the face amount of all outstanding letters of credit issued for the account of such Person (other than letters of credit relating to indebtedness included in Indebtedness of such Person pursuant to another clause of this definition) and, without duplication, the unreimbursed amount of all drafts drawn thereunder, (vi) indebtedness secured by any Lien on property or assets of such Person, whether or not assumed (but in any event not exceeding the fair market value of the property or asset), (vii) all direct guarantees of Indebtedness referred to above of another Person, (viii) all amounts payable in connection with mandatory redemptions or repurchases of preferred stock or member interests or other preferred or priority equity interests and (ix) any obligations of such Person (in the nature of principal or interest) in respect of acceptances or similar obligations issued or created for the account of such Person.

“Indemnitee” has the meaning set forth in ‎Section 9.03.

“Interest Period” means, with respect to each Euro-Dollar Loan, the period commencing on the date of borrowing specified in the applicable Notice of Borrowing or on the date specified in an applicable Notice of Interest Rate Election and ending one, two, three or six, or, if deposits of a corresponding maturity are generally available in the London interbank market, twelve, months thereafter, as the Borrower may elect in such notice; provided that:

(a)    any Interest Period which would otherwise end on a day which is not a Euro‑Dollar Business Day shall be extended to the next succeeding Euro‑Dollar Business Day unless such Euro‑Dollar Business Day falls in another calendar month, in which case such Interest Period shall end on the next preceding Euro‑Dollar Business Day; and

(b)    any Interest Period which begins on the last Euro‑Dollar Business Day of a calendar month (or on a day for which there is no numerically corresponding day in the calendar month at the end of such Interest Period) shall end on the last Euro‑Dollar Business Day of a calendar month;

providedfurther that no Interest Period applicable to any Loan of any Lender may end after the Maturity Date.

“Internal Revenue Code” means the Internal Revenue Code of 1986, as amended, or any successor statute.

7

“Investment Grade Status” exists as to any Person at any date if all senior long-term unsecured debt securities of such Person outstanding at such date which has been rated by S&P or Moody’s are rated BBB‑ or higher by S&P or Baa3 or higher by Moody’s, as the case may be, or if such Person does not have a rating of its long-term unsecured debt securities, then if the corporate credit rating of such Person, if any exists, from S&P is BBB- or higher or the issuer rating of such Person, if any exists, from Moody’s is Baa3 or higher.

“Irregular Interest Period” means any Interest Period with a duration other than one, two, three, six or twelve months.

“Lender” means each bank or other financial institution listed on the signature pages hereof, each Assignee which becomes a Lender pursuant to ‎Section 8.06 or ‎Section 9.06(c), and their respective successors.

“Lender Party” means any of the Lenders and the Administrative Agent.

“LIBOR Market Index Rate” means, for any day, the rate for one month U.S. dollar deposits as appears on the display designated as Reuters Screen LIBOR01 Page (or on any successor or substitute page of such service or any successor to or, if such service is not available, substitute for such service providing rate quotations comparable to those currently provided on such page of such service, as reasonably determined by the Administrative Agent from time to time for purposes of providing quotations of interest rates applicable to U.S. dollar deposits are offered to leading banks in the London interbank deposit market), approximately 11:00 a.m. London time, for such day; or if such day is not a Euro-Dollar Business Day, for the immediately preceding Euro-Dollar Business Day (or if not so reported, then as determined by the Administrative Agent from another recognized source or interbank quotation.)

“Lien” means, with respect to any asset, any mortgage, lien, pledge, charge, security interest or encumbrance of any kind in respect of such asset. For the purposes of this Agreement, the Borrower or any of its Subsidiaries shall be deemed to own subject to a Lien any asset which it has acquired or holds subject to the interest of a vendor or lessor under any conditional sale agreement, capital lease or other title retention agreement relating to such asset.

“Loan” means a loan made or to be made by a Lender pursuant to Section 2.01; provided that, if any such loan or loans (or portions thereof) are combined or subdivided pursuant to a Notice of Interest Rate Election, the term “Loan” shall refer to the combined principal amount resulting from such combination or to each of the separate principal amounts resulting from such subdivision, as the case may be.

“London Interbank Offered Rate” has the meaning set forth in ‎Section 2.06(b).

“Master Credit Facility” means the Credit Agreement dated as of November 18, 2011, as amended by Amendment No. 1 and Consent dated as of December 18, 2013, Amendment No. 2 and Consent, dated as of January 30, 2015 and Amendment No. 3 and Consent dated as of March 16, 2017, among the Borrower, the other borrowers thereto, the lenders party thereto, Wells Fargo Bank, National Association, as administrative agent, and the other agents party thereto, as the same may be amended, amended and restated, modified, supplemented, refinanced or replaced from time to time after the date hereof.

8

“Material Debt” means, with respect to the Borrower, Indebtedness of the Borrower or any of its Material Subsidiaries (other than any Non-Recourse Indebtedness) in an aggregate principal amount exceeding $150,000,000.

“Material Plan” has the meaning set forth in ‎Section 6.01(i).

“Material Subsidiary” means at any time, with respect to the Borrower, any Subsidiary of the Borrower whose total assets exceeds 15% of the total assets (after intercompany eliminations) of the Borrower and its Subsidiaries, determined on a consolidated basis in accordance with GAAP, all as reflected in the consolidated financial statements of the Borrower most recently delivered to the Administrative Agent and the Lenders pursuant to ‎Section 5.01(a) or ‎5.01(b).

“Maturity Date” means December 14, 2018September 12, 2019 or, if such day is not a Domestic Business Day, the immediately preceding Domestic Business Day.

“Moody’s” means Moody’s Investors Service, Inc.

“Non-Consenting Lender” means any Lender that does not approve any consent, waiver or amendment that (i) requires the approval of all affected Lenders in accordance with the terms of ‎Section 9.05(a) and (ii) has been approved by the Required Lenders.

“Non-Recourse Indebtedness” means any Indebtedness incurred by a Subsidiary of the Borrower to develop, construct, own, improve or operate a defined facility or project  (a) as to which the Borrower (i) does not provide credit support of any kind (including any undertaking, agreement or instrument that would constitute Indebtedness but excluding tax sharing arrangements and similar arrangements to make contributions to such Subsidiary to account for tax benefits generated by such Subsidiary), (ii) is not directly or indirectly liable as a guarantor or otherwise, or (iii) does not constitute the lender; (b) no default with respect to which would permit upon notice, lapse of time or both any holder of any other Indebtedness (other than the Loans or the Notes) of the Borrower to declare a default on such other Indebtedness or cause the payment thereof to be accelerated or payable prior to its stated maturity; and (c) as to which the lenders will not have any recourse to the stock or assets of the Borrower or other Subsidiary (other than the stock of or intercompany loans to such Subsidiary); provided that in each case in clauses (a) and (c) above, the Borrower or other Subsidiary may provide credit support and recourse in an amount not exceeding 15% in the aggregate of any such Indebtedness and such Indebtedness shall still be deemed to be Non-Recourse Indebtedness.

“Notes” means promissory notes of the Borrower, in the form required by ‎Section 2.04, evidencing the obligation of the Borrower to repay the Loans made to it, and “Note” means any one of such promissory notes issued hereunder.

“Notice of Borrowing” has the meaning set forth in ‎Section 2.02.

“Notice of Interest Rate Election” has the meaning set forth in ‎Section 2.09(b).

“OFAC” means the Office of Foreign Assets Control of the United States Department of the Treasury.

“Other Taxes” has the meaning set forth in ‎Section 8.04(a).

“Parent” means, with respect to any Lender, any Person controlling such Lender.

9

“Participant” has the meaning set forth in ‎Section 9.06(b).

“Participant Register” has the meaning set forth in ‎Section 9.06(b).

“PBGC” means the Pension Benefit Guaranty Corporation or any entity succeeding to any or all of its functions under ERISA.

“Percentage” means, with respect to any Lender at any time, the percentage which the amount of its Commitment at such time represents of the aggregate amount of all the Commitments at such time; provided that in the case of ‎Section 2.19 when a Defaulting Lender shall exist, “Percentage” shall mean the percentage of the total Commitments (disregarding any Defaulting Lender’s Commitment) represented by such Lender’s Commitment.

“Person” means an individual, a corporation, a partnership, an association, a trust or any other entity or organization, including a government or political subdivision or an agency or instrumentality thereof.

“Plan” means at any time an employee pension benefit plan which is covered by Title IV of ERISA or Sections 412 or 430 of the Internal Revenue Code or Sections 302 and 303 of ERISA and is either (i) maintained by a member of the ERISA Group for employees of a member of the ERISA Group or (ii) maintained pursuant to a collective bargaining agreement or any other arrangement under which more than one employer makes contributions and to which a member of the ERISA Group is then making or accruing an obligation to make contributions or has within the preceding five plan years made contributions.

“Prime Rate” means the per annum rate of interest established from time to time by the Administrative Agent at its principal office in New York, New York as its Prime Rate. Any change in the interest rate resulting from a change in the Prime Rate shall become effective as of 12:01 a.m. of the Domestic Business Day on which each change in the Prime Rate is announced by the Administrative Agent. The Prime Rate is a reference rate used by the Administrative Agent in determining interest rates on certain loans and is not intended to be the lowest rate of interest charged on any extension of credit to any debtor.

“Quarterly Payment Date” means the first Domestic Business Day of each January, April, July and October.

“Regulation U” means Regulation U of the Board of Governors of the Federal Reserve System, as in effect from time to time.

“Related Parties” means, with respect to any Person, such Person’s Subsidiaries and Affiliates and the partners, directors, officers, employees, agents, trustees, administrators and managers of such Person and of such Person’s Subsidiaries and Affiliates.

“Required Lenders” means, at any time, two or more Lenders having at least 51% in aggregate amount of the sum of the unfunded Commitments and the outstanding Loans (excluding the Commitment(s) and the Loan(s) of any Defaulting Lender(s)).

“Sanctioned Person” means, at any time (a) any Person listed in any Sanctions-related list of specially designated Persons maintained by OFAC, the U.S. Department of State, United Nations Security Council, the European Union or Her Majesty’s Treasury of the United Kingdom, (b) any

10

Person that has a place of business, or is organized or resident, in a jurisdiction that is the subject of any comprehensive territorial Sanctions or (c) any Person owned or controlled by any such Person.

“Sanctions” means economic or financial sanctions or trade embargoes imposed, administered or enforced from time to time by (a) OFAC or the U.S. Department of State, or (b) the United Nations Security Council, the European Union or Her Majesty’s Treasury of the United Kingdom.

“Second Funding Date” means the first date (if any) after the Effective Date on which all the conditions precedent in Section 3.03 are satisfied or waived in accordance with Section 9.05 and the Loans are made to the Borrower pursuant to Section 2.01.

“S&P” means Standard & Poor’s Financial Services LLC, a subsidiary of S&P Global Inc., and any successor thereto.

“Subsidiary” means, as to any Person, any corporation or other entity of which securities or other ownership interests having ordinary voting power to elect a majority of the board of directors or other persons performing similar functions are at the time directly or indirectly owned by such Person; unless otherwise specified, “Subsidiary” means a Subsidiary of the Borrower.

“Substantial Assets” means, with respect to the Borrower, assets sold or otherwise disposed of in a single transaction or a series of related transactions representing 25% or more of the consolidated assets of the Borrower and its Consolidated Subsidiaries, taken as a whole.

“Taxes” has the meaning set forth in ‎Section 8.04(a).

“Ticking Fee” has the meaning set forth in Section 2.07.

“Ticking Fee End Date” has the meaning set forth in Section 2.07.

“Unfunded Vested Liabilities” means, with respect to any Plan at any time, the amount (if any) by which (i) the present value of all benefits under such Plan, determined on a plan termination basis using the assumptions under 4001(a)(18) of ERISA, exceeds (ii) the fair market value of all Plan assets allocable to such benefits, all determined as of the then most recent valuation date for such Plan, but only to the extent that such excess represents a potential liability of a member of the ERISA Group to the PBGC or the Plan under Title IV of ERISA.

“United States” means the United States of America, including the States and the District of Columbia, but excluding its territories and possessions.

“U.S. Tax Compliance Certificate” has the meaning set forth in Section 8.04(d)(iii).

“U.S. Tax Law Change” has the meaning set forth in ‎Section 8.04(a).

“Write-Down and Conversion Powers” means, with respect to any EEA Resolution Authority, the write-down and conversion powers of such EEA Resolution Authority from time to time under the Bail-In Legislation for the applicable EEA Member Country, which write-down and conversion powers are described in the EU Bail-In Legislation Schedule.

Section 1.02.    Accounting Terms and Determinations. Unless otherwise specified herein, all accounting terms used herein shall be interpreted, all accounting determinations

11

hereunder shall be made, and all financial statements required to be delivered hereunder shall be prepared in accordance with generally accepted accounting principles as in effect from time to time, applied on a basis consistent (except for changes concurred in by the Borrower’s independent public accountants) with the most recent audited consolidated financial statements of the Borrower and its Consolidated Subsidiaries delivered to the Lenders; provided, that if the Borrower notifies the Administrative Agent that it wishes to amend the financial covenant in ‎Section 5.10 to eliminate the effect of any change in generally accepted accounting principles on the operation of such covenant (or if the Administrative Agent notifies the Borrower that the Required Lenders wish to amend ‎Section 5.10 for such purpose), then the Borrower’s compliance with such covenant shall be determined on the basis of generally accepted accounting principles as in effect immediately before the relevant change in generally accepted accounting principles became effective, until either such notice is withdrawn or such covenant is amended in a manner satisfactory to the Borrower and the Required Lenders.

Section 1.03.    Types of Borrowings. Borrowings are classified for purposes of this Agreement by reference to the pricing of Loans comprising such Borrowing (e.g., a “Euro-Dollar Borrowing” is a Borrowing comprised of Euro Dollar Loans).

ARTICLE 2The Credit

Section 2.01.    Commitments to Lend. Each Lender severally agrees, on the terms and conditions set forth in this Agreement, to make Loans to the Borrower on the Effective Date and on the Second Funding Date pursuant to this subsection in an amount not to exceed in the aggregate such Lender’s Commitment in effect on the date of such Borrowing. Each Additional Lender severally agrees, on the terms and conditions set forth in this Agreement, to make Loans to the Borrower on the Amendment Effective Date pursuant to this subsection in an amount not to exceed in the aggregate such Lender’s Commitment. Each Borrowing shall be made from the several Lenders ratably in proportion to their respective Commitments in effect on the date of such Borrowing. Amounts borrowed under this ‎Section 2.01 and repaid or prepaid may not be reborrowed. Each Lender’s Commitment shall be permanently reduced by the amount of the Loans funded by such Lender on the date of such Borrowing. Each Lender’s (other than any Additional Lender’s) Commitment shall terminate immediately and without further action upon the earliest of (x) the Effective Date after giving effect to the funding of such Lender’s Loans on such date (and solely to the extent the entire aggregate principal amount of such Lender’s Commitment is funded on such date), (y) the Second Funding Date after giving effect to the funding of such Lender’s Loans on such date and (z) the Commitment Termination Date.

Section 2.02.    Notice of Borrowings. The Borrower shall give the Administrative Agent notice (a “Notice of Borrowing”) not later than 11:00 A.M. (Eastern time) on (x) the date of each Base Rate Borrowing and (y) the third Euro‑Dollar Business Day before each Euro‑Dollar Borrowing, specifying:

(a)    the date of the Borrowing, which shall be a Domestic Business Day in the case of a Base Rate Borrowing or a Euro‑Dollar Business Day in the case of a Euro‑Dollar Borrowing;

(b)    the aggregate amount of the Borrowing which shall not exceed the aggregate amount of the Commitments on the date of the Borrowing specified;

12

(c)    whether the Loans comprising the Borrowing are to bear interest initially at the Base Rate or a Euro-Dollar Rate; and

(d)    in the case of a Euro-Dollar Borrowing, the duration of the initial Interest Period applicable thereto, subject to the provisions of the definition of Interest Period.

Section 2.03.    Notice to Lenders; Funding of Loans. (a) Upon receipt (or deemed receipt) of a Notice of Borrowing, the Administrative Agent shall promptly notify each Lender of the contents thereof and of such Lender’s share (if any) of a Borrowing and such Notice of Borrowing shall not thereafter be revocable by the Borrower.

(b)    Not later than 1:00 P.M. (Eastern time) on the date of a Borrowing, each Lender participating therein shall (except as provided in subsection ‎(c) of this Section) make available its share of the Borrowing, in Federal or other immediately available funds, to the Administrative Agent at its address specified in or pursuant to ‎Section 9.01. Unless the Administrative Agent determines that any applicable condition specified in Section 3.03 has not been satisfied, the Administrative Agent will disburse the funds so received from the Lenders to an account designated by an Approved Officer of the Borrower.

(c)    Unless the Administrative Agent shall have received notice from a Lender prior to 1:00 P.M. (Eastern time) on the date of a Borrowing that such Lender will not make available to the Administrative Agent such Lender’s share of the Borrowing, the Administrative Agent may assume that such Lender has made such share available to the Administrative Agent on the date of such Borrowing in accordance with subsection ‎(b) of this ‎Section 2.03 and the Administrative Agent may, in reliance upon such assumption, make available to the Borrower on such date a corresponding amount. If and to the extent that such Lender shall not have so made such share available to the Administrative Agent, such Lender and, if such Lender shall not have made such payment within two Domestic Business Days of demand therefor, the Borrower agrees to repay to the Administrative Agent forthwith on demand such corresponding amount together with interest thereon, for each day from the date such amount is made available to the Borrower until the date such amount is repaid to the Administrative Agent, at (i) in the case of the Borrower, a rate per annum equal to the higher of the Federal Funds Rate and the interest rate applicable thereto pursuant to ‎Section 2.06 and (ii) in the case of such Lender, the Federal Funds Rate. If such Lender shall repay to the Administrative Agent such corresponding amount, such amount so repaid shall constitute such Lender’s Loan included in the applicable Borrowing for purposes of this Agreement.

(d)    The failure of any Lender to make a Loan to be made by it as part of a Borrowing shall not relieve any other Lender of its obligation, if any, hereunder to make a Loan on the date of such Borrowing, but no Lender shall be responsible for the failure of any other Lender to make a Loan to be made by such other Lender.

Section 2.04.    Registry; Notes. (a) The Administrative Agent shall maintain a register (the “Register”) on which it will record the Commitment of each Lender, each Loan made by such Lender and each repayment of any Loan made by such Lender. Any such recordation by the Administrative Agent on the Register shall be conclusive, absent manifest error. Failure to make any such recordation, or any error in such recordation, shall not affect the Borrower’s obligations hereunder.

13

(b)    The Borrower hereby agrees that, promptly upon the request of any Lender at any time, the Borrower shall deliver to such Lender a duly executed Note, in substantially the form of Exhibit A hereto, payable to such Lender or its registered assigns as permitted pursuant to ‎Section 9.06 and representing the obligation of the Borrower to pay the unpaid principal amount of the Loans made to the Borrower by such Lender, with interest as provided herein on the unpaid principal amount from time to time outstanding.

(c)    Each Lender shall record the date, amount and maturity of each Loan made by it and the date and amount of each payment of principal made by the Borrower with respect thereto, and each Lender receiving a Note pursuant to this Section, if such Lender so elects in connection with any transfer or enforcement of its Note, may endorse on the schedule forming a part thereof appropriate notations to evidence the foregoing information with respect to each such Loan then outstanding; provided that the failure of such Lender to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Notes. Such Lender is hereby irrevocably authorized by the Borrower so to endorse its Note and to attach to and make a part of its Note a continuation of any such schedule as and when required.

Section 2.05.    Maturity of Loans. Each Loan made by any Lender shall mature, and the principal amount thereof shall be due and payable together with accrued interest thereon, on the Maturity Date.

Section 2.06.    Interest Rates. (a) Each Base Rate Loan shall bear interest on the outstanding principal amount thereof, for each day from the date such Loan is made until it becomes due, at a rate per annum equal to the Base Rate for such day. Such interest shall be payable quarterly in arrears on each Quarterly Payment Date and at maturity. Any overdue principal of or overdue interest on any Base Rate Loan shall bear interest, payable on demand, for each day until paid at a rate per annum equal to the sum of 1% plus the Base Rate for such day.

(b)    Each Euro‑Dollar Loan shall bear interest on the outstanding principal amount thereof, for each day during each Interest Period applicable thereto, at a rate per annum equal to the sum of the Applicable Margin for such day plus the London Interbank Offered Rate applicable to such Interest Period. Such interest shall be payable for each Interest Period on the last day thereof and, if such Interest Period is longer than three months, at intervals of three months after the first day thereof. If the London-Interbank Offered Rate shall be less than zero, such rate shall be deemed zero for purposes of this Agreement.

The “London Interbank Offered Rate” applicable to any Interest Period means the rate appearing on Reuters Screen LIBOR01 Page (or on any successor or substitute page of such service, or any successor to or, if such service is not available, substitute for such service providing rate quotations comparable to those currently provided on such page of such service, as determined by the Administrative Agent from time to time for purposes of providing quotations of interest rates applicable to U.S. dollar deposits that are offered to leading banks in the London interbank deposit market) at approximately 11:00 A.M. (London time) two Euro-Dollar Business Days prior to the commencement of such Interest Period, as the rate for U.S. dollar deposits with a maturity comparable to such Interest Period. In the event that such rate is not so available at such time for any reason, then the “London Interbank Offered Rate” for such Interest Period shall be the average (rounded upward, if necessary, to the next higher 1/16 of 1%) of the respective rates per annum at which deposits in U.S. dollars are offered to leading banks in the London interbank market at approximately 11:00 A.M. (London time) two Euro-Dollar Business Days before the first day of such Interest Period

14

in an amount approximately equal to the principal amount of the Loan of such leading banks to which such Interest Period is to apply and for a period of time comparable to such Interest Period.

(c)    Any overdue principal of or overdue interest on any Euro‑Dollar Loan shall bear interest, payable on demand, for each day from and including the date payment thereof was due to but excluding the date of actual payment, at a rate per annum equal to the sum of 1% plus the higher of (i) the sum of the Applicable Margin for such day plus the London Interbank Offered Rate applicable to such Loan at the date such payment was due and (ii) the rate applicable to Base Rate Loans for such day.

(d)    The Administrative Agent shall determine each interest rate applicable to the Loans hereunder. The Administrative Agent shall give prompt notice to the Borrower and the participating Lenders by facsimile of each rate of interest so determined, and its determination thereof shall be conclusive in the absence of manifest error unless the Borrower raises an objection thereto within five Domestic Business Days after receipt of such notice.

Section 2.07.    Ticking Fee. The Borrower agrees to pay to the Administrative Agent for the account of each Lender a ticking fee (the “Ticking Fee”) in an amount equal to 0.10% per annum, accruing on the daily average of the unfunded Commitment of such Lender then outstanding, if any, accruing from and including the Effective Date, to but excluding the earlier of (i) the Commitment Termination Date and (ii) the Second Funding Date (such earlier date, the “Ticking Fee End Date”); provided that (A) no Ticking Fee shall accrue on the Commitment of a Defaulting Lender so long as such Lender shall be a Defaulting Lender and (B) any Ticking Fee accrued with respect to the Commitment of a Defaulting Lender during the period prior to the time such Lender became a Defaulting Lender and unpaid at such time shall not be payable by the Borrower so long as such Lender shall be a Defaulting Lender.  The Ticking Fee shall be payable on the Ticking Fee End Date.

Section 2.08.    [Reserved].

Section 2.09.    Method of Electing Interest Rates. (a) The Loans included in each Borrowing shall bear interest initially at the type of rate specified by the Borrower in the Notice of Borrowing. Thereafter, the Borrower may from time to time elect to change or continue the type of interest rate borne by each Group of Loans (subject in each case to the provisions of ‎Article 8 and the last sentence of this subsection ‎(a)), as follows:

(i)    if such Loans are Base Rate Loans, the Borrower may elect to convert such Loans to Euro‑Dollar Loans as of any Euro‑Dollar Business Day; and

(ii)    if such Loans are Euro‑Dollar Loans, the Borrower may elect to convert such Loans to Base Rate Loans or elect to continue such Loans as Euro‑Dollar Loans for an additional Interest Period, subject to ‎Section 2.13 in the case of any such conversion or continuation effective on any day other than the last day of the then current Interest Period applicable to such Loans.

Each such election shall be made by delivering a notice (a “Notice of Interest Rate Election”) to the Administrative Agent not later than 11:00 A.M. (Eastern time) on the third Euro‑Dollar Business Day before the conversion or continuation selected in such notice is to be effective (or one Business Day if the conversion is from a Euro-Dollar Loan to a Base Rate Loan). A Notice of Interest Rate

15

Election may, if it so specifies, apply to only a portion of the aggregate principal amount of the relevant Group of Loans; provided that (i) such portion is allocated ratably among the Loans comprising such Group and (ii) the portion to which such notice applies, and the remaining portion to which it does not apply, are each $10,000,000 or any larger multiple of $1,000,000.

(b)    Each Notice of Interest Rate Election shall specify:

(i)    the Group of Loans (or portion thereof) to which such notice applies;

(ii)    the date on which the conversion or continuation selected in such notice is to be effective, which shall comply with the applicable clause of subsection ‎2.09(a) above;

(iii)    if the Loans comprising such Group are to be converted, the new type of Loans and, if the Loans being converted are to be Euro-Dollar Loans, the duration of the next succeeding Interest Period applicable thereto; and

(iv)    if such Loans are to be continued as Euro‑Dollar Loans for an additional Interest Period, the duration of such additional Interest Period.

Each Interest Period specified in a Notice of Interest Rate Election shall comply with the provisions of the definition of the term “Interest Period”.

Notwithstanding anything to the contrary provided herein, the Borrower may request Irregular Interest Periods (without premium or penalty) in order to consolidate outstanding Interest Periods. Upon receipt of a Notice of Interest Rate Election from the Borrower requesting such Irregular Interest Period, and solely in the event that all Lenders agree to provide such Irregular Interest Period, the Administrative Agent and Lenders shall provide the Borrower with such Irregular Interest Period; provided that if the applicable Irregular Interest Period is not available in the London interbank market, in the reasonable judgment of the Administrative Agent, the Administrative Agent shall set the applicable Euro-Dollar Rate for such Irregular Interest Period through interpolating the available London Interbank Offered Rate for periods having terms ending immediately prior to and immediately following such Irregular Interest Period (e.g., for a 75 day Interest Period, the Administrative Agent shall use the midpoint of a two month and three month London Interbank Offered Rate).

(c)    Promptly after receiving a Notice of Interest Rate Election from the Borrower pursuant to subsection ‎2.09(a) above, the Administrative Agent shall notify each Lender of the contents thereof and such notice shall not thereafter be revocable by the Borrower. If no Notice of Interest Rate Election is timely received prior to the end of an Interest Period for any Group of Loans, the Borrower shall be deemed to have elected that such Group of Loans be converted to Base Rate Loans as of the last day of such Interest Period.

(d)    An election by the Borrower to change or continue the rate of interest applicable to any Group of Loans pursuant to this Section shall not constitute a “Borrowing” subject to the provisions of ‎Section 3.03.

Section 2.10.    [Reserved].

16

Section 2.11.    Optional Prepayments. (a) The Borrower may (i) upon notice to the Administrative Agent not later than 11:00 A.M. (Eastern time) on any Domestic Business Day prepay on such Domestic Business Day any Group of Base Rate Loans and (ii) upon at least three Euro‑Dollar Business Days’ notice to the Administrative Agent not later than 11:00 A.M. (Eastern time) prepay any Group of Euro‑Dollar Loans, in each case in whole at any time, or from time to time in part in amounts aggregating $5,000,000 or any larger multiple of $1,000,000, by paying the principal amount to be prepaid together with accrued interest thereon to the date of prepayment and together with any additional amounts payable pursuant to ‎Section 2.13. Each such optional prepayment shall be applied to prepay ratably the Loans of the several Lenders included in such Group or Borrowing.

(b)    Upon receipt of a notice of prepayment pursuant to this Section, the Administrative Agent shall promptly notify each Lender of the contents thereof and of such Lender’s share (if any) of such prepayment and such notice shall not thereafter be revocable by the Borrower.

Section 2.12.    General Provisions as to Payments. (a)The Borrower shall make each payment of principal of, and interest on, the Loans and of fees hereunder, not later than 1:00 P.M. (Eastern time) on the date when due, in Federal or other funds immediately available in New York City, to the Administrative Agent at its address referred to in ‎Section 9.01 and without reduction by reason of any set-off, counterclaim or deduction of any kind. The Administrative Agent will promptly distribute to each Lender in like funds its ratable share of each such payment received by the Administrative Agent for the account of the Lenders. Whenever any payment of principal of, or interest on, the Base Rate Loans or of fees shall be due on a day which is not a Domestic Business Day, the date for payment thereof shall be extended to the next succeeding Domestic Business Day. Whenever any payment of principal of, or interest on, the Euro‑Dollar Loans shall be due on a day which is not a Euro‑Dollar Business Day, the date for payment thereof shall be extended to the next succeeding Euro‑Dollar Business Day unless such Euro‑Dollar Business Day falls in another calendar month, in which case the date for payment thereof shall be the next preceding Euro‑Dollar Business Day. If the date for any payment of principal is extended by operation of law or otherwise, interest thereon shall be payable for such extended time.

(b)    Unless the Administrative Agent shall have received notice from the Borrower prior to the date on which any payment is due to the Lenders hereunder that the Borrower will not make such payment in full, the Administrative Agent may assume that the Borrower has made such payment in full to the Administrative Agent on such date and the Administrative Agent may, in reliance upon such assumption, cause to be distributed to each Lender on such due date an amount equal to the amount then due such Lender. If and to the extent that the Borrower shall not have so made such payment, each Lender shall repay to the Administrative Agent forthwith on demand such amount distributed to such Lender together with interest thereon, for each day from the date such amount is distributed to such Lender until the date such Lender repays such amount to the Administrative Agent, at the Federal Funds Rate.

Section 2.13.    Funding Losses. If the Borrower makes any payment of principal with respect to any Euro-Dollar Loan (other than payments made by an Assignee pursuant to ‎Section 8.06(a) or by the Borrower pursuant to ‎Section 8.06(b) in respect of a Defaulting Lender’s Euro-Dollar Loans) (whether voluntary, mandatory, automatic, by reason of acceleration, or otherwise) or any Euro-Dollar Loan is converted to a Base Rate Loan or continued as a Euro-Dollar Loan for a new Interest Period (pursuant to ‎Article 2, ‎6 or ‎8 or otherwise) on any day other than the last day of an Interest Period applicable thereto, or if the Borrower fails to borrow, prepay, convert or

17

continue any Euro-Dollar Loans after notice has been given to any Lender in accordance with Section ‎2.03(a), ‎2.09(c) or ‎2.11(b), the Borrower shall reimburse each Lender within 15 days after demand for any resulting loss or expense incurred by it (or by an existing or prospective Participant in the related Loan), including (without limitation) any loss incurred in obtaining, liquidating or employing deposits from third parties, but excluding loss of margin for the period after any such payment or conversion or failure to borrow, prepay, convert or continue; provided that such Lender shall have delivered to the Borrower a certificate setting forth in reasonable detail the calculation of the amount of such loss or expense, which certificate shall be conclusive in the absence of manifest error.

Section 2.14.    Computation of Interest and Fees. Interest based on clause (a) of the definition of Base Rate shall be computed on the basis of a year of 365 days (or 366 days in a leap year) and paid for the actual number of days elapsed (including the first day but excluding the last day). All other interest and all fees shall be computed on the basis of a year of 360 days and paid for the actual number of days elapsed (including the first day but excluding the last day).

Section 2.15.    [Reserved].

Section 2.16.    Regulation D Compensation. In the event that a Lender is required to maintain reserves of the type contemplated by the definition of “Euro‑Dollar Reserve Percentage”, such Lender may require the Borrower to pay, contemporaneously with each payment of interest on the Euro‑Dollar Loans, additional interest on the related Euro‑Dollar Loan of such Lender at a rate per annum determined by such Lender up to but not exceeding the excess of (i) (A) the applicable London Interbank Offered Rate divided by (B) one minus the Euro‑Dollar Reserve Percentage over (ii) the applicable London Interbank Offered Rate. Any Lender wishing to require payment of such additional interest (x) shall so notify the Borrower and the Administrative Agent, in which case such additional interest on the Euro‑Dollar Loans of such Lender shall be payable to such Lender at the place indicated in such notice with respect to each Interest Period commencing at least three Euro‑Dollar Business Days after the giving of such notice and (y) shall notify the Borrower at least three Euro‑Dollar Business Days prior to each date on which interest is payable on the Euro‑Dollar Loans of the amount then due it under this Section. Each such notification shall be accompanied by such information as the Borrower may reasonably request.

“Euro‑Dollar Reserve Percentage” means for any day, that percentage (expressed as a decimal) which is in effect on such day, as prescribed by the Board of Governors of the Federal Reserve System (or any successor) for determining the maximum reserve requirement for a member bank of the Federal Reserve System in New York City with deposits exceeding five billion dollars in respect of “Eurocurrency liabilities” (or in respect of any other category of liabilities which includes deposits by reference to which the interest rate on Euro‑Dollar Loans is determined or any category of extensions of credit or other assets which includes loans by a non‑United States office of any Lender to United States residents).

Section 2.17.    [Reserved].

Section 2.18.    [Reserved].

18

Section 2.19.    Defaulting Lenders. If any Lender becomes a Defaulting Lender, then the following provisions shall apply for so long as such Lender is a Defaulting Lender, to the extent permitted by applicable law:

(a)    [Reserved];

(b)    [Reserved];

(c)    any payment of principal, interest, fees or other amounts received by the Administrative Agent for the account of a Defaulting Lender (whether voluntary or mandatory, at maturity, pursuant to ‎Article 6 or otherwise) shall be applied at such time or times as may be determined by the Administrative Agent as follows:

(i)    first, to the payment of any amounts owing by such Defaulting Lender to the Administrative Agent hereunder;

(ii)    second, as the Borrower may request (so long as no Default exists), to the funding of any Loan in respect of which such Defaulting Lender has failed to fund its portion thereof as required by this Agreement, as determined by the Administrative Agent;

(iii)    third, if so determined by the Administrative Agent and the Borrower, to be held in a deposit account and released pro rata in order to satisfy such Defaulting Lender’s potential future funding obligations with respect to Loans under this Agreement;

(iv)    fourth, to the payment of any amounts owing to the Lenders as a result of any judgment of a court of competent jurisdiction obtained by any Lender against such Defaulting Lender as a result of such Defaulting Lender’s breach of its obligations under this Agreement;

(v)    fifth, so long as no Default exists, to the payment of any amounts owing to the Borrower as a result of any judgment of a court of competent jurisdiction obtained by the Borrower against such Defaulting Lender as a result of such Defaulting Lender’s breach of its obligations under this Agreement; and

(vi)    sixth, to such Defaulting Lender or as otherwise directed by a court of competent jurisdiction; provided that if (x) such payment is a payment of the principal amount of any Loans in respect of which such Defaulting Lender has not fully funded its appropriate share, and (y) such Loans were made at a time when the conditions set forth in ‎Section 3.03 were satisfied or waived, such payment shall be applied solely to pay the Loans of all non-Defaulting Lenders on a pro rata basis prior to being applied to the payment of any Loans of such Defaulting Lender until such time as all Loans are held by the Lenders pro rata in accordance with the Commitments.

Any payments, prepayments or other amounts paid or payable to a Defaulting Lender that are applied (or held) to pay amounts owed by a Defaulting Lender pursuant to this ‎Section 2.19(c) shall be deemed paid to and redirected by such Defaulting Lender, and each Lender irrevocably consents hereto; and

19

(d)    in the event that the Administrative Agent and the Borrower agree that a Defaulting Lender has adequately remedied all matters that caused such Lender to be a Defaulting Lender, on such date such Lender shall purchase at par such of the Loans of the other Lenders as the Administrative Agent shall determine may be necessary in order for such Lender to hold such Loans in accordance with its Percentage; provided, that no adjustments will be made retroactively with respect to fees accrued or payments made by or on behalf of the Borrower while such Lender was a Defaulting Lender; and provided, further, that except to the extent otherwise expressly agreed by the affected parties, no change hereunder from Defaulting Lender to Lender will constitute a waiver or release of any claim of any party hereunder arising from that Lender’s having been a Defaulting Lender.

ARTICLE 3Conditions

Section 3.01.    Effective Date. This Agreement shall become effective on the date that each of the following conditions shall have been satisfied (or waived in accordance with ‎Section 9.05(a)):

(a)    receipt by the Administrative Agent of counterparts hereof signed by each of the parties hereto (or, in the case of any party as to which an executed counterpart shall not have been received, receipt by the Administrative Agent in form satisfactory to it of facsimile or other written confirmation from such party of execution of a counterpart hereof by such party);

(b)    receipt by the Administrative Agent of (i) an opinion of internal counsel of the Borrower and (ii) an opinion of Moore & Van Allen PLLC, special counsel for the Borrower, in each case in form and substance reasonably satisfactory to the Required Lenders;

(c)    receipt by the Administrative Agent of a certificate signed by a Vice President, the Treasurer, an Assistant Treasurer or the Controller of the Borrower, dated the Effective Date, to the effect set forth in clauses ‎(c) and ‎(d) of ‎Section 3.03 (without giving effect to the parenthetical in such clause ‎(d));

(d)    receipt by the Administrative Agent of all documents it may have reasonably requested prior to the date hereof relating to the existence of the Borrower, the corporate authority for and the validity of this Agreement and the Notes, and any other matters relevant hereto, all in form and substance satisfactory to the Administrative Agent;

(e)    receipt by the Administrative Agent of evidence satisfactory to it that the upfront fees, arrangement fees, administrative agency fees and expenses payable by the Borrower on the Effective Date have been paid; and

(f)    receipt by the Administrative Agent, at least three Domestic Business Days prior to the Effective Date, of all documentation and other information about the Borrower that shall have been reasonably requested by the Administrative Agent in writing at least 10 Domestic Business Days prior to the Effective Date and that the Administrative Agent reasonably determines is required by United States regulatory authorities under applicable “know your customer” and anti-money laundering rules and regulations, including without limitation the Patriot Act.

20

provided that the Commitments shall not become effective unless all of the foregoing conditions are satisfied not later than June 30, 2017. The Administrative Agent shall promptly notify the Borrower and the Lenders of the Effective Date, and such notice shall be conclusive and binding on all parties hereto.

Section 3.02.    [Reserved].

Section 3.03.    Borrowings. The obligation of any Lender to make a Loan on any Funding Date to the Borrower is subject to the satisfaction of the following conditions:

(a)    receipt by the Administrative Agent of a Notice of Borrowing as required by ‎Section 2.02;

(b)    [Reserved];

(c)    the fact that, immediately after such Borrowing, no Default with respect to the Borrower shall have occurred and be continuing; and

(d)    the fact that the representations and warranties of the Borrower contained in this Agreement (except the representations and warranties set forth in Sections 4.04(c) and 4.06) shall be true on and as of the date of such Borrowing.

Each Borrowing hereunder shall be deemed to be a representation and warranty by the Borrower on the date of such Borrowing or issuance as to the facts specified in clauses ‎(c) and ‎(d) of this Section.

ARTICLE 4Representations and Warranties

The Borrower represents and warrants that:

Section 4.01.    Organization and Power. The Borrower is duly organized, validly existing and in good standing under the laws of the jurisdiction of its organization and has all requisite powers and all material governmental licenses, authorizations, consents and approvals required to carry on its business as now conducted and is duly qualified to do business in each jurisdiction where such qualification is required, except where the failure so to qualify would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole.

Section 4.02.    Corporate and Governmental Authorization; No Contravention. The execution, delivery and performance by the Borrower of this Agreement and the Notes are within the Borrower’s powers, have been duly authorized by all necessary company action, require no action by or in respect of, or filing with, any Governmental Authority (except for consents, authorizations or filings which have been obtained or made, as the case may be, and are in full force and effect) and do not contravene, or constitute a default under, any provision of applicable law or regulation or of the articles of incorporation, by‑laws, certificate of formation or the limited liability company agreement of the Borrower or of any material agreement, judgment, injunction, order, decree or other instrument binding upon the Borrower or result in the creation or imposition of any Lien on any asset of the Borrower or any of its Material Subsidiaries.

21

Section 4.03.    Binding Effect. This Agreement constitutes a valid and binding agreement of the Borrower and each Note, if and when executed and delivered by it in accordance with this Agreement, will constitute a valid and binding obligation of the Borrower, in each case enforceable in accordance with its terms, except as the same may be limited by bankruptcy, insolvency or similar laws affecting creditors’ rights generally and by general principles of equity.

Section 4.04.    Financial Information. (a)The consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of October 31, 2016 and the related consolidated statements of income, cash flows, capitalization and retained earnings for the fiscal year then ended, reported on by Deloitte & Touche, copies of which have been delivered to each of the Lenders by using the Borrower’s Syndtrak site or otherwise made available, fairly present in all material respects, in conformity with generally accepted accounting principles, the consolidated financial position of the Borrower and its Consolidated Subsidiaries as of such date and their consolidated results of operations and cash flows for such fiscal year.

(b)    (i) The unaudited consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of December 31, 2016 and the related unaudited consolidated statements of income and cash flows for the two months then ended, copies of which have been delivered to each of the Lenders by using the Borrower’s Syndtrak site or otherwise made available, fairly present in all material respects, in conformity with generally accepted accounting principles applied on a basis consistent with the financial statements referred to in subsection ‎(a) of this Section, the consolidated financial position of the Borrower and its Consolidated Subsidiaries as of such date and their consolidated results of operations and changes in financial position for such two-month period (subject to normal year‑end adjustments and the absence of footnotes).

(ii) The unaudited consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of March 31, 2017 and the related unaudited consolidated statements of income and cash flows for the three months then ended, copies of which have been delivered to each of the Lenders by using the Borrower’s Syndtrak site or otherwise made available, fairly present in all material respects, in conformity with generally accepted accounting principles applied on a basis consistent with the financial statements referred to in subsection ‎(a) of this Section, the consolidated financial position of the Borrower and its Consolidated Subsidiaries as of such date and their consolidated results of operations and changes in financial position for such three-month period (subject to normal year‑end adjustments and the absence of footnotes).

(c)    Since October 31, 2016, there has been no material adverse change in the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, except as publicly disclosed prior to the Effective Date.

Section 4.05.    Regulation U. The Borrower and its Material Subsidiaries are not engaged in the business of extending credit for the purpose of purchasing or carrying margin stock (within the meaning of Regulation U issued by the Board of Governors of the Federal Reserve System) and no proceeds of any Borrowing by the Borrower will be used to purchase or carry any margin stock or to extend credit to others for the purpose of purchasing or carrying any margin stock. Not more than 25% of the value of the assets of the Borrower and its Material Subsidiaries is represented by margin stock.

22

Section 4.06.    Litigation. Except as publicly disclosed prior to the Effective Date, there is no action, suit or proceeding pending against, or to the knowledge of the Borrower threatened against or affecting, the Borrower or any of its Subsidiaries before any court or arbitrator or any Governmental Authority which would be likely to be decided adversely to the Borrower or such Subsidiary and, as a result, have a material adverse effect upon the business, consolidated financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or which in any manner draws into question the validity of this Agreement or any Note.

Section 4.07.    Compliance with Laws. The Borrower and each of its Material Subsidiaries is in compliance in all material respects with all applicable laws, ordinances, rules, regulations and requirements of Governmental Authorities (including, without limitation, ERISA and Environmental Laws) except where (i) non-compliance would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) the necessity of compliance therewith is contested in good faith by appropriate proceedings.

Section 4.08.    Taxes. The Borrower and its Material Subsidiaries have filed all United States federal income tax returns and all other material tax returns which are required to be filed by them and have paid all taxes due pursuant to such returns or pursuant to any assessment received by the Borrower or any such Material Subsidiary except (i) where nonpayment would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) where the same are contested in good faith by appropriate proceedings. The charges, accruals and reserves on the books of the Borrower and its Material Subsidiaries in respect of taxes or other governmental charges are, in the opinion of the Borrower, adequate.

Section 4.09.    Anti-corruption Law and Sanctions. The Borrower and its Material Subsidiaries have implemented and maintain in effect policies and procedures designed to prevent violations by the Borrower, its Subsidiaries and their respective directors, officers, employees and agents (acting in their capacity as such) of the applicable Anti-Corruption Laws and Sanctions, and the Borrower and its Material Subsidiaries are in compliance in all material respects with all applicable Anti-Corruption Laws and Sanctions, except where (i) noncompliance would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) the necessity of compliance therewith is contested in good faith by appropriate proceedings. None of (i) the Borrower or any Material Subsidiary or, (ii) to the knowledge of the Borrower, any director, officer or employee of the Borrower or any Material Subsidiary or (iii) to the knowledge of the Borrower, any agent of the Borrower or any Material Subsidiary acting in any capacity in connection with or benefitting from the credit facility established hereby, is a Sanctioned Person.

ARTICLE 5Covenants

The Borrower agrees that, so long as any Lender has any Commitment hereunder with respect to the Borrower or any amount payable hereunder remains unpaid by the Borrower:

Section 5.01.    Information. The Borrower will deliver to each of the Lenders:

23

(a)    as soon as available and in any event within 120 days after the end of each fiscal year of the Borrower, a consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of the end of such fiscal year and the related consolidated statements of income, cash flows, capitalization and retained earnings for such fiscal year, setting forth in each case in comparative form the figures for the previous fiscal year, all reported on in a manner consistent with past practice and with applicable requirements of the Securities and Exchange Commission by Deloitte & Touche or other independent public accountants of nationally recognized standing;

(b)    as soon as available and in any event within 60 days after the end of each of the first three quarters of each fiscal year of the Borrower, a consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of the end of such quarter and the related consolidated statements of income and cash flows for such quarter and for the portion of the Borrower’s fiscal year ended at the end of such quarter, setting forth in each case in comparative form the figures for the corresponding quarter and the corresponding portion of the Borrower’s previous fiscal year, all certified (subject to normal year-end adjustments) as to fairness of presentation in all material respects, generally accepted accounting principles and consistency (except as provided by ‎Section 1.02) by an Approved Officer of the Borrower;

(c)    within the maximum time period specified for the delivery of each set of financial statements referred to in clauses ‎(a) and ‎(b) above, a certificate of an Approved Officer of the Borrower (i) setting forth in reasonable detail the calculations required to establish whether the Borrower was in compliance with the requirements of ‎Section 5.10 on the date of such financial statements and (ii) stating whether any Default exists on the date of such certificate and, if any Default then exists, setting forth the details thereof and the action which the Borrower is taking or proposes to take with respect thereto;

(d)    within five days after any officer of the Borrower with responsibility relating thereto obtains knowledge of any Default, if such Default is then continuing, a certificate of an Approved Officer of the Borrower setting forth the details thereof and the action which the Borrower is taking or proposes to take with respect thereto;

(e)    promptly upon the filing thereof, copies of all registration statements (other than the exhibits thereto and any registration statements on Form S-8 or its equivalent) and reports on Forms 10-K, 10-Q and 8-K (or their equivalents) which the Borrower shall have filed with the Securities and Exchange Commission;

(f)    if and when any member of the Borrower’s ERISA Group (i) gives or is reasonably expected to give notice to the PBGC of any “reportable event” (as defined in Section 4043 of ERISA) with respect to any Material Plan which might constitute grounds for a termination of such Plan under Title IV of ERISA, or knows that the plan administrator of any Material Plan has given or is required to give notice of any such reportable event, a copy of the notice of such reportable event given or required to be given to the PBGC; (ii) receives notice of complete or partial withdrawal liability under Title IV of ERISA or notice that any Material Plan is in reorganization, is insolvent or has been terminated, a copy of such notice; (iii) receives notice from the PBGC under Title IV of ERISA of an intent to terminate, impose material liability (other than for premiums under Section 4007 of ERISA) in respect of, or appoint a trustee to administer any Plan, a copy of such notice; (iv) applies for a waiver of the minimum funding standard under Section 412 of the Internal Revenue Code, a copy of such application; (v) gives notice of intent to terminate any Material Plan under Section 4041(c) of ERISA, a copy of such notice and other

24

information filed with the PBGC; (vi) gives notice of withdrawal from any Material Plan pursuant to Section 4063 of ERISA, a copy of such notice; (vii) receives notice of the cessation of operations at a facility of any member of the ERISA Group in the circumstances described in Section 4062(e) of ERISA; or (viii) fails to make any payment or contribution to any Material Plan or makes any amendment to any Material Plan which has resulted or could result in the imposition of a Lien or the posting of a bond or other security, a certificate of the chief financial officer or the chief accounting officer of the Borrower setting forth details as to such occurrence and action, if any, which the Borrower or applicable member of the ERISA Group is required or proposes to take;

(g)    [reserved]; and

(h)    from time to time such additional information regarding the financial position or business of the Borrower and its Subsidiaries as the Administrative Agent, at the request of any Lender, may reasonably request.

Information required to be delivered pursuant to these Sections ‎5.01(a), ‎5.01(b) and ‎5.01(e) shall be deemed to have been delivered on the date on which such information has been posted on the Securities and Exchange Commission website on the Internet at sec.gov/edaux/searches.htm, on the Borrower’s Syndtrak site or at another website identified in a notice from the Borrower to the Lenders and accessible by the Lenders without charge; provided that (i) a certificate delivered pursuant to ‎Section 5.01(c) shall also be deemed to have been delivered upon being posted to the Borrower’s Syndtrak site and (ii) the Borrower shall deliver paper copies of the information referred to in Sections ‎5.01(a), ‎5.01(b) and ‎5.01(e) to any Lender which requests such delivery.

Section 5.02.    Payment of Taxes. The Borrower will pay and discharge, and will cause each of its Material Subsidiaries to pay and discharge, at or before maturity, all their tax liabilities, except where (i) nonpayment would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) the same may be contested in good faith by appropriate proceedings, and will maintain, and will cause each of its Material Subsidiaries to maintain, in accordance with generally accepted accounting principles, appropriate reserves for the accrual of any of the same.

Section 5.03.    Maintenance of Property; Insurance. (a)The Borrower will keep, and will cause each of its Material Subsidiaries to keep, all property necessary in its business in good working order and condition, ordinary wear and tear excepted, except where the failure to do so would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole.

(b)    The Borrower will, and will cause each of its Material Subsidiaries to, maintain (either in the name of the Borrower or in such Subsidiary’s own name) with financially sound and responsible insurance companies, insurance on all their respective properties in at least such amounts and against at least such risks (and with such risk retention) as are usually insured against by companies of established repute engaged in the same or a similar business; provided that self‑insurance by the Borrower or any such Material Subsidiary, shall not be deemed a violation of this covenant to the extent that companies engaged in similar businesses and owning similar properties self‑insure; and will furnish to the Lenders, upon request from the Administrative Agent, information presented in reasonable detail as to the insurance so carried.

25

Section 5.04.    Maintenance of Existence. The Borrower will preserve, renew and keep in full force and effect, and will cause each of its Material Subsidiaries to preserve, renew and keep in full force and effect their respective corporate or other legal existence and their respective rights, privileges and franchises material to the normal conduct of their respective businesses; provided that nothing in this ‎Section 5.04 shall prohibit the termination of any right, privilege or franchise of the Borrower or any such Material Subsidiary or of the corporate or other legal existence of any such Material Subsidiary, or the change in form of organization of the Borrower or any such Material Subsidiary, if the Borrower in good faith determines that such termination or change is in the best interest of the Borrower, is not materially disadvantageous to the Lenders and, (i) in the case of a change in the form of organization of the Borrower, the Administrative Agent has consented thereto and (ii) in the case of a change in the jurisdiction of the Borrower to a jurisdiction outside of the United States, the Lenders have consented thereto.

Section 5.05.    Compliance with Laws. The Borrower will comply, and cause each of its Material Subsidiaries to comply, in all material respects with all applicable laws, ordinances, rules, regulations, and requirements of Governmental Authorities (including, without limitation, ERISA, applicable Sanctions and Anti-Corruption Laws and Environmental Laws) except where (i) noncompliance would not have a material adverse effect on the business, financial position or results of operations of the Borrower and its Consolidated Subsidiaries, considered as a whole, or (ii) the necessity of compliance therewith is contested in good faith by appropriate proceedings.

Section 5.06.    Books and Records. The Borrower will keep, and will cause each of its Material Subsidiaries to keep, proper books of record and account in which full, true and correct entries shall be made of all financial transactions in relation to its business and activities in accordance with its customary practices; and will permit, and will cause each such Material Subsidiary to permit, representatives of any Lender at such Lender’s expense (accompanied by a representative of the Borrower, if the Borrower so desires) to visit any of their respective properties, to examine any of their respective books and records and to discuss their respective affairs, finances and accounts with their respective officers, employees and independent public accountants, all upon such reasonable notice, at such reasonable times and as often as may reasonably be desired.

Section 5.07.    Negative Pledge. The Borrower will not create, assume or suffer to exist any Lien on any asset now owned or hereafter acquired by it, except:

(a)    Liens granted by the Borrower existing as of the Effective Date, securing Indebtedness outstanding on the date of this Agreement in an aggregate principal amount not exceeding $100,000,000;

(b)    [Reserved];

(c)    any Lien on any asset of any Person existing at the time such Person is merged or consolidated with or into the Borrower and not created in contemplation of such event;

(d)    any Lien existing on any asset prior to the acquisition thereof by the Borrower and not created in contemplation of such acquisition;

26

(e)    any Lien on any asset securing Indebtedness incurred or assumed for the purpose of financing all or any part of the cost of acquiring such asset; provided that such Lien attaches to such asset concurrently with or within 180 days after the acquisition thereof;

(f)    any Lien arising out of the refinancing, extension, renewal or refunding of any Indebtedness secured by any Lien permitted by any of the foregoing clauses of this Section; provided that such Indebtedness is not increased (except by accrued interest, prepayment premiums and fees and expenses incurred in connection with such refinancing, extension, renewal or refunding) and is not secured by any additional assets;

(g)    Liens for taxes, assessments or other governmental charges or levies not yet due or which are being contested in good faith by appropriate proceedings and with respect to which adequate reserves or other appropriate provisions are being maintained in accordance with generally accepted accounting principles;

(h)    statutory Liens of landlords and Liens of carriers, warehousemen, mechanics, materialmen and other Liens imposed by law, created in the ordinary course of business and for amounts not past due for more than 60 days or which are being contested in good faith by appropriate proceedings which are sufficient to prevent imminent foreclosure of such Liens, are promptly instituted and diligently conducted and with respect to which adequate reserves or other appropriate provisions are being maintained in accordance with generally accepted accounting principles;

(i)    Liens incurred or deposits made in the ordinary course of business (including, without limitation, surety bonds and appeal bonds) in connection with workers’ compensation, unemployment insurance and other types of social security benefits or to secure the performance of tenders, bids, leases, contracts (other than for the repayment of Indebtedness), statutory obligations and other similar obligations or arising as a result of progress payments under government contracts;

(j)    easements (including, without limitation, reciprocal easement agreements and utility agreements), rights‑of‑way, covenants, consents, reservations, encroachments, variations and other restrictions, charges or encumbrances (whether or not recorded) affecting the use of real property;

(k)    Liens with respect to judgments and attachments which do not result in an Event of Default;

(l)    Liens, deposits or pledges to secure the performance of bids, tenders, contracts (other than contracts for the payment of money), leases (permitted under the terms of this Agreement), public or statutory obligations, surety, stay, appeal, indemnity, performance or other obligations arising in the ordinary course of business;

(m)    other Liens including Liens imposed by Environmental Laws arising in the ordinary course of its business which (i) do not secure Indebtedness, (ii) do not secure any obligation in an amount exceeding $100,000,000 at any time at which Investment Grade Status does not exist as to the Borrower and (iii) do not in the aggregate materially detract from the value of its assets or materially impair the use thereof in the operation of its business;

27

(n)    Liens securing obligations under Hedging Agreements entered into to protect against fluctuations in interest rates or exchange rates or commodity prices and not for speculative purposes, provided that such Liens run in favor of a Lender hereunder or under the Master Credit Facility or a Person who was, at the time of issuance, a Lender;

(o)    Liens not otherwise permitted by the foregoing clauses of this Section on assets of the Borrower securing obligations in an aggregate principal or face amount at any date not to exceed 15% of the Consolidated Net Assets of the Borrower;

(p)    [Reserved]; and

(q)    Liens on regulatory assets up to the amount approved by state legislatures and/or regulatory orders.

Section 5.08.    Consolidations, Mergers and Sales of Assets. The Borrower will not (i) consolidate or merge with or into any other Person or (ii) sell, lease or otherwise transfer, directly or indirectly, Substantial Assets to any Person (other than a Subsidiary of the Borrower); provided that the Borrower may merge with another Person if the Borrower is the Person surviving such merger and, after giving effect thereto, no Default shall have occurred and be continuing.

Section 5.09.    Use of Proceeds. The proceeds of the Loans made under this Agreement will be used by the Borrower for its general corporate purposes. None of such proceeds will be used, directly or indirectly, for the purpose, whether immediate, incidental or ultimate, of buying or carrying any “margin stock” within the meaning of Regulation U. None of such proceeds will be used (i) for the purpose of knowingly financing the activities of or any transactions with any Sanctioned Person or in any country, region or territory that is the subject of Sanctions applicable to the Borrower and its Subsidiaries and where the financed activity would be prohibited by such applicable Sanctions, at the time of such financing or (ii) in furtherance of an offer, payment, promise to pay, or authorization of the payment or giving of money, or anything else of value, to any Person in violation of any Anti-Corruption Laws.

Section 5.10.    Indebtedness/Capitalization Ratio. The ratio of Consolidated Indebtedness of the Borrower to Consolidated Capitalization of the Borrower as at the end of any fiscal quarter of the Borrower will not exceed 70%.

ARTICLE 6Defaults

Section 6.01.    Events of Default. Subject to Section 9.05(b)(ii), if one or more of the following events (“Events of Default”) with respect to the Borrower shall have occurred and be continuing:

(a)    the Borrower shall fail to pay when due any principal of any Loan to it or shall fail to pay, within five days of the due date thereof, any interest, fees or any other amount payable by it hereunder;

(b)    the Borrower shall fail to observe or perform any covenant contained in Sections 5.01(d), ‎5.04, ‎5.07, ‎5.08, ‎5.10 or the second or third sentence of ‎5.09, inclusive;

28

(c)    the Borrower shall fail to observe or perform any covenant or agreement contained in this Agreement (other than those covered by clause ‎(a) or ‎(b) above) for 30 days after notice thereof has been given to the Borrower by the Administrative Agent at the request of any Lender;

(d)    any representation, warranty, certification or statement made by the Borrower in this Agreement or in any certificate, financial statement or other document delivered pursuant to this Agreement shall prove to have been incorrect in any material respect when made (or deemed made);

(e)    the Borrower or any of its Material Subsidiaries shall fail to make any payment in respect of Material Debt (other than Loans to the Borrower hereunder) when due after giving effect to any applicable grace period;

(f)    any event or condition shall occur and shall continue beyond the applicable grace or cure period, if any, provided with respect thereto so as to result in the acceleration of the maturity of Material Debt;

(g)    the Borrower or any of its Material Subsidiaries shall commence a voluntary case or other proceeding seeking liquidation, reorganization or other relief with respect to itself or its debts under any bankruptcy, insolvency or other similar law now or hereafter in effect or seeking the appointment of a trustee, receiver, liquidator, custodian or other similar official of it or any substantial part of its property, or shall consent to any such relief or to the appointment of or taking possession by any such official in an involuntary case or other proceeding commenced against it, or shall make a general assignment for the benefit of creditors, or shall admit in writing its inability to, or shall fail generally to, pay its debts as they become due, or shall take any corporate action to authorize any of the foregoing;

(h)    an involuntary case or other proceeding shall be commenced against the Borrower or any of its Material Subsidiaries seeking liquidation, reorganization or other relief with respect to it or its debts under any bankruptcy, insolvency or other similar law now or hereafter in effect or seeking the appointment of a trustee, receiver, liquidator, custodian or other similar official of it or any substantial part of its property, and such involuntary case or other proceeding shall remain undismissed and unstayed for a period of 90 days; or an order for relief shall be entered against the Borrower or any of its Material Subsidiaries under the federal bankruptcy laws as now or hereafter in effect;

(i)    any member of the Borrower’s ERISA Group shall fail to pay when due an amount or amounts aggregating in excess of $150,000,000 which it shall have become liable to pay to the PBGC or to a Plan under Title IV of ERISA; or notice of intent to terminate a Plan or Plans of such ERISA Group having aggregate Unfunded Vested Liabilities in excess of $150,000,000 (collectively, a “Material Plan”) shall be filed under Title IV of ERISA by any member of such ERISA Group, any plan administrator or any combination of the foregoing; or the PBGC shall institute proceedings under Title IV of ERISA to terminate or to cause a trustee to be appointed to administer any such Material Plan or a proceeding shall be instituted by a fiduciary of any such Material Plan against any member of such ERISA Group to enforce Section 515 or 4219(c)(5) of ERISA and such proceeding shall not have been dismissed within 90 days thereafter; or a condition shall exist by reason of which the PBGC would be entitled to obtain a decree adjudicating that any such Material Plan must be terminated;

29

(j)    a judgment or other court order for the payment of money in excess of $150,000,000 shall be rendered against the Borrower or any of its Material Subsidiaries and such judgment or order shall continue without being vacated, discharged, satisfied or stayed or bonded pending appeal for a period of 45 days;

(k)    the Borrower shall cease to be a Subsidiary of Duke Energy Corporation; or

(l)    any “Event of Default” (as defined in the Master Credit Facility) with respect to the Borrower under the Master Credit Facility (including any “Event of Default” under Section 6.01(k) of the Master Credit Facility);

then, and in every such event, the Administrative Agent shall (i) if requested by Lenders having more than 66-2/3% in aggregate amount of the Commitments, by notice to the Borrower terminate the Commitments as to the Borrower and they shall thereupon terminate, and the Borrower shall no longer be entitled to borrow hereunder, and (ii) if requested by Lenders holding more than 66-2/3% in aggregate principal amount of the Loans of the Borrower, by notice to the Borrower declare such Loans (together with accrued interest thereon) to be, and such Loans (together with accrued interest thereon) shall thereupon become, immediately due and payable without presentment, demand, protest or other notice of any kind, all of which are hereby waived by the Borrower; provided that in the case of any of the Events of Default specified in clause ‎(g) or ‎(h) above with respect to the Borrower, without any notice to the Borrower or any other act by the Administrative Agent or the Lenders, the Commitments shall thereupon terminate with respect to the Borrower and the Loans of the Borrower (together with accrued interest thereon) shall become immediately due and payable without presentment, demand, protest or other notice of any kind, all of which are hereby waived by the Borrower.

Section 6.02.    Notice of Default. The Administrative Agent shall give notice to the Borrower under ‎Section 6.01(c) promptly upon being requested to do so by any Lender and shall thereupon notify all the Lenders thereof.

ARTICLE 7The Administrative Agent

Section 7.01.    Appointment and Authorization. Each Lender irrevocably appoints and authorizes the Administrative Agent to take such action as agent on its behalf and to exercise such powers under this Agreement and the Notes as are delegated to the Administrative Agent by the terms hereof or thereof, together with all such powers as are reasonably incidental thereto.

Section 7.02.    Administrative Agent and Affiliates. U.S. Bank National Associationshall have the same rights and powers under this Agreement as any other Lender and may exercise or refrain from exercising the same as though it were not the Administrative Agent, and U.S. Bank National Association and its affiliates may accept deposits from, lend money to, and generally engage in any kind of business with the Borrower or any Subsidiary or affiliate of the Borrower as if it were not the Administrative Agent hereunder.

Section 7.03.    Action by Administrative Agent. The obligations of the Administrative Agent hereunder are only those expressly set forth herein. Without limiting the generality of the foregoing, the Administrative Agent shall not be required to take any action with respect to any Default, except as expressly provided in ‎Article 6.

30

Section 7.04.    Consultation with Experts. The Administrative Agent may consult with legal counsel (who may be counsel for the Borrower), independent public accountants and other experts selected by it and shall not be liable for any action taken or omitted to be taken by it in good faith in accordance with the advice of such counsel, accountants or experts.

Section 7.05.    Liability of Administrative Agent. Neither the Administrative Agent nor any of its affiliates nor any of their respective directors, officers, agents or employees shall be liable to any Lender for any action taken or not taken by it in connection herewith (i) with the consent or at the request of the Required Lenders or (ii) in the absence of its own gross negligence or willful misconduct. Neither the Administrative Agent nor any of its affiliates nor any of their respective directors, officers, agents or employees shall be responsible for or have any duty to ascertain, inquire into or verify (i) any statement, warranty or representation made in connection with this Agreement or any borrowing hereunder; (ii) the performance or observance of any of the covenants or agreements of the Borrower; (iii) the satisfaction of any condition specified in ‎Article 3, except receipt of items required to be delivered to the Administrative Agent; or (iv) the validity, effectiveness or genuineness of this Agreement, the Notes or any other instrument or writing furnished in connection herewith. The Administrative Agent shall not incur any liability by acting in reliance upon any notice, consent, certificate, statement, or other writing (which may be a bank wire, facsimile or similar writing) believed by it in good faith to be genuine or to be signed by the proper party or parties. Without limiting the generality of the foregoing, the use of the term “agent” in this Agreement with reference to the Administrative Agent is not intended to connote any fiduciary or other implied (or express) obligations arising under agency doctrine of any applicable law. Instead, such term is used merely as a matter of market custom and is intended to create or reflect only an administrative relationship between independent contracting parties.

Section 7.06.    Indemnification. Each Lender shall, ratably in accordance with the aggregate amount of such Lender’s unfunded Commitments and Loans outstanding, indemnify the Administrative Agent and its Related Parties (to the extent not reimbursed or indemnified by the Borrower) against any cost, expense (including counsel fees and disbursements), claim, demand, action, loss, penalties or liability (except such as result from such indemnitees’ gross negligence or willful misconduct) that such indemnitees may suffer or incur in connection with this Agreement or any action taken or omitted by the Administrative Agent in its capacity as such, or by any Related Party acting for the Administrative Agent in connection with such capacity.

Section 7.07.    Credit Decision. Each Lender acknowledges that it has, independently and without reliance upon the Administrative Agent or any other Lender, and based on such documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Agreement. Each Lender also acknowledges that it will, independently and without reliance upon the Administrative Agent or any other Lender, and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking any action under this Agreement.

Section 7.08.    Successor Administrative Agent.

(a)    The Administrative Agent may resign at any time by giving notice thereof to the Lenders and the Borrower. Upon any such resignation, (i) the Borrower, with the consent of the Required Lenders (such consent not to be unreasonably withheld or delayed) or (ii) if an Event of Default has occurred and is continuing, then the Required Lenders, shall have the right to appoint

31

a successor Administrative Agent. If no successor Administrative Agent shall have been so appointed, and shall have accepted such appointment, within 30 days after the retiring Administrative Agent gives notice of resignation, then the retiring Administrative Agent may, on behalf of the Lenders, appoint a successor Administrative Agent, which shall be a commercial bank organized or licensed under the laws of the United States of America or of any State thereof and having a combined capital and surplus of at least $250,000,000.

(b)    If the Person serving as Administrative Agent is a Defaulting Lender, (i) the Borrower, with the consent of the Required Lenders (such consent not to be unreasonably withheld or delayed) or (ii) if an Event of Default has occurred and is continuing, then the Required Lenders, shall have the right to appoint a successor Administrative Agent.

(c)    Upon the acceptance of its appointment as Administrative Agent hereunder by a successor Administrative Agent, such successor Administrative Agent shall thereupon succeed to and become vested with all the rights, duties and obligations of the retiring Administrative Agent, and the retiring Administrative Agent shall be discharged from its duties and obligations hereunder; provided that if such successor Administrative Agent is appointed without the consent of the Borrower, such successor Administrative Agent may be replaced by the Borrower with the consent of the Required Lenders so long as no Event of Default has occurred and is continuing at the time. After any retiring Administrative Agent’s resignation or removal hereunder as Administrative Agent, the provisions of this Article shall inure to its benefit as to any actions taken or omitted to be taken by it while it was Administrative Agent.

(d)    The fees payable by the Borrower to any successor Administrative Agent shall be the same as those payable to its predecessor unless otherwise agreed between the Borrower and such successor.

Section 7.09.    Administrative Agent’s Fee. The Borrower shall pay to the Administrative Agent for its own account fees in the amounts and at the times previously agreed upon between the Borrower and the Administrative Agent.

ARTICLE 8Change in Circumstances

Section 8.01.    Basis for Determining Interest Rate Inadequate or Unfair. If on or prior to the first day of any Interest Period for any Euro-Dollar Borrowing:

(a)    the Administrative Agent determines (which determination shall be conclusive absent manifest error) that deposits in dollars (in the applicable amounts) are not being offered to financial institutions in general in the relevant market for such Interest Period, or

(b)    Lenders having 66-2/3% or more of the aggregate amount of the affected Loans advise the Administrative Agent that the London Interbank Offered Rate as determined by the Administrative Agent will not adequately and fairly reflect the cost to such Lenders of funding their Euro‑Dollar Loans for such Interest Period,

the Administrative Agent shall forthwith give notice thereof to the Borrower and the Lenders, whereupon until the Administrative Agent notifies the Borrower that the circumstances giving rise to such suspension no longer exist, (i) the obligations of the Lenders to make Euro-Dollar Loans or

32

to continue or convert outstanding Loans as or into Euro-Dollar Loans shall be suspended and (ii) each outstanding Euro-Dollar Loan shall be converted into a Base Rate Loan on the last day of the then current Interest Period applicable thereto. Unless the Borrower notifies the Administrative Agent at least one Domestic Business Day before the date of any Euro-Dollar Borrowing for which a Notice of Borrowing has previously been given that it elects not to borrow on such date, such Borrowing shall instead be made as a Base Rate Borrowing.

Section 8.02.    Illegality. If any Change In Law shall make it unlawful or impossible for any Lender (or its Euro‑Dollar Lending Office) to make, maintain or fund any of its Euro‑Dollar Loans and such Lender shall so notify the Administrative Agent, the Administrative Agent shall forthwith give notice thereof to the other Lenders and the Borrower, whereupon until such Lender notifies the Borrower and the Administrative Agent that the circumstances giving rise to such suspension no longer exist, the obligation of such Lender to make Euro‑Dollar Loans, or to continue or convert outstanding Loans as or into Euro-Dollar Loans, shall be suspended. Before giving any notice to the Administrative Agent pursuant to this Section, such Lender shall designate a different Euro‑Dollar Lending Office if such designation will avoid the need for giving such notice and will not be otherwise disadvantageous to such Lender in the good faith exercise of its discretion. If such notice is given, each Euro-Dollar Loan of such Lender then outstanding shall be converted to a Base Rate Loan either (a) on the last day of the then current Interest Period applicable to such Euro-Dollar Loan if such Lender may lawfully continue to maintain and fund such Loan to such day or (b) immediately if such Lender shall determine that it may not lawfully continue to maintain and fund such Loan to such day.

Section 8.03.    Increased Cost and Reduced Return. (a) If any Change In Law (i) shall impose, modify or deem applicable any reserve, special deposit, compulsory loan, insurance charge or similar requirement (including, without limitation, any such requirement imposed by the Board of Governors of the Federal Reserve System, but excluding with respect to any Euro‑Dollar Loan any such requirement included in an applicable Euro‑Dollar Reserve Percentage) against assets of, deposits with or for the account of, or credit extended by, any Lender (or its Applicable Lending Office); (ii) shall subject any Lender or Agent to any taxes (other than (A) Taxes, (B) taxes described in clauses (ii), (iii) or (iv) of the exclusions from the definition of Taxes and (C) Connection Income Taxes) on its loans, loan principal, letters of credit, commitments, or other obligations, or its deposits, reserves, other liabilities or capital attributable thereto; or (iii) shall impose on any Lender (or its Applicable Lending Office) or on the London interbank market any other condition, cost or expense affecting its Euro-Dollar Loans, its Note or its obligation to make Euro-Dollar Loans and the result of any of the foregoing is to increase the cost to such Lender (or its Applicable Lending Office) of making or maintaining any Euro-Dollar Loan (or, in the case of an adoption or change with respect to taxes, any Loan), or to reduce the amount of any sum received or receivable by such Lender (or its Applicable Lending Office) under this Agreement or under its Note with respect thereto, by an amount deemed by such Lender to be material, then, within 15 days after demand by such Lender (with a copy to the Administrative Agent), the Borrower shall pay to such Lender such additional amount or amounts as will compensate such Lender for such increased cost or reduction; provided that no such amount shall be payable with respect to any period commencing more than 90 days prior to the date such Lender first notifies the Borrower of its intention to demand compensation therefor under this ‎Section 8.03(a).

(b)    If any Lender shall have determined that any Change In Law has or would have the effect of reducing the rate of return on capital or liquidity of such Lender (or its Parent) as a

33

consequence of such Lender’s obligations hereunder to a level below that which such Lender (or its Parent) could have achieved but for such Change In Law (taking into consideration its policies with respect to capital adequacy or liquidity) by an amount deemed by such Lender to be material, then from time to time, within 15 days after demand by such Lender (with a copy to the Administrative Agent), the Borrower shall pay to such Lender such additional amount or amounts as will compensate such Lender (or its Parent) for such reduction; provided that no such amount shall be payable with respect to any period commencing less than 30 days after the date such Lender first notifies the Borrower of its intention to demand compensation under this ‎Section 8.03(b).

(c)    Each Lender will promptly notify the Borrower and the Administrative Agent of any event of which it has knowledge, occurring after the date hereof, which will entitle such Lender to compensation pursuant to this Section and will designate a different Applicable Lending Office if such designation will avoid the need for, or reduce the amount of, such compensation and will not, in the judgment of such Lender, be otherwise disadvantageous to such Lender. A certificate of any Lender claiming compensation under this Section and setting forth the additional amount or amounts to be paid to it hereunder shall be conclusive in the absence of manifest error. In determining such amount, such Lender may use any reasonable averaging and attribution methods.

Section 8.04.    Taxes. (a)For purposes of this ‎Section 8.04 the following terms have the following meanings:

“FATCA” means Sections 1471 through 1474 of the Internal Revenue Code, as of the date of this Agreement (or any amended or successor version that is substantively comparable and not materially more onerous to comply with) and any current or future regulations or official interpretations thereof and any agreement entered into pursuant to Section 1471(b)(1) of the Internal Revenue Code. For purposes of this Section 8.04, “applicable law” includes FATCA.

“Taxes” means any and all present or future taxes, duties, levies, imposts, deductions, charges or withholdings including any interest, additions to tax or penalties applicable thereto with respect to any payment by or on account of any obligation of the Borrower pursuant to this Agreement or any Note, excluding (i) in the case of each Lender and the Administrative Agent, taxes imposed on its income, net worth or gross receipts and franchise or similar taxes imposed on it by a jurisdiction under the laws of which such Lender or the Administrative Agent (as the case may be) is organized or in which its principal executive office is located or, in the case of each Lender, in which its Applicable Lending Office is located, (ii) in the case of each Lender, any United States withholding tax imposed on such payments except to the extent that (A) such Lender is subject to United States withholding tax by reason of a U.S. Tax Law Change or (B) in the case of a Lender not listed on the signature pages hereof or a Participant, amounts with respect to such Taxes were payable pursuant to ‎Section 8.04 to such Lender’s assignor or to such Participant’s participating Lender immediately before such Lender or Participant acquired the applicable interest in a Loan or Commitment; (iii) Taxes attributable to such Lender’s or Administrative Agent’s failure to comply with ‎Section 8.04(d) or ‎(e) and (iv) any U.S. federal withholding Taxes imposed under FATCA.

“Other Taxes” means any present or future stamp or documentary taxes and any other excise or property taxes, or similar charges or levies, which arise from any payment made pursuant to this Agreement or under any Note or from the execution or delivery of, or otherwise with respect to, this Agreement or any Note.

34

“U.S. Tax Law Change” means with respect to any Lender or Participant the occurrence (x) in the case of each Lender listed on the signature pages hereof, after the date of its execution and delivery of this Agreement and (y) in the case of any other Lender, after the date such Lender shall have become a Lender hereunder, and (z) in the case of each Participant, after the date such Participant became a Participant hereunder, of the adoption of any applicable U.S. federal law, U.S. federal rule or U.S. federal regulation relating to taxation, or any change therein, or the entry into force, modification or revocation of any income tax convention or treaty to which the United States is a party.

(b)    Any and all payments by or any account of the Borrower to or for the account of any Lender or the Administrative Agent hereunder or under any Note shall be made without deduction for any Taxes or Other Taxes, except as required by applicable law; provided that if the Borrower or the Administrative Agent shall be required by law to deduct any Taxes or Other Taxes from any such payments, (i) the sum payable by the Borrower shall be increased as necessary so that after all required deductions are made (including deductions applicable to additional sums payable under this ‎Section 8.04) such Lender or the Administrative Agent (as the case may be) receives an amount equal to the sum it would have received had no such deductions been made, (ii) the Borrower or the Administrative Agent shall make such deductions, (iii) the Borrower or the Administrative Agent shall pay the full amount deducted to the relevant taxation authority or other authority in accordance with applicable law and (iv) if the withholding agent is the Borrower, the Borrower shall furnish to the Administrative Agent, at its address referred to in ‎Section 9.01, the original or a certified copy of a receipt evidencing payment thereof.

(c)    The Borrower agrees to indemnify each Lender and the Administrative Agent for the full amount of Taxes or Other Taxes (including, without limitation, any Taxes or Other Taxes imposed or asserted by any jurisdiction on amounts payable under this ‎Section 8.04) paid by such Lender or the Administrative Agent (as the case may be) and any reasonable expenses arising therefrom or with respect thereto. This indemnification shall be paid within 15 days after such Lender or the Administrative Agent (as the case may be) makes demand therefor.

(d)    Each Lender organized under the laws of a jurisdiction outside the United States, on or prior to the date of its execution and delivery of this Agreement in the case of each Lender listed on the signature pages hereof and on or prior to the date on which it becomes a Lender in the case of each other Lender, and from time to time thereafter as required by law or requested by the Borrower or the Administrative Agent (but only so long as such Lender remains lawfully able to do so), shall provide the Borrower and the Administrative Agent (in such number of copies as shall be requested by the recipient) with whichever of the following is applicable (including any successor forms prescribed by the Internal Revenue Service):

(i)    in the case of a Lender claiming the benefits of an income tax treaty to which the United States is a party (x) with respect to payments of interest hereunder or under any Note, executed originals of IRS Form W-8BEN establishing an exemption from, or reduction of, U.S. federal withholding Tax pursuant to the “interest” article of such tax treaty and (y) with respect to any other applicable payments hereunder or under any Note, IRS Form W-8BEN establishing an exemption from, or reduction of, U.S. federal withholding Tax pursuant to the “business profits” or “other income” article of such tax treaty;

(ii)    executed originals of IRS Form W-8ECI;

35

(iii)    in the case of a Lender claiming the benefits of the exemption for portfolio interest under Section 881(c) of the Internal Revenue Code, (x) a certificate reasonably acceptable to the Administrative Agent to the effect that such Lender is not a “bank” within the meaning of Section 881(c)(3)(A) of the Internal Revenue Code, a “10 percent shareholder” of the Borrower within the meaning of Section 881(c)(3)(B) of the Internal Revenue Code, or a “controlled foreign corporation” described in Section 881(c)(3)(C) of the Internal Revenue Code (a “U.S. Tax Compliance Certificate”) and (y) executed originals of IRS Form W-8BEN; or

(iv)    to the extent a Lender is not the beneficial owner, executed originals of IRS Form W-8IMY, accompanied by IRS Form W-8ECI, IRS Form W-8BEN, a U.S. Tax Compliance Certificate, IRS Form W-9, and/or other certification documents from each beneficial owner, as applicable; provided that if the Lender is a partnership and one or more direct or indirect partners of such Lender are claiming the portfolio interest exemption, such Lender may provide a U.S. Tax Compliance Certificate on behalf of each such direct and indirect partner.

(e)    Any Lender that is organized under the laws of a jurisdiction within the United States shall deliver to the Borrower and the Administrative Agent on or prior to the date on which such Lender becomes a Lender under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower or the Administrative Agent), executed originals of IRS Form W-9 certifying that such Lender is exempt from U.S. federal backup withholding tax.

(f)    If a payment made to a Lender hereunder or under any Note would be subject to U.S. federal withholding Tax imposed by FATCA if such Lender were to fail to comply with the applicable reporting requirements of FATCA (including those contained in Section 1471(b) or 1472(b) of the Internal Revenue Code, as applicable), such Lender shall deliver to the Borrower and the Administrative Agent at the time or times prescribed by law and at such time or times reasonably requested by the Borrower or the Administrative Agent such documentation prescribed by applicable law (including as prescribed by Section 1471(b)(3)(C)(i) of the Internal Revenue Code) and such additional documentation reasonably requested by the Borrower or the Administrative Agent as may be necessary for the Borrower and the Administrative Agent to comply with their obligations under FATCA and to determine that such Lender has complied with such Lender’s obligations under FATCA or to determine the amount to deduct and withhold from such payment. Solely for purposes of this clause ‎(f), “FATCA” shall include any amendments made to FATCA after the date of this Agreement.

(g)    Each Lender agrees that if any form or certification it previously delivered expires or becomes obsolete or inaccurate in any respect, it shall update such form or certification or promptly notify the Borrower and the Administrative Agent in writing of its legal inability to do so.

(h)    If a Lender, which is otherwise exempt from or subject to a reduced rate of withholding tax, becomes subject to Taxes because of its failure to deliver a form required hereunder, the Borrower shall take such steps as such Lender shall reasonably request to assist such Lender to recover such Taxes.

(i)    If the Borrower is required to pay additional amounts to or for the account of any Lender pursuant to this ‎Section 8.04, then such Lender will take such action (including changing

36

the jurisdiction of its Applicable Lending Office) as in the good faith judgment of such Lender (i) will eliminate or reduce any such additional payment which may thereafter accrue and (ii) is not otherwise disadvantageous to such Lender.

(j)    If any Lender or the Administrative Agent receives a refund of any Taxes or Other Taxes for which the Borrower has made a payment under ‎Section 8.04(b) or ‎(c) and such refund was received from the taxing authority which originally imposed such Taxes or Other Taxes, such Lender or the Administrative Agent agrees to reimburse the Borrower to the extent of such refund; provided that nothing contained in this paragraph ‎(j) shall require any Lender or the Administrative Agent to seek any such refund or make available its tax returns (or any other information relating to its taxes which it deems to be confidential).

(k)    Each Lender shall severally indemnify the Administrative Agent, within 10 days after demand therefor, for (i) any Taxes attributable to such Lender (but only to the extent that the Borrower has not already indemnified the Administrative Agent for such Taxes and without limiting the obligation of the Borrower to do so), (ii) any taxes attributable to such Lender’s failure to comply with the provisions of ‎Section 9.06(b) relating to the maintenance of a Participant Register and (iii) any taxes excluded from the definition of Taxes attributable to such Lender, in each case, that are payable or paid by the Administrative Agent in connection with this Agreement or any Note, and any reasonable expenses arising therefrom or with respect thereto. A certificate as to the amount of such payment or liability delivered to any Lender by the Administrative Agent shall be conclusive absent manifest error. Each Lender hereby authorizes the Administrative Agent to set off and apply any and all amounts at any time owing to such Lender hereunder or under any Note or otherwise payable by the Administrative Agent to the Lender from any other source against any amount due to the Administrative Agent under this paragraph ‎(k).

Section 8.05.    Base Rate Loans Substituted for Affected Euro-Dollar Loans. If (i) the obligation of any Lender to make or to continue or convert outstanding Loans as or into Euro‑Dollar Loans has been suspended pursuant to ‎Section 8.02 or (ii) any Lender has demanded compensation under ‎Section 8.03(a) with respect to its Euro-Dollar Loans and the Borrower shall, by at least five Euro‑Dollar Business Days’ prior notice to such Lender through the Administrative Agent, have elected that the provisions of this Section shall apply to such Lender, then, unless and until such Lender notifies the Borrower that the circumstances giving rise to such suspension or demand for compensation no longer apply:

(a)    all Loans which would otherwise be made by such Lender as (or continued as or converted to) Euro‑Dollar Loans, as the case may be, shall instead be Base Rate Loans (on which interest and principal shall be payable contemporaneously with the related Euro-Dollar Loans of the other Lenders), and

(b)    after each of its Euro‑Dollar Loans has been repaid, all payments of principal which would otherwise be applied to repay such Loans shall be applied to repay its Base Rate Loans instead.

If such Lender notifies the Borrower that the circumstances giving rise to such suspension or demand for compensation no longer exist, the principal amount of each such Base Rate Loan shall be converted into a Euro-Dollar Loan on the first day of the next succeeding Interest Period applicable to the related Euro-Dollar Loans of the other Lenders.

37

Section 8.06.    Substitution of Lender; Termination Option. If (i) the obligation of any Lender to make or to convert or continue outstanding Loans as or into Euro-Dollar Loans has been suspended pursuant to ‎Section 8.02, (ii) any Lender has demanded compensation under ‎Section 8.03 or ‎8.04 (including any demand made by a Lender on behalf of a Participant), (iii) [reserved], (iv) any Lender becomes a Defaulting Lender, (v) Investment Grade Status ceases to exist as to any Lender or, (vi) for purposes of ‎(a) below only, any Lender becomes a Non-Consenting Lender, then:

(a)    the Borrower shall have the right, with the assistance of the Administrative Agent (or, if the Administrative Agent is a Defaulting Lender, the Required Lenders), to designate an Assignee (which may be one or more of the Lenders) mutually satisfactory to the Borrower and, so long as any such Persons are not Defaulting Lenders, the Administrative Agent (whose consent shall not be unreasonably withheld or delayed) to purchase for cash, pursuant to an Assignment and Assumption Agreement in substantially the form of Exhibit D hereto, the outstanding Loans of such Lender and assume the Commitment of such Lender (including any Commitments and Loans that have been participated), without recourse to or warranty by, or expense to, such Lender, for a purchase price equal to the principal amount of all of such Lender’s outstanding Loans plus any accrued but unpaid interest thereon and the accrued but unpaid fees in respect of such Lender’s Commitment hereunder and all other amounts payable by the Borrower to such Lender hereunder plus such amount, if any, as would be payable pursuant to ‎Section 2.13 if the outstanding Loans of such Lender were prepaid in their entirety on the date of consummation of such assignment; and

(b)    if at the time Investment Grade Status exists as to the Borrower, the Borrower may elect to terminate this Agreement as to such Lender (including any Commitments and Loans that have been participated); provided that (i) the Borrower notifies such Lender through the Administrative Agent (or, if the Administrative Agent is a Defaulting Lender, the Required Lenders) of such election at least three Euro‑Dollar Business Days before the effective date of such termination and (ii) the Borrower repay or prepay the principal amount of all outstanding Loans made by such Lender plus any accrued but unpaid interest thereon and the accrued but unpaid fees in respect of such Lender’s Commitment hereunder plus all other amounts payable by the Borrower to such Lender hereunder, not later than the effective date of such termination.

ARTICLE 9Miscellaneous

Section 9.01.    Notices.

(a)    All notices, requests and other communications to any party hereunder shall be in writing (including electronic transmission, bank wire, facsimile transmission or similar writing) and shall be given to such party: (x) in the case of the Borrower or the Administrative Agent, at its address or facsimile number set forth on the signature pages hereof, (y) in the case of any Lender, at its address or facsimile number set forth in its Administrative Questionnaire or (z) in the case of any party, such other address or facsimile number as such party may hereafter specify for the purpose by notice to the Administrative Agent and the Borrower. Each such notice, request or other communication shall be effective (i) if given by facsimile, when such facsimile is transmitted to the facsimile number specified in this Section and the appropriate answerback or confirmation slip, as the case may be, is received or (ii) if given by any other means, when delivered at the address specified in this Section; provided that notices to the Administrative

38

Agent under ‎Article 2 or ‎Article 8 shall not be effective until delivered. Notices delivered through electronic communications shall be effective as and to the extent provided in subsection ‎(b) below.

(b)    Notices and other communications to the Lenders hereunder may be delivered or furnished by electronic communication (including e-mail and internet or intranet websites) pursuant to procedures approved by the Administrative Agent or as otherwise determined by the Administrative Agent, provided that the foregoing shall not apply to notices to any Lender pursuant to ‎Article 2 if such Lender has notified the Administrative Agent that it is incapable of receiving notices under such Section by electronic communication. The Administrative Agent or the Borrower may, in its respective discretion, agree to accept notices and other communications to it hereunder by electronic communications pursuant to procedures approved by it or as it otherwise determines, provided that such determination or approval may be limited to particular notices or communications. Unless the Administrative Agent otherwise prescribes, (i) notices and other communications sent to an e-mail address shall be deemed received upon the sender’s receipt of an acknowledgement from the intended recipient (such as by the “return receipt requested” function, as available, return e-mail or other written acknowledgement), provided that if such notice or other communication is not given during the normal business hours of the recipient, such notice or communication shall be deemed to have been given at the opening of business on the next Domestic Business Day or Euro-Dollar Business Day, as applicable, for the recipient, and (ii) notices or communications posted to an internet or intranet website shall be deemed received upon the deemed receipt by the intended recipient at its e-mail address as described in the foregoing clause ‎(i) of notification that such notice or communication is available and identifying the website address therefor.

Section 9.02.    No Waivers. No failure or delay by the Administrative Agent or any Lender in exercising any right, power or privilege hereunder or under any Note shall operate as a waiver thereof nor shall any single or partial exercise thereof preclude any other or further exercise thereof or the exercise of any other right, power or privilege. The rights and remedies herein provided shall be cumulative and not exclusive of any rights or remedies provided by law.

Section 9.03.    Expenses; Indemnification. (a) The Borrower shall pay (i) all reasonable out‑of‑pocket expenses of the Administrative Agent, including reasonable fees and disbursements of one special counsel for the Administrative Agent, in connection with the preparation of this Agreement, any waiver or consent hereunder or any amendment hereof or any Default or alleged Default with respect to the Borrower hereunder and (ii) if an Event of Default with respect to the Borrower occurs, all reasonable out‑of‑pocket expenses incurred by the Administrative Agent or any Lender, including reasonable fees and disbursements of one primary counsel for the Administrative Agent and the Lenders (and (x) if necessary, a single firm of local counsel to the Administrative Agent and the Lenders in each appropriate jurisdiction and (y) solely in the case of any actual or potential conflict of interest, one additional counsel in each relevant jurisdiction to the affected Persons similarly situated), in connection with such Event of Default and collection and other enforcement proceedings resulting therefrom.

(b)    The Borrower agrees to indemnify the Administrative Agent and each Lender and the respective Related Parties of the foregoing (each an “Indemnitee”) and hold each Indemnitee harmless from and against any and all liabilities, losses, penalties, damages, costs and expenses of any kind, including, without limitation, the reasonable fees and disbursements of one counsel for

39

all Indemnitees taken as a whole and, in the case of any actual or potential conflict of interest, one additional counsel to each group of affected Indemnitees similarly situated taken as a whole, which may be incurred by such Indemnitee in connection with any investigative, administrative or judicial proceeding (whether or not such Indemnitee shall be designated a party thereto) relating to or arising out of this Agreement or any actual or proposed use of proceeds of Loans hereunder; provided that no Indemnitee shall have the right to be indemnified hereunder for such Indemnitee’s own gross negligence or willful misconduct as determined by a court of competent jurisdiction. This Section shall not apply to Taxes other than any Taxes that represent losses, claims, damages, etc. arising from any non-Tax claim.

(c)    To the fullest extent permitted by applicable law, the Borrower shall not assert, and hereby waives, any claim against any Indemnitee, on any theory of liability, for special, indirect, consequential or punitive damages (as opposed to direct or actual damages) arising out of, in connection with, or as a result of, this Agreement, or any agreement or instrument contemplated hereby, the transactions contemplated hereby or thereby, any Loan or the use of the proceeds thereof. No Indemnitee referred to in paragraph ‎(b) above shall be liable for any damages arising from the use by unintended recipients of any information or other materials distributed by it through telecommunications, electronic or other information transmission systems in connection with this Agreement or the transactions contemplated hereby or thereby.

Section 9.04.    Sharing of Set-offs. Each Lender agrees that if it shall, by exercising any right of set‑off or counterclaim or otherwise, receive payment of a proportion of the aggregate amount then due with respect to the Loans held by it which is greater than the proportion received by any other Lender in respect of the aggregate amount then due with respect to the Loans held by such other Lender, the Lender receiving such proportionately greater payment shall purchase such participations in the Loans held by the other Lenders, and such other adjustments shall be made, as may be required so that all such payments with respect to the Loans held by the Lenders shall be shared by the Lenders pro rata; provided that nothing in this Section shall impair the right of any Lender to exercise any right of set‑off or counterclaim it may have and to apply the amount subject to such exercise to the payment of indebtedness of the Borrower other than its indebtedness under this Agreement.

Section 9.05.    Amendments and Waivers. (a) Any provision of this Agreement or the Notes may be amended or waived if, but only if, such amendment or waiver is in writing and is signed by the Borrower and the Required Lenders (and, if the rights or duties of the Administrative Agent is affected thereby, by the Administrative Agent); provided that no such amendment or waiver shall (x) unless signed by each adversely affected Lender, (i) increase the Commitment of any Lender or subject any Lender to any additional obligation, (ii) reduce the principal of or rate of interest on any Loan or any interest thereon or any fees hereunder, (iii) postpone the date fixed for any payment of principal of or interest on any Loan or interest thereon or any fees hereunder or for termination of any Commitment, or (iv) change the provisions of ‎Section 9.04 or of any other provision of this Agreement providing for the ratable application of payments in respect of the Loans or (y) unless signed by all Lenders, change the definition of Required Lenders or the provisions of this ‎Section 9.05.

(b)    (i) If any representation or warranty in Article 4 of the Master Credit Facility, any covenant in Article 5 of the Master Credit Facility or any event of default in Article 6 of the Master Credit Facility and, in each case, any related definitions in the Master Credit Facility, is replaced, changed, amended, modified, supplemented or removed or (ii) any Default or Event of

40

Default (as such terms are defined in the Master Credit Facility) is waived (any of the foregoing in clauses (i) and (ii), a “Change”), regardless of whether the Master Credit Facility is replaced, refinanced, amended and restated, amended, modified or supplemented and regardless of whether any such Change occurs in the corresponding article or definitions, such Change shall be incorporated automatically into this Agreement, or in the case of a waiver will be applied automatically to this Agreement for the corresponding Default or Event of Default occurring hereunder, upon the later of (A) the effectiveness of such Change in the Master Credit Facility and (B) the 30th day after the Administrative Agent’s receipt of notice from the Borrower of such Change, provided that the Required Lenders hereunder do not notify the Borrower through the Administrative Agent within 30 days after the Administrative Agent’s receipt of such notice from the Borrower of their election (which may be made in their discretion) that such Change shall not be effective with respect to this Agreement; provided that no Change to the Master Credit Facility shall amend, waive, modify or impact the rights or remedies of the Lenders with respect to a Default or Event of Default under ‎Section 6.01(a) of this Agreement.

Section 9.06.    Successors and Assigns. (a) The provisions of this Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns and each Indemnitee, except that no Borrower may assign or otherwise transfer any of its rights under this Agreement without the prior written consent of all Lenders.

(b)    Any Lender may, with the consent (unless an Event of Default then exists) of the Borrower (such consent not to be unreasonably withheld or delayed), at any time grant to one or more banks or other institutions (each a “Participant”) participating interests in its Commitment or any or all of its Loans; provided that any Lender may, without the consent of the Borrower, at any time grant participating interests in its Commitment or any or all of its Loans to another Lender, an Approved Fund or an Affiliate of such transferor Lender. In the event of any such grant by a Lender of a participating interest to a Participant, whether or not upon notice to the Administrative Agent, such Lender shall remain responsible for the performance of its obligations hereunder, and the Borrower and the Administrative Agent shall continue to deal solely and directly with such Lender in connection with such Lender’s rights and obligations under this Agreement. Any agreement pursuant to which any Lender may grant such a participating interest shall provide that (A) such Participant agrees to be subject to ‎Section 8.06 as if it were an Assignee under paragraph ‎(c) of this ‎Section 9.06 or as if it were the Lender granting such participation and (B) such Lender shall retain the sole right and responsibility to enforce the obligations of the Borrower hereunder including, without limitation, the right to approve any amendment, modification or waiver of any provision of this Agreement; provided that such participation agreement may provide that such Lender will not agree to any modification, amendment or waiver of this Agreement described in clause (x)‎(i), (ii) or (iii)of ‎Section 9.05(a) without the consent of the Participant. The Borrower agrees that each Participant shall, to the extent provided in its participation agreement, be entitled to the benefits of ‎Article 8 with respect to its participating interest, subject to the performance by such Participant of the obligations of a Lender thereunder (it being understood that the documentation required under ‎Section 8.04 shall be delivered by the Participant to the participating Lender and the Participant agrees to be subject to the provisions of Sections ‎8.04(i), ‎8.04(j) and ‎8.06 as if it were an Assignee). In addition, each Lender that sells a participation agrees, at the Borrower’s request, to use reasonable efforts to cooperate with the Borrower to effectuate the provisions of ‎Section 8.06 with respect to any Participant. An assignment or other transfer which is not permitted by subsection ‎(c) or ‎(d) below shall be given effect for purposes of this Agreement only to the extent of a participating interest granted in accordance with this subsection ‎(b). Each Lender that sells a participation shall, acting

41

solely for this purpose as a non-fiduciary agent of the Borrower, maintain a register on which it enters the name and address of each Participant and the principal amounts (and stated interest) of each Participant’s interest in the Loans or other obligations hereunder or under any Note (the “Participant Register”); provided that no Lender shall have any obligation to disclose all or any portion of the Participant Register (including the identity of any Participant (other than for the consent requirements set forth in the first sentence of this ‎Section 9.06(b)) or any information relating to a Participant’s interest in any Commitments, Loans or its other obligations hereunder or under any Note) to any Person except to the extent that such disclosure is necessary to establish that such Commitment, Loan or other obligation is in registered form under Section 5f.103-1(c) of the United States Treasury Regulations. The entries in the Participant Register shall be conclusive absent manifest error, and such Lender shall treat each Person whose name is recorded in the Participant Register as the owner of such participation for all purposes of this Agreement notwithstanding any notice to the contrary. For the avoidance of doubt, the Administrative Agent (in its capacity as Administrative Agent) shall have no responsibility for maintaining a Participant Register.

(c)    Any Lender may at any time assign to one or more banks or other financial institutions (each an “Assignee”) other than (w) the Borrower, (x) a Subsidiary or Affiliate of the Borrower, (y) a Defaulting Lender or any Person who, upon becoming a Lender hereunder, would constitute a Defaulting Lender, or (z) a natural person (or a holding company, investment vehicle or trust for, or owned and operated for the primary benefit of, a natural person), all, or a proportionate part (equivalent to a Commitment of not less than $10,000,000 (unless the Borrower and the Administrative Agent shall otherwise agree)) of all, of its rights and obligations under this Agreement and its Note (if any), and such Assignee shall assume such rights and obligations, pursuant to an Assignment and Assumption Agreement in substantially the form of Exhibit D hereto executed by such Assignee and such transferor Lender, with (and only with and subject to) the prior written consent of the Administrative Agent (which shall not be unreasonably withheld or delayed) and, so long as no Event of Default has occurred and is continuing, the Borrower (which shall not be unreasonably withheld or delayed); provided that unless such assignment is of the entire right, title and interest of the transferor Lender hereunder, after making any such assignment such transferor Lender shall have a Commitment of at least $10,000,000 (unless the Borrower and the Administrative Agent shall otherwise agree). Upon execution and delivery of such instrument of assumption and payment by such Assignee to such transferor Lender of an amount equal to the purchase price agreed between such transferor Lender and such Assignee, such Assignee shall be a Lender party to this Agreement and shall have all the rights and obligations of a Lender with a Commitment as set forth in such instrument of assumption, and the transferor Lender shall be released from its obligations hereunder to a corresponding extent, and no further consent or action by any party shall be required. Upon the consummation of any assignment pursuant to this subsection ‎(c), the transferor Lender, the Administrative Agent and the Borrower shall make appropriate arrangements so that, if required by the Assignee, a Note(s) is issued to the Assignee. The Assignee shall, prior to the first date on which interest or fees are payable hereunder for its account, deliver to the Borrower and the Administrative Agent any certifications, forms or other documentation in accordance with ‎Section 8.04. All assignments (other than assignments to Affiliates) shall be subject to a transaction fee established by, and payable by the transferor Lender to, the Administrative Agent for its own account (which shall not exceed $3,500).

42

(d)    Any Lender may at any time assign all or any portion of its rights under this Agreement and its Note (if any) to a Federal Reserve Bank. No such assignment shall release the transferor Lender from its obligations hereunder or modify any such obligations.

(e)    No Assignee, Participant or other transferee of any Lender’s rights (including any Applicable Lending Office other than such Lender’s initial Applicable Lending Office) shall be entitled to receive any greater payment under ‎Section 8.03 or ‎8.04 than such Lender would have been entitled to receive with respect to the rights transferred, unless such transfer is made by reason of the provisions of ‎Section 8.02, ‎8.03 or ‎8.04 requiring such Lender to designate a different Applicable Lending Office under certain circumstances or at a time when the circumstances giving rise to such greater payment did not exist.

Section 9.07.    Collateral. Each of the Lenders represents to the Administrative Agent and each of the other Lenders that it in good faith is not relying upon any “margin stock” (as defined in Regulation U) as collateral in the extension or maintenance of the credit provided for in this Agreement.

Section 9.08.    Confidentiality. The Administrative Agent and each Lender (i) agrees to keep any information delivered or made available by the Borrower pursuant to this Agreement confidential from anyone other than persons employed or retained by such Lender and its Affiliates who are engaged in evaluating, approving, structuring or administering the credit facility contemplated hereby and (ii) further agrees on behalf of itself and, to the extent it has the power to do so, its Affiliates and agents, to keep all other information delivered or made available to it by the Borrower or Affiliate of the Borrower for other purposes which, (x) is marked confidential and is expressly made available subject to the terms of this section, and (y) is not otherwise subject to a confidentiality agreement, confidential from anyone other than persons employed or retained by such Lender and its Affiliates and agents who need to receive such information in furtherance of the engagement or matter pursuant to which the information is provided; provided that nothing herein shall prevent any Lender or, solely with respect to information disclosed in a manner set forth in clauses ‎(b) through ‎(g) and Error! Reference source not found.(k) in this ‎Section 9.08, any Affiliate of such Lender from disclosing such information, to the extent necessary under the circumstances under which such disclosure is required, (a) to any other Lender or the Administrative Agent, (b) upon the order of any court or administrative agency, (c) upon the request or demand of any regulatory agency or authority or self-regulatory body, (d) which had been publicly disclosed other than as a result of a disclosure by the Administrative Agent or any Lender prohibited by this Agreement or which had already been in the possession of any Lender or not acquired from the Borrower or persons known by the Lenders to be in breach of an obligation of confidentiality to the Borrower, (e) in connection with any litigation to which the Administrative Agent, any Lender or any Affiliate or their respective subsidiaries or Parent may be a party, (f) to the extent necessary in connection with the exercise of any remedy hereunder or other engagement or matter, (g) to such Lender’s, Affiliate’s or the Administrative Agent’s legal counsel and independent auditors, (h) subject to provisions substantially similar to those contained in this ‎Section 9.08, to any actual or proposed Participant or Assignee, (i) to any direct, indirect, actual or prospective counterparty (and its advisor) to any swap, derivative or securitization transaction related to the obligations under this Agreement, (j) on a confidential basis to the CUSIP Service Bureau or any similar agency in connection with the issuance and monitoring of CUSIP numbers with respect to the loans, (k) on a confidential basis to rating agencies in consultation and coordination with the Borrower, (l) for purposes of establishing a “due diligence” defense, (m) with the consent of the Borrower and (n) on a

43

confidential basis to any credit insurance provider requiring access to such information in connection with credit insurance for the benefit of the disclosing Lender.

Section 9.09.    Governing Law; Submission to Jurisdiction. This Agreement and each Note (if any) shall be construed in accordance with and governed by the law of the State of New York. The Borrower and each Lender Party hereby submits to the exclusive jurisdiction of the United States District Court for the Southern District of New York and of any New York State court sitting in New York County for purposes of all legal proceedings arising out of or relating to this Agreement or the transactions contemplated hereby. The Borrower and each Lender Party irrevocably waives, to the fullest extent permitted by law, any objection which it may now or hereafter have to the laying of the venue of any such proceeding brought in such a court and any claim that any such proceeding brought in such a court has been brought in an inconvenient forum.

Section 9.10.    Counterparts; Integration. This Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument. Delivery of an executed signature page of this Agreement by facsimile or electronic transmission shall be effective as delivery of a manually executed counterpart hereof. This Agreement constitutes the entire agreement and understanding among the parties hereto and supersedes any and all prior agreements and understandings, oral or written, relating to the subject matter hereof.

Section 9.11.    WAIVER OF JURY TRIAL. EACH OF THE BORROWER, THE ADMINISTRATIVE AGENT AND THE LENDERS, TO THE FULLEST EXTENT IT MAY EFFECTIVELY DO SO UNDER APPLICABLE LAW, HEREBY IRREVOCABLY WAIVES ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED HEREBY.

Section 9.12.    USA Patriot Act. Each Lender hereby notifies the Borrower that pursuant to the requirements of the USA Patriot Act, Title III of Pub. L. 107-56 (signed into law October 26, 2001) (the “Act”), it is required to obtain, verify and record information that identifies the Borrower, which information includes the name and address of the Borrower and other information that will allow such Lender to identify the Borrower in accordance with the Act.

Section 9.13.    [Reserved].

Section 9.14.    No Fiduciary Duty. The Borrower agrees that in connection with all aspects of the Loans contemplated by this Agreement and any communications in connection therewith, (i) the Borrower and its Subsidiaries, on the one hand, and the Administrative Agent, the Lenders and their respective affiliates, on the other hand, will have a business relationship that does not create, by implication or otherwise, any fiduciary duty on the part of the Administrative Agent, the Lenders or their respective affiliates, and no such duty will be deemed to have arisen in connection with any such transactions or communications and (ii) the Administrative Agent, the Lenders and their respective Affiliates may be engaged in a broad range of transactions that involve interests that differ from those of the Borrower and its Affiliates, and neither the Administrative Agent nor any Lender has any obligation to disclose any of such interests to the Borrower or any of its Affiliates.

44

Section 9.15.    Survival. Each party’s rights and obligations under Articles ‎7, ‎8 and ‎9 shall survive the resignation or replacement of the Administrative Agent or any assignment of rights by, or the replacement of, a Lender, the termination of the Commitments and the repayment, satisfaction or discharge of all obligations hereunder or under any Note and the termination of this Agreement.

Section 9.16.    Acknowledgment and Consent to Bail-In of EEA Financial Institutions. Notwithstanding anything to the contrary in any Loan Document or in any other agreement, arrangement or understanding among any such parties, each party hereto acknowledges that any liability of any EEA Financial Institution arising under any Loan Document, to the extent such liability is unsecured, may be subject to the write-down and conversion powers of an EEA Resolution Authority and agrees and consents to, and acknowledges and agrees to be bound by:

(a)    the application of any Write-Down and Conversion Powers by an EEA Resolution Authority to any such liabilities arising hereunder which may be payable to it by any party hereto that is an EEA Financial Institution; and

(b)    the effects of any Bail-in Action on any such liability, including, if applicable:

(i)    a reduction in full or in part or cancellation of any such liability;

(ii)    a conversion of all, or a portion of, such liability into shares or other instruments of ownership in such EEA Financial Institution, its parent undertaking, or a bridge institution that may be issued to it or otherwise conferred on it, and that such shares or other instruments of ownership will be accepted by it in lieu of any rights with respect to any such liability under this Agreement or any other Loan Document; or

(iii)    the variation of the terms of such liability in connection with the exercise of the write-down and conversion powers of any EEA Resolution Authority.

[SIGNATURE PAGES FOLLOW]

45

IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed by their respective authorized officers as of the day and year above first written.

PIEDMONT NATURAL GAS COMPANY, INC., as the Borrower.
By:
	Name:
	Title:

[Signature Page to Credit Agreement]

U.S. BANK NATIONAL ASSOCIATION, as a Lender and as Administrative Agent
By:
	Name:
	Title:

[Signature Page to Credit Agreement]

[LENDER], as a Lender
By:
	Name:
	Title:

[Signature Page to Credit Agreement]

COMMITMENT SCHEDULE

Lender	Total Commitments
U.S. Bank National Association	$70,000,000
Branch Banking and Trust Company	$70,000,000
Regions Bank	$70,000,000
PNC Bank, National Association	$40,000,000
The Bank of New York Mellon	$50,000,000
KeyBank, National Association	$50,000,000
TOTAL	$250,000,000350,000,000

EXHIBIT A

NOTE

New York, New York

______ __, 20__

For value received, Piedmont Natural Gas Company, Inc., a North Carolina corporation (the “Borrower”), promises to pay to [ ] (the “Lender”) or its registered assigns, for the account of its Applicable Lending Office, the unpaid principal amount of each Loan made by the Lender to the Borrower pursuant to the Credit Agreement referred to below on the date specified in the Credit Agreement. The Borrower promises to pay interest on the unpaid principal amount of each such Loan on the dates and at the rate or rates provided for in the Credit Agreement. All such payments of principal and interest shall be made in lawful money of the United States in Federal or other immediately available funds at the office of U.S. Bank National Association.

All Loans made by the Lender, the respective types and maturities thereof and all repayments of the principal thereof shall be recorded by the Lender, and the Lender, if the Lender so elects in connection with any transfer or enforcement of its Note, may endorse on the schedule attached hereto appropriate notations to evidence the foregoing information with respect to the Loans then outstanding; provided that the failure of the Lender to make any such recordation or endorsement shall not affect the obligations of the Borrower hereunder or under the Credit Agreement.

This note is one of the Notes referred to in the Term Loan Credit Agreement dated as of June 14, 2017 among Piedmont Natural Gas Company, Inc., the Lenders party thereto and U.S. Bank National Association, as Administrative Agent (as the same may be amended from time to time, the “Credit Agreement”). Terms defined in the Credit Agreement are used herein with the same meanings. Reference is made to the Credit Agreement for provisions for the prepayment hereof and the acceleration of the maturity hereof.

A-1

PIEDMONT NATURAL GAS COMPANY, INC.
By:
	Title:

A-2

Note (cont’d)

LOANS AND PAYMENTS OF PRINCIPAL

Date Amount of Loan Type of Loan Amount of Principal Repaid Maturity Date Notation Made By

A-3

EXHIBIT B

[RESERVED]

C-1

EXHIBIT C

[RESERVED]

C-1

EXHIBIT D

ASSIGNMENT AND ASSUMPTION AGREEMENT

AGREEMENT dated as of _________, 20__ among [ASSIGNOR] (the “Assignor”), [ASSIGNEE] (the “Assignee”), [PIEDMONT NATURAL GAS COMPANY, INC.] and U.S. BANK NATIONAL ASSOCIATION, as Administrative Agent (the “Administrative Agent”).

WITNESSETH

WHEREAS, this Assignment and Assumption Agreement (the “Agreement”) relates to the Term Loan Credit Agreement dated as of June 14, 2017 among Piedmont Natural Gas Company, Inc., the Assignor and the other Lenders party thereto, as Lenders and the Administrative Agent (the “Credit Agreement”);

WHEREAS, as provided under the Credit Agreement, the Assignor has a Commitment to make Loans to the Borrower in an aggregate principal amount at any time outstanding not to exceed $__________;

WHEREAS, Loans made to the Borrower by the Assignor under the Credit Agreement in the aggregate principal amount of $__________ are outstanding at the date hereof; and

WHEREAS, the Assignor proposes to assign to the Assignee all of the rights of the Assignor under the Credit Agreement in respect of a portion of its [Commitment /outstanding Loan] thereunder in an amount equal to $__________ (the “Assigned Amount”), and the Assignee proposes to accept assignment of such rights and assume the corresponding obligations from the Assignor on such terms;*

NOW, THEREFORE, in consideration of the foregoing and the mutual agreements contained herein, the parties hereto agree as follows:

SECTION 1.    Definitions. All capitalized terms not otherwise defined herein shall have the respective meanings set forth in the Credit Agreement.

SECTION 2.    Assignment. The Assignor hereby assigns and sells to the Assignee all of the rights of the Assignor under the Credit Agreement to the extent of the Assigned Amount, and the Assignee hereby accepts such assignment from the Assignor and assumes all of the obligations of the Assignor under the Credit Agreement to the extent of the Assigned Amount, including the purchase from the Assignor of the corresponding portion of the principal amount of the Loans made by the Assignor outstanding at the date hereof. Upon the execution and delivery hereof by the Assignor, the Assignee [,Piedmont Natural Gas Company, Inc.] and the Administrative Agent, and the payment of the amounts specified in Section 3 required to be paid on the date hereof (i) the Assignee shall, as of the date hereof, succeed to the rights and be obligated to perform the obligations of a Lender under the Credit Agreement with a Commitment in an amount equal to the Assigned Amount, and (ii) the Commitment of the Assignor shall, as of the date hereof, be reduced by a like amount and the Assignor released from its obligations under the Credit Agreement to the extent such obligations have been assumed by the Assignee. The assignment provided for herein shall be without recourse to the Assignor.

D-1

SECTION 3.    Payments. As consideration for the assignment and sale contemplated in Section 2 hereof, the Assignee shall pay to the Assignor on the date hereof in Federal funds the amount heretofore agreed between them.¹ Each of the Assignor and the Assignee hereby agrees that if it receives any amount under the Credit Agreement which is for the account of the other party hereto, it shall receive the same for the account of such other party to the extent of such other party’s interest therein and shall promptly pay the same to such other party.

SECTION 4.    Consent to Assignment. This Agreement is conditioned upon the consent of [Piedmont Natural Gas Company, Inc.,] and the Administrative Agent pursuant to ‎Section 9.06(c) of the Credit Agreement. The execution of this Agreement by [Piedmont Natural Gas Company, Inc.,] and the Administrative Agent is evidence of this consent. Pursuant to ‎Section 9.06(c) the Borrower agrees to execute and deliver a Note, if required by the Assignee, payable to the order of the Assignee to evidence the assignment and assumption provided for herein.

SECTION 5.    Non-reliance on Assignor. The Assignor makes no representation or warranty in connection with, and shall have no responsibility with respect to, the solvency, financial condition, or statements of the Borrower, or the validity and enforceability of the obligations of the Borrower in respect of the Credit Agreement or any Note. The Assignee acknowledges that it has, independently and without reliance on the Assignor, and based on such documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Agreement and will continue to be responsible for making its own independent appraisal of the business, affairs and financial condition of the Borrower.

SECTION 6.    Governing Law. This Agreement shall be governed by and construed in accordance with the laws of the State of New York.

SECTION 7.    Counterparts. This Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument.

SECTION 8.    Administrative Questionnaire. Attached is an Administrative Questionnaire duly completed by the Assignee.

¹ Amount should combine principal together with accrued interest and breakage

compensation, if any, to be paid by the Assignee. It may be preferable in an appropriate case to

specify these amounts generically or by formula rather than as a fixed sum.

D-2

IN WITNESS WHEREOF, the parties have caused this Agreement to be executed and delivered by their duly authorized officers as of the date first above written.

[ASSIGNOR]
By:
	Title:

[ASSIGNEE]
By:
	Title:

[PIEDMONT NATURAL GAS COMPANY, INC.]
By:
	Title:

[U.S. BANK NATIONAL ASSOCIATION] as Administrative Agent
By:
	Title:

D-3

EX-12

EXHIBIT 12

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES - DUKE ENERGY CORPORATION

The ratio of earnings to fixed charges is calculated using the Securities and Exchange Commission guidelines.

	Nine Months Ended September 30,		Years Ended December 31,
(in millions)	2018		2017		2016		2015		2014		2013
Earnings as defined for fixed charges calculation
Add:
Pretax income from continuing operations(a)	$	2,603	$	4,142	$	3,668	$	3,832	$	3,636	$	3,204
Fixed charges	1,772		2,205		2,170		1,859		1,871		1,886
Distributed income of equity investees	81		16		30		104		136		109
Deduct:
Interest capitalized	7		4		10		18		7		8
Total earnings	$	4,449	$	6,359	$	5,858	$	5,777	$	5,636	$	5,191
Fixed charges:
Interest on debt, including capitalized portions	$	1,695	$	2,104	$	2,066	$	1,733	$	1,733	$	1,760
Estimate of interest within rental expense	77		101		104		126		138		126
Total fixed charges	$	1,772	$	2,205	$	2,170	$	1,859	$	1,871	$	1,886
Ratio of earnings to fixed charges	2.5		2.9		2.7		3.1		3.0		2.8

(a)    Excludes amounts attributable to noncontrolling interests and income or loss from equity investees.

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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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: November 2, 2018

/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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

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 September 30, 2018, 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

November 2, 2018

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 31, 2018
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	Sep. 30, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		712,877,558
Trading Symbol	DUK
Entity Emerging Growth Company	false
Entity Small Business	false
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
Entity Emerging Growth Company	false
Entity Small Business	false
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
Entity Emerging Growth Company	false
Entity Small Business	false
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
Entity Emerging Growth Company	false
Entity Small Business	false
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
Entity Emerging Growth Company	false
Entity Small Business	false
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
Entity Emerging Growth Company	false
Entity Small Business	false
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
Entity Emerging Growth Company	false
Entity Small Business	false
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
Entity Emerging Growth Company	false
Entity Small Business	false

XML

Condensed Consolidated Statements of Operations and Comprehensive Income - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Operating Revenues
Regulated electric	$ 6,216	$ 6,091	$ 16,678	$ 16,122
Regulated natural gas	230	247	1,221	1,168
Nonregulated electric and other	182	144	507	476
Total operating revenues	6,628	6,482	18,406	17,766
Operating Expenses
Operation, maintenance and other	1,584	1,476	4,592	4,385
Depreciation and amortization	1,039	900	2,979	2,594
Property and other taxes	323	313	954	924
Impairment charges	124	207	339	216
Total operating expenses	5,059	4,827	14,505	13,374
Gains (Losses) on Sales of Other Assets and Other, net	10	6	(87)	24
Operating Income	1,579	1,661	3,814	4,416
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	37	36	49	101
Other income and expenses, net	131	122	327	358
Total other income and expenses	168	158	376	459
Interest Expense	517	498	1,550	1,475
Income From Continuing Operations Before Income Taxes	1,230	1,321	2,640	3,400
Income Tax Expense From Continuing Operations	168	364	449	1,035
Income From Continuing Operations	1,062	957	2,191	2,365
Income (Loss) From Discontinued Operations, net of tax	4	(2)	(1)	(4)
Net Income	1,066	955	2,190	2,361
Less: Net (Loss) Income Attributable to Noncontrolling Interests	(16)	1	(12)	5
Net Income Attributable to Duke Energy Corporation	1,082	954	2,202	2,356
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments	1		3	2
Net unrealized (losses) gains on cash flow hedges	(3)	2	10	(2)
Reclassification into earnings from cash flow hedges	6	(2)	5	3
Unrealized (losses) gains on available-for-sale securities		2	(5)	10
Other Comprehensive Income, net of tax	4	2	13	13
Comprehensive Income	1,070	957	2,203	2,374
Less: Comprehensive (Loss) Income Attributable to Noncontrolling Interests	(16)	1	(12)	5
Comprehensive Income Attributable to Duke Energy Corporation	$ 1,086	$ 956	$ 2,215	$ 2,369
Income from continuing operations attributable to Duke Energy Corporation common stockholders
Basic (usd per share)	$ 1.51	$ 1.36	$ 3.12	$ 3.37
Diluted (usd per share)	1.51	1.36	3.11	3.37
Loss from discontinued operations attributable to Duke Energy Corporation common stockholders
Basic (usd per share)				(0.01)
Diluted (usd per share)				(0.01)
Net income attributable to Duke Energy Corporation common stockholders
Basic (usd per share)	1.51	1.36	3.12	3.36
Diluted (usd per share)	$ 1.51	$ 1.36	$ 3.11	$ 3.36
Weighted average shares outstanding
Basic (shares)	713	700	705	700
Diluted (shares)	714	700	706	700
Duke Energy Carolinas [Member]
Operating Revenues
Total operating revenues	$ 2,090	$ 2,136	$ 5,525	$ 5,581
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	490	531	1,370	1,394
Operation, maintenance and other	514	494	1,464	1,472
Depreciation and amortization	305	281	866	804
Property and other taxes	67	67	214	206
Impairment charges	1		191
Total operating expenses	1,377	1,373	4,105	3,876
Gains (Losses) on Sales of Other Assets and Other, net			(1)
Operating Income	713	763	1,419	1,705
Other Income and Expenses
Total other income and expenses	34	40	108	140
Interest Expense	106	108	323	314
Income From Continuing Operations Before Income Taxes	641	695	1,204	1,531
Income Tax Expense From Continuing Operations	145	229	268	522
Net Income Attributable to Duke Energy Corporation	496	466	936	1,009
Other Comprehensive Income (Loss), net of tax
Reclassification into earnings from cash flow hedges			1	1
Other Comprehensive Income, net of tax			1	1
Comprehensive Income Attributable to Duke Energy Corporation	496	466	937	1,010
Progress Energy [Member]
Operating Revenues
Total operating revenues	3,045	2,864	8,119	7,435
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	1,148	1,031	3,019	2,588
Operation, maintenance and other	680	588	1,913	1,697
Depreciation and amortization	419	334	1,183	958
Property and other taxes	145	140	399	386
Impairment charges	1	135	34	137
Total operating expenses	2,393	2,228	6,548	5,766
Gains (Losses) on Sales of Other Assets and Other, net	11	5	23	19
Operating Income	663	641	1,594	1,688
Other Income and Expenses
Total other income and expenses	51	36	128	112
Interest Expense	214	193	626	595
Income From Continuing Operations Before Income Taxes	500	484	1,096	1,205
Income Tax Expense From Continuing Operations	94	141	186	384
Net Income	406	343	910	821
Less: Net (Loss) Income Attributable to Noncontrolling Interests	2	2	6	7
Net Income Attributable to Duke Energy Corporation	404	341	904	814
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments		3	2	5
Net unrealized (losses) gains on cash flow hedges	2	(2)	5	4
Unrealized (losses) gains on available-for-sale securities		1	(1)	3
Other Comprehensive Income, net of tax	2	2	6	12
Comprehensive Income	408	345	916	833
Less: Comprehensive (Loss) Income Attributable to Noncontrolling Interests	2	2	6	7
Comprehensive Income Attributable to Duke Energy Corporation	406	343	910	826
Duke Energy Progress [Member]
Operating Revenues
Total operating revenues	1,582	1,460	4,333	3,878
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	535	475	1,452	1,214
Operation, maintenance and other	431	365	1,187	1,069
Depreciation and amortization	253	182	723	536
Property and other taxes	40	40	115	120
Impairment charges			33
Total operating expenses	1,259	1,062	3,510	2,939
Gains (Losses) on Sales of Other Assets and Other, net	7		9	3
Operating Income	330	398	832	942
Other Income and Expenses
Total other income and expenses	24	27	61	84
Interest Expense	82	65	241	217
Income From Continuing Operations Before Income Taxes	272	360	652	809
Income Tax Expense From Continuing Operations	56	114	120	262
Net Income Attributable to Duke Energy Corporation	216	246	532	547
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Attributable to Duke Energy Corporation	216	246	532	547
Duke Energy Florida [Member]
Operating Revenues
Total operating revenues	1,462	1,401	3,780	3,551
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	614	557	1,567	1,374
Operation, maintenance and other	245	220	719	623
Depreciation and amortization	166	154	460	423
Property and other taxes	105	99	284	265
Impairment charges	1	135	1	137
Total operating expenses	1,131	1,165	3,031	2,822
Operating Income	331	236	749	729
Other Income and Expenses
Total other income and expenses	28	19	75	58
Interest Expense	73	71	210	211
Income From Continuing Operations Before Income Taxes	286	184	614	576
Income Tax Expense From Continuing Operations	43	64	100	208
Net Income Attributable to Duke Energy Corporation	243	120	514	368
Other Comprehensive Income (Loss), net of tax
Unrealized (losses) gains on available-for-sale securities		1	(1)	3
Other Comprehensive Income, net of tax			(1)	3
Comprehensive Income Attributable to Duke Energy Corporation	243	121	513	371
Duke Energy Ohio [Member]
Operating Revenues
Regulated electric	373	371	1,055	1,036
Regulated natural gas	84	90	361	360
Nonregulated electric and other	12	10	36	30
Total operating revenues	469	471	1,452	1,426
Operating Expenses
Operation, maintenance and other	76	125	337	388
Depreciation and amortization	64	63	196	193
Property and other taxes	73	65	218	204
Impairment charges				1
Total operating expenses	330	371	1,151	1,180
Gains (Losses) on Sales of Other Assets and Other, net		1	(106)	1
Operating Income	139	101	195	247
Other Income and Expenses
Total other income and expenses	3	5	17	15
Interest Expense	23	22	68	67
Income From Continuing Operations Before Income Taxes	119	84	144	195
Income Tax Expense From Continuing Operations	19	28	23	67
Income From Continuing Operations	100	56	121	128
Income (Loss) From Discontinued Operations, net of tax		(1)		(1)
Net Income				127
Net Income Attributable to Duke Energy Corporation	100	55	121	127
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Attributable to Duke Energy Corporation	100	55	121	127
Duke Energy Indiana [Member]
Operating Revenues
Total operating revenues	819	802	2,288	2,302
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	272	259	730	744
Operation, maintenance and other	198	177	576	546
Depreciation and amortization	130	120	386	336
Property and other taxes	16	19	56	56
Impairment charges	30		30
Total operating expenses	646	575	1,778	1,682
Gains (Losses) on Sales of Other Assets and Other, net		1		1
Operating Income	173	228	510	621
Other Income and Expenses
Total other income and expenses	23	12	36	32
Interest Expense	42	44	125	132
Income From Continuing Operations Before Income Taxes	154	196	421	521
Income Tax Expense From Continuing Operations	35	75	104	203
Net Income Attributable to Duke Energy Corporation	119	121	317	318
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Attributable to Duke Energy Corporation	119	121	317	318
Piedmont Natural Gas [Member]
Operating Revenues
Total operating revenues	172	183	940	884
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	54	63	387	333
Operation, maintenance and other	85	73	252	226
Depreciation and amortization	40	38	118	109
Property and other taxes	12	13	36	38
Impairment charges				7
Total operating expenses	191	187	793	713
Operating Income	(19)	(4)	147	171
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	3	3	6	8
Other income and expenses, net	3	0	9	(1)
Total other income and expenses	6	3	15	7
Interest Expense	19	20	60	59
Income From Continuing Operations Before Income Taxes	(32)	(21)	102	119
Income Tax Expense From Continuing Operations	(11)	(10)	21	43
Net Income Attributable to Duke Energy Corporation	(21)	(11)	81	76
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Attributable to Duke Energy Corporation	(21)	(11)	81	76
Electricity, US Regulated [Member] | Duke Energy Ohio [Member]
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	99	100	284	283
Electricity, Nonregulated [Member] | Duke Energy Ohio [Member]
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	14	13	43	42
Electricity [Member]
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	1,931	1,863	5,181	4,853
Natural Gas [Member]
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	58	68	460	402
Natural Gas [Member] | Duke Energy Ohio [Member]
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	$ 4	$ 5	$ 73	$ 69

XML

Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income	$ 1,066	$ 955	$ 2,190	$ 2,361
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	1		3	2
Net unrealized (losses) gains on cash flow hedges	(3)	2	10	(2)
Reclassification into earnings from cash flow hedges	6	(2)	5	3
Unrealized (losses) gains on available-for-sale securities		2	(5)	10
Other Comprehensive Income, net of tax	4	2	13	13
Comprehensive Income	1,070	957	2,203	2,374
Less: Comprehensive (Loss) Income Attributable to Noncontrolling Interests	(16)	1	(12)	5
Comprehensive Income Attributable to Duke Energy Corporation	$ 1,086	$ 956	$ 2,215	$ 2,369

XML

Condensed Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents	$ 303	$ 358
Receivables (net of allowance for doubtful accounts)	682	779
Receivables of VIEs (net of allowance for doubtful accounts)	2,397	1,995
Inventory	3,140	3,250
Regulatory assets (includes amounts related to VIEs)	1,906	1,437
Other	1,092	634
Total current assets	9,520	8,453
Property, Plant and Equipment
Cost	132,677	127,507
Accumulated depreciation and amortization	(43,200)	(41,537)
Generation facilities to be retired, net	388	421
Net property, plant and equipment	89,865	86,391
Other Noncurrent Assets
Goodwill	19,303	19,396
Regulatory assets	12,616	12,442
Nuclear decommissioning trust funds	7,421	7,097
Investments in equity method unconsolidated affiliates	1,328	1,175
Other	3,112	2,960
Total other noncurrent assets	43,780	43,070
Total Assets	143,165	137,914
Current Liabilities
Accounts payable	3,234	3,043
Notes payable and commercial paper	2,891	2,163
Taxes accrued	674	551
Interest accrued	557	525
Current maturities of long-term debt (includes amounts related to VIEs)	3,455	3,244
Asset retirement obligations	902	689
Regulatory liabilities	506	402
Other	1,703	1,865
Total current liabilities	13,922	12,482
Long-Term Debt (includes amounts related to VIEs)	50,507	49,035
Other Noncurrent Liabilities
Deferred income taxes	7,765	6,621
Asset retirement obligations	9,354	9,486
Regulatory liabilities	15,587	15,330
Accrued pension and other post-retirement benefit costs	1,001	1,103
Investment tax credits	539	539
Other	1,477	1,581
Total other noncurrent liabilities	35,723	34,660
Commitments and Contingencies
Equity
Common stock	1	1
Additional paid-in capital	39,747	38,792
Retained earnings	3,313	3,013
Accumulated other comprehensive loss	(66)	(67)
Total Duke Energy Corporation stockholders' equity	42,995	41,739
Noncontrolling interests	18	(2)
Total equity	43,013	41,737
Total Liabilities and Equity	143,165	137,914
Duke Energy Carolinas [Member]
Current Assets
Cash and cash equivalents	27	16
Receivables (net of allowance for doubtful accounts)	203	200
Receivables of VIEs (net of allowance for doubtful accounts)	795	640
Receivables from affiliated companies	158	95
Inventory	976	971
Regulatory assets (includes amounts related to VIEs)	435	299
Other	55	19
Total current assets	2,649	2,240
Property, Plant and Equipment
Cost	44,086	42,939
Accumulated depreciation and amortization	(15,536)	(15,063)
Net property, plant and equipment	28,550	27,876
Other Noncurrent Assets
Regulatory assets	3,188	2,853
Nuclear decommissioning trust funds	3,943	3,772
Other	1,009	979
Total other noncurrent assets	8,140	7,604
Total Assets	39,339	37,720
Current Liabilities
Accounts payable	888	842
Accounts payable to affiliated companies	142	209
Notes payable to affiliated companies	804	104
Taxes accrued	189	234
Interest accrued	141	108
Current maturities of long-term debt (includes amounts related to VIEs)	506	1,205
Asset retirement obligations	292	337
Regulatory liabilities	144	126
Other	419	486
Total current liabilities	3,525	3,651
Long-Term Debt (includes amounts related to VIEs)	9,589	8,598
Long-Term Debt Payable to Affiliated Companies	300	300
Other Noncurrent Liabilities
Deferred income taxes	3,639	3,413
Asset retirement obligations	3,420	3,273
Regulatory liabilities	6,480	6,231
Accrued pension and other post-retirement benefit costs	97	95
Investment tax credits	233	232
Other	508	566
Total other noncurrent liabilities	14,377	13,810
Commitments and Contingencies
Equity
Member's equity	11,554	11,368
Accumulated other comprehensive loss	(6)	(7)
Total member's equity	11,548	11,361
Total Liabilities and Equity	39,339	37,720
Progress Energy [Member]
Current Assets
Cash and cash equivalents	43	40
Receivables (net of allowance for doubtful accounts)	131	123
Receivables of VIEs (net of allowance for doubtful accounts)	1,098	780
Receivables from affiliated companies	15	31
Notes receivable from affiliated companies	445	240
Inventory	1,473	1,592
Regulatory assets (includes amounts related to VIEs)	1,122	741
Other	256	334
Total current assets	4,583	3,881
Property, Plant and Equipment
Cost	49,822	47,323
Accumulated depreciation and amortization	(16,652)	(15,857)
Generation facilities to be retired, net	388	421
Net property, plant and equipment	33,558	31,887
Other Noncurrent Assets
Goodwill	3,655	3,655
Regulatory assets	5,987	6,010
Nuclear decommissioning trust funds	3,477	3,324
Other	1,019	931
Total other noncurrent assets	14,138	13,920
Total Assets	52,279	49,688
Current Liabilities
Accounts payable	1,301	1,006
Accounts payable to affiliated companies	327	251
Notes payable to affiliated companies	794	805
Taxes accrued	244	101
Interest accrued	228	212
Current maturities of long-term debt (includes amounts related to VIEs)	1,322	771
Asset retirement obligations	475	295
Regulatory liabilities	246	213
Other	672	729
Total current liabilities	5,609	4,383
Long-Term Debt (includes amounts related to VIEs)	17,440	16,916
Long-Term Debt Payable to Affiliated Companies	150	150
Other Noncurrent Liabilities
Deferred income taxes	3,947	3,502
Asset retirement obligations	4,960	5,119
Regulatory liabilities	5,275	5,306
Accrued pension and other post-retirement benefit costs	513	545
Other	255	302
Total other noncurrent liabilities	14,950	14,774
Commitments and Contingencies
Equity
Additional paid-in capital	9,143	9,143
Retained earnings	5,009	4,350
Accumulated other comprehensive loss	(24)	(25)
Total Duke Energy Corporation stockholders' equity	14,128	13,468
Noncontrolling interests	2	(3)
Total equity	14,130	13,465
Total Liabilities and Equity	52,279	49,688
Duke Energy Progress [Member]
Current Assets
Cash and cash equivalents	17	20
Receivables (net of allowance for doubtful accounts)	34	56
Receivables of VIEs (net of allowance for doubtful accounts)	635	459
Receivables from affiliated companies	6	3
Notes receivable from affiliated companies	52
Inventory	956	1,017
Regulatory assets (includes amounts related to VIEs)	677	352
Other	112	97
Total current assets	2,489	2,004
Property, Plant and Equipment
Cost	31,091	29,583
Accumulated depreciation and amortization	(11,484)	(10,903)
Generation facilities to be retired, net	388	421
Net property, plant and equipment	19,995	19,101
Other Noncurrent Assets
Regulatory assets	3,822	3,507
Nuclear decommissioning trust funds	2,744	2,588
Other	653	599
Total other noncurrent assets	7,219	6,694
Total Assets	29,703	27,799
Current Liabilities
Accounts payable	808	402
Accounts payable to affiliated companies	252	179
Notes payable to affiliated companies		240
Taxes accrued	92	64
Interest accrued	100	102
Current maturities of long-term debt (includes amounts related to VIEs)	603	3
Asset retirement obligations	470	295
Regulatory liabilities	162	139
Other	353	376
Total current liabilities	2,840	1,800
Long-Term Debt (includes amounts related to VIEs)	7,401	7,204
Long-Term Debt Payable to Affiliated Companies	150	150
Other Noncurrent Liabilities
Deferred income taxes	2,076	1,883
Asset retirement obligations	4,371	4,378
Regulatory liabilities	4,128	3,999
Accrued pension and other post-retirement benefit costs	240	248
Investment tax credits	143	143
Other	48	45
Total other noncurrent liabilities	11,006	10,696
Commitments and Contingencies
Equity
Total member's equity	8,306	7,949
Total Liabilities and Equity	29,703	27,799
Duke Energy Florida [Member]
Current Assets
Cash and cash equivalents	20	13
Receivables (net of allowance for doubtful accounts)	95	65
Receivables of VIEs (net of allowance for doubtful accounts)	463	321
Receivables from affiliated companies	20	2
Notes receivable from affiliated companies	393	313
Inventory	517	574
Regulatory assets (includes amounts related to VIEs)	445	389
Other	27	86
Total current assets	1,980	1,763
Property, Plant and Equipment
Cost	18,722	17,730
Accumulated depreciation and amortization	(5,161)	(4,947)
Net property, plant and equipment	13,561	12,783
Other Noncurrent Assets
Regulatory assets	2,165	2,503
Nuclear decommissioning trust funds	734	736
Other	315	284
Total other noncurrent assets	3,214	3,523
Total Assets	18,755	18,069
Current Liabilities
Accounts payable	492	602
Accounts payable to affiliated companies	83	74
Taxes accrued	232	34
Interest accrued	74	56
Current maturities of long-term debt (includes amounts related to VIEs)	269	768
Asset retirement obligations	4
Regulatory liabilities	84	74
Other	315	334
Total current liabilities	1,553	1,942
Long-Term Debt (includes amounts related to VIEs)	7,102	6,327
Other Noncurrent Liabilities
Deferred income taxes	2,012	1,761
Asset retirement obligations	589	742
Regulatory liabilities	1,146	1,307
Accrued pension and other post-retirement benefit costs	241	264
Other	56	108
Total other noncurrent liabilities	4,044	4,182
Commitments and Contingencies
Equity
Member's equity	6,058	5,614
Accumulated other comprehensive loss	(2)	4
Total member's equity	6,056	5,618
Total Liabilities and Equity	18,755	18,069
Duke Energy Ohio [Member]
Current Assets
Cash and cash equivalents	7	12
Receivables (net of allowance for doubtful accounts)	112	68
Receivables from affiliated companies	71	133
Notes receivable from affiliated companies		14
Inventory	135	133
Regulatory assets (includes amounts related to VIEs)	41	49
Other	28	39
Total current assets	394	448
Property, Plant and Equipment
Cost	9,176	8,732
Accumulated depreciation and amortization	(2,683)	(2,691)
Net property, plant and equipment	6,493	6,041
Other Noncurrent Assets
Goodwill	920	920
Regulatory assets	427	445
Other	62	21
Total other noncurrent assets	1,409	1,386
Total Assets	8,296	7,875
Current Liabilities
Accounts payable	251	313
Accounts payable to affiliated companies	54	62
Notes payable to affiliated companies	268	29
Taxes accrued	159	190
Interest accrued	34	21
Current maturities of long-term debt (includes amounts related to VIEs)	452	3
Asset retirement obligations	7	3
Regulatory liabilities	57	36
Other	67	71
Total current liabilities	1,349	728
Long-Term Debt (includes amounts related to VIEs)	1,589	2,039
Long-Term Debt Payable to Affiliated Companies	25	25
Other Noncurrent Liabilities
Deferred income taxes	790	781
Asset retirement obligations	91	81
Regulatory liabilities	865	891
Accrued pension and other post-retirement benefit costs	84	59
Other	113	108
Total other noncurrent liabilities	1,943	1,920
Equity
Common stock	762	762
Additional paid-in capital	2,776	2,670
Retained earnings	(148)	(269)
Total Duke Energy Corporation stockholders' equity	3,390	3,163
Total Liabilities and Equity	8,296	7,875
Duke Energy Indiana [Member]
Current Assets
Cash and cash equivalents	17	9
Receivables (net of allowance for doubtful accounts)	56	57
Receivables from affiliated companies	98	125
Inventory	434	450
Regulatory assets (includes amounts related to VIEs)	190	165
Other	64	30
Total current assets	859	836
Property, Plant and Equipment
Cost	15,298	14,948
Accumulated depreciation and amortization	(4,831)	(4,662)
Net property, plant and equipment	10,467	10,286
Other Noncurrent Assets
Regulatory assets	950	978
Other	233	189
Total other noncurrent assets	1,183	1,167
Total Assets	12,509	12,289
Current Liabilities
Accounts payable	177	196
Accounts payable to affiliated companies	72	78
Notes payable to affiliated companies	201	161
Taxes accrued	44	95
Interest accrued	54	57
Current maturities of long-term debt (includes amounts related to VIEs)	62	3
Asset retirement obligations	128	54
Regulatory liabilities	25	24
Other	109	104
Total current liabilities	872	772
Long-Term Debt (includes amounts related to VIEs)	3,571	3,630
Long-Term Debt Payable to Affiliated Companies	150	150
Other Noncurrent Liabilities
Deferred income taxes	988	925
Asset retirement obligations	616	727
Regulatory liabilities	1,761	1,723
Accrued pension and other post-retirement benefit costs	110	76
Investment tax credits	147	147
Other	31	18
Total other noncurrent liabilities	3,653	3,616
Equity
Total member's equity	4,263	4,121
Total Liabilities and Equity	12,509	12,289
Piedmont Natural Gas [Member]
Current Assets
Cash and cash equivalents	6	19
Receivables (net of allowance for doubtful accounts)	83	275
Receivables from affiliated companies	10	7
Notes receivable from affiliated companies	11
Inventory	51	66
Regulatory assets (includes amounts related to VIEs)	38	95
Other	48	52
Total current assets	247	514
Property, Plant and Equipment
Cost	7,265	6,725
Accumulated depreciation and amortization	(1,553)	(1,479)
Net property, plant and equipment	5,712	5,246
Other Noncurrent Assets
Goodwill	49	49
Regulatory assets	305	283
Investments in equity method unconsolidated affiliates	63	61
Other	65	65
Total other noncurrent assets	482	458
Total Assets	6,441	6,218
Current Liabilities
Accounts payable	131	125
Accounts payable to affiliated companies	27	13
Notes payable to affiliated companies		364
Taxes accrued	31	19
Interest accrued	25	31
Current maturities of long-term debt (includes amounts related to VIEs)	350	250
Regulatory liabilities	34	3
Other	51	69
Total current liabilities	649	874
Long-Term Debt (includes amounts related to VIEs)	1,788	1,787
Other Noncurrent Liabilities
Deferred income taxes	586	564
Asset retirement obligations	15	15
Regulatory liabilities	1,171	1,141
Accrued pension and other post-retirement benefit costs	3	5
Other	186	170
Total other noncurrent liabilities	1,961	1,895
Commitments and Contingencies
Equity
Common stock	1,160	860
Retained earnings	883	802
Total Duke Energy Corporation stockholders' equity	2,043	1,662
Total Liabilities and Equity	$ 6,441	$ 6,218

XML

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Allowance for doubtful accounts - receivables	$ 17	$ 14
Regulatory assets, current	1,906	1,437
Other, current assets	1,092	634
Regulatory assets, noncurrent	12,616	12,442
Current maturities of long-term debt	3,455	3,244
Long-Term Debt	$ 50,507	$ 49,035
Common stock, par value	$ 0.001	$ 0.001
Common stock, shares authorized	2,000,000,000	2,000,000,000
Common stock, shares outstanding	713,000,000	700,000,000
Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	$ 55	$ 54
Regulatory assets, current	52	51
Regulatory assets, noncurrent	1,055	1,091
Current maturities of long-term debt	228	225
Long-Term Debt	4,015	4,306
Duke Energy Carolinas [Member]
Allowance for doubtful accounts - receivables	2	2
Regulatory assets, current	435	299
Other, current assets	55	19
Regulatory assets, noncurrent	3,188	2,853
Current maturities of long-term debt	506	1,205
Long-Term Debt	9,589	8,598
Duke Energy Carolinas [Member] | Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	7	7
Progress Energy [Member]
Allowance for doubtful accounts - receivables	5	4
Regulatory assets, current	1,122	741
Other, current assets	256	334
Regulatory assets, noncurrent	5,987	6,010
Current maturities of long-term debt	1,322	771
Long-Term Debt	$ 17,440	$ 16,916
Common stock, par 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 - receivables of VIEs	$ 8	$ 7
Regulatory assets, current	52	51
Regulatory assets, noncurrent	1,055	1,091
Current maturities of long-term debt	53	53
Long-Term Debt	1,636	1,689
Duke Energy Progress [Member]
Allowance for doubtful accounts - receivables	2	1
Regulatory assets, current	677	352
Other, current assets	112	97
Regulatory assets, noncurrent	3,822	3,507
Current maturities of long-term debt	603	3
Long-Term Debt	7,401	7,204
Duke Energy Progress [Member] | Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	5	5
Duke Energy Florida [Member]
Allowance for doubtful accounts - receivables	3	3
Regulatory assets, current	445	389
Other, current assets	27	86
Regulatory assets, noncurrent	2,165	2,503
Current maturities of long-term debt	269	768
Long-Term Debt	7,102	6,327
Duke Energy Florida [Member] | Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	3	2
Regulatory assets, current	52	51
Other, current assets	14	40
Regulatory assets, noncurrent	1,055	1,091
Current maturities of long-term debt	53	53
Long-Term Debt	1,336	1,389
Duke Energy Ohio [Member]
Allowance for doubtful accounts - receivables	3	3
Regulatory assets, current	41	49
Other, current assets	28	39
Regulatory assets, noncurrent	427	445
Current maturities of long-term debt	452	3
Long-Term Debt	$ 1,589	$ 2,039
Common stock, par value	$ 8.50	$ 8.50
Common stock, shares authorized	120,000,000	120,000,000
Common stock, shares outstanding	90,000,000	90,000,000
Duke Energy Indiana [Member]
Allowance for doubtful accounts - receivables	$ 2	$ 2
Regulatory assets, current	190	165
Other, current assets	64	30
Regulatory assets, noncurrent	950	978
Current maturities of long-term debt	62	3
Long-Term Debt	3,571	3,630
Piedmont Natural Gas [Member]
Allowance for doubtful accounts - receivables	1	2
Regulatory assets, current	38	95
Other, current assets	48	52
Regulatory assets, noncurrent	305	283
Current maturities of long-term debt	350	250
Long-Term Debt	$ 1,788	$ 1,787
Common stock, shares authorized	100	100
Common stock, shares outstanding	100	100

XML

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	$ 2,190	$ 2,361
Net income (attributable to parent)	2,202	2,356
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	3,447	2,990
Equity component of AFUDC	(175)	(175)
Losses (gains) on sales of other assets	87	(28)
Impairment charges	339	216
Deferred income taxes	1,099	1,016
Equity in earnings of unconsolidated affiliates	(49)	(101)
Accrued pension and other post-retirement benefit costs	46	19
Contributions to qualified pension plans	(141)	(8)
Payments for asset retirement obligations	(389)	(420)
Payment for disposal of other assets	(105)
Other rate case adjustments	37
Provision for rate refunds	375
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	15	4
Receivables	(288)	80
Inventory	104	248
Other current assets	(648)	(210)
Increase (decrease) in
Accounts payable	389	(554)
Taxes accrued	122	233
Other current liabilities	(180)	(532)
Other assets	(585)	(159)
Other liabilities	(23)	(2)
Net cash provided by operating activities	5,667	4,978
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(6,752)	(5,841)
Contributions to equity method investments	(298)	(370)
Purchases of debt and equity securities	(2,763)	(3,170)
Proceeds from sales and maturities of debt and equity securities	2,718	3,199
Other	(175)	(149)
Net cash used in investing activities	(7,270)	(6,331)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	4,110	5,710
Proceeds from the issuance of common stock	834
Payments for the redemption of long-term debt	(2,278)	(2,035)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	243	265
Payments for the redemption of short-term debt with original maturities greater than 90 days	(207)	(237)
Notes payable and commercial paper	638	(647)
Dividends paid	(1,835)	(1,825)
Other	42	8
Net cash provided by financing activities	1,547	1,239
Net decrease in cash, cash equivalents and restricted cash	(56)	(114)
Cash, cash equivalents and restricted cash at beginning of period	505	541
Cash, cash equivalents and restricted cash at end of period	449	427
Cash and cash equivalents at beginning of period	358
Cash and cash equivalents at end of period	303
Significant non-cash transactions:
Accrued capital expenditures	1,016	740
Non-cash dividends	79
Duke Energy Carolinas [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	936	1,009
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,084	1,051
Equity component of AFUDC	(57)	(79)
Losses (gains) on sales of other assets	1
Impairment charges	191
Deferred income taxes	266	330
Accrued pension and other post-retirement benefit costs	3
Contributions to qualified pension plans	(46)
Payments for asset retirement obligations	(174)	(201)
Provision for rate refunds	163
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	2	1
Receivables	(154)	(40)
Receivable from affiliated companies	(63)	17
Inventory	(11)	50
Other current assets	(54)	8
Increase (decrease) in
Accounts payable	69	(78)
Accounts payable to affiliated companies	(67)	(88)
Taxes accrued	(47)	225
Other current liabilities	(129)	(149)
Other assets	18	(18)
Other liabilities	(47)	(26)
Net cash provided by operating activities	1,884	2,012
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,006)	(1,747)
Purchases of debt and equity securities	(1,386)	(1,660)
Proceeds from sales and maturities of debt and equity securities	1,386	1,664
Notes receivable from affiliated companies		66
Other	(103)	(58)
Net cash used in investing activities	(2,109)	(1,735)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	991
Payments for the redemption of long-term debt	(704)	(115)
Notes payable to affiliated companies	700	468
Distributions to parent	(750)	(625)
Other	(1)	(1)
Net cash provided by financing activities	236	(273)
Net increase (decrease) in cash and cash equivalents	11	4
Cash and cash equivalents at beginning of period	16	14
Cash and cash equivalents at end of period	27	18
Significant non-cash transactions:
Accrued capital expenditures	299	292
Progress Energy [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	910	821
Net income (attributable to parent)	904	814
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,458	1,130
Equity component of AFUDC	(80)	(68)
Losses (gains) on sales of other assets	(23)	(20)
Impairment charges	34	137
Deferred income taxes	342	651
Accrued pension and other post-retirement benefit costs	18	(9)
Contributions to qualified pension plans	(45)
Payments for asset retirement obligations	(164)	(190)
Other rate case adjustments	37
Provision for rate refunds	101
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	14	1
Receivables	(316)	(182)
Receivable from affiliated companies	16	102
Inventory	119	126
Other current assets	(156)	(312)
Increase (decrease) in
Accounts payable	427	(281)
Accounts payable to affiliated companies	76	(59)
Taxes accrued	143	143
Other current liabilities	(28)	(184)
Other assets	(668)	(100)
Other liabilities	(34)	(85)
Net cash provided by operating activities	2,181	1,621
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,689)	(2,419)
Purchases of debt and equity securities	(1,216)	(1,393)
Proceeds from sales and maturities of debt and equity securities	1,225	1,411
Net proceeds from the sales of other assets	20
Notes receivable from affiliated companies	(205)	(90)
Other	(142)	(36)
Net cash used in investing activities	(3,007)	(2,527)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,785	1,720
Payments for the redemption of long-term debt	(719)	(611)
Notes payable to affiliated companies	(11)	(129)
Dividends to parent	(250)	(125)
Other	(3)	(3)
Net cash provided by financing activities	802	852
Net decrease in cash, cash equivalents and restricted cash	(24)	(54)
Cash, cash equivalents and restricted cash at beginning of period	87	110
Cash, cash equivalents and restricted cash at end of period	63	56
Cash and cash equivalents at beginning of period	40
Cash and cash equivalents at end of period	43
Significant non-cash transactions:
Accrued capital expenditures	441	174
Equitization of certain notes payable to affiliates		1,047
Dividend to parent related to a legal entity restructuring		547
Duke Energy Progress [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	532	547
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	869	691
Equity component of AFUDC	(41)	(35)
Losses (gains) on sales of other assets	(9)	(4)
Impairment charges	33
Deferred income taxes	187	287
Accrued pension and other post-retirement benefit costs	11	(15)
Contributions to qualified pension plans	(25)
Payments for asset retirement obligations	(133)	(149)
Other rate case adjustments	37
Provision for rate refunds	101
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3	(2)
Receivables	(154)	(47)
Receivable from affiliated companies	(3)	(3)
Inventory	62	52
Other current assets	(239)	(34)
Increase (decrease) in
Accounts payable	325	(286)
Accounts payable to affiliated companies	73	(20)
Taxes accrued	28	33
Other current liabilities	(27)	(139)
Other assets	(358)	(49)
Other liabilities	11	(9)
Net cash provided by operating activities	1,283	818
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,526)	(1,247)
Purchases of debt and equity securities	(831)	(995)
Proceeds from sales and maturities of debt and equity securities	807	974
Net proceeds from the sales of other assets	20
Notes receivable from affiliated companies	(52)	64
Other	(82)	(26)
Net cash used in investing activities	(1,664)	(1,230)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	796	812
Payments for the redemption of long-term debt	(2)	(270)
Notes payable to affiliated companies	(240)
Dividends to parent	(175)	(125)
Other	(1)	(1)
Net cash provided by financing activities	378	416
Net increase (decrease) in cash and cash equivalents	(3)	4
Cash and cash equivalents at beginning of period	20	11
Cash and cash equivalents at end of period	17	15
Significant non-cash transactions:
Accrued capital expenditures	261	116
Duke Energy Florida [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	514	368
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	581	431
Equity component of AFUDC	(40)	(33)
Impairment charges	1	137
Deferred income taxes	169	366
Accrued pension and other post-retirement benefit costs	4	3
Contributions to qualified pension plans	(20)
Payments for asset retirement obligations	(31)	(41)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	7	3
Receivables	(163)	(140)
Receivable from affiliated companies	(18)	1
Inventory	57	74
Other current assets	51	(195)
Increase (decrease) in
Accounts payable	101	6
Accounts payable to affiliated companies	9	(35)
Taxes accrued	198	109
Other current liabilities	1	(45)
Other assets	(308)	(35)
Other liabilities	(58)	(71)
Net cash provided by operating activities	1,055	903
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,162)	(1,172)
Purchases of debt and equity securities	(385)	(398)
Proceeds from sales and maturities of debt and equity securities	418	437
Notes receivable from affiliated companies	(80)	(70)
Other	(61)	(10)
Net cash used in investing activities	(1,270)	(1,213)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	989	908
Payments for the redemption of long-term debt	(717)	(341)
Notes payable to affiliated companies		(297)
Distributions to parent	(75)
Other	(1)	(1)
Net cash provided by financing activities	196	269
Net decrease in cash, cash equivalents and restricted cash	(19)	(41)
Cash, cash equivalents and restricted cash at beginning of period	53	69
Cash, cash equivalents and restricted cash at end of period	34	28
Cash and cash equivalents at beginning of period	13
Cash and cash equivalents at end of period	20
Significant non-cash transactions:
Accrued capital expenditures	180	102
Duke Energy Ohio [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income		127
Net income (attributable to parent)	121	127
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	199	196
Equity component of AFUDC	(10)	(8)
Losses (gains) on sales of other assets	106	(1)
Impairment charges		1
Deferred income taxes	9	70
Accrued pension and other post-retirement benefit costs	3	3
Contributions to qualified pension plans		(4)
Payments for asset retirement obligations	(3)	(4)
Provision for rate refunds	23
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions		1
Receivables	(44)	3
Receivable from affiliated companies	62	48
Inventory	(2)	1
Other current assets	12	(8)
Increase (decrease) in
Accounts payable	(47)	(48)
Accounts payable to affiliated companies	(8)	(4)
Taxes accrued	(31)	(21)
Other current liabilities	19	(6)
Other assets	3	(13)
Other liabilities	(17)	(2)
Net cash provided by operating activities	395	331
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(588)	(457)
Cost of removal, net of salvage	(63)	(25)
Notes receivable from affiliated companies	14	7
Other	1
Net cash used in investing activities	(636)	(475)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		182
Payments for the redemption of long-term debt	(3)	(2)
Notes payable to affiliated companies	239	(16)
Dividends to parent		(25)
Other		(1)
Net cash provided by financing activities	236	138
Net increase (decrease) in cash and cash equivalents	(5)	(6)
Cash and cash equivalents at beginning of period	12	13
Cash and cash equivalents at end of period	7	7
Significant non-cash transactions:
Accrued capital expenditures	83	65
Non-cash equity contribution from parent or Transfer of ownership interest of certain equity method investees to parent	106
Duke Energy Indiana [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	317	318
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	388	339
Equity component of AFUDC	(28)	(20)
Losses (gains) on sales of other assets		(1)
Impairment charges	30
Deferred income taxes	94	101
Accrued pension and other post-retirement benefit costs	5	4
Contributions to qualified pension plans	(8)
Payments for asset retirement obligations	(49)	(26)
Provision for rate refunds	58
(Increase) decrease in
Receivables	1	53
Receivable from affiliated companies	27	31
Inventory	16	54
Other current assets	(59)	18
Increase (decrease) in
Accounts payable	28	(71)
Accounts payable to affiliated companies	(6)	(1)
Taxes accrued	(51)	115
Other current liabilities	6	(18)
Other assets	29	(24)
Other liabilities	(13)	32
Net cash provided by operating activities	785	904
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(619)	(603)
Purchases of debt and equity securities	(42)	(15)
Proceeds from sales and maturities of debt and equity securities	18	6
Notes receivable from affiliated companies		57
Other	3	(40)
Net cash used in investing activities	(640)	(595)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt	(1)	(3)
Notes payable to affiliated companies	40
Distributions to parent	(175)	(300)
Other	(1)	(1)
Net cash provided by financing activities	(137)	(304)
Net increase (decrease) in cash and cash equivalents	8	5
Cash and cash equivalents at beginning of period	9	17
Cash and cash equivalents at end of period	17	22
Significant non-cash transactions:
Accrued capital expenditures	71	101
Piedmont Natural Gas [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	81	76
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	120	112
Impairment charges		7
Deferred income taxes	2	127
Equity in earnings of unconsolidated affiliates	(6)	(8)
Accrued pension and other post-retirement benefit costs	(3)	9
Provision for rate refunds	31
(Increase) decrease in
Receivables	192	157
Receivable from affiliated companies	(3)	(1)
Inventory	16	13
Other current assets	58	(129)
Increase (decrease) in
Accounts payable	(48)	(52)
Accounts payable to affiliated companies	14	(1)
Taxes accrued	11	(37)
Other current liabilities	8	(21)
Other assets	(4)	(9)
Other liabilities	(5)	(7)
Net cash provided by operating activities	464	236
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(497)	(407)
Cost of removal, net of salvage	(8)
Contributions to equity method investments		(12)
Notes receivable from affiliated companies	(11)
Other	3	2
Net cash used in investing activities	(513)	(417)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	100	250
Payments for the redemption of long-term debt		(35)
Notes payable and commercial paper		(330)
Notes payable to affiliated companies	(364)	284
Capital contributions from parent	300
Other		(1)
Net cash provided by financing activities	36	168
Net increase (decrease) in cash and cash equivalents	(13)	(13)
Cash and cash equivalents at beginning of period	19	25
Cash and cash equivalents at end of period	6	12
Significant non-cash transactions:
Accrued capital expenditures	$ 89	47
Non-cash equity contribution from parent or Transfer of ownership interest of certain equity method investees to parent		$ 149

XML

Condensed Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total		Common Stockholders' Equity [Member]		Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]		Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent [Member]	Net Gains (Losses) on Cash Flow Hedges [Member]	Net Unrealized (Losses) Gains on Available for Sale Securities [Member]		Pension and OPEB Adjustments [Member]	Noncontrolling Interest [Member]		Duke Energy Carolinas [Member]	Duke Energy Carolinas [Member] Member's Equity [Member]	Duke Energy Carolinas [Member] Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent [Member]	Duke Energy Carolinas [Member] Net Gains (Losses) on Cash Flow Hedges [Member]	Progress Energy [Member]		Progress Energy [Member] Common Stockholders' Equity [Member]		Progress Energy [Member] Additional Paid-in Capital [Member]	Progress Energy [Member] Retained Earnings [Member]		Progress Energy [Member] Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent [Member]	Progress Energy [Member] Net Gains (Losses) on Cash Flow Hedges [Member]	Progress Energy [Member] Net Unrealized (Losses) Gains on Available for Sale Securities [Member]		Progress Energy [Member] Pension and OPEB Adjustments [Member]	Progress Energy [Member] Noncontrolling Interest [Member]	Duke Energy Progress [Member]	Duke Energy Florida [Member]	Duke Energy Florida [Member] Member's Equity [Member]		Duke Energy Florida [Member] Net Unrealized (Losses) Gains 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]	Piedmont Natural Gas [Member]	Piedmont Natural Gas [Member] Common Stock [Member]	Piedmont Natural Gas [Member] Retained Earnings [Member]
Beginning Balance at Dec. 31, 2016	$ 41,041		$ 41,033		$ 1	$ 38,741	$ 2,384			$ (20)	$ (1)		$ (72)	$ 8						$ 11,807		$ 11,820		$ 8,094	$ 3,764			$ (23)	$ 1		$ (16)	$ (13)
Beginning Balance, in shares at Dec. 31, 2016					700,000,000
Beginning Balance (member's equity) at Dec. 31, 2016																$ 10,772	$ 10,781		$ (9)														$ 7,358	$ 4,900	$ 4,899		$ 1								$ 4,067
Beginning Balance (parent) at Dec. 31, 2016																																							$ 2,996		$ 762	$ 2,695		$ (461)		$ 1,672	$ 860	$ 812
Net Income	2,361		2,356				2,356							5						821		814			814							7							127
Net income (attributable to parent)	2,356															1,009	1,009			814													547	368	368				127					127	318	76		76
Other comprehensive income (loss)	13		13							1	10		2			1			1	12		12						4	3		5			3			3
Common stock issuances, including dividend reinvestment and employee benefits	33		33			33
Common stock dividends	(1,825)		(1,825)				(1,825)									(625)	(625)			(672)	[1]	(672)	[1]		(672)	[1]							(125)						(25)			(25)			(300)
Distributions to noncontrolling interest in subsidiaries	(2)													(2)
Equitization of certain notes payable to affiliates																				1,047		1,047		1,047
Other	21	[2]	21	[2]			21	[2]								(1)	(1)			2		2		2										3	3											(149)		(149)
Ending Balance at Sep. 30, 2017	41,642		41,631		$ 1	38,774	2,936			$ (19)	9		(70)	11						13,017		13,023		9,143	3,906			$ (19)	4		(11)	(6)
Ending Balance, in shares at Sep. 30, 2017					700,000,000
Ending Balance (member's equity) at Sep. 30, 2017																11,156	11,164		$ (8)														7,780	5,274	5,270		4								4,085
Ending Balance (parent) at Sep. 30, 2017																																							$ 3,098		762	2,670		(334)		$ 1,599	860	739
Beginning Balance at Dec. 31, 2017	$ 41,737		41,739		$ 1	38,792	3,013		$ (10)		12		(69)	(2)						$ 13,465		13,468		9,143	4,350		$ (18)		5		(12)	(3)
Beginning Balance, in shares at Dec. 31, 2017	700,000,000				700,000,000															100																			90,000,000							100
Beginning Balance (member's equity) at Dec. 31, 2017																11,361	11,368	$ (7)															7,949	5,618	5,614		4								4,121
Beginning Balance (parent) at Dec. 31, 2017	$ 41,739																			$ 13,468																			$ 3,163		762	2,670		(269)		$ 1,662	860	802
Net Income	2,190		2,202				2,202							(12)						910		904			904							6
Net income (attributable to parent)	2,202															936	936			904													532	514	514				121					121	317	81		81
Other comprehensive income (loss)	13		13						15		(5)		3			1		1		6		6					5		(1)		2			(1)			(1)
Common stock issuances, including dividend reinvestment and employee benefits, shares					13,000,000
Common stock issuances, including dividend reinvestment and employee benefits	955		955			955
Common stock dividends	(1,914)		(1,914)				(1,914)									(750)	(750)			(250)		(250)			(250)								(175)	(75)	(75)										(175)
Distributions to noncontrolling interest in subsidiaries	(1)													(1)						(1)												(1)
Other	33	[3]					12	[3]			(12)	[3]		33	[3]										5	[4]			(5)	[4]					5	[5]	(5)	[5]	$ 106	[6]		106	[6]			$ 300	300
Ending Balance at Sep. 30, 2018	$ 43,013		$ 42,995		$ 1	$ 39,747	$ 3,313		$ 5		$ (5)		$ (66)	$ 18						$ 14,130		$ 14,128		$ 9,143	$ 5,009		$ (13)		$ (1)		$ (10)	$ 2
Ending Balance, in shares at Sep. 30, 2018	713,000,000				713,000,000															100																			90,000,000							100
Ending Balance (member's equity) at Sep. 30, 2018																$ 11,548	$ 11,554	$ (6)															$ 8,306	$ 6,056	$ 6,058		$ (2)								$ 4,263
Ending Balance (parent) at Sep. 30, 2018	$ 42,995																			$ 14,128																			$ 3,390		$ 762	$ 2,776		$ (148)		$ 2,043	$ 1,160	$ 883

[1] Includes a $547 million non-cash dividend related to a legal entity restructuring.

[2] Cumulative-effect adjustment due to implementation of a new accounting standard related to stock-based compensation and the associated income taxes.

[3] Amounts in Retained Earnings and Accumulated Other Comprehensive Loss represent a cumulative-effect adjustment due to implementation of a new accounting standard related to Financial Instruments Classification and Measurement. See Note 1 for more information. Amount in Noncontrolling Interests relates to tax equity financing activity in the Commercial Renewables segment.

[4] Amounts in Retained Earnings and Accumulated Other Comprehensive Loss represent a cumulative-effect adjustment due to implementation of a new accounting standard related to Financial Instruments Classification and Measurement. See Note 1 for more information.

[5] Amounts in Member's Equity and Accumulated Other Comprehensive Income (Loss) represent a cumulative-effect adjustment due to implementation of a new accounting standard related to Financial Instruments Classification and Measurement. See Note 1 for more information.

[6] Represents a non-cash settlement through equity of an intercompany payable from Duke Energy Ohio to its parent.

XML

Condensed Consolidated Statements of Changes in Equity (Parenthetical) $ in Millions	9 Months Ended
	Sep. 30, 2017 USD ($)
Progress Energy [Member]
Dividend to parent related to a legal entity restructuring	$ 547

XML

Organization and Basis of Presentation

9 Months Ended

Sep. 30, 2018

Organization, Consolidation and Presentation of Financial Statements [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

18

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 and (ii) subsidiaries that are not registrants but included in the consolidated Duke Energy balances.

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.

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 subject to the regulatory provisions of the NCUC, PSCSC, Tennessee Public Utility Commission (TPUC) and FERC.

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles in the U.S. (GAAP) 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 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/A for the year ended December 31, 2017.

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.

REVENUE

Duke Energy recognizes revenue as customers obtain control of promised goods and services in an amount that reflects consideration expected in exchange for those goods or services. Generally, the delivery of electricity and natural gas results in the transfer of control to customers at the time the commodity is delivered and the amount of revenue recognized is equal to the amount billed to each customer, including estimated volumes delivered when billings have not yet occurred. See Note 13 for further information.

OTHER CURRENT ASSETS

Duke Energy recorded a receivable related to the Tax Act in Other within Current Assets in September 2018. As a result, Income taxes receivable exceeds five percent of Total current assets on the Duke Energy Condensed Consolidated Balance Sheets and is $655 million and $260 million as of September 30, 2018, and December 31, 2017, respectively. See Note 17 for further information.

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

Duke Energy, Progress Energy and Duke Energy Florida have restricted cash balances related primarily to collateral assets, escrow deposits and variable interest entities (VIEs). See Note 12 for additional information. Restricted cash amounts are included in Other within Current Assets and Other Noncurrent Assets. The following table presents the components of cash, cash equivalents and restricted cash included in the Condensed Consolidated Balance Sheets.

	September 30, 2018						December 31, 2017
					Duke						Duke
	Duke		Progress		Energy		Duke		Progress		Energy
	Energy		Energy		Florida		Energy		Energy		Florida
Current Assets
Cash and cash equivalents	$	303	$	43	$	20	$	358	$	40	$	13
Other	139		14		14		138		40		40
Other Noncurrent Assets
Other	7		6		—		9		7		—
Total cash, cash equivalents and restricted cash	$	449	$	63	$	34	$	505	$	87	$	53

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 at September 30, 2018, and December 31, 2017. The components of inventory are presented in the tables below.

	September 30, 2018
			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	$	2,283	$	758	$	1,071	$	748	$	323	$	87	$	294	$	1
Coal	515		176		187		99		88		14		138		—
Natural gas, oil and other fuel	342		42		215		109		106		34		2		50
Total inventory	$	3,140	$	976	$	1,473	$	956	$	517	$	135	$	434	$	51

	December 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	$	2,293	$	744	$	1,118	$	774	$	343	$	82	$	309	$	2
Coal	603		192		255		139		116		17		139		—
Natural gas, oil and other fuel	354		35		219		104		115		34		2		64
Total inventory	$	3,250	$	971	$	1,592	$	1,017	$	574	$	133	$	450	$	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 on a net basis.

Excise taxes accounted for on a gross basis within both Operating Revenues and Property and other taxes on the Condensed Consolidated Statements of Operations were as follows.

	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Duke Energy	$	114	$	107	$	308	$	289
Duke Energy Carolinas	10		9		27		27
Progress Energy	71		67		181		168
Duke Energy Progress	5		5		15		14
Duke Energy Florida	66		62		166		154
Duke Energy Ohio	26		24		81		75
Duke Energy Indiana	6		6		17		16
Piedmont	1		1		2		3

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2018 and 2017 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 standards had the most significant impact on the Duke Energy results of operations, cash flows and financial position for the nine months endedSeptember 30, 2018.

Revenue from Contracts with Customers. In May 2014, the Financial Accounting Standards Board (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 expected in exchange for those goods or services. The amendments also required 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. The majority of Duke Energy’s revenue is in scope of the new guidance. Other revenue arrangements, such as alternative revenue programs and certain purchase power agreements (PPAs) and lighting agreements accounted for as leases, are excluded from the scope of this guidance and, therefore, are accounted for and evaluated for separate presentation and disclosure under other relevant accounting guidance.

Duke Energy elected the modified retrospective method of adoption effective January 1, 2018. Under the modified retrospective method of adoption, prior year reported results are not restated. Adoption of this standard did not result in a material change in the timing or pattern of revenue recognition and a cumulative-effect adjustment was not recorded at January 1, 2018. Duke Energy utilized certain practical expedients including applying this guidance to open contracts at the date of adoption, expensing costs to obtain a contract where the amortization period of the asset would have been one year or less, ignoring the effects of a significant financing when the period between transfer of the good or service and payment is one year or less and recognizing revenues for certain contracts under the invoice practical expedient, which allows revenue recognition to be consistent with invoiced amounts (including unbilled estimates) provided certain criteria are met, including consideration of whether the invoiced amounts reasonably represent the value provided to customers.

In preparation for adoption, Duke Energy identified material revenue streams and reviewed representative contracts and tariffs, including those associated with certain long-term customer contracts such as wholesale contracts, PPAs and other customer arrangements. Duke Energy also monitored the activities of the power and utilities industry revenue recognition task force and has reviewed published positions on specific industry issues to evaluate the impact, if any, on Duke Energy’s specific contracts and conclusions.

Duke Energy applied the available practical expedient to portfolios of tariffs and contracts with similar characteristics. The vast majority of sales, including energy provided to retail customers, are from tariff offerings that provide natural gas or electricity without a defined contractual term ("at-will"). In most circumstances, revenue from contracts with customers is equivalent to the electricity or natural gas supplied and billed in that period (including unbilled estimates). As such, adoption of the new rules did not result in a shift in the timing or pattern of revenue recognition for such sales. While there have been changes to the captions and descriptions of revenues in Duke Energy’s financial statements, the most significant impact as a result of adopting the standard are additional disclosures around the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers. See Note 13 for further information.

Financial Instruments Classification and Measurement. On January 1, 2018, Duke Energy adopted FASB guidance, which revised the classification and measurement of certain financial instruments. The adopted guidance changes the presentation of realized and unrealized gains and losses in certain equity securities that were previously recorded in accumulated other comprehensive income (AOCI). These gains and losses are now recorded in net income. 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. This guidance had a 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' equity securities are deferred as regulatory assets or liabilities pursuant to accounting guidance for regulated operations. The resulting adjustment of unrealized gains and losses in AOCI to retained earnings was immaterial. The primary impact to Duke Energy as a result of implementing this guidance is adding disclosure requirements to present separately the financial assets and financial liabilities by measurement category and form of financial asset. See Notes 10 and 11 for further information.

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 Condensed Consolidated Statements of Cash Flows. Under the updated guidance, restricted cash and restricted cash equivalents are included within beginning-of-period and end-of-period cash and cash equivalents on the Condensed Consolidated Statements of Cash Flows. Duke Energy adopted this guidance on January 1, 2018. The guidance has been applied using a retrospective transition method to each period presented. The adoption by Duke Energy of the revised guidance resulted in a change to the amount of Cash, cash equivalents and restricted cash explained when reconciling the beginning-of-period and end-of-period total amounts shown on the Condensed Consolidated Statements of Cash Flows. In addition, a reconciliation has been provided of Cash, cash equivalents and restricted cash reported within the Condensed Consolidated Balance Sheets that sums to the total of the same such amounts in the Condensed Consolidated Statements of Cash Flows. Prior to adoption, the Duke Energy Registrants reflected changes in noncurrent restricted cash within Cash Flows from Investing Activities and changes in current restricted cash within Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows.

In August 2016, the FASB issued accounting guidance addressing diversity in practice for eight separate cash flow issues. The guidance requires entities to classify distributions received from equity method investees using either the cumulative earnings approach or the nature of the distribution approach. Duke Energy adopted this guidance on January 1, 2018, and elected the nature of distribution approach. This approach requires all distributions received to be categorized based on legal documentation describing the nature of the activities generating the distribution. Cash inflows resulting in a return on investment (surplus) will be reflected in Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows, whereas cash inflows resulting in a return of investment (capital) will be reflected in Cash Flows from Investing Activities on the Condensed Consolidated Statements of Cash Flows. The guidance has been applied using the retrospective transition method to each period presented. There are no changes to the Condensed Consolidated Statements of Cash Flows for the periods presented as a result of this accounting change.

Retirement Benefits. In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic costs related to benefit plans. Previous guidance required the aggregation of all the components of net periodic costs on the Condensed Consolidated Statement of Operations and did 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 is included within Operating Income within the same line as other compensation expenses. All other components of net periodic costs are 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 previous guidance, which permitted all components of net periodic costs to be eligible for capitalization.

Duke Energy adopted this guidance on January 1, 2018. Under previous guidance, Duke Energy presented the total non-capitalized net periodic costs within Operation, maintenance and other on the Condensed Consolidated Statements of Operations. The adoption of this guidance resulted in a retrospective change to reclassify the presentation of the non-service cost (benefit) components of net periodic costs to Other income and expenses. Duke Energy utilized the practical expedient for retrospective presentation. The change in components of net periodic costs eligible for capitalization is applicable prospectively. Since Duke Energy’s service cost component is greater than the total net periodic costs, the change results in increased capitalization of net periodic costs, higher Operation, maintenance and other and higher Other income and expenses. The resulting prospective impact to Duke Energy is an immaterial increase in Net Income. See Note 15 for further information.

For Duke Energy, the retrospective change resulted in higher Operation, maintenance and other and higher Other income and expenses, net, of $156 million, $131 million and $96 million for the years ended December 31, 2017, 2016 and 2015, respectively. There was no change to Net Income for these prior periods.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of September 30, 2018.

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. The guidance will be applied using a modified retrospective approach. Upon adoption, agreements considered leases for the use of certain aircraft, space on communication towers, industrial equipment, fleet vehicles, fuel transportation (barges and railcars), land and office space will be recognized on the balance sheet. Duke Energy expects to elect certain of the following practical expedients upon adoption:

Practical Expedient	Description	Election
Package of transition practical expedients (for leases commenced prior to adoption date and must be adopted as a package)	Do not need to 1) reassess whether any expired or existing contracts are/or contain leases, 2) reassess the lease classification for any expired or existing leases and 3) reassess initial direct costs for any existing leases.	Duke Energy plans to elect this practical expedient.
Short-term lease expedient (elect by class of underlying asset)	Elect as an accounting policy to not apply the recognition requirements to short-term leases by asset class.	Duke Energy plans to elect this practical expedient for all asset classes.
Lease and non-lease components (elect by class of underlying asset)	Elect as an accounting policy to not separate non-lease components from lease components and instead account for each lease and associated non-lease component as a single lease component by asset class.	Duke Energy is currently assessing the election of this practical expedient.
Hindsight expedient (when determining lease term)	Elect to use hindsight to determine the lease term.	Duke Energy plans to elect this practical expedient.
Existing and expired land easements not previously accounted for as leases	Elect to not evaluate existing or expired easements under the new guidance and carry forward current accounting treatment.	Duke Energy plans to elect this practical expedient.
Comparative reporting requirements for initial adoption	Elect to apply transition requirements at adoption date, recognize cumulative effect adjustment to retained earnings in period of adoption and not apply ASC 842 to comparative periods, including disclosures.	Duke Energy plans to elect this practical expedient.
Lessor expedient (elect by class of underlying asset)	Elect as an accounting policy to aggregate non-lease components with the related lease component when specified conditions are met by asset class. Account for the combined component based on its predominant characteristic (revenue or operating lease).	Duke Energy is currently assessing the election of this practical expedient.

Duke Energy is currently evaluating the financial statement impact of adopting this standard and is continuing to monitor industry implementation issues, including leases within asset retirement obligations, pipeline laterals and renewable energy PPAs. In arrangements where Duke Energy is the lessee, it expects an increase in assets and liabilities on its balance sheet along with the addition of required disclosures of key lease information. However, the ultimate lessee impact of the new standard has not yet been determined. Duke Energy does not expect a material change to its financial statements from adoption of the new standard for contracts where it is the lessor. System enhancements, including additional processes and controls, will be required to facilitate the identification, tracking and reporting of potential leases based upon requirements of the new lease standard. Duke Energy is implementing a third-party software tool to help with the adoption and ongoing accounting under the new standard.

XML

Business Segments

9 Months Ended

Sep. 30, 2018

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

Duke Energy

Duke Energy's segment structure includes the following segments: Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables.

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 midstream 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 interest expense on holding company debt, unallocated corporate costs and Duke Energy’s wholly owned captive insurance company, Bison Insurance Company Limited (Bison). Other also includes Duke Energy's 17.5 percent interest in National Methanol Company (NMC), a large regional producer of methyl tertiary butyl ether 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 September 30, 2018
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	6,253	$	232	$	127		$	6,612	$	16		$	—		$	6,628
Intersegment revenues	7		24		—			31		18			(49		)	—
Total revenues	$	6,260	$	256	$	127		$	6,643	$	34		$	(49	)	$	6,628
Segment income (loss)(a)(b)(c)	$	1,167	$	17	$	(62	)	$	1,122	$	(44	)	$	—		$	1,078
Add back noncontrolling interests																(16		)
Income from discontinued operations, net of tax																4
Net income																$	1,066
Segment assets	$	123,847	$	11,806	$	4,212		$	139,865	$	3,115		$	185		$	143,165

	Three Months Ended September 30, 2017
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	6,122	$	249	$	95		$	6,466	$	16		$	—		$	6,482
Intersegment revenues	7		23		—			30		19			(49		)	—
Total revenues	$	6,129	$	272	$	95		$	6,496	$	35		$	(49	)	$	6,482
Segment income (loss)(b)(d)(e)	$	1,020	$	19	$	(49	)	$	990	$	(34	)	$	—		$	956
Add back noncontrolling interests																1
Loss from discontinued operations, net of tax																(2		)
Net income																$	955

(a) All segments include adjustments to the December 31, 2017 estimate of the income tax effects of the Tax Act. See Note 17 for additional information.

(b) Other includes costs to achieve the Piedmont acquisition.

(c) Commercial Renewables includes an impairment charge related to goodwill. See Note 7 for additional information.

(d) Electric Utilities and Infrastructure includes an impairment charge related to the unrecovered Levy Nuclear Project costs at Duke Energy Florida.

(e) Commercial Renewables includes impairment charges related to certain wind projects.

	Nine Months Ended September 30, 2018
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	16,783	$	1,229	$	347		$	18,359	$	47		$	—		$	18,406
Intersegment revenues	23		72		—			95		54			(149		)	—
Total revenues	$	16,806	$	1,301	$	347		$	18,454	$	101		$	(149	)	$	18,406
Segment income (loss)(a)(b)(c)(d)(e)(f)	$	2,492	$	161	$	(4	)	$	2,649	$	(446	)	$	—		$	2,203
Add back noncontrolling interests																(12		)
Loss from discontinued operations, net of tax																(1		)
Net income																$	2,190

	Nine Months Ended September 30, 2017
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	16,211	$	1,175	$	333	$	17,719	$	47		$	—		$	17,766
Intersegment revenues	23		68		—		91		56			(147		)	—
Total revenues	$	16,234	$	1,243	$	333	$	17,810	$	103		$	(147	)	$	17,766
Segment income (loss)(c)(g)(h)	$	2,384	$	179	$	2	$	2,565	$	(205	)	$	—		$	2,360
Add back noncontrolling interests															5
Loss from discontinued operations, net of tax															(4		)
Net income															$	2,361

(a) All segments include adjustments to the December 31, 2017 estimate of the income tax effects of the Tax Act. See Note 17 for additional information.

(b) Electric Utilities and Infrastructure includes regulatory and legislative impairment charges related to rate case orders, settlements or other actions of regulators or legislative bodies. See Note 3 for additional information.

(c) Other includes costs to achieve the Piedmont acquisition.

(d) Gas Utilities and Infrastructure includes an impairment of the investment in Constitution Pipeline Company, LLC (Constitution). See Note 3 for additional information.

(e) Other includes the loss on the sale of the retired Beckjord Generating Station (Beckjord) described below and a valuation allowance recorded against the alternative minimum tax credits subject to sequestration. See Note 17 for additional information on the valuation allowance.

(f) Commercial Renewables includes an impairment charge related to goodwill. See Note 7 for additional information.

(g) Electric Utilities and Infrastructure includes an impairment charge related to the unrecovered Levy Nuclear Project costs at Duke Energy Florida.

(h) Commercial Renewables includes impairment charges related to certain wind projects.

In February 2018, Duke Energy sold Beckjord, a nonregulated facility retired during 2014, and recorded a pretax loss of $106 million within Gains (Losses) on Sales of Other Assets and Other, net and $1 million within Operation, maintenance and other on Duke Energy's Condensed Consolidated Statements of Operations for the nine months endedSeptember 30, 2018. The sale included the transfer of coal ash basins and other real property and indemnification from any and all potential future claims related to the property, whether arising under environmental laws or otherwise.

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 Northern Kentucky. Gas Utilities and Infrastructure transports and sells natural gas in portions of Ohio and Northern Kentucky. Both reportable operating segments conduct operations primarily through Duke Energy Ohio and its wholly owned subsidiary, Duke Energy Kentucky.

The remainder of Duke Energy Ohio's operations is presented as Other, which 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 September 30, 2018
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations			Consolidated
Total revenues	$	373	$	84	$	457	$	12	$	—		$	469
Segment income/Net income	$	85	$	12	$	97	$	3	$	—		$	100
Segment assets	$	5,484	$	2,775	$	8,259	$	39	$	(2	)	$	8,296

	Three Months Ended September 30, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	371	$	90	$	461	$	10		$	471
Segment income (loss)	$	50	$	14	$	64	$	(8	)	$	56
Loss from discontinued operations, net of tax										(1		)
Net income										$	55

	Nine Months Ended September 30, 2018
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	1,055	$	361	$	1,416	$	36		$	1,452
Segment income (loss)/Net income(a)	$	157	$	64	$	221	$	(100	)	$	121

	Nine Months Ended September 30, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	1,036	$	360	$	1,396	$	30		$	1,426
Segment income (loss)	$	96	$	56	$	152	$	(24	)	$	128
Loss from discontinued operations, net of tax										(1		)
Net income										$	127

(a)    Other includes the loss on the sale of Beckjord.

XML

Regulatory Matters

9 Months Ended

Sep. 30, 2018

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

Grid Improvement – South Carolina

On June 22, 2018, Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the PSCSC seeking an accounting order authorizing deferral of certain costs incurred in connection with grid reliability, resiliency and modernization work that is being performed under the companies’ grid improvement initiative. On October 3, 2018, the PSCSC granted Duke Energy Carolinas' and Duke Energy Progress' joint petition.

Hurricane Florence Storm Damage

In September 2018, Hurricane Florence made landfall and inflicted severe damage to the Duke Energy Carolinas and Duke Energy Progress territories in North Carolina and South Carolina. Approximately 1.8 million customers were impacted. The companies incurred approximately $455 million in operation and maintenance expenses ($35 million and $420 million for Duke Energy Carolinas and Duke Energy Progress, respectively,) and approximately $85 million in capital costs ($10 million and $75 million for Duke Energy Carolinas and Duke Energy Progress, respectively,) which are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of September 30, 2018, resulting from the hurricane restoration efforts. Most of the operation and maintenance expenses are deferred in Regulatory assets within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of September 30, 2018. The balance of operation and maintenance expenses are included in Operation, maintenance and other on the Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2018.

Given the magnitude of the storm, Duke Energy Progress intends to request approval in North Carolina and South Carolina to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate case. These requests are expected to be filed during the fourth quarter of 2018.

Duke Energy Carolinas

2017 North Carolina Rate Case

On August 25, 2017, Duke Energy Carolinas filed an application with the NCUC for a rate increase for retail customers of approximately $647 million, which represented an approximate 13.6 percent increase in annual base revenues. The rate increase was driven by capital investments subsequent to the previous base rate case, including the William States Lee Combined Cycle Facility discussed below, grid improvement projects, advanced metering infrastructure (AMI), investments in customer service technologies, costs of complying with coal combustion residuals (CCR) regulations and the North Carolina Coal Ash Management Act of 2014 (Coal Ash Act) and recovery of costs related to licensing and development of the William States Lee III Nuclear Station (Lee Nuclear Station) discussed below.

On February 28, 2018, Duke Energy Carolinas and the North Carolina Public Staff (Public Staff) filed an Agreement and Stipulation of Partial Settlement resolving certain portions of the proceeding. Terms of the settlement included a return on equity of 9.9 percent and a capital structure of 52 percent equity and 48 percent debt. As a result of the settlement, Duke Energy Carolinas recorded a pretax charge of approximately $4 million to Operation, maintenance and other on the Condensed Consolidated Statements of Operations.

On June 1, 2018, Duke Energy Carolinas and certain intervenors filed a Pilot Grid Rider Agreement and Stipulation (Grid Rider Stipulation) in which the parties agreed to the proposal Duke Energy Carolinas introduced in a post-hearing brief on April 27, 2018, along with additional commitments by Duke Energy Carolinas. Also on June 1, 2018, Duke Energy Carolinas and the Commercial Group filed a Partial Stipulation and Settlement Agreement to be considered in conjunction with the Stipulation.

Components of the Grid Rider Stipulation included:

• Duke Energy Carolinas would recover grid improvement costs through a pilot, three-year Grid Rider except for costs related to targeted undergrounding of power lines, cable and conduit replacement, and power pole replacement;

• Excluded costs were to be deferred with a return until Duke Energy Carolinas’ next base rate case proceeding; and

• Costs incurred during the three-year pilot, both rider recoverable and deferred, were subject to a 4.5 percent cumulative cap of total annual electric service revenue.

On June 22, 2018, the NCUC issued an order approving the Stipulation of Partial Settlement and requiring a revenue reduction. The order also included the following material components not covered in the Stipulation:

• Recovery of $554 million of deferred coal ash basin closure costs over a five-year period with a return at Duke Energy Carolinas' weighted average cost of capital (WACC);

• Assessment of a $70 million management penalty ratably over a five-year period by reducing the annual recovery of the deferred coal ash costs;

• Denial of Duke Energy Carolinas' request for recovery of future estimated ongoing annual coal ash costs of $201 million with approval to defer such costs with a return at Duke Energy Carolinas' WACC, to be considered for recovery in the next rate case;

• Inclusion in rates of costs related to the Lee Combined Cycle Facility, two new solar facilities, and AMI deployment as requested;

• Recovery of Lee Nuclear Station licensing and development cost of $347 million over a 12-year period, but denial of a return on the deferred balance of costs;

• Reduction in revenue related to lower income tax expense resulting from the Federal Tax Cuts and Jobs Act (Tax Act), and a requirement to maintain all excess deferred income tax (EDIT) resulting from the Tax Act in a regulatory liability account pending flow back to customers as approved by the commission at the earlier of three years or Duke Energy Carolinas’ next general rate case proceeding; and

• Denial of the proposed Grid Rider Stipulation related to grid improvement costs and denial of deferral accounting treatment of the costs at this time. Duke Energy Carolinas may petition for deferral of grid modernization costs outside of a general rate case proceeding if it can show financial hardship or a stipulation that includes greater consensus among intervening parties on costs being classified as grid modernization.

As a result of the Order, Duke Energy Carolinas recorded a pretax charge of approximately $150 million to Impairment charges and Operation, maintenance and other on the Condensed Consolidated Statements of Operations. The charge is primarily related to the denial of a return on the Lee Nuclear Project and for previously recognized return impacted by the coal ash management penalty described above. On July 27, 2018, NCUC approved Duke Energy Carolinas' compliance filing. As a result, revised customer rates were effective on August 1, 2018.

On July 20, 2018, the North Carolina Attorney General filed a Notice of Appeal to the North Carolina Supreme Court from the June 22, 2018, Order Accepting Stipulation, Deciding Contested Issues and Requiring Revenue Reduction issued by the NCUC. The Attorney General contends the commission’s order should be reversed and remanded, as it is in excess of the commission’s statutory authority; affected by errors of law; unsupported by competent, material and substantial evidence in view of the entire record as submitted; and arbitrary or capricious. The Sierra Club, North Carolina Sustainable Energy Association, North Carolina Justice Center, North Carolina Housing Coalition, Natural Resource Defense Council and Southern Alliance for Clean Energy have also filed Notices of Appeal to the North Carolina Supreme Court from the June 22, 2018, Order Accepting Stipulation, Deciding Contested Issues and Requiring Revenue Reduction. On August 8, 2018, the Public Staff filed a Notice of Cross Appeal to the North Carolina Supreme Court from the June 22, 2018, Order Accepting Stipulation, Deciding Contested Issues and Requiring Revenue Reduction issued by the NCUC. The Public Staff contends the commission’s order should be reversed and remanded, as it is affected by errors of law, and is unsupported by substantial evidence with regard to the commission’s failure to consider substantial evidence of coal ash related environmental violations. The briefing will likely be delayed until the second quarter of 2019. Duke Energy Carolinas cannot predict the outcome of this matter.

2018 South Carolina Rate Case

On October 8, 2018, Duke Energy Carolinas filed a notice with the PSCSC of the company’s intent to file a base rate adjustment application no earlier than 30 days from the notice submittal date.

FERC Formula Rate Matter

On July 31, 2017, Piedmont Municipal Power Agency (PMPA) filed a complaint with FERC against Duke Energy Carolinas alleging that Duke Energy Carolinas misapplied the formula rate under the PPA between the parties by including in its rates amortization expense associated with regulatory assets and recorded in a certain account without FERC approval. On February 15, 2018, FERC issued an order ruling in favor of PMPA and ordered Duke Energy Carolinas to refund to PMPA all amounts improperly collected under the PPA. Duke Energy Carolinas has issued to PMPA and similarly situated wholesale customers refunds of approximately $25 million. FERC also set the matter for settlement and hearing. PMPA and other customers filed a protest to Duke Energy Carolinas' refund report claiming that the refunds are inadequate in that (1) Duke Energy Carolinas invoked the limitations periods in the contracts to limit the time period for which the refunds were paid and the customers disagree that this limitation applies, and (2) Duke Energy Carolinas refunded only amounts recovered through a certain account and the customers have asserted that the order applies to all regulatory assets. On July 3, 2018, FERC issued an order accepting Duke Energy Carolinas' refund report and ruling that these two claims are outside the scope of FERC's February order. Duke Energy Carolinas will file revised formula rates as well as settlement agreements which are subject to FERC approval. Duke Energy Carolinas cannot predict the outcome of this matter.

William States Lee Combined Cycle Facility

On April 9, 2014, the PSCSC granted Duke Energy Carolinas and North Carolina Electric Membership Corporation (NCEMC) a Certificate of Environmental Compatibility and Public Convenience and Necessity for the construction and operation of a 750-megawatt (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 its share of the cost to build the facility was approximately $650 million, including allowance for funds used during construction (AFUDC). Approximately $600 million is being recovered through base rate or deferral filings in North Carolina and South Carolina. The remaining amount will be included in future rate filings. The project commenced commercial operation on April 5, 2018. NCEMC owns approximately 13 percent of the project.

Lee 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 concurred with the prudency of Duke Energy Carolinas incurring 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.

The Duke Energy Carolinas rate case filing discussed above included a request to cancel the development of the Lee Nuclear Station project, recover incurred licensing and development costs and maintain the license issued by the NRC as an option for potential future development. The cancellation request was due to the Westinghouse bankruptcy filing and other market activity. The NCUC Order issued on June 22, 2018, approved the cancellation of the Lee Nuclear Project, allowed Duke Energy Carolinas to continue to maintain the COLs, provided for recovery of the North Carolina retail allocation of project development costs, including AFUDC accrued through December 31, 2017, over 12 years and disallowed any return on the unamortized balance during the 12-year recovery period.

Given the recent repeal of certain sections of the Base Load Review Act in South Carolina combined with the cancellation of the project, Duke Energy Carolinas determined that it was no longer probable it would be allowed a return on its share of project development costs attributable to South Carolina. As a result, Duke Energy Carolinas recorded a pretax impairment in the second quarter of $29 million within Impairment charges on the Condensed Consolidated Statements of Operations and Comprehensive Income.

South Carolina Petition

On June 22, 2018, Duke Energy Carolinas filed a petition with the PSCSC requesting an accounting order to defer certain costs incurred in connection with the addition of the William States Lee Combined Cycle Facility, the ongoing deployment of Duke Energy Carolinas new billing and Customer Information System and the addition of the Carolinas West Primary Distribution Control Center. This request totaling approximately $33 million was approved on July 25, 2018.

Sale of Hydroelectric (Hydro) Plants

In May 2018, Duke Energy Carolinas entered an agreement for the sale of five hydro plants with a combined 18.7-MW generation capacity in the Western Carolinas region to Northbrook Energy. The completion of the transaction is subject to approval from FERC, as well as other state regulatory agencies and is contingent upon regulatory approval from the NCUC and PSCSC to defer the total estimated loss on the sale of approximately $40 million. On July 5, 2018, Duke Energy Carolinas filed with NCUC for approval of the sale of the five hydro plants to Northbrook, to transfer the Certificates of Public Convenience and Necessity (CPCN) for the four North Carolina hydro plants and to establish a regulatory asset for the North Carolina retail portion of the difference between sales proceeds and net book value. On September 4, 2018, the Public Staff filed comments supporting the CPCN transfer with conditions, specifically that the commission direct Duke Energy Carolinas and the Public Staff to further evaluate the reasonableness of Duke Energy Carolinas' expenditures at the facilities in the 36 months leading up to the agreement for the sale for consideration in the next rate case. On September 18, 2018, Duke Energy Carolinas filed reply comments opposing this condition. The Public Staff also recommended that the amortization period for the regulatory asset start in the month in which the asset transfer is completed, rather than be delayed until the next rate case. On August 28, 2018, Duke Energy Carolinas filed with PSCSC its Application for Approval of Transfer and Sale of Hydroelectric Generation Facilities, Acceptance for Filing of a Power Purchase Agreement and an Accounting Order to Establish a Regulatory Asset. On September 10, 2018, the South Carolina Office of Regulatory Staff (ORS) provided a letter to the commission stating its position on the application and on September 18, 2018, Duke Energy Carolinas requested this matter be carried over to allow Duke Energy Carolinas time to discuss certain accounting issues with the ORS. On October 9, 2018, Duke Energy Carolinas filed a Notice of Application for Transfer of Licenses with the FERC, which provides 30 days to file comments and motions to intervene.

If commission approvals are not received, Duke Energy Carolinas can cancel the sales agreement and retain the hydro facilities. If commission approvals are received, the closing is expected to occur during the first quarter of 2019. After closing, Duke Energy Carolinas will purchase all the capacity and energy generated by these facilities at the avoided cost for five years through power purchase agreements. Duke Energy Carolinas cannot predict the outcome of this matter.

Duke Energy Progress

2017 North Carolina Rate Case

On June 1, 2017, Duke Energy Progress filed an application with the NCUC for a rate increase for retail customers of approximately $477 million, which represented an approximate 14.9 percent increase in annual base revenues. Subsequent to the filing, Duke Energy Progress adjusted the requested amount to $420 million, representing an approximate 13 percent increase. The rate increase is driven by capital investments subsequent to the previous base rate case, costs of complying with CCR regulations and the Coal Ash Act, costs relating to storm recovery, investments in customer service technologies and recovery of costs associated with renewable purchased power.

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. The final estimate of incremental operation and maintenance and capital costs of $116 million was filed with the NCUC in September 2017. On July 10, 2017, the NCUC consolidated Duke Energy Progress' storm deferral request into the Duke Energy Progress rate case docket for decision.

On November 22, 2017, Duke Energy Progress and the Public Staff filed an Agreement and Stipulation of Partial Settlement resolving certain portions of the proceeding. Terms of the settlement included a return on equity of 9.9 percent and a capital structure of 52 percent equity and 48 percent debt. As a result of the settlement, in 2017 Duke Energy Progress recorded pretax charges totaling approximately $25 million to Impairment charges and Operation, maintenance and other on the Condensed Consolidated Statements of Operations, principally related to disallowances from rate base of certain projects at the Mayo and Sutton plants. On February 23, 2018, the NCUC issued an order approving the stipulation. The order also included the following material components not covered in the stipulation:

• Recovery of the remaining $234 million of deferred coal ash basin closure costs over a five-year period with a return at Duke Energy Progress' WACC, excluding $9.5 million of retail deferred coal ash basin costs related to ash hauling at Duke Energy Progress' Asheville Plant;

• Assessment of a $30 million management penalty ratably over a five-year period by reducing the annual recovery of the deferred coal ash costs;

• Denial of Duke Energy Progress' request for recovery of future estimated ongoing annual coal ash costs of $129 million with approval to defer such costs with a return at Duke Energy Progress' WACC, to be considered for recovery in the next rate case; and

• Approval to recover $51 million of the approximately $80 million deferred storm costs over a five-year period with amortization beginning in October 2016. The order did not allow the deferral of the associated capital costs or a return on the deferred balance during the deferral period.

The order also impacted certain amounts that were similarly recorded on Duke Energy Carolinas' Condensed Consolidated Balance Sheets. As a result of the order, Duke Energy Progress and Duke Energy Carolinas recorded pretax charges of $68 million and $14 million, respectively, in the first quarter of 2018 to Impairment charges, Operation, maintenance and other and Interest Expense on the Condensed Consolidated Statements of Operations. These charges primarily related to the coal ash basin disallowance and previously recognized return impacted by the coal ash management penalty and deferred storm cost adjustments. Revised customer rates became effective on March 16, 2018.

On May 15, 2018, the Public Staff filed a Notice of Cross Appeal to the North Carolina Supreme Court from the February 23, 2018, Order Accepting Stipulation, Deciding Contested Issues and Granting Partial Rate Increase issued by the NCUC. The Public Staff contend the commission’s order should be reversed and remanded, as it is affected by errors of law, and is unsupported by competent, material and substantial evidence in view of the entire record as submitted. The North Carolina Attorney General and Sierra Club have also filed Notices of Appeal to the North Carolina Supreme Court from the February 23, 2018, Order Accepting Stipulation, Deciding Contested Issues and Granting Partial Rate Increase. The briefing will likely be delayed until the second quarter of 2019. Duke Energy Progress cannot predict the outcome of this matter.

2016 South Carolina Rate Case

In December 2016, the PSCSC approved a rate case settlement agreement among the ORS, intervenors and Duke Energy Progress. Terms of the settlement agreement included an approximate $56 million increase in revenues over a two-year period. An increase of approximately $38 million in revenues was effective January 1, 2017, and an additional increase of approximately $18.5 million in revenues was effective January 1, 2018. Duke Energy Progress amortized approximately $18.5 million from the cost of removal reserve in 2017. Other settlement terms included a rate of return on equity of 10.1 percent, recovery of coal ash costs incurred from January 1, 2015, through June 30, 2016, over a 15‑year period and ongoing deferral of allocated ash basin closure costs from July 1, 2016, until the next base rate case. The settlement also provides that Duke Energy Progress will not seek an increase in rates in South Carolina to occur prior to 2019, with limited exceptions.

2018 South Carolina Rate Case

On October 8, 2018, Duke Energy Progress filed a notice with the PSCSC of the company’s intent to file a base rate adjustment application no earlier than 30 days from the notice submittal date.

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 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, 2018, 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 complete and construction of these plants began in 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 $352 million and $385 million is included in Generation facilities to be retired, net on Duke Energy Progress' Condensed Consolidated Balance Sheets as of September 30, 2018, and December 31, 2017, respectively. Duke Energy Progress' request for a regulatory asset at the time of retirement with amortization over a 10-year period was approved by the NCUC on February 23, 2018.

Shearon Harris Nuclear Plant Expansion

In 2006, Duke Energy Progress selected a site at Harris to evaluate for possible future nuclear expansion. On February 19, 2008, Duke Energy Progress filed its COL application with the NRC for two Westinghouse AP1000 reactors at Harris, which the NRC docketed for review. On May 2, 2013, Duke Energy Progress filed a letter with the NRC requesting the NRC to suspend its review activities associated with the COL at the Harris site. The NCUC and PSCSC approved deferral of retail costs. Total deferred costs were approximately $47 million as of December 31, 2017, and are recorded in Regulatory assets on Duke Energy Progress’ Condensed Consolidated Balance Sheets. On November 17, 2016, the FERC approved Duke Energy Progress’ rate recovery request filing for the wholesale ratepayers’ share of the abandonment costs, including a debt-only return to be recovered through revised formula rates and amortized over a 15-year period beginning May 1, 2014. As part of the settlement agreement for the 2017 North Carolina Rate Case discussed above, Duke Energy Progress will amortize the regulatory asset over an eight-year period. NCUC approved the settlement on February 23, 2018.

South Carolina Petitions

On June 22, 2018, Duke Energy Progress filed a petition with the PSCSC seeking an accounting order authorizing Duke Energy Progress to adopt new depreciation rates, effective March 16, 2018, that reflect the results of Duke Energy Progress’ most recent depreciation study. Also on June 22, 2018, Duke Energy Progress filed a petition with the PSCSC requesting an accounting order to defer certain costs incurred in connection with the deployment of AMI, the ongoing deployment of Duke Energy Progress' new billing and Customer Information System, new depreciation rates and costs incurred in connection with the return of certain excess deferred state income taxes from North Carolina. These requests totaling approximately $20 million were approved on July 25, 2018.

FERC Form 1 Reporting Matter

On October 18, 2017, Fayetteville Public Works Commission (FPWC) filed with FERC a complaint against Duke Energy Progress. In the complaint, FPWC alleges that Duke Energy Progress’ change in its method of reporting materials and supplies inventory on FERC Form 1 for 2015 constituted a change in accounting practice that Duke Energy Progress was not permitted to implement without first obtaining FERC approval. On April 23, 2018, FERC issued an order finding that Duke Energy Progress’ new reporting methodology was not proper and required Duke Energy Progress to revise its FERC Form 1s beginning in 2014 and to issue refunds to formula rate customers. Duke Energy Progress estimates that these refunds will total approximately $14 million. On May 23, 2018, Duke Energy Progress filed a request for rehearing alleging that FERC’s order is incorrect. Duke Energy Progress revised its FERC Form 1 filings in June 2018. On August 31, 2018, Duke Energy Progress filed with FERC a refund report memorializing its payment of refunds to FPWC. Duke Energy Progress cannot predict the outcome of this matter.

Tax Act

As ordered by the NCUC on October 5, 2018, Duke Energy Progress filed a proposal on October 25, 2018, to adjust rates to reflect the reduction in federal corporate income tax rate from 35 to 21 percent for taxable years beginning after December 31, 2017, as outlined in the Tax Act. Duke Energy Progress proposes that this rate decrement be effective for service rendered on and after December 1, 2018. The Public Staff is requested to file comments on the proposal no later than November 14, 2018, and other parties may also file comments on the proposals no later than November 14, 2018. Duke Energy Progress cannot predict the outcome of this matter.

Duke Energy Florida

Storm Restoration Cost Recovery

In September 2017, Duke Energy Florida’s service territory suffered significant damage from Hurricane Irma, resulting in approximately 1.3 million customers experiencing outages. In the fourth quarter of 2017, Duke Energy Florida also incurred preparation costs related to Hurricane Nate. On December 28, 2017, Duke Energy Florida filed a petition with the FPSC to recover incremental storm restoration costs for hurricanes Irma and Nate and to replenish the storm reserve. On February 6, 2018, the FPSC approved a stipulation that would apply tax savings resulting from the Tax Act toward storm costs effective January 2018 in lieu of implementing a storm surcharge. Storm costs are currently expected to be fully recovered by approximately mid-2021. On May 31, 2018, Duke Energy Florida filed a petition for approval of actual storm restoration costs and associated recovery process related to Hurricanes Irma and Nate. The petition is seeking the approval for the recovery in the amount of $510 million in actual recoverable storm restoration costs, including the replenishment of Duke Energy Florida’s storm reserve of $132 million, and the process for recovering these recoverable storm costs. On August 20, 2018, the FPSC approved Duke Energy Florida's unopposed Motion for Continuance filed August 17, 2018, to allow for an evidentiary hearing in this matter. The commission has scheduled the hearing to begin on May 21, 2019. At September 30, 2018, Duke Energy Florida's Condensed Consolidated Balance Sheets included approximately $258 million of recoverable costs under the FPSC's storm rule in Regulatory assets within Current Assets and Other Noncurrent Assets related to storm recovery. Duke Energy Florida cannot predict the outcome of this matter.

Tax Act

Pursuant to Duke Energy Florida's 2017 Revised and Restated Settlement Agreement, on May 31, 2018, Duke Energy Florida filed a petition related to the Tax Act, which included annual tax savings of $84 million and annual amortization of EDIT of $67 million for a total of $151 million. The pretax revenue requirement impact is $201 million, of which $50 million will be offset with accelerated depreciation of Crystal River 4 and 5 coal units and $151 million will be offset by Hurricane Irma storm cost recovery as explained in the Storm Restoration Cost Recovery section above. The petition is subject to review and approval by the FPSC. Duke Energy Florida cannot predict the outcome of this matter.

Citrus County Combined Cycle Facility

On October 2, 2014, the FPSC granted Duke Energy Florida a Determination of Need for the construction of a 1,640-MW combined-cycle natural gas plant in Citrus County, Florida. On May 5, 2015, the Florida Department of Environmental Protection approved Duke Energy Florida's Site Certification Application. The project has received all required permits and approvals and construction began in October 2015. The facility is expected to be commercially available by the end of 2018 at an estimated cost of $1.5 billion, including AFUDC. Actual costs are expected to exceed this estimate by an immaterial amount after recoveries; therefore, an impairment is not expected. On April 2, 2018, Duke Energy Florida filed a petition seeking approval to include in base rates the revenue requirements associated with the new facility. The annual retail revenue requirement is approximately $200 million. On July 10, 2018, the FPSC voted to approve Duke Energy Florida's request to include the revenue requirements for the new Citrus County combined-cycle units in base rates. The first 820-MW power block came on line on October 26, 2018, and the rate increase for this unit will be effective in December 2018. The second 820-MW power block remains on track to start serving customers in December 2018. The rate increase for the second unit is expected to take place in January 2019. The plant will receive natural gas from the Sabal Trail pipeline discussed below.

Solar Base Rate Adjustment

On July 31, 2018, Duke Energy Florida petitioned the FPSC to include in base rates the revenue requirements for its first two solar generation projects, the Hamilton Project and the Columbia Project, as authorized by the 2017 Second Revised and Restated Stipulation and Settlement Agreement. The annual retail revenue requirement for the Hamilton Project is $15.2 million and the increase would take effect with the first billing cycle in January 2019. The Columbia Project has a projected annual revenue requirement of $14 million and a projected in-service date in early 2020; the associated rate increase would take place with the first month’s billing cycle after the Columbia Project goes into service. At its October 30, 2018, Agenda Conference, the FPSC approved the rate increase related to the Hamilton Project to go into effect beginning with the first billing cycle in January 2019 under its file and suspend authority. Rates are subject to true up pending the outcome of the final hearing, which is scheduled to take place on April 2, 2019.

Duke Energy Ohio

2017 Electric Security Plan Filing

On June 1, 2017, Duke Energy Ohio filed with the PUCO a request for a standard service offer in the form of an electric security plan (ESP). If approved by the PUCO, the term of the ESP would be from June 1, 2018, to May 31, 2025. Terms of the ESP include continuation of market-based customer rates through competitive procurement processes for generation, continuation and expansion of existing rider mechanisms and proposed new rider mechanisms relating to regulatory mandates, costs incurred to enhance the customer experience and transform the grid and a service reliability rider for vegetation management. On February 15, 2018, the procedural schedule was suspended to facilitate ongoing settlement discussions. On April 13, 2018, Duke Energy Ohio filed a Motion to consolidate this proceeding with several other cases currently pending before the PUCO, including, but not limited to, its Electric Base Rate Case. Additionally, on April 13, 2018, Duke Energy Ohio, along with certain intervenors, filed a Stipulation and Recommendation (Stipulation) with the PUCO resolving certain issues in this proceeding. The Stipulation establishes a regulatory model for the next seven years via the approval of the ESP and continues the current model for procuring supply for non-shopping customers, including recovery mechanisms. The Stipulation is subject to the review and approval of PUCO. An evidentiary hearing to review the Stipulation and other issues in the cases concluded on August 6, 2018. Initial briefs were filed on September 11, 2018. Reply briefs were filed October 2, 2018. Duke Energy Ohio cannot predict the outcome of this matter.

Electric 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. On September 26, 2017, the PUCO staff filed a report recommending a revenue decrease between approximately $18 million and $29 million and a return on equity between 9.22 percent and 10.24 percent. On February 15, 2018, the procedural schedule was suspended to facilitate ongoing settlement discussions. On April 13, 2018, Duke Energy Ohio filed a Motion to consolidate this proceeding with several other cases currently pending before the PUCO. On April 13, 2018, Duke Energy Ohio, along with certain intervenors, filed the Stipulation with the PUCO resolving numerous issues including those in this base rate proceeding. Major components of the Stipulation related to the base distribution rate case include a $19 million decrease in annual base distribution revenue with a return on equity unchanged from the current rate of 9.84 percent based upon a capital structure of 50.75 percent equity and 49.25 percent debt. Upon approval of new rates, Duke Energy Ohio's rider for recovering its initial SmartGrid implementation ends as these costs will be recovered through base rates. The Stipulation also renews 14 existing riders, some of which were included in the company's ESP, and adds two new riders including the Enhanced Service Reliability Rider to recover vegetation management costs not included in base rates, up to $10 million per year (operation and maintenance only) and the PowerForward Rider to recover costs incurred to enhance the customer experience and further transform the grid (operation and maintenance and capital). The Stipulation is subject to the review and approval of the PUCO. An evidentiary hearing to review the Stipulation and other issues in the cases concluded on August 6, 2018. Initial briefs were filed on September 11, 2018. Reply briefs were filed October 2, 2018. In addition to the changes in revenue attributable to the Stipulation, Duke Energy Ohio’s capital-related riders, including the Distribution Capital Investments Rider, began to reflect the lower federal income tax rate associated with the Tax Act with updates to customers’ bills beginning April 1, 2018. This change reduces electric revenue by approximately $20 million on an annualized basis. Duke Energy Ohio cannot predict the outcome of this matter.

Ohio Valley Electric Corporation

On March 31, 2017, Duke Energy Ohio filed for approval to adjust its existing price stabilization rider (Rider PSR), which is currently set at zero dollars, to pass through net costs related to its contractual entitlement to capacity and energy from the generating assets owned by OVEC. 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. Various intervenors have filed motions to dismiss or stay the proceeding and Duke Energy Ohio has opposed these filings. On April 13, 2018, Duke Energy Ohio filed a Motion to consolidate this proceeding with several other cases currently pending before the PUCO. Also on April 13, 2018, Duke Energy Ohio, along with certain intervenors, filed a Stipulation with the PUCO resolving numerous issues including those related to Rider PSR. The Stipulation, if approved, would activate Rider PSR for recovery of net costs incurred since January 1, 2018. The Stipulation is subject to the review and approval of PUCO. An evidentiary hearing to review the Stipulation and other issues in the cases concluded on August 6, 2018. Initial briefs were filed on September 11, 2018. Reply briefs were filed October 2, 2018. See Note 12 for additional discussion of Duke Energy Ohio's ownership interest in OVEC. Duke Energy Ohio cannot predict the outcome of this matter.

Tax Act – Ohio

On July 25, 2018, Duke Energy Ohio filed an application to establish a new rider to implement the benefits of the Tax Act for electric distribution customers. Duke Energy Ohio requested commission approval to implement the rider effective October 1, 2018, as a credit to all distribution customers based upon a percent reduction to Duke Energy Ohio’s distribution rates. The new rider will flow through to customers the benefit of the lower statutory federal tax rate from 35 to 21 percent since January 1, 2018, all future benefits of the lower tax rates and a full refund of deferred income taxes collected at the higher tax rates in prior years. Deferred income taxes subject to normalization rules will be refunded consistent with federal law and deferred income taxes not subject to normalization rules will be refunded over a 10-year period. An order is expected during the fourth quarter of 2018. Duke Energy Ohio's transmission rates reflect lower federal income tax but guidance from FERC on amortization of both protected and unprotected transmission-related EDITs is still pending. On October 24, 2018, the PUCO issued a Finding and Order that, among other things, directed all rate-regulated utilities file an application not for an increase in rates to reflect the impact of the Tax Act on their current rates by January 1, 2019, unless otherwise exempted or directed by the PUCO. Duke Energy Ohio's July 25, 2018, filing for electric distribution operations is consistent with the commission's October 24, 2018, Finding and Order and no further action is needed. Options for Duke Energy Ohio gas customers are still being evaluated. 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. In December 2016, the PUCO granted the intervenors request for rehearing for the purpose of further review. Duke Energy Ohio cannot predict the outcome of this matter.

On June 15, 2016, Duke Energy Ohio filed an application for approval of a three-year energy efficiency and peak demand reduction portfolio of programs. A stipulation and modified stipulation were filed on December 22, 2016, and January 27, 2017, respectively. Under the terms of the stipulations, which included support for deferral authority of all costs and a cap on shared savings incentives, Duke Energy Ohio has offered its energy efficiency and peak demand reduction programs throughout 2017. On February 3, 2017, Duke Energy Ohio filed for deferral authority of its costs incurred in 2017 in respect of its proposed energy efficiency and peak demand reduction portfolio. On September 27, 2017, the PUCO issued an order approving a modified stipulation. The modifications impose an annual cap of approximately $38 million on program costs and shared savings incentives combined, but allowed for Duke Energy Ohio to file for a waiver of costs in excess of the cap in 2017. The PUCO approved the waiver request up to a total cost of $56 million. On November 21, 2017, the PUCO granted Duke Energy Ohio's and intervenor's applications for rehearing of the September 27, 2017, order. On January 10, 2018, the PUCO denied the Ohio Consumers' Counsel’s application for rehearing of the PUCO order granting Duke Energy Ohio's waiver request; however, a decision on Duke Energy Ohio's application for rehearing remains pending. Duke Energy Ohio cannot predict the outcome of this matter.

2014 Electric Security Plan

In April 2015, the PUCO modified and approved Duke Energy Ohio's proposed ESP, with a three-year term and an effective date of June 1, 2015. The PUCO approved a competitive procurement process for SSO load, a distribution capital investment rider (Rider DCI) and a tracking mechanism for incremental distribution expenses caused by major storms. The PUCO also approved a placeholder tariff for a price stabilization rider, but denied Duke Energy Ohio's specific request to include Duke Energy Ohio's entitlement to generation from OVEC in the rider at this time; however, the order allows Duke Energy Ohio to submit additional information to request recovery in the future. On May 4, 2015, Duke Energy Ohio filed an application for rehearing requesting the PUCO to modify or amend certain aspects of the order. On May 28, 2015, the PUCO granted all applications for rehearing filed in the case for future consideration. On March 21, 2018, the PUCO issued an order denying Duke Energy Ohio's issues on rehearing. On April 20, 2018, Duke Energy Ohio filed a second application for rehearing based upon the commission’s March 21, 2018, Order. On May 16, 2018, the commission issued its third Entry on Rehearing granting in part, and denying in part, Duke Energy Ohio’s rehearing request.

On March 9, 2018, Duke Energy Ohio filed a motion to extend its then-current ESP, including all terms and conditions thereof, pending approval of a new ESP. On May 30, 2018, the PUCO granted the request, with modification. Specifically, the PUCO did not extend the cap applicable to Rider DCI beyond July 31, 2018. Duke Energy Ohio sought rehearing of this finding. On July 25, 2018, the PUCO granted the request and allowed a continuing cap on recovery under Rider DCI. On August 24, 2018, OMA and OCC filed an Application for Rehearing of the commission's decision. Duke Energy Ohio filed a Memorandum Contra OCC's request for rehearing of the commission's continuation of Rider DCI on September 4, 2018. On September 19, 2018, the PUCO issued an Order granting rehearing on the matter for further consideration. Duke Energy Ohio cannot predict the outcome of this matter.

On May 21, 2018, the Ohio Manufacturers' Association (OMA) filed a notice of appeal of PUCO's approval of Duke Energy Ohio’s ESP with the Ohio Supreme Court, challenging PUCO's approval of Duke Energy Ohio’s Price Stability Rider as a placeholder and its Rider DCI to recover incremental revenue requirement for distribution capital since Duke Energy Ohio’s last base rate case. On July 16, 2018, the Office of the Ohio Consumers' Counsel (OCC) filed its own appeal of Duke Energy Ohio’s ESP with the Ohio Supreme Court raising similar issues to that of the OMA. Duke Energy Ohio's Application for Rehearing was granted on July 25, 2018. Duke Energy Ohio filed a Motion to Intervene in the two Ohio Supreme Court appeals. OMA's Supreme Court brief was filed on August 20, 2018. PUCO submitted its brief on October 26, 2018, and Duke Energy Ohio filed its brief on October 29, 2018. 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 (the Central Corridor Project) in its Ohio service territory to increase system reliability and enable the retirement of older infrastructure. Duke Energy Ohio estimates the pipeline development costs and construction activities will range from $163 million to $245 million in direct costs (excluding overheads and AFUDC). Project construction activities, schedule and final costs are still subject to uncertainty due to potential additional permitting delays, construction productivity and other conditions and risks, which could result in additional project cost availability and a potential delay in the targeted in-service date. On January 20, 2017, Duke Energy Ohio filed an amended application with the Ohio Power Siting Board (OPSB) for approval of one of two proposed routes. A public hearing was held on June 15, 2017, and an adjudicatory hearing was scheduled to begin September 11, 2017. On August 24, 2017, an Attorney Examiner granted a request made by Duke Energy Ohio to delay the procedural schedule while it works through various issues related to the pipeline route. In April 2018, Duke Energy Ohio filed a motion with OPSB to establish a procedural schedule and filed supplemental information supporting its application. If approved, construction of the pipeline extension is expected to be completed before the 2021/2022 winter season. Duke Energy Ohio cannot predict the outcome of this matter.

Duke Energy Kentucky Electric Rate Case

On September 1, 2017, Duke Energy Kentucky filed a rate case with the KPSC requesting an increase in electric base rates of approximately $49 million, which represents an approximate 15 percent increase on the average customer bill. Subsequent to the filing, Duke Energy Kentucky adjusted the requested amount to $30.1 million, in part to reflect the benefits of the Tax Act, representing an approximate 9 percent increase on the average customer bill. The rate increase is driven by increased investment in utility plant, increased operations and maintenance expenses, and recovery of regulatory assets. The application also includes requests to implement an Environmental Surcharge Mechanism to recover environmental costs not recovered in base rates, to establish a Distribution Capital Investment Rider to recover incremental costs of specific programs, to establish a FERC Transmission Cost Reconciliation Rider to recover escalating transmission costs and to modify existing Profit Sharing Mechanism to increase customers' share of proceeds from the benefits of owning generation and to mitigate shareholder risks associated with that generation. An evidentiary hearing concluded on March 8, 2018, and the KPSC issued an order on April 13, 2018. Major components of the Order include approval of an $8.4 million increase in base rates with a return on equity at 9.725 percent based upon a capital structure of 49 percent equity on a total allocable capitalization of approximately $650 million. The Order approved the Environmental Surcharge Mechanism Rider and in June 2018 recovery began of capital-related environmental costs, including costs related to ash and ash disposal, and environmental operation and maintenance expenses formerly recovered in base rates, including expenses for environmental reagents and emission allowances. The incremental revenue from this rider will be approximately $13 million on an annualized basis. The order settles all issues associated with the Tax Act as it relates to the electric business by lowering the income tax component of the revenue requirement and refunding protected EDIT under allowable normalization rules and unprotected EDIT over 10 years. The Order denied requests to implement riders for certain transmission costs and distribution capital investments. Duke Energy Kentucky implemented new base rates on May 1, 2018. On May 3, 2018, Duke Energy Kentucky filed an application for rehearing on certain aspects of the order; on May 23, 2018, the KPSC granted a rehearing. On October 2, 2018, the KPSC issued its rehearing order correcting certain findings in its initial order and making additional changes that are immaterial to the company's earnings. Duke Energy Kentucky does not plan any further appeals.

Duke Energy Kentucky Natural Gas Base Rate Case

On August 31, 2018, Duke Energy Kentucky filed an application with the KPSC requesting an increase in natural gas base rates of approximately $10.5 million, an approximate 11.1 percent average increase across all customer classes. The increase is net of approximately $5.2 million in annual savings as a result of the Tax Act. The drivers for this case are capital invested since the Duke Energy Kentucky’s last rate case in 2009. Duke Energy Kentucky is also seeking implementation of a Weather Normalization Adjustment Mechanism, amortization of regulatory assets and to implement the impacts of the Tax Act, prospectively. The KPSC accepted Duke Energy Kentucky’s filing as of September 10, 2018, as meeting all filing requirements and issued its first round of discovery. A procedural schedule was set. A hearing is set to commence on February 5, 2019. A ruling is expected in late first quarter 2019. Duke Energy Kentucky cannot predict the outcome of this matter.

FERC 494 Refund of Regional Transmission Enhancement Projects

FERC Order No. 494 Settlement Agreement (FERC 494 Settlement Agreement) was entered into by most of the PJM Interconnection, LLC (PJM) transmission owners, including Duke Energy Ohio and Duke Energy Kentucky, and the PJM state regulatory commissions approximately two years ago and was planned to be effective on January 1, 2016; however, it was not approved by FERC until May 31, 2018. The FERC 494 Settlement Agreement was due to the Seventh Circuit Court of Appeals finding that FERC had failed to adequately justify the costs that the customers in the western part of PJM were being charged for high voltage transmission projects, or Regional Transmission Expansion Plan (RTEP) projects (500 kV and above) built in the east. These costs were being allocated to all PJM customers on a load-ratio share basis but the court determined that these costs were not justifiable to customers in the west, including Duke Energy Ohio and Duke Energy Kentucky, that did not benefit from the RTEP projects. Costs for the periods 2012 through 2015 are expected to be refunded to Duke Energy Ohio and Duke Energy Kentucky on a monthly basis through December 2025. The refund amount for similar costs incurred beginning in 2016 through June 30, 2018, prior to the change in cost allocation by PJM was determined in the third quarter of 2018 and these amounts will be refunded over a 12-month period beginning in July 2018. These refunds, totaling approximately $47 million for Duke Energy Ohio and Duke Energy Kentucky, have been recorded to Operation, maintenance and other on the Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2018.

Duke Energy Indiana

FERC Transmission Return on Equity Complaint

Customer groups have filed with the FERC complaints against Midcontinent Independent System Operator, Inc. (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 claim, among other things, 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. On October 16, 2018, FERC issued an order in response to the Emera remand proceeding proposing a new method for determining whether an existing return on equity is unjust and unreasonable, and a new process for determining a just and reasonable return on equity. The parties involved in the Emera proceeding are directed to file briefs by December 15, 2018. Duke Energy Indiana is in discussions with the other MISO Transmission Owners to determine strategy in light of this order. 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.

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 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 it 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. Duke Energy Indiana recorded an obligation and a regulatory asset related to the settlement amount in fourth quarter 2016. On June 30, 2017, the parties finalized a settlement agreement. Terms of the settlement included Duke Energy Indiana paying $29 million for back damages. Additionally, the parties agreed on the method by which the contract will be bid into the market in the future. The settlement amount was paid in June 2017. The IURC issued an order on September 27, 2017, approving recovery of the settlement amount through Duke Energy Indiana's fuel clause. The IURC order has been appealed to the Indiana Court of Appeals. On May 21, 2018, the Indiana Court of Appeals upheld the commission's decision. The appellants have requested rehearing at the Indiana Court of Appeals. The Indiana Court of Appeals denied the request for rehearing. The appellants have requested transfer to the Indiana Supreme Court, including briefs in support from environmental groups. Duke Energy Indiana cannot predict the outcome of this matter.

Edwardsport Integrated Gasification Combined Cycle Plant

On September 20, 2018, Duke Energy Indiana, the Indiana Office of Utility Consumer Counselor (OUCC), the Duke Industrial Group and Nucor Steel – Indiana entered into a settlement agreement to resolve integrated gasification combined cycle (IGCC) ratemaking issues for calendar years 2018 and 2019. The agreement will remain in effect until new rates are established in Duke Energy Indiana's next base rate case, which is expected to be filed in mid-2019 with rates effective in mid-2020. It addresses the pending Edwardsport filing at the commission and eliminates the need for future filings until the overall rate case. This settlement includes caps on Duke Energy Indiana’s retail operating expenses for 2018 and 2019, reduces Duke Energy Indiana's regulatory asset by $30 million (with a corresponding reduction of the amount of amortization of the regulatory asset included in rates by $10 million annually beginning with the implementation of final IGCC 17 rates), and provides funding for low- income assistance and clean energy projects. Duke Energy Indiana recognized pretax impairment and related charges of $32 million in the third quarter of 2018. The settlement is subject to IURC approval. An evidentiary hearing is scheduled for December 2018. Duke Energy Indiana cannot predict the outcome of this matter.

Tax Act

On June 27, 2018, Duke Energy Indiana, the Indiana Office of Utility Consumer Counselor, the Indiana Industrial Group and Nucor Steel – Indiana filed testimony consistent with their Stipulation and Settlement Agreement (Settlement Agreement) in the federal tax act proceeding with the IURC. The Settlement Agreement outlines how Duke Energy Indiana will implement the impacts of the Tax Act. Material components of the Settlement Agreement were as follows:

• Riders to reflect the change in the statutory federal tax rate from 35 to 21 percent as they are filed in 2018;

• Base rates to reflect the change in the statutory federal tax rate from 35 to 21 percent upon IURC approval, but no later than September 1, 2018;

• Duke Energy Indiana to continue to defer protected federal EDIT until January 1, 2020, at which time it will be returned to customers according to the Average Rate Assumption Method (ARAM) required by the Internal Revenue Service over approximately 26 years; and

• Duke Energy Indiana to begin returning unprotected federal EDIT upon IURC approval, over 10 years. In order to mitigate the negative impacts to cash flow and credit metrics, the Settlement Agreement allows Duke Energy Indiana to return $7 million per year over the first five years, with a step up to $35 million per year in the following five years.

The settlement was subject to the review and approval of the IURC. An evidentiary hearing was held on July 13, 2018. On August 22, 2018, the IURC approved the settlement and rates have been adjusted effective September 1, 2018.

Piedmont

South Carolina Rate Stabilization Adjustment Filing

On June 15, 2018, Piedmont filed with the PSCSC under the South Carolina Rate Stabilization Act its quarterly monitoring report for the 12-month period ending March 31, 2018. The filing included a revenue deficiency calculation and tariff rates in order to permit Piedmont the opportunity to earn the rate of return on common equity established in its last general rate case. The filing also incorporated the impacts of the Tax Act by lowering the income tax component of the revenue requirement, refunding protected EDIT under allowable normalization rules, unprotected EDIT and amounts over collected from the customers from January 1, 2018, through the end of the review period for this proceeding. A settlement agreement reached between Piedmont and ORS was filed with the PSCSC on September 14, 2018, and approved by the PSCSC on October 3, 2018. Terms of the settlement include implementation of rates for the 12-month period beginning November 2018 with a return on equity of 10.2 percent.

North Carolina Integrity Management Rider Filing

In October 2018, Piedmont filed a petition under the Integrity Management Rider (IMR) mechanism to collect an additional $9.5 million in annual revenues effective December 2018 based on the eligible capital investments closed to integrity and safety projects over the six-month period ended September 30, 2018. Piedmont cannot predict the outcome of this matter.

In May 2018, Piedmont filed, and the NCUC approved, a petition under the IMR mechanism to update rates, effective June 2018, based on the eligible capital investments closed to integrity and safety projects over the six-month period ending March 31, 2018, and the decrease in the corporate federal income tax rate effective January 1, 2018. The combined effect of the update was a reduction to annual revenues of approximately $5.7 million.

OTHER REGULATORY MATTERS

Progress Energy Merger FERC Mitigation

Since December 2014, the FERC Office of Enforcement has conducted an investigation of Duke Energy’s market power filings in its application for approval of the Progress Energy merger submitted in 2012. On June 8, 2018, the FERC issued an order approving a settlement agreement under which Duke Energy paid a penalty of $3.5 million. The FERC Office of Enforcement stated in its conclusion that Duke Energy violated FERC regulations by failing to fully and accurately describe certain specific matters in its market power filings. Duke neither admitted nor denied the alleged violations.

Atlantic Coast Pipeline, LLC

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, in part, the needs identified by Duke Energy Carolinas, Duke Energy Progress and Piedmont. 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, which is accounted for as an equity method investment 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.

In 2018, the FERC issued a series of Notices to Proceed, which authorized the project to begin certain construction-related activities along the pipeline route, including supply header and compressors. On May 11, 2018, and October 19, 2018, FERC issued Notices to Proceed allowing full construction activities in all areas of West Virginia except in the Monongahela National Forest. On July 24, 2018, FERC issued a Notice to Proceed allowing full construction activities along the project route in North Carolina. On October 19, 2018, the conditions to effectiveness of the Virginia 401 water quality certification were satisfied. Immediately following receipt of the Virginia 401 certification, ACP filed a request for FERC to issue a Notice to Proceed with full construction activities in Virginia, receipt of which is expected shortly. We appreciate the professional and collaborative process the permitting agencies have pursued to ensure that this critical energy infrastructure project will meet the stringent environmental standards required by law and regulation.

ACP is the subject of challenges in state and federal courts and agencies, including, among others, challenges of the project’s incidental take statement (ITS), crossings of the Blue Ridge Parkway, the Appalachian Trail, and the Monongahela and George Washington National Forests, the project’s U.S. Army Corps of Engineers (USACE) 404 permit, the Virginia conditional 401 water quality certification, the FERC Environmental Impact Statement order and the FERC order approving the Certificate of Public Convenience and Necessity. Each of these challenges alleges non-compliance on the part of federal and state permitting authorities and adverse ecological consequences if the project is permitted to proceed. ACP is vigorously defending these challenges and coordinating with the federal and state authorities which are the direct parties to the challenges. Since July 2018, notable developments in these challenges include a stay issued by the U.S. Court of Appeals for the Fourth Circuit (Fourth Circuit) on construction activities through the Monongahela and George Washington National Forests, a reissuance of the project’s ITS and Blue Ridge Parkway right-of-way and renewed challenges of these reissued permits and the USACE’s lifting of its administrative stay of ACP’s Huntington District 404 permit.

The FERC Stop Work Order following the Fourth Circuit's vacatur of the project's ITS and Blue Ridge Parkway right-of-way, together with delays in obtaining permits necessary for construction have impacted the cost and schedule for the project. As a result, project cost estimates have increased from a range of $6.0 billion to $6.5 billion to a range of $6.5 billion to $7.0 billion, excluding financing costs. ACP is pursuing a phased in-service approach with customers whereby it maintains a late 2019 in-service date for key segments of the project to meet peak winter demand in critically constrained regions served by the project. ACP will be pursuing a mid-2020 in-service date for the remaining segments. Abnormal weather, work delays (including delays due to judicial or regulatory action) and other conditions may result in cost or schedule modifications in the future.

Sabal Trail Transmission, LLC

On May 4, 2015, Duke Energy acquired a 7.5 percent ownership interest in Sabal Trail, which is accounted for as an equity method investment, 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 to construct 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 traverses 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. See Note 12 for additional information related to Duke Energy's ownership interest.

On February 3, 2016, the FERC issued an order granting the request for a CPCN to construct and operate the pipeline. The Sabal Trail pipeline received other required regulatory approvals and the Phase 1 mainline was placed in service in July 2017. On October 12, 2017, Sabal Trail filed a request with FERC to place in service a lateral line to Duke Energy Florida's Citrus County Combined Cycle Facility. This request is required to support commissioning and testing activities at the facility. On March 16, 2018, FERC approved the Citrus lateral and it was placed in service.

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 (D.C. Circuit Court of Appeals). On August 22, 2017, the appeals court ruled against FERC in the case for failing to include enough information on the impact of greenhouse-gas emissions carried by the pipeline, vacated the CPCN order and remanded the case to FERC. In response to the August 2017 court decision, the FERC issued a draft Supplemental Environmental Impact Statement (SEIS) on September 27, 2017. On October 6, 2017, FERC and a group of industry intervenors, including Sabal Trail and Duke Energy Florida, filed separate petitions with the D.C. Circuit Court of Appeals requesting rehearing regarding the court's decision to vacate the CPCN order. On January 31, 2018, the D.C. Circuit Court of Appeals denied the requests for rehearing. On February 2, 2018, Sabal Trail filed a request with FERC for expedited issuance of its order on remand and reissuance of the CPCN. In the alternative, the pipeline requested that FERC issue a temporary emergency CPCN to allow for continued operations. On February 5, 2018, FERC issued the final SEIS. On February 6, 2018, FERC and the intervenors in this case each filed motions for stay with the D.C. Circuit Court to stay the court's mandate. On March 7, 2018, the D.C. Circuit Court of Appeals granted FERC and Sabal Trail’s stay request. On March 14, 2018, FERC issued its final order on remand, which recertified the project. On August 10, 2018, FERC denied requests for rehearing of the final order on remand.

Constitution Pipeline Company, LLC

Duke Energy owns a 24 percent ownership interest in Constitution, which is accounted for as an equity method investment. 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. Before the permitting delays discussed below, Duke Energy's total anticipated contributions were approximately $229 million. As a result of the permitting delays and project uncertainty, total anticipated contributions by Duke Energy can no longer be reasonably estimated. Since April 2016, with the actions of the New York State Department of Environmental Conservation (NYSDEC), Constitution stopped construction and discontinued capitalization of future development costs until the project's uncertainty is resolved.

In December 2014, Constitution received approval from the FERC to construct and operate the proposed pipeline. However, on April 22, 2016, the 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. Court of Appeals for the Second Circuit (U.S. Court of Appeals) challenging the legality and appropriateness of the NYSDEC’s decision and on August 18, 2017, the petition was denied in part and dismissed in part. In September 2017, Constitution filed a petition for a rehearing of portions of the decision unrelated to the water quality certification, which was denied by the U.S. Court of Appeals. In January 2018, Constitution petitioned the Supreme Court of the United States to review the U.S. Court of Appeals decision, and on April 30, 2018, the Supreme Court denied Constitution's petition. In October 2017, Constitution filed a petition for declaratory order requesting FERC to find that the NYSDEC waived its rights to issue a Section 401 water quality certification by not acting on Constitution's application within a reasonable period of time as required by statute. This petition was based on precedent established by another pipeline’s successful petition with FERC following a District of Columbia Circuit Court ruling. On January 11, 2018, FERC denied Constitution's petition. In February 2018, Constitution filed a rehearing request with FERC of its finding that the NYSDEC did not waive the Section 401 certification requirement. On July 19, 2018, FERC denied Constitution's rehearing request. Constitution is currently unable to approximate an in-service date for the project due to the NYSDEC's denial of the water quality certification. The Constitution partners remain committed to the project and are evaluating next steps to move the project forward. On June 25, 2018, Constitution filed with FERC a Request for Extension of Time until December 2, 2020, for construction of the project. Duke Energy cannot predict the outcome of this matter.

During the nine months ended September 30, 2018, Duke Energy recorded an other-than-temporary impairment (OTTI) of $55 million within Equity in earnings of unconsolidated affiliates on Duke Energy's Condensed Consolidated Statements of Operations. The charge represents the excess carrying value over the estimated fair value of the project, which was based on a Level 3 Fair Value measurement that was determined from the income approach using discounted cash flows. The impairment was primarily due to the recent actions taken by the courts and regulators to uphold the NYSDEC's denial of the certification and uncertainty associated with the remaining legal and regulatory challenges.

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. 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 U.S. Environmental Protection Agency (EPA) regulations recently approved or proposed.

The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement due to a lack of requisite environmental control equipment. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of September 30, 2018, 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	$	132
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2(b)	766	100
Duke Energy Indiana
Gallagher Units 2 and 4(c)	280	123
Total Duke Energy	1,631	$	355

(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 expects to retire these coal units by the end of 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 2016 settlement of Edwardsport IGCC matters.

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

XML

Commitments and Contingencies

9 Months Ended

Sep. 30, 2018

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 (ARO) 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 on 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 Accounts Payable within Current Liabilities and Other within Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets.

	Nine Months Ended September 30, 2018
				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	$	81		$	10		$	15		$	3		$	12		$	47		$	5		$	2
Provisions/adjustments	7			3			2			3			(1		)	3			1			—
Cash reductions	(20		)	(2		)	(5		)	(1		)	(4		)	(12		)	(1		)	—
Balance at end of period	$	68		$	11		$	12		$	5		$	7		$	38		$	5		$	2

	Nine Months Ended September 30, 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	(1		)	2			1			—		1			(3		)	(2		)	1
Cash reductions	(13		)	(2		)	(3		)	—		(3		)	(7		)	(1		)	—
Balance at end of period	$	84		$	10		$	16		$	3	$	12		$	49		$	7		$	2

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	$	57
Duke Energy Carolinas	17
Duke Energy Ohio	30
Piedmont	2

LITIGATION

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 Coal Ash Act and the EPA CCR rule at 15 coal-fired plants in North Carolina and South Carolina. The parties are engaged in discovery. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

NCDEQ State Enforcement Actions

In the first quarter of 2013, the Southern Environmental Law Center (SELC) sent notices of intent to sue Duke Energy Carolinas and Duke Energy Progress related to alleged Clean Water Act (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 in the North Carolina Superior Court.

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. On February 13, 2017, the court issued an order denying motions for partial summary judgment brought by both the environmental groups and Duke Energy Carolinas and Duke Energy Progress for the remaining seven plants. On March 15, 2017, Duke Energy Carolinas and Duke Energy Progress filed a Notice of Appeal with the North Carolina Court of Appeals to challenge the trial court’s order. The parties were unable to reach an agreement at mediation in April 2017 and submitted briefs to the trial court on remaining issues to be tried. On August 1, 2018, the Court of Appeals dismissed the appeal and the matter is proceeding before the trial court. No trial date has been scheduled. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

Federal Citizens Suits

On June 13, 2016, the Roanoke River Basin Association (RRBA) 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 (NPDES) permit provisions survived the motion to dismiss, and Duke Energy Progress filed its response on May 10, 2017. Duke Energy Progress and RRBA each filed motions for summary judgment on March 23, 2018. The court has not yet ruled on these motions.

On May 16, 2017, RRBA filed a federal citizen suit in the U.S. District Court for the Middle District of North Carolina, which asserts two claims relating to alleged violations of NPDES permit provisions at the Roxboro Plant and one claim relating to the use of nearby water bodies. Duke Energy Progress and RRBA each filed motions for summary judgment on April 17, 2018, and the court has not yet ruled on these motions.

On May 8, 2018, on motion from Duke Energy Progress, the court ordered trial in both of the above matters to be consolidated. Trial is currently scheduled for July 15, 2019.

On June 20, 2017, RRBA filed a federal citizen suit in the U.S. District Court for the Middle District of North Carolina challenging the closure plans at the Mayo Plant under the EPA CCR Rule. Duke Energy Progress filed a motion to dismiss, which was granted by the court on March 30, 2018. RRBA had until April 30, 2018, to file an appeal to the Fourth Circuit but did not do so.

On August 2, 2017, RRBA filed a federal citizen suit in the U.S. District Court for the Middle District of North Carolina challenging the closure plans at the Roxboro Plant under the EPA CCR Rule. Duke Energy Progress filed a motion to dismiss on October 2, 2017, which was granted by the court on May 29, 2018. RRBA had until June 28, 2018, to file an appeal to the Fourth Circuit but did not do so.

On December 5, 2017, various parties filed a federal citizen suit in the U.S. District Court for the Middle District of North Carolina for alleged violations at Duke Energy Carolinas' Belews Creek Steam Station (Belews Creek) under the CWA. Duke Energy Carolinas filed a motion to dismiss on February 5, 2018, and on August 13, 2018, the court issued an order denying Duke Energy Carolinas’ motion to dismiss. Duke Energy Carolinas' answer to the complaint was filed on August 27, 2018. On October 10, 2018, Duke Energy Carolinas filed Motions to Dismiss for lack of standing, Motion for Judgment on the Pleadings and Motion to Stay Discovery. A hearing on the motion to stay is scheduled for December 12, 2018, and a scheduling conference has been set for January 2019.

Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of these matters.

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). Results of Comprehensive Site Assessments testing performed by Duke Energy under the Coal Ash Act 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 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 led 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 an 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. Settlement payments are being made, and, as of September 30, 2018, Duke Energy Carolinas and Duke Energy Progress have remaining reserves of $4 million and $2 million, respectively.

On August 23, 2017, a class-action suit was filed in Wake County Superior Court, North Carolina, against Duke Energy Carolinas and Duke Energy Progress on behalf of certain property owners living near coal ash impoundments at Allen, Asheville, Belews Creek, Buck, Cliffside, Lee, Marshall, Mayo and Roxboro. The class is defined as those who are “well-eligible” under the Coal Ash Act or those to whom Duke Energy has promised a permanent replacement water supply and seeks declaratory and injunctive relief, along with compensatory damages. Plaintiffs allege that Duke Energy’s improper maintenance of coal ash impoundments caused harm, particularly through groundwater contamination. Despite NCDEQ’s preliminary approval, Plaintiffs contend that Duke Energy’s proposed permanent water solutions plan fails to comply with the Coal Ash Act. On September 28, 2017, Duke Energy Carolinas and Duke Energy Progress filed a Motion to Dismiss and Motion to Strike the class designation. The parties entered into a Settlement Agreement on January 24, 2018, which resulted in the dismissal of the underlying class action on January 25, 2018.

On September 14, 2017, a complaint was filed against Duke Energy Progress in New Hanover County Superior Court by a group of homeowners residing approximately 1 mile from Duke Energy Progress' Sutton Steam Plant (Sutton). The homeowners allege that coal ash constituents have been migrating from ash impoundments at Sutton into their groundwater for decades and that in 2015, Duke Energy Progress discovered these releases of coal ash, but failed to notify any officials or neighbors and failed to take remedial action. The homeowners claim unspecified physical and mental injuries as a result of consuming their well water and seek actual damages for personal injury, medical monitoring and punitive damages. On March 6, 2018, Plaintiffs' counsel voluntarily dismissed the action without prejudice

It is not possible to estimate the maximum exposure of loss, if any, that may occur in connection with future claims that 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 September 30, 2018, there were 160 asserted claims for non-malignant cases with cumulative relief sought of up to $43 million, and 63 asserted claims for malignant cases with cumulative relief sought of up to $19 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 $461 million at September 30, 2018, and $489 million at December 31, 2017. 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 2037, 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 2037 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 $764 million in excess of the self-insured retention. Receivables for insurance recoveries were $553 million at September 30, 2018, and $585 million at December 31, 2017. These amounts are classified in Other within Other Noncurrent Assets and Receivables within Current Assets 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 Progress and Duke Energy Florida

Spent Nuclear Fuel Matters

On October 16, 2014, Duke Energy Progress and Duke Energy Florida sued the U.S. in the U.S. Court of Federal Claims. The lawsuit claimed the Department of Energy breached a contract in failing to accept spent nuclear fuel under the Nuclear Waste Policy Act of 1982 and asserted damages for the cost of on-site storage. Duke Energy Progress and Duke Energy Florida asserted damages for the period January 1, 2011, through December 31, 2013, of $48 million and $25 million, respectively. On November 17, 2017, the court awarded Duke Energy Progress and Duke Energy Florida $48 million and $21 million, respectively, subject to appeal. No appeals were filed and Duke Energy Progress and Duke Energy Florida recognized the recoveries in the first quarter of 2018. Claims for all periods through 2013 have been resolved. On June 22, 2018, Duke Energy Progress and Duke Energy Florida filed a complaint for damages incurred for 2014 through first quarter 2018.

Duke Energy Progress

Gypsum Supply Agreement Matter

On June 30, 2017, CertainTeed Gypsum NC, Inc. (CertainTeed) filed a declaratory judgment action against Duke Energy Progress in the North Carolina Business Court relating to a gypsum supply agreement. In its complaint, CertainTeed sought an order from the court declaring that the minimum amount of gypsum Duke Energy Progress must provide to CertainTeed under the supply agreement is 50,000 tons per month through 2029. Subsequently, CertainTeed also sought a preliminary injunction requiring Duke Energy Progress to provide 50,000 tons of gypsum per month through the trial date. The parties reached an agreement under which Duke Energy Progress delivered 50,000 tons of gypsum per month through August 2018. Trial in this matter was completed on July 16, 2018. On August 29, 2018, the court issued an order and opinion finding that Duke Energy Progress is required to supply 50,000 tons of gypsum/month, but that CertainTeed’s sole remedy for Duke Energy Progress’ long-term discontinuance under the agreement is liquidated damages. This ruling effectively limits CertainTeed’s remedies in the event that Duke Energy Progress elects to permanently discontinue gypsum supply at the Roxboro plant. The estimated maximum amount that would be owed under the liquidated damages provision is approximately $90 million. Both CertainTeed and Duke Energy Progress have filed cross-appeals, as they explore a possible resolution. Duke Energy Progress cannot predict the outcome of this matter.

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 to the Eleventh Circuit U.S. Court of Appeals (Eleventh Circuit). On July 11, 2018, the Eleventh Circuit affirmed the U.S. District Court's dismissal of the lawsuit. The deadline to file a petition for cert was October 9, 2018, and no petition was filed; therefore, the dismissal of the lawsuit is final.

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 sought recovery of $54 million in milestone payments in excess of work performed under an Engineering, Procurement and Construction agreement (EPC) for Levy as well as a determination by the court of the amounts due to Westinghouse as a result of the termination of an EPC contract. Duke Energy Florida recognized an exit obligation as a result of the termination of the EPC. On March 31, 2014, Westinghouse filed a separate lawsuit against Duke Energy Florida in U.S. District Court for the Western District of Pennsylvania alleging damages under the same EPC contract 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 would 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, granting Westinghouse a $30 million termination fee claim and dismissing Duke Energy Florida's $54 million refund claim. Westinghouse's claim for termination costs continued to trial. Following a trial on the matter, the court issued an order in December 2016 denying Westinghouse’s claim for termination costs and reaffirming its earlier ruling in favor of Westinghouse on the $30 million termination fee. Judgment was entered against Duke Energy Florida in the amount of approximately $34 million, which includes prejudgment interest. Westinghouse appealed the trial court's order to the Fourth Circuit and Duke Energy Florida cross-appealed.

On March 29, 2017, Westinghouse filed Chapter 11 bankruptcy in the Southern District of New York, which automatically stayed the appeal. On May 23, 2017, the bankruptcy court entered an order lifting the stay with respect to the appeal. Briefing of the appeal concluded on October 20, 2017. Westinghouse and Duke Energy Florida executed a settlement agreement resolving this matter on April 5, 2018. The bankruptcy court approved the settlement and Duke Energy Florida paid approximately $34 million to Westinghouse in July 2018 pursuant to this agreement. At the request of the parties, the Fourth Circuit has dismissed the appeal.

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 Sixth Circuit, which affirmed the trial court's ruling on April 10, 2018. The dismissal of the lawsuit is therefore final.

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 related to the termination of an EPC contract discussed above. 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)	September 30, 2018		December 31, 2017
Reserves for Legal Matters
Duke Energy	$	63	$	88
Duke Energy Carolinas	11		30
Progress Energy	50		55
Duke Energy Progress	11		13
Duke Energy Florida	23		24
Piedmont	1		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.

XML

Debt and Credit Facilities

9 Months Ended

Sep. 30, 2018

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).

				Nine Months Ended September 30, 2018
						Duke		Duke		Duke		Duke
	Maturity	Interest		Duke		Energy		Energy		Energy		Energy
Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Progress		Florida
Unsecured Debt
March 2018(a)	April 2025	3.950	%	$	250	$	250	$	—	$	—	$	—
May 2018(b)	May 2021	2.819	%	500		500		—		—		—
September 2018(c)	September 2078	5.625	%	500		500		—		—		—
First Mortgage Bonds
March 2018(d)	March 2023	3.050	%	500		—		500		—		—
March 2018(d)	March 2048	3.950	%	500		—		500		—		—
June 2018(e)	July 2028	3.800	%	600		—		—		—		600
June 2018(e)	July 2048	4.200	%	400		—		—		—		400
August 2018(f)	September 2023	3.375	%	300		—		—		300		—
August 2018(f)	September 2028	3.700	%	500		—		—		500		—
Total issuances				$	4,050	$	1,250	$	1,000	$	800	$	1,000

(a) Debt issued to pay down short-term debt.

(b) Debt issued to pay down short-term debt. Debt issuance has a floating interest rate.

(c) Callable after September 2023 at par. Debt issued to pay down short-term debt and for general corporate purposes.

(d) Debt issued to repay at maturity a $300 million first mortgage bond due April 2018, pay down intercompany short-term debt and for general corporate purposes.

(e) Debt issued to repay a portion of intercompany short-term debt under money-pool borrowing arrangement and for general corporate purposes.

(f) Debt issued to repay short-term debt and for general corporate purposes.

CURRENT MATURITIES OF LONG-TERM DEBT

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

(in millions)	Maturity Date	Interest Rate			September 30, 2018
Unsecured Debt
Progress Energy	March 2019	7.050	%		$	450
Duke Energy (Parent)	September 2019	5.050	%		500
Piedmont	September 2019	2.848	%	(b)	350
First Mortgage Bonds
Duke Energy Carolinas	November 2018	7.000	%		500
Duke Energy Progress	January 2019	5.300	%		600
Duke Energy Ohio	April 2019	5.450	%		450
Other(a)					605
Current maturities of long-term debt					$	3,455

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

(b)    Debt issuance has a floating interest rate.

AVAILABLE CREDIT FACILITIES

Master Credit Facility

In January 2018, Duke Energy extended the termination date of substantially all of its existing $8 billion Master Credit Facility capacity from March 16, 2022, to March 16, 2023. In May 2018, Duke Energy completed the extension process with 100 percent of all commitments to the Master Credit Facility extending to March 16, 2023. 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.

	September 30, 2018
				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		$	2,650		$	1,750		$	1,400		$	650	$	450		$	600		$	500
Reduction to backstop issuances
Commercial paper(b)	(2,519		)	(988		)	(872		)	(150		)	—		(216		)	(293		)	—
Outstanding letters of credit	(55		)	(47		)	(4		)	(2		)	—		—			—			(2		)
Tax-exempt bonds	(81		)	—			—			—			—		—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—		—			—			—
Available capacity under the Master Credit Facility	$	4,845		$	1,615		$	624		$	998		$	650	$	234		$	226		$	498

(a) Represents the sublimit of each borrower.

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

Three-Year Revolving Credit Facility

Duke Energy (Parent) has a $1.0 billion revolving credit facility (the Three Year Revolver) through June 2020. As of September 30, 2018, $500 million has been drawn under the Three Year Revolver. This balance is classified as Long-Term Debt on Duke Energy's Condensed Consolidated Balance Sheets. Any undrawn commitments can be drawn and borrowings can be prepaid, at any time throughout the term of the facility. The terms and conditions of the Three Year Revolver are generally consistent with those governing Duke Energy's Master Credit Facility.

Piedmont Term Loan Facility

In September 2018, Piedmont executed an amendment to its existing senior unsecured term loan (the Piedmont Term Loan). The amendment increased commitments from $250 million to $350 million and extended the maturity date to September 2019. As of September 30, 2018, the entire $350 million has been drawn under the Piedmont Term Loan. The balance is classified as Current maturities of long-term debt on Piedmont's Condensed Consolidated Balance Sheets.

XML

Asset Retirement Obligations

9 Months Ended

Sep. 30, 2018

Asset Retirement Obligation [Abstract]

Asset Retirement Obligations

ASSET RETIREMENT OBLIGATIONS

The Duke Energy Registrants record AROs when there is a legal obligation to incur retirement costs associated with the retirement of a long-lived asset and the obligation can be reasonably estimated. The following table presents the AROs recorded on the Condensed Consolidated Balance Sheets.

	September 30, 2018
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Decommissioning of Nuclear Power Facilities(a)	$	5,367	$	2,031	$	3,181	$	2,650	$	531	$	—	$	—	$	—
Closure of Ash Impoundments	4,575		1,623		2,175		2,154		20		52		725		—
Other	314		58		79		37		42		46		19		15
Total ARO	$	10,256	$	3,712	$	5,435	$	4,841	$	593	$	98	$	744	$	15
Less: current portion	902		292		475		470		4		7		128		—
Total noncurrent ARO	$	9,354	$	3,420	$	4,960	$	4,371	$	589	$	91	$	616	$	15

(a)    Duke Energy amount includes purchase accounting adjustments related to the merger with Progress Energy.

ARO Liability Rollforward

Actual closure costs incurred could be materially different from current estimates that form the basis of the recorded AROs. The following table presents the change in liability associated with AROs for the Duke Energy Registrants.

				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Balance at December 31, 2017(a)	$	10,175		$	3,610		$	5,414		$	4,673		$	742		$	84		$	781		$	15
Accretion expense(b)	319			133			168			145			23			3			22			—
Liabilities settled(c)	(431		)	(198		)	(186		)	(155		)	(31		)	(5		)	(42		)	—
Liabilities incurred in the current year	34			8			—			—			—			—			25			—
Revisions in estimates of cash flows(d)	159			159			39			178			(141		)	16			(42		)	—
Balance at September 30, 2018	$	10,256		$	3,712		$	5,435		$	4,841		$	593		$	98		$	744		$	15

(a) Primarily relates to decommissioning nuclear power facilities, closure of ash impoundments, asbestos removal, closure of landfills at fossil generation facilities, retirement of natural gas mains and removal of renewable energy generation assets.

(b) For the nine months ended September 30, 2018, substantially all accretion expense relates to Duke Energy's regulated operations and has been deferred in accordance with regulatory accounting treatment.

(c) Primarily relates to ash impoundment closures and nuclear decommissioning of Crystal River Unit 3.

(d) Primarily relates to increases in groundwater monitoring estimates for closure of ash impoundments, partially offset by modifications to the timing of expected cash flows and a reduction for nuclear decommissioning at Crystal River Unit 3 compared to original estimates.

Asset retirement costs associated with the AROs for operating plants and retired plants are included in Net property, plant and equipment and Regulatory assets within Other Noncurrent Assets, respectively, on the Condensed Consolidated Balance Sheets.

XML

Goodwill

9 Months Ended

Sep. 30, 2018

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill

GOODWILL

Duke Energy

The following table presents the goodwill by reportable operating segment included on Duke Energy's Condensed Consolidated Balance Sheets at September 30, 2018, and December 31, 2017.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables			Total
Goodwill balance at December 31, 2017	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(29		)	$	(29	)
Goodwill balance at December 31, 2017, adjusted for accumulated impairment charges	$	17,379	$	1,924	$	93		$	19,396
Goodwill balance at September 30, 2018	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(122		)	(122		)
Goodwill balance at September 30, 2018, adjusted for accumulated impairment charges	$	17,379	$	1,924	$	—		$	19,303

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 September 30, 2018, and December 31, 2017.

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.

Impairment Testing

Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont are required to perform an annual goodwill impairment test as of the same date each year and, accordingly, perform their annual impairment testing of goodwill as of August 31. Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont update their test between annual tests if events or circumstances occur that would more likely than not reduce the fair value of a reporting unit below its carrying value.

In the third quarter of 2018, based on the results of the annual quantitative goodwill impairment test, management determined that the fair value of the Commercial Renewables reporting unit was below its respective carrying value, including goodwill. Determination of the Commercial Renewables reporting unit fair value was based on an income approach, which estimates the fair value based on discounted future cash flows. The fair value of the Commercial Renewables reporting unit is impacted by several factors, including forecasted tax credit utilization, the cost of capital, current and forecasted solar and wind volumes, and legislative developments. Certain assumptions used in determining the fair value of the reporting unit in the 2018 impairment test changed from those used in the 2017 annual impairment test including the cost of capital as a result of rising interest rates and the timing of tax credit utilization due to the Tax Act and IRS (Internal Revenue Service) clarification on bonus depreciation in August 2018. Based on the quantitative impairment test, the estimated fair value of the Commercial Renewables reporting unit was below its carrying value by an immaterial amount but still more than the goodwill balance assigned to the reporting unit. As such, the entire remaining goodwill balance of approximately $93 million was impaired during the third quarter of 2018.

The fair value of all other reporting units for Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont exceeded their respective carrying values at the date of the annual impairment analysis. As such, no other impairment charges were recorded in the third quarter of 2018.

XML

Related Party Transactions

9 Months Ended

Sep. 30, 2018

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 on the Condensed Consolidated Statements of Operations and Comprehensive Income are presented in the following table.

	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	214	$	206	$	647	$	645
Indemnification coverages(b)	6		5		17		17
JDA revenue(c)	13		9		66		42
JDA expense(c)	61		39		134		91
Intercompany natural gas purchases(d)	3		3		11		5
Progress Energy
Corporate governance and shared service expenses(a)	$	216	$	207	$	613	$	555
Indemnification coverages(b)	8		10		25		29
JDA revenue(c)	61		39		134		91
JDA expense(c)	13		9		66		42
Intercompany natural gas purchases(d)	20		19		58		57
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	138	$	112	$	382	$	321
Indemnification coverages(b)	3		4		9		11
JDA revenue(c)	61		39		134		91
JDA expense(c)	13		9		66		42
Intercompany natural gas purchases(d)	20		19		58		57
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	78	$	95	$	231	$	234
Indemnification coverages(b)	5		6		16		18
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	85	$	90	$	264	$	275
Indemnification coverages(b)	1		1		3		3
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	105	$	94	$	302	$	281
Indemnification coverages(b)	2		2		6		6
Piedmont
Corporate governance and shared service expenses(a)	$	39	$	11	$	115	$	25
Indemnification coverages(b)	1		1		2		2
Intercompany natural gas sales(d)	23		22		69		62

(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 primarily 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 Joint Dispatch Agreement (JDA), which allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power and expenses from the purchase of power pursuant to the JDA are recorded in Operating Revenues and Fuel used in electric generation and purchased power, respectively, on the Condensed Consolidated Statements of Operations and Comprehensive Income.

(d) Piedmont provides long-term natural gas delivery service to certain Duke Energy Carolinas and Duke Energy Progress natural gas-fired generation facilities. Piedmont records the sales in Operating revenues, and Duke Energy Carolinas and Duke Energy Progress record the related purchases as a component of Fuel used in electric generation and purchased power on their respective Condensed Consolidated Statements of Operations and Comprehensive Income. These intercompany revenues and expenses are eliminated in consolidation.

In addition to the amounts presented above, the Subsidiary Registrants have 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. These transactions of the Subsidiary Registrants were not material for the three and nine months ended September 30, 2018, and 2017.

As discussed in Note 12, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to Cinergy Receivables Company LLC (CRC), an indirect subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but also include a subordinated note from CRC 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. The following table presents expenses for the three and nine months ended September 30, 2018, and 2017, which are included in Cost of natural gas on Piedmont's Condensed Consolidated Statements of Operations and Comprehensive Income.

		Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	Type of expense	2018		2017		2018		2017
Cardinal	Transportation Costs	$	2	$	2	$	5	$	6
Pine Needle	Natural Gas Storage Costs	2		2		6		6
Hardy Storage	Natural Gas Storage Costs	2		2		7		7
Total		$	6	$	6	$	18	$	19

Piedmont had accounts payable to its equity method investments of $2 million at September 30, 2018, and December 31, 2017, related to these transactions. 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
September 30, 2018
Intercompany income tax receivable	$	32	$	196	$	80	$	—	$	—	$	22	$	11
Intercompany income tax payable	—		—		—		77		9		—		—
December 31, 2017
Intercompany income tax receivable	$	—	$	168	$	—	$	44	$	22	$	—	$	7
Intercompany income tax payable	44		—		21		—		—		35		—

XML

Derivatives and Hedging

9 Months Ended

Sep. 30, 2018

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 natural gas supply contracts to provide diversification, reliability and natural gas cost benefits to its 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 or Treasury locks 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 and nine months ended September 30, 2018, and 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 primarily include contracts not designated as a hedge because they are accounted for under regulatory accounting or 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 on the Duke Energy Registrant's Condensed Consolidated Statements of Operations and Comprehensive Income.

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

	September 30, 2018
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	411	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,127		400		500		250		250		27
Total notional amount(a)	$	1,538	$	400	$	500	$	250	$	250	$	27

	December 31, 2017
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	660	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	927		400		500		250		250		27
Total notional amount	$	1,587	$	400	$	500	$	250	$	250	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $411 million in cash flow hedges and $200 million in undesignated contracts as of September 30, 2018, and $660 million in cash flow hedges as of December 31, 2017.

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 natural 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 natural 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.

	September 30, 2018
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	170	—	—	—	—	170	—
Natural gas (millions of dekatherms)	744	119	167	158	9	1	457

	December 31, 2017
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	34	—	—	—	—	34	—
Natural gas (millions of dekatherms)	770	105	183	133	50	2	480

LOCATION AND FAIR VALUE OF DERIVATIVE ASSETS AND LIABILITIES RECOGNIZED ON 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	September 30, 2018
			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	$	46	$	2	$	3	$	2	$	1	$	8	$	29	$	4
Noncurrent	1		—		—		—		—		—		—		—
Total Derivative Assets – Commodity Contracts	$	47	$	2	$	3	$	2	$	1	$	8	$	29	$	4
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	6	$	5	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	6		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		—		—		—		—		—		—
Noncurrent	17		—		—		—		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	30	$	5	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Assets	$	77	$	7	$	3	$	2	$	1	$	8	$	29	$	4

Derivative Liabilities	September 30, 2018
			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	$	26	$	14	$	5	$	5	$	—	$	—	$	—	$	7
Noncurrent	177		14		17		8		—		—		—		146
Total Derivative Liabilities – Commodity Contracts	$	203	$	28	$	22	$	13	$	—	$	—	$	—	$	153
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	2	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	7		—		6		3		3		1		—		—
Noncurrent	13		—		9		8		2		3		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	22	$	—	$	15	$	11	$	5	$	4	$	—	$	—
Total Derivative Liabilities	$	225	$	28	$	37	$	24	$	5	$	4	$	—	$	153

Derivative Assets	December 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	$	34	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Noncurrent	1		—		1		1		—		—		—		—
Total Derivative Assets – Commodity Contracts	$	35	$	2	$	3	$	2	$	1	$	1	$	27	$	2
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	1	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	15		—		—		—		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	16	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Assets	$	51	$	2	$	3	$	2	$	1	$	1	$	27	$	2

Derivative Liabilities	December 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	$	36	$	6	$	18	$	8	$	10	$	—	$	—	$	11
Noncurrent	146		4		10		4		—		—		—		131
Total Derivative Liabilities – Commodity Contracts	$	182	$	10	$	28	$	12	$	10	$	—	$	—	$	142
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	29	$	25	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	6		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		1		—		—		1		—		—
Noncurrent	12		—		7		6		2		4		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	48	$	25	$	8	$	6	$	2	$	5	$	—	$	—
Total Derivative Liabilities	$	230	$	35	$	36	$	18	$	12	$	5	$	—	$	142

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	September 30, 2018
				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	$	53		$	7		$	3		$	2		$	1	$	8	$	29	$	4
Gross amounts offset	(4		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Assets: Other	$	49		$	5		$	1		$	—		$	1	$	8	$	29	$	4
Noncurrent
Gross amounts recognized	$	24		$	—		$	—		$	—		$	—	$	—	$	—	$	—
Gross amounts offset	(1		)	—			—			—			—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	23		$	—		$	—		$	—		$	—	$	—	$	—	$	—

Derivative Liabilities	September 30, 2018
				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	$	35		$	14		$	11		$	8		$	3	$	1	$	—	$	7
Gross amounts offset	(4		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Liabilities: Other	$	31		$	12		$	9		$	6		$	3	$	1	$	—	$	7
Noncurrent
Gross amounts recognized	$	190		$	14		$	26		$	16		$	2	$	3	$	—	$	146
Gross amounts offset	(1		)	—			(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	189		$	14		$	25		$	15		$	2	$	3	$	—	$	146

Derivative Assets	December 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	$	35	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Gross amounts offset	—		—		—		—		—		—		—		—
Net amounts presented in Current Assets: Other	$	35	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Noncurrent
Gross amounts recognized	$	16	$	—	$	1	$	1	$	—	$	—	$	—	$	—
Gross amounts offset	—		—		—		—		—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	16	$	—	$	1	$	1	$	—	$	—	$	—	$	—

Derivative Liabilities	December 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	$	66		$	31		$	19		$	8		$	10	$	1	$	—	$	11
Gross amounts offset	(3		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Liabilities: Other	$	63		$	29		$	17		$	6		$	10	$	1	$	—	$	11
Noncurrent
Gross amounts recognized	$	164		$	4		$	17		$	10		$	2	$	4	$	—	$	131
Gross amounts offset	(1		)	—			(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	163		$	4		$	16		$	9		$	2	$	4	$	—	$	131

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.

	September 30, 2018
			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	$	48	$	26	$	23	$	22	$	—
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	48		26		23		22		—

	December 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	$	59	$	35	$	25	$	15	$	10
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	59		35		25		15		10

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.

XML

Investments in Debt and Equity Securities

9 Months Ended

Sep. 30, 2018

Investments, Debt and Equity Securities [Abstract]

Investments In Debt And Equity Securities

INVESTMENTS IN DEBT AND EQUITY SECURITIES

Duke Energy’s investments in debt and equity securities are primarily comprised of investments held in (i) the nuclear decommissioning trust funds (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. The Duke Energy Registrants classify investments in debt securities as available-for-sale (AFS) and investments in equity securities as fair value through net income (FV-NI). 

For investments in debt securities classified as AFS, the unrealized gains and losses are included in other comprehensive income until realized, at which time, they are reported through net income. For investments in equity securities classified as FV-NI, both realized and unrealized gains and losses are reported through net income. Substantially all of Duke Energy’s investments in debt and equity securities qualify for regulatory accounting, and accordingly, all associated realized and unrealized gains and losses on these investments are deferred as a regulatory asset or liability.

Duke Energy classifies the majority of 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 securities within the Investment Trusts are considered OTTIs and are recognized immediately and deferred to regulatory accounts where appropriate.

Other AFS Securities

Unrealized gains and losses on all other AFS 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 September 30, 2018, and December 31, 2017.

Other Investments amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

DUKE ENERGY

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	75	$	—	$	—	$	115
Equity securities	3,117		48		5,272		2,805		27		4,914
Corporate debt securities	5		10		595		17		2		570
Municipal bonds	—		7		346		4		3		344
U.S. government bonds	5		25		974		11		7		1,027
Other debt securities	—		3		141		—		1		118
Total NDTF Investments	$	3,127	$	93	$	7,403	$	2,837	$	40	$	7,088
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	15
Equity securities	51		—		115		59		—		123
Corporate debt securities	—		1		64		1		—		57
Municipal bonds	1		1		85		2		1		83
U.S. government bonds	—		1		59		—		—		41
Other debt securities	—		1		43		—		1		44
Total Other Investments	$	52	$	4	$	387	$	62	$	2	$	363
Total Investments	$	3,179	$	97	$	7,790	$	2,899	$	42	$	7,451

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	100
Due after one through five years	492
Due after five through 10 years	561
Due after 10 years	1,154
Total	$	2,307

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	19	$	85
Realized losses	16		60
AFS:
Realized gains	4		14
Realized losses	7		32

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	37	$	170
Realized losses	25		124

DUKE ENERGY CAROLINAS

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	32
Equity securities	1,692		29		2,890		1,531		12		2,692
Corporate debt securities	2		7		372		9		2		359
Municipal bonds	—		2		80		—		1		60
U.S. government bonds	1		14		439		3		4		503
Other debt securities	—		3		137		—		1		112
Total NDTF Investments	$	1,695	$	55	$	3,936	$	1,543	$	20	$	3,758

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	12
Due after one through five years	161
Due after five through 10 years	289
Due after 10 years	566
Total	$	1,028

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	11	$	47
Realized losses	8		30
AFS:
Realized gains	4		13
Realized losses	6		24

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	20	$	110
Realized losses	13		76

PROGRESS ENERGY

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	57	$	—	$	—	$	83
Equity securities	1,425		19		2,382		1,274		15		2,222
Corporate debt securities	3		3		223		8		—		211
Municipal bonds	—		5		266		4		2		284
U.S. government bonds	4		11		535		8		3		524
Other debt securities	—		—		4		—		—		6
Total NDTF Investments	$	1,432	$	38	$	3,467	$	1,294	$	20	$	3,330
Other Investments
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	12
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	66	$	2	$	—	$	59
Total Investments	$	1,433	$	38	$	3,533	$	1,296	$	20	$	3,389

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	83
Due after one through five years	268
Due after five through 10 years	217
Due after 10 years	508
Total	$	1,076

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	8	$	38
Realized losses	8		30
AFS:
Realized gains	—		1
Realized losses	1		8

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	16	$	58
Realized losses	12		47

DUKE ENERGY PROGRESS

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	42	$	—	$	—	$	50
Equity securities	1,101		14		1,913		980		12		1,795
Corporate debt securities	2		2		162		6		—		149
Municipal bonds	—		5		265		4		2		283
U.S. government bonds	3		8		352		5		2		310
Other debt securities	—		—		2		—		—		4
Total NDTF Investments	$	1,106	$	29	$	2,736	$	995	$	16	$	2,591
Other Investments
Cash and cash equivalents	$	—	$	—	$	8	$	—	$	—	$	1
Total Other Investments	$	—	$	—	$	8	$	—	$	—	$	1
Total Investments	$	1,106	$	29	$	2,744	$	995	$	16	$	2,592

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	40
Due after one through five years	200
Due after five through 10 years	156
Due after 10 years	385
Total	$	781

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	7	$	32
Realized losses	7		27
AFS:
Realized gains	—		1
Realized losses	1		6

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	14	$	49
Realized losses	11		41

DUKE ENERGY FLORIDA

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	15	$	—	$	—	$	33
Equity securities	324		5		469		294		3		427
Corporate debt securities	1		1		61		2		—		62
Municipal bonds	—		—		1		—		—		1
U.S. government bonds	1		3		183		3		1		214
Other debt securities	—		—		2		—		—		2
Total NDTF Investments(b)	$	326	$	9	$	731	$	299	$	4	$	739
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	1
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	48	$	2	$	—	$	48
Total Investments	$	327	$	9	$	779	$	301	$	4	$	787

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

(b) During the nine months endedSeptember 30, 2018, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of the Crystal River Unit 3 nuclear plant.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	43
Due after one through five years	68
Due after five through 10 years	61
Due after 10 years	123
Total	$	295

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	1	$	6
Realized losses	1		3
AFS:
Realized gains	—		—
Realized losses	—		2

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	2	$	9
Realized losses	1		6

DUKE ENERGY INDIANA

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are measured at FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
Investments
Equity securities	$	40	$	—	$	78	$	49	$	—	$	97
Corporate debt securities	—		—		8		—		—		3
Municipal bonds	—		1		32		—		1		28
Total Investments	$	40	$	1	$	118	$	49	$	1	$	128

(a) Realized and unrealized gains and losses where regulatory accounting is applied are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	2
Due after one through five years	20
Due after five through 10 years	5
Due after 10 years	13
Total	$	40

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months ended September 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were insignificant.

XML

Fair Value Measurements

9 Months Ended

Sep. 30, 2018

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 and (iii) inputs other than quoted market prices that are observable for the asset or liability, such as interest rate curves and yield curves observable at commonly quoted intervals, volatilities 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 at fair value using the net asset value (NAV) per share practical expedient. The NAV is derived based on the investment cost, less any impairment, plus or minus changes resulting from observable price changes for an identical or similar investment of the same issuer.

Fair value accounting guidance permits entities to elect to measure certain financial instruments that are not required to be accounted for at fair value, such as equity method investments or the company’s own debt, at fair value. The Duke Energy Registrants have not elected to record any of these items at fair value.

Transfers between levels represent assets or liabilities that were previously (i) categorized at a higher level for which the inputs to the estimate became less observable or (ii) classified at a lower level for which the inputs became more observable during the period. The Duke Energy Registrant’s policy is to recognize transfers between levels of the fair value hierarchy at the end of the period. There were no transfers between levels during the three and nine months endedSeptember 30, 2018, and 2017.

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 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 natural 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 natural gas purchase contracts; and increases (decreases) in electricity forward prices result in unfavorable (favorable) fair value adjustments for electricity sales contracts. Duke Energy regularly evaluates and validates pricing inputs used to estimate the fair value of natural gas commodity contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.

Interest rate derivatives

Most over-the-counter interest rate contract derivatives are valued using financial models 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 11 in Duke Energy's Annual Report on Form 10-K/A for the year ended December 31, 2017, 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 tables below for all Duke Energy Registrants exclude cash collateral, which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type for the Duke Energy Registrants.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 2			Level 3			Not Categorized
NDTF equity securities	$	5,272		$	5,203	$	—		$	—		$	69
NDTF debt securities	2,131			510		1,621			—			—
Other equity securities	115			115		—			—			—
Other debt securities	272			78		194			—			—
Derivative assets	77			4		36			37			—
Total assets	7,867			5,910		1,851			37			69
Derivative liabilities	(225		)	—		(72		)	(153		)	—
Net assets (liabilities)	$	7,642		$	5,910	$	1,779		$	(116	)	$	69

	December 31, 2017
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	4,914		$	4,840		$	—		$	—		$	74
NDTF debt securities	2,174			635			1,539			—			—
Other equity securities	123			123			—			—			—
Other debt securities	241			57			184			—			—
Derivative assets	51			3			20			28			—
Total assets	7,503			5,658			1,743			28			74
Derivative liabilities	(230		)	(2		)	(86		)	(142		)	—
Net assets (liabilities)	$	7,273		$	5,656		$	1,657		$	(114	)	$	74

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 Cost of natural gas on the Duke Energy Registrants' Condensed Consolidated Statements of Operations and Comprehensive Income. Amounts included in changes of net assets on the Duke Energy Registrants' Condensed Consolidated Balance Sheets are included in regulatory assets or liabilities. All derivative assets and liabilities are presented on a net basis.

	Three Months Ended September 30, 2018								Three Months Ended September 30, 2017
(in millions)	Investments		Derivatives (net)			Total			Investments		Derivatives (net)			Total
Balance at beginning of period	$	—	$	(97	)	$	(97	)	$	—	$	(91	)	$	(91	)
Purchases, sales, issuances and settlements:
Settlements	—		(14		)	(14		)	—		(12		)	(12		)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	—		(5		)	(5		)	—		10			10
Balance at end of period	$	—	$	(116	)	$	(116	)	$	—	$	(93	)	$	(93	)

	Nine Months Ended September 30, 2018								Nine Months Ended September 30, 2017
(in millions)	Investments		Derivatives (net)			Total			Investments			Derivatives (net)			Total
Balance at beginning of period	$	—	$	(114	)	$	(114	)	$	5		$	(166	)	$	(161	)
Total pretax realized or unrealized gains included in comprehensive income	—		—			—			1			—			1
Purchases, sales, issuances and settlements:
Purchases	—		56			56			—			55			55
Sales	—		—			—			(6		)	—			(6		)
Settlements	—		(43		)	(43		)	—			(30		)	(30		)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	—		(15		)	(15		)	—			48			48
Balance at end of period	$	—	$	(116	)	$	(116	)	$	—		$	(93	)	$	(93	)

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.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	2,890		$	2,821	$	—		$	69
NDTF debt securities	1,046			122		924			—
Derivative assets	7			—		7			—
Total assets	3,943			2,943		931			69
Derivative liabilities	(28		)	—		(28		)	—
Net assets	$	3,915		$	2,943	$	903		$	69

	December 31, 2017
(in millions)	Total Fair Value			Level 1			Level 2			Not Categorized
NDTF equity securities	$	2,692		$	2,618		$	—		$	74
NDTF debt securities	1,066			204			862			—
Derivative assets	2			—			2			—
Total assets	3,760			2,822			864			74
Derivative liabilities	(35		)	(1		)	(34		)	—
Net assets	$	3,725		$	2,821		$	830		$	74

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

	Investments
	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Balance at beginning of period	$	—	$	—	$	—	$	3
Total pretax realized or unrealized gains included in comprehensive income	—		—		—		1
Purchases, sales, issuances and settlements:
Sales	—		—		—		(4		)
Balance at end of period	$	—	$	—	$	—	$	—

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1			Level 2
NDTF equity securities	$	2,382		$	2,382	$	—		$	2,222		$	2,222		$	—
NDTF debt securities	1,085			388		697			1,108			431			677
Other debt securities	66			18		48			59			12			47
Derivative assets	3			—		3			3			1			2
Total assets	3,536			2,788		748			3,392			2,666			726
Derivative liabilities	(37		)	—		(37		)	(36		)	(1		)	(35		)
Net assets	$	3,499		$	2,788	$	711		$	3,356		$	2,665		$	691

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1			Level 2
NDTF equity securities	$	1,913		$	1,913	$	—		$	1,795		$	1,795		$	—
NDTF debt securities	823			254		569			796			243			553
Other debt securities	8			8		—			1			1			—
Derivative assets	2			—		2			2			1			1
Total assets	2,746			2,175		571			2,594			2,040			554
Derivative liabilities	(24		)	—		(24		)	(18		)	(1		)	(17		)
Net assets	$	2,722		$	2,175	$	547		$	2,576		$	2,039		$	537

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	469		$	469	$	—		$	427		$	427	$	—
NDTF debt securities	262			134		128			312			188		124
Other debt securities	48			—		48			48			1		47
Derivative assets	1			—		1			1			—		1
Total assets	780			603		177			788			616		172
Derivative liabilities	(5		)	—		(5		)	(12		)	—		(12		)
Net assets	$	775		$	603	$	172		$	776		$	616	$	160

DUKE ENERGY OHIO

The following table provides recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 2			Level 3		Total Fair Value			Level 2			Level 3
Derivative assets	$	8		$	—		$	8	$	1		$	—		$	1
Derivative liabilities	(4		)	(4		)	—		(5		)	(5		)	—
Net assets (liabilities)	$	4		$	(4	)	$	8	$	(4	)	$	(5	)	$	1

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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	9		$	3		$	1		$	5
Purchases, sales, issuances and settlements:
Purchases	—			—			7			3
Settlements	(1		)	(1		)	(2		)	(3		)
Total gains (losses) included on the Condensed Consolidated Balance Sheet	—			—			2			(3		)
Balance at end of period	$	8		$	2		$	8		$	2

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Total Fair Value		Level 1		Level 2		Level 3
Other equity securities	$	78	$	78	$	—	$	—	$	97	$	97	$	—	$	—
Other debt securities	40		—		40		—		31		—		31		—
Derivative assets	29		—		—		29		27		—		—		27
Total assets	$	147	$	78	$	40	$	29	$	155	$	97	$	31	$	27

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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	44		$	51		$	27		$	16
Purchases, sales, issuances and settlements:
Purchases	—			—			49			52
Settlements	(13		)	(11		)	(41		)	(27		)
Total losses included on the Condensed Consolidated Balance Sheet	(2		)	(12		)	(6		)	(13		)
Balance at end of period	$	29		$	28		$	29		$	28

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.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 3
Derivative assets	$	4		$	4	$	—
Derivative liabilities	(153		)	—		(153		)
Net (liabilities) assets	$	(149	)	$	4	$	(153	)

	December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 3
Other debt securities	$	1		$	1	$	—
Derivative assets	2			2		—
Total assets	3			3		—
Derivative liabilities	(142		)	—		(142		)
Net (liabilities) assets	$	(139	)	$	3	$	(142	)

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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	(150	)	$	(145	)	$	(142	)	$	(187	)
Total (losses) gains and settlements	(3		)	22			(11		)	64
Balance at end of period	$	(153	)	$	(123	)	$	(153	)	$	(123	)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

	September 30, 2018
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
Financial Transmission Rights (FTRs)	$	8		RTO auction pricing	FTR price – per megawatt-hour (MWh)	$	1.03		-	$	4.10
Duke Energy Indiana
FTRs	29			RTO auction pricing	FTR price – per MWh	(2.32		)	-	8.11
Piedmont
Natural gas contracts	(153		)	Discounted cash flow	Forward natural gas curves – price per million British thermal unit (MMBtu)	1.74			-	3.41
Duke Energy
Total Level 3 derivatives	$	(116	)

	December 31, 2017
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
FTRs	$	1		RTO auction pricing	FTR price – per MWh	$	0.07		-	$	1.41
Duke Energy Indiana
FTRs	27			RTO auction pricing	FTR price – per MWh	(0.77		)	-	7.44
Piedmont
Natural gas contracts	(142		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	2.10			-	2.88
Duke Energy
Total Level 3 derivatives	$	(114	)

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.

	September 30, 2018				December 31, 2017
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy(a)	$	53,962	$	53,949	$	52,279	$	55,331
Duke Energy Carolinas	10,395		10,887		10,103		11,372
Progress Energy	18,912		19,825		17,837		20,000
Duke Energy Progress	8,154		8,231		7,357		7,992
Duke Energy Florida	7,371		7,749		7,095		7,953
Duke Energy Ohio	2,066		2,136		2,067		2,249
Duke Energy Indiana	3,783		4,178		3,783		4,464
Piedmont	2,138		2,175		2,037		2,209

(a) Book value of long-term debt includes $1.6 billion as of September 30, 2018, and $1.7 billion as of December 31, 2017, of unamortized debt discount and premium, net in purchase accounting adjustments related to the mergers with Progress Energy and Piedmont that are excluded from fair value of long-term debt.

At both September 30, 2018, and December 31, 2017, 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.

XML

Variable Interest Entities

9 Months Ended

Sep. 30, 2018

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 re-evaluation, 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 nine months ended September 30, 2018, and the year ended December 31, 2017, 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 and associated restricted receivables described above.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
(in millions)	CRC		DERF		DEPR		DEFR
Expiration date	December 2020		December 2020		February 2021		April 2021
Credit facility amount	$	325	$	450	$	300	$	225
Amounts borrowed at September 30, 2018	325		450		300		225
Amounts borrowed at December 31, 2017	325		450		300		225
Restricted Receivables at September 30, 2018	504		795		635		456
Restricted Receivables at December 31, 2017	545		640		459		317

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 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.

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)	September 30, 2018		December 31, 2017
Receivables of VIEs	$	7	$	4
Regulatory Assets: Current	52		51
Current Assets: Other	14		40
Other Noncurrent Assets: Regulatory assets	1,055		1,091
Current Liabilities: Other	3		10
Current maturities of long-term debt	53		53
Long-Term Debt	1,111		1,164

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)	September 30, 2018			December 31, 2017
Current Assets: Other	$	203		$	174
Property, plant and equipment, cost	4,025			3,923
Accumulated depreciation and amortization	(695		)	(591		)
Other Noncurrent Assets: Other	268			50
Current maturities of long-term debt	175			170
Long-Term Debt	1,604			1,700
Other Noncurrent Liabilities: Deferred income taxes	—			(148		)
Other Noncurrent Liabilities: Other	225			241

NON-CONSOLIDATED VIEs

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

	September 30, 2018
	Duke Energy								Duke		Duke
	Pipeline		Commercial		Other				Energy		Energy
(in millions)	Investments(a)		Renewables		VIEs		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	—	$	56	$	94
Investments in equity method unconsolidated affiliates	729		190		47		966		—		—
Total assets	$	729	$	190	$	47	$	966	$	56	$	94
Other current liabilities	—		—		3		3		—		—
Deferred income taxes	14		—		—		14		—		—
Other noncurrent liabilities	—		—		11		11		—		—
Total liabilities	$	14	$	—	$	14	$	28	$	—	$	—
Net assets	$	715	$	190	$	33	$	938	$	56	$	94

(a) See Pipeline Investments table below for further details regarding Investments in equity method unconsolidated affiliates.

	December 31, 2017
	Duke Energy										Duke		Duke
	Pipeline			Commercial		Other					Energy		Energy
(in millions)	Investments			Renewables		VIEs		Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	—	$	—	$	—		$	87	$	106
Investments in equity method unconsolidated affiliates	697			180		42		919			—		—
Other noncurrent assets	17			—		—		17			—		—
Total assets	$	714		$	180	$	42	$	936		$	87	$	106
Taxes accrued	(29		)	—		—		(29		)	—		—
Other current liabilities	—			—		4		4			—		—
Deferred income taxes	42			—		—		42			—		—
Other noncurrent liabilities	—			—		12		12			—		—
Total liabilities	$	13		$	—	$	16	$	29		$	—	$	—
Net assets	$	701		$	180	$	26	$	907		$	87	$	106

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 4.

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 Duke Energy's ownership interest and investment balances in these joint ventures.

			VIE Investment Amount (in millions)
	Ownership		September 30,		December 31,
Entity Name	Interest		2018		2017
ACP	47	%	$	704	$	397
Sabal Trail(a)	7.5	%	—		219
Constitution(b)	24	%	25		81
Total			$	729	$	697

(a) At December 31, 2017, Sabal Trail was considered a VIE due to having insufficient equity to finance their own activities without subordinated financial support. However, Sabal Trail is now a fully operational, well capitalized entity. As a result, Sabal Trail has sufficient equity to finance its own activities, and therefore, is no longer considered a VIE. Duke Energy's investment in Sabal Trail was $112 million at September 30, 2018.

(b) During the nine months ended September 30, 2018, Duke Energy recorded an OTTI of $55 million related to Constitution within Equity in earnings of unconsolidated affiliates on Duke Energy's Condensed Consolidated Statements of Income. See Note 3 for additional information.

In 2017, ACP executed a $3.4 billion revolving credit facility with a stated maturity date of October 2021. Duke Energy entered into a guarantee agreement to support its share of the ACP revolving credit facility. Duke Energy's maximum exposure to loss under the terms of the guarantee is $486 million, which represents 47 percent of the outstanding borrowings under the credit facility as of September 30, 2018.

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 Pioneer Transmission, LLC (Pioneer). Pioneer is considered a VIE due to having insufficient equity to finance its 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 OVEC having insufficient equity to finance its 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. On March 31, 2018, FirstEnergy Solutions (FES), a subsidiary of FirstEnergy and an ICPA counterparty with a power participation ratio of 4.85 percent, filed for Chapter 11 bankruptcy, which could increase costs allocated to the counterparties. On July 31, 2018, the bankruptcy court rejected the FES ICPA, which means OVEC is an unsecured creditor in the FES bankruptcy proceeding. Duke Energy Ohio cannot predict the impact of the bankruptcy filing on its OVEC interests. In addition, certain proposed environmental rulemaking could result in future increased OVEC 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
	2018		2017		2018		2017
Anticipated credit loss ratio	0.5	%	0.5	%	0.3	%	0.3	%
Discount rate	2.9	%	2.1	%	2.9	%	2.1	%
Receivable turnover rate	13.6	%	13.5	%	10.9	%	10.7	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Receivables sold	$	218	$	273	$	326	$	312
Less: Retained interests	56		87		94		106
Net receivables sold	$	162	$	186	$	232	$	206

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

	Duke Energy Ohio								Duke Energy Indiana
	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
(in millions)	2018		2017		2018		2017		2018		2017		2018		2017
Sales
Receivables sold	$	450	$	438	$	1,478	$	1,392	$	754	$	720	$	2,140	$	2,047
Loss recognized on sale	4		2		10		7		5		3		12		9
Cash flows
Cash proceeds from receivables sold	$	449	$	434	$	1,499	$	1,421	$	743	$	713	$	2,140	$	2,064
Collection fees received	—		1		1		1		—		—		1		1
Return received on retained interests	2		—		5		2		3		2		7		5

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

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

XML

Revenue

9 Months Ended

Sep. 30, 2018

Revenue from Contract with Customer [Abstract]

Revenue

REVENUE

As described in Note 1, Duke Energy adopted Revenue from Contracts with Customers effective January 1, 2018, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. No cumulative effect adjustment was recorded as the vast majority of Duke Energy’s revenues are at-will and without a defined contractual term. Additionally, comparative disclosures for 2018 operating results with the previous revenue recognition rules are not applicable as Duke Energy’s revenue recognition has not materially changed as a result of the new standard.

Duke Energy recognizes revenue consistent with amounts billed under tariff offerings or at contractually agreed upon rates based on actual physical delivery of electric or natural gas service, including estimated volumes delivered when billings have not yet occurred. As such, the majority of Duke Energy’s revenues have fixed pricing based on the contractual terms of the published tariffs, with variability in expected cash flows attributable to the customer’s volumetric demand and ultimate quantities of energy or natural gas supplied and used during the billing period. The stand-alone selling price of related sales are designed to support recovery of prudently incurred costs and an appropriate return on invested assets and are primarily governed by published tariff rates or contractual agreements approved by relevant regulatory bodies. As described in Note 1, certain excise taxes and franchise fees 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 as part of revenues. Duke Energy elects to account for all other taxes net of revenues.

Performance obligations are satisfied over time as energy or natural gas is delivered and consumed with billings generally occurring monthly and related payments due within 30 days, depending on regulatory requirements. In no event does the timing between payment and delivery of the goods and services exceed one year. Using this output method for revenue recognition provides a faithful depiction of the transfer of electric and natural gas service as customers obtain control of the commodity and benefit from its use at delivery. Additionally, Duke Energy has an enforceable right to consideration for energy or natural gas delivered at any discrete point in time, and will recognize revenue at an amount that reflects the consideration to which Duke Energy is entitled for the energy or natural gas delivered.

As described above, the majority of Duke Energy’s tariff revenues are at-will and, as such, related contracts with customers have an expected duration of one year or less and will not have future performance obligations for disclosure. Additionally, other long-term revenue streams, including wholesale contracts, generally provide services that are part of a single performance obligation, the delivery of electricity or natural gas. As such, other than material fixed consideration under long-term contracts, related disclosures for future performance obligations are also not applicable.

Duke Energy earns substantially all of its revenues through its reportable segments, Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables.

Electric Utilities and Infrastructure

Electric Utilities and Infrastructure earns the majority of its revenues through retail and wholesale electric service through the generation, transmission, distribution and sale of electricity. Duke Energy generally provides retail and wholesale electric service customers with their full electric load requirements or with supplemental load requirements when the customer has other sources of electricity.

Retail electric service is generally marketed throughout Duke Energy's electric service territory through standard service offers. The standard service offers are through tariffs determined by regulators in Duke Energy's regulated service territory. Each tariff, which is assigned to customers based on customer class, has multiple components such as an energy charge, a demand charge, a basic facilities charge and applicable riders. Duke Energy considers each of these components to be aggregated into a single performance obligation for providing electric service, or in the case of distribution only customers in Duke Energy Ohio, for delivering electricity. Electricity is considered a single performance obligation satisfied over time consistent with the series guidance and is provided and consumed over the billing period (generally one month). Retail electric service is typically provided to at-will customers that can cancel service at any time, without a substantive penalty. Additionally, Duke Energy adheres to applicable regulatory requirements in each jurisdiction to ensure the collectability of amounts billed and appropriate mitigating procedures are followed when necessary. As such, revenue from contracts with customers for such contracts is equivalent to the electricity supplied and billed in that period (including unbilled estimates).

Wholesale electric service is generally provided under long-term contracts using cost-based pricing. FERC regulates costs that may be recovered from customers and the amount of return companies are permitted to earn. Wholesale contracts include both energy and demand charges. For full requirements contracts, Duke Energy considers both charges as a single performance obligation for providing integrated electric service. For contracts where energy and demand charges are considered separate performance obligations, energy and demand are each a distinct performance obligation under the series guidance and are satisfied as energy is delivered and stand-ready service is provided on a monthly basis. This service represents consumption over the billing period and revenue is recognized consistent with billings and unbilled estimates, which generally occur monthly. Contractual amounts owed are typically trued up annually based upon incurred costs in accordance with FERC published filings and the specific customer’s actual peak demand. Estimates of variable consideration related to potential additional billings or refunds owed are updated quarterly.

The majority of wholesale revenues are full requirements contracts where the customers purchase the substantial majority of their energy needs and do not have a fixed quantity of contractually required energy or capacity. As such, related forecasted revenues are considered optional purchases. Supplemental requirements contracts that include contracted blocks of energy and capacity at contractually fixed prices have the following estimated remaining performance obligations:

	Remaining Performance Obligations
(in millions)	2018		2019		2020		2021		2022		Thereafter		Total
Progress Energy	$	24	$	112	$	121	$	80	$	82	$	81	$	500
Duke Energy Progress	2		9		9		9		9		18		56
Duke Energy Florida	22		103		112		71		73		63		444
Duke Energy Indiana	2		9		10		5		—		—		26

Revenues for block sales are recognized monthly as energy is delivered and stand-ready service is provided, consistent with invoiced amounts and unbilled estimates.

Gas Utilities and Infrastructure

Gas Utilities and Infrastructure earns its revenue through retail and wholesale natural gas service through the transportation, distribution and sale of natural gas. Duke Energy generally provides retail and wholesale natural gas service customers with all natural gas load requirements. Additionally, while natural gas can be stored, substantially all natural gas provided by Duke Energy is consumed by customers simultaneously with receipt of delivery.

Retail natural gas service is marketed throughout Duke Energy's natural gas service territory using published tariff rates. The tariff rates are established by regulators in Duke Energy's service territories. Each tariff, which is assigned to customers based on customer class, have multiple components, such as a commodity charge, demand charge, customer or monthly charge and transportation costs. Duke Energy considers each of these components to be aggregated into a single performance obligation for providing natural gas service. For contracts where Duke Energy provides all of the customer’s natural gas needs, the delivery of natural gas is considered a single performance obligation satisfied over time, and revenue is recognized monthly based on billings and unbilled estimates as service is provided and the commodity is consumed over the billing period. Additionally, natural gas service is typically at-will and customers can cancel service at any time, without a substantive penalty. Duke Energy also adheres to applicable regulatory requirements to ensure the collectability of amounts billed and receivable and appropriate mitigating procedures are followed when necessary.

Certain long-term individually negotiated contracts exist to provide natural gas service. These contracts are regulated and approved by state commissions. The negotiated contracts have multiple components, including a natural gas and a demand charge, similar to retail natural gas contracts. Duke Energy considers each of these components to be a single performance obligation for providing natural gas service. This service represents consumption over the billing period, generally one month.

Fixed capacity payments under long-term contracts for the Gas segment include minimum margin contracts and supply arrangements with municipalities and power generation facilities. Revenues for related sales are recognized monthly as natural gas is delivered and stand-ready service is provided, consistent with invoiced amounts and unbilled estimates. Estimated remaining performance obligations are as follows:

	Remaining Performance Obligations
(in millions)	2018		2019		2020		2021		2022		Thereafter		Total
Piedmont	$	18	$	71	$	70	$	65	$	64	$	462	$	750

Commercial Renewables

Commercial Renewables earns the majority of its revenues through long-term PPAs and generally sells all of its wind and solar facility output, electricity and Renewable Energy Credits (RECs) to customers. The majority of these PPAs have historically been accounted for as leases. For PPAs that are not accounted for as leases, the delivery of electricity and the delivery of RECs are considered separate performance obligations.

The delivery of electricity is a performance obligation satisfied over time and represents generation and consumption of the electricity over the billing period, generally one month. The delivery of RECs is a performance obligation satisfied at a point in time and represents delivery of each REC generated by the wind or solar facility. The majority of self-generated RECs are bundled with energy in Duke Energy’s contracts and, as such, related revenues are recognized as energy is generated and delivered as that pattern is consistent with Duke Energy’s performance. Commercial Renewables recognizes revenue based on the energy generated and billed for the period, generally one month, at contractual rates (including unbilled estimates) according to the invoice practical expedient. Amounts are typically due within 30 days of invoice.

Other

The remainder of Duke Energy’s operations is presented as Other, which does not include material revenues from contracts with customers.

Disaggregated Revenues

For the Electric and Gas segments, revenue by customer class is most meaningful to Duke Energy as each respective customer class collectively represents unique customer expectations of service, generally has different energy and demand requirements, and operates under tailored, regulatory approved pricing structures. Additionally, each customer class is impacted differently by weather and a variety of economic factors including the level of population growth, economic investment, employment levels, and regulatory activities in each of Duke Energy’s jurisdictions. As such, analyzing revenues disaggregated by customer class allows Duke Energy to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. For the Commercial Renewables segment, the majority of revenues from contracts with customers are from selling all of the unit-contingent output at contractually defined pricing under long-term PPAs with consistent expectations regarding the timing and certainty of cash flows. Disaggregated revenues are presented as follows:

	Three Months Ended September 30, 2018
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	2,729	$	823	$	1,425	$	572	$	853	$	203	$	279	$	—
General	1,763		635		800		373		427		112		218		—
Industrial	835		352		246		177		69		33		202		—
Wholesale	589		132		372		335		37		3		81		—
Other revenues	225		109		134		90		44		20		29		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	6,141	$	2,051	$	2,977	$	1,547	$	1,430	$	371	$	809	$	—
Gas Utilities and Infrastructure
Residential	$	116	$	—	$	—	$	—	$	—	$	59	$	—	$	57
Commercial	66		—		—		—		—		20		—		46
Industrial	28		—		—		—		—		3		—		24
Power Generation	—		—		—		—		—		—		—		13
Other revenues	23		—		—		—		—		1		—		22
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	233	$	—	$	—	$	—	$	—	$	83	$	—	$	162
Commercial Renewables
Revenue from contracts with customers	$	61	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	16	$	—	$	—	$	—	$	—	$	12	$	—	$	—
Total revenue from contracts with customers	$	6,451	$	2,051	$	2,977	$	1,547	$	1,430	$	466	$	809	$	162
Other revenue sources(a)	$	177	$	39	$	68	$	35	$	32	$	3	$	10	$	10
Total revenues	$	6,628	$	2,090	$	3,045	$	1,582	$	1,462	$	469	$	819	$	172

	Nine Months Ended September 30, 2018
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	7,264	$	2,263	$	3,636	$	1,540	$	2,096	$	564	$	802	$	—
General	4,619		1,608		2,109		972		1,137		318		584		—
Industrial	2,235		893		678		481		197		96		567		—
Wholesale	1,737		366		1,140		1,019		121		5		226		—
Other revenues	558		261		359		222		137		57		66		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	16,413	$	5,391	$	7,922	$	4,234	$	3,688	$	1,040	$	2,245	$	—
Gas Utilities and Infrastructure
Residential	$	682	$	—	$	—	$	—	$	—	$	236	$	—	$	446
Commercial	354		—		—		—		—		97		—		257
Industrial	107		—		—		—		—		13		—		93
Power Generation	—		—		—		—		—		—		—		40
Other revenues	101		—		—		—		—		13		—		88
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	1,244	$	—	$	—	$	—	$	—	$	359	$	—	$	924
Commercial Renewables
Revenue from contracts with customers	$	141	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	47	$	—	$	—	$	—	$	—	$	36	$	—	$	—
Total Revenue from contracts with customers	$	17,845	$	5,391	$	7,922	$	4,234	$	3,688	$	1,435	$	2,245	$	924
Other revenue sources(a)	$	561	$	134	$	197	$	99	$	92	$	17	$	43	$	16
Total revenues	$	18,406	$	5,525	$	8,119	$	4,333	$	3,780	$	1,452	$	2,288	$	940

(a) Other revenue sources include revenues from leases, derivatives and alternative revenue programs that are not considered revenues from contracts with customers. Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over or under collection of related revenues.

IMPACT OF WEATHER AND THE TIMING OF BILLING PERIODS

Revenues and costs are influenced by seasonal weather patterns. Peak sales of electricity occur during the summer and winter months, which results in higher revenue and cash flows during these periods. By contrast, lower sales of electricity occur during the spring and fall, allowing for scheduled plant maintenance. Residential and general service customers are more impacted by weather than industrial customers. Estimated weather impacts are based on actual current period weather compared to normal weather conditions. Normal weather conditions are defined as the long-term average of actual historical weather conditions. Heating-degree days measure the variation in weather based on the extent the average daily temperature falls below a base temperature. Cooling-degree days measure the variation in weather based on the extent the average daily temperature rises above the base temperature. Each degree of temperature below the base temperature counts as one heating-degree day and each degree of temperature above the base temperature counts as one cooling-degree day.

The estimated impact of weather on earnings for Electric Utilities and Infrastructure is based on the temperature variances from a normal condition and customers' historic usage patterns. The methodology used to estimate the impact of weather does not consider all variables that may impact customer response to weather conditions, such as humidity in the summer or wind chill in the winter. The precision of this estimate may also be impacted by applying long-term weather trends to shorter-term periods.

Gas Utilities and Infrastructure's costs and revenues are influenced by seasonal patterns due to peak natural gas sales occurring during the winter months as a result of space heating requirements. Residential customers are the most impacted by weather. There are certain regulatory mechanisms for the North Carolina, South Carolina, Tennessee and Ohio service territories that normalize the margins collected from certain customer classes during the winter. In North Carolina, rate design provides protection from both weather and other usage variations such as conservation, while South Carolina and Tennessee revenues are adjusted solely based on weather. Ohio primarily employs a fixed charge each month regardless of the season and usage.

UNBILLED REVENUE

Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy or 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 and meter reading schedules, and the impact of weather normalization or margin decoupling mechanisms.

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

(in millions)	September 30, 2018		December 31, 2017
Duke Energy	$	802	$	944
Duke Energy Carolinas	278		342
Progress Energy	283		228
Duke Energy Progress	163		143
Duke Energy Florida	120		85
Duke Energy Ohio	2		4
Duke Energy Indiana	25		21
Piedmont	3		86

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

(in millions)	September 30, 2018		December 31, 2017
Duke Energy Ohio	$	68	$	104
Duke Energy Indiana	121		132

XML

Common Stock

9 Months Ended

Sep. 30, 2018

Equity [Abstract]

Common Stock

COMMON STOCK

Basic Earnings Per Share (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 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 September 30,				Nine Months Ended September 30,
(in millions, except per-share amounts)	2018		2017		2018		2017
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	1,077	$	954	$	2,199	$	2,356
Weighted average shares outstanding – basic	713		700		705		700
Equity Forwards	1		—		1		—
Weighted average shares outstanding – diluted	714		700		706		700
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	1.51	$	1.36	$	3.12	$	3.37
Diluted	$	1.51	$	1.36	$	3.11	$	3.37
Potentially dilutive items excluded from the calculation(a)	2		2		2		2
Dividends declared per common share	$	0.9275	$	0.89	$	2.7075	$	2.60

(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 Issuance

On February 20, 2018, Duke Energy filed a prospectus supplement and executed an Equity Distribution Agreement (the EDA) under which it may sell up to $1 billion of its common stock through an at-the-market (ATM) offering program, including an equity forward sales component. The EDA was entered into with Wells Fargo Securities, LLC, Citigroup Global Markets Inc., and J.P. Morgan Securities LLC (the Agents). Under the terms of the EDA, Duke Energy may issue and sell, through any of the Agents, shares of common stock through September 23, 2019. In June 2018, Duke Energy marketed two separate tranches, each for 1.3 million shares, of common stock. The first tranche was marketed with Wells Fargo Bank at an initial forward price of $72.02 per share and the second tranche was marketed with Citibank at an initial forward price of $78.71 per share through equity forward transactions under the ATM program. The Equity Forwards require Duke Energy to either physically settle the transactions by issuing 2.6 million shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreements or net settle in whole or in part through the delivery or receipt of cash or shares. The settlement alternative is at Duke Energy's election.

Separately, in March 2018, Duke Energy marketed an equity offering of 21.3 million shares of common stock through an Underwriting Agreement with Credit Suisse Securities (USA) LLC, J.P. Morgan Securities LLC, Barclays Capital Inc. and Goldman Sachs & Co. LLC, as representatives of several underwriters, Credit Suisse Capital LLC and J.P. Morgan Securities LLC as Forward Sellers, and Credit Suisse Capital LLC and JPMorgan Chase National Bank Associate, acting as forward purchasers. In connection with the offering, Duke Energy entered into equity forward sale agreements with Credit Suisse Securities (USA) LLC as Agent for Credit Suisse Capital LLC and J.P. Morgan Chase Bank, National Association. The sale price was $75 per share less certain net adjustments for an initial forward price of $74.07 per share. The Equity Forwards require Duke Energy to either physically settle the transactions by issuing 21.3 million shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreements, or net settle in whole or in part through the delivery or receipt of cash or shares. The settlement alternative is at Duke Energy's election. In June 2018, Duke Energy physically settled one-half of the equity forwards by delivering approximately 10.6 million shares of common stock in exchange for net cash proceeds of approximately $781 million.

For contracts that have not been settled, no amounts have or will be recorded in Duke Energy's Condensed Consolidated Financial Statements with respect to the equity or ATM offerings until settlements of the Equity Forwards occur, which is expected by December 31, 2018. If Duke Energy had elected to net share settle these contracts as of September 30, 2018, Duke Energy would have been required to deliver 1.1 million shares. The initial forward sale price will be subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the relevant forward sale agreement. Until settlement of the Equity Forwards, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Duke Energy's stock is higher than the average forward sales price.

For the nine months ended September 30, 2018, Duke Energy has issued 1.7 million shares through its Dividend Reinvestment Program (DRIP) with an increase in additional paid-in capital of approximately $134 million

XML

Stock-Based Compensation

9 Months Ended

Sep. 30, 2018

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Stock-Based Compensation

STOCK-BASED COMPENSATION

Stock-based compensation awarded to employees or outside directors is measured at the service inception date or grant date. The fair value of the award is expensed or capitalized over the requisite service period. For awards with performance conditions, the probability of vesting is assessed at each reporting period and compensation cost is adjusted based upon that assessment.

The following table presents information related to Duke Energy's stock–based compensation.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2018		2017		2018		2017
Restricted stock unit awards	$	10	$	10	$	32	$	30
Performance awards	13		7		27		20
Pretax stock-based compensation cost	$	23	$	17	$	59	$	50
Stock-based compensation cost capitalized	$	1	$	1	$	3	$	2
Stock-based compensation expense	$	22	$	16	$	56	$	48
Tax benefit associated with stock-based compensation expense	$	5	$	6	$	13	$	18

XML

Employee Benefit Plans

9 Months Ended

Sep. 30, 2018

Retirement Benefits [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. The following table presents contributions made by the Duke Energy Registrants to their qualified defined benefit pension plans during the nine months ended September 30, 2018.

			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana
Contributions	$	141	$	46	$	45	$	25	$	20	$	8

Duke Energy and Duke Energy Ohio made contributions of $8 million and $4 million, respectively, to their qualified defined benefit pension plans during the nine months ended September 30, 2017.

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

Components of Net Periodic Benefit Costs

The tables below present total net periodic benefit costs prior to capitalization of amounts reflected as Net property, plant and equipment on the Condensed Consolidated Balance Sheets. Only the service cost component of net periodic benefit costs is eligible to be capitalized. The remaining non-capitalized portions of net periodic benefit costs are classified as either: (1) service cost, which is recorded in Operations, maintenance and other on the Condensed Consolidated Statements of Operations; or as (2) components of non-service cost, which is recorded in Other income and expenses, net on the Condensed Consolidated Statements of Operations. See Note 1 for further information on impacts of the retirement benefits accounting standard adopted by Duke Energy on January 1, 2018.

Pension and other post-retirement benefit costs presented in the tables below for the Subsidiary Registrants are amounts allocated from Duke Energy for the employees of the respective Subsidiary Registrants. The Condensed Consolidated Statements of Operations of the Subsidiary Registrants also include allocated net periodic benefit costs for their proportionate share of pension and post-retirement benefit costs related to employees of the Duke Energy shared services affiliate. However, in the tables below these amounts are only presented in the Duke Energy column. For additional information on the corporate governance and shared service expenses allocated from the Duke Energy shared service affiliate, see Note 8.

QUALIFIED PENSION PLANS

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

	Three Months Ended September 30, 2018
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	47		$	15		$	13		$	7		$	5		$	2		$	2		$	2
Interest cost on projected benefit obligation	74			18			24			10			13			4			6			3
Expected return on plan assets	(140		)	(37		)	(45		)	(21		)	(23		)	(7		)	(10		)	(6		)
Amortization of actuarial loss	33			7			11			6			6			1			2			3
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(3		)
Net periodic pension costs	$	6		$	1		$	2		$	2		$	1		$	—		$	—		$	(1	)

	Three Months Ended September 30, 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			4			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	)	$	1		$	2

	Nine Months Ended September 30, 2018
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	137		$	45		$	39		$	22		$	16		$	4		$	7		$	6
Interest cost on projected benefit obligation	224			54			70			31			38			13			18			9
Expected return on plan assets	(420		)	(111		)	(133		)	(63		)	(69		)	(21		)	(31		)	(18		)
Amortization of actuarial loss	99			21			33			16			18			3			6			9
Amortization of prior service credit	(24		)	(6		)	(3		)	(1		)	(1		)	—			—			(9		)
Net periodic pension costs	$	16		$	3		$	6		$	5		$	2		$	(1	)	$	—		$	(3	)

	Nine Months Ended September 30, 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	$	120		$	36		$	36		$	18		$	15		$	3		$	6		$	9
Interest cost on projected benefit obligation	246			60			75			36			39			14			21			9
Expected return on plan assets	(408		)	(106		)	(129		)	(63		)	(63		)	(21		)	(33		)	(18		)
Amortization of actuarial loss	108			24			42			18			21			3			9			9
Amortization of prior service credit	(18		)	(6		)	(3		)	—			—			—			—			(3		)
Other	6			—			3			1			—			—			—			1
Net periodic pension costs	$	54		$	8		$	24		$	10		$	12		$	(1	)	$	3		$	7

NON-QUALIFIED PENSION PLANS

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

	Three Months Ended September 30, 2018
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	3	$	—	$	1	$	—	$	—
Amortization of actuarial loss	2		—		—		—		—
Net periodic pension costs	$	5	$	—	$	1	$	—	$	—

	Three Months Ended September 30, 2017
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	4	$	—	$	1	$	1	$	1
Amortization of actuarial loss	2		—		1		—		—
Net periodic pension costs	$	6	$	—	$	2	$	1	$	1

	Nine Months Ended September 30, 2018
				Duke				Duke		Duke
	Duke			Energy		Progress		Energy		Energy
(in millions)	Energy			Carolinas		Energy		Progress		Florida
Service cost	$	1		$	1	$	—	$	—	$	—
Interest cost on projected benefit obligation	9			—		3		1		1
Amortization of actuarial loss	6			—		—		—		—
Amortization of prior service (credit) cost	(1		)	—		1		—		—
Net periodic pension costs	$	15		$	1	$	4	$	1	$	1

	Nine Months Ended September 30, 2017
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	10	$	1	$	3	$	2	$	2
Amortization of actuarial loss	6		—		3		—		—
Net periodic pension costs	$	16	$	1	$	6	$	2	$	2

OTHER POST-RETIREMENT BENEFIT PLANS

Duke Energy provides, and the Subsidiary Registrants participate in, certain 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 September 30, 2018
				Duke						Duke		Duke			Duke		Duke
	Duke			Energy			Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress		Florida			Ohio		Indiana		Piedmont
Service cost	$	2		$	—		$	—		$	—	$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	7			2			3			2		1			—		1		—
Expected return on plan assets	(4		)	(2		)	—			—		—			—		—		—
Amortization of actuarial loss	2			1			—			—		—			—		1		—
Amortization of prior service credit	(5		)	(1		)	(2		)	—		(1		)	—		—		—
Net periodic other post-retirement benefit costs	$	2		$	—		$	1		$	2	$	—		$	—	$	2	$	—

	Three Months Ended September 30, 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			—		1		—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—		—
Amortization of actuarial loss	2			—			5			3			2			—		—		—
Amortization of prior service credit	(29		)	(2		)	(21		)	(14		)	(8		)	—		—		—
Net periodic other post-retirement benefit costs	$	(20	)	$	(2	)	$	(12	)	$	(9	)	$	(4	)	$	—	$	1	$	—

	Nine Months Ended September 30, 2018
				Duke						Duke		Duke			Duke		Duke
	Duke			Energy			Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress		Florida			Ohio		Indiana		Piedmont
Service cost	$	5		$	1		$	—		$	—	$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	21			5			9			5		4			1		3		—
Expected return on plan assets	(10		)	(6		)	—			—		—			—		—		—
Amortization of actuarial loss	5			2			1			—		—			—		3		—
Amortization of prior service credit	(15		)	(3		)	(6		)	—		(4		)	—		—		(1		)
Net periodic other post-retirement benefit costs	$	6		$	(1	)	$	4		$	5	$	—		$	1	$	6	$	(1	)

	Nine Months Ended September 30, 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	$	3		$	—		$	—		$	—		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	27			6			11			6			6			—			1		—
Expected return on plan assets	(10		)	(6		)	—			—			—			—			—		—
Amortization of actuarial loss (gain)	6			(2		)	15			9			6			(1		)	—		—
Amortization of prior service credit	(87		)	(6		)	(63		)	(41		)	(23		)	—			—		—
Net periodic other post-retirement benefit costs	$	(61	)	$	(8	)	$	(37	)	$	(26	)	$	(11	)	$	(1	)	$	1	$	—

EMPLOYEE SAVINGS PLAN

Duke Energy sponsors, and the Subsidiary Registrants participate in, an employee savings plan that covers substantially all employees. The following table includes 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 September 30,
2018	$	49	$	15	$	13	$	9	$	4	$	—	$	3	$	4
2017	43		14		12		9		4		1		2		2
Nine Months Ended September 30,
2018	$	167	$	53	$	45	$	31	$	14	$	2	$	8	$	10
2017	147		49		42		30		13		3		7		5

XML

Income Taxes

9 Months Ended

Sep. 30, 2018

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

Tax Act

On December 22, 2017, President Trump signed the Tax Act into law. Among other provisions, the Tax Act lowered the corporate federal income tax rate from 35 to 21 percent, limits interest deductions outside of regulated utility operations, requires the normalization of excess deferred taxes associated with property under ARAM as a prerequisite to qualifying for accelerated depreciation and repealed the federal manufacturing deduction. The Tax Act also repealed the corporate alternative minimum tax (AMT) and stipulates a refund of 50 percent of remaining AMT credit carryforwards (to the extent the credits exceed regular tax for the year) for tax years 2018, 2019 and 2020 with all remaining AMT credits to be refunded in tax year 2021. During the three months ended September 30, 2018, the company reclassified $573 million which is 50 percent of the remaining estimated AMT credit carryforwards from noncurrent deferred tax liability to a current federal income tax receivable as a result of the Tax Act. The company reclassified the estimated AMT credit carryforwards during the three months ended September 30, 2018, since the company expects to receive it as a refund from the IRS in the three months ended September 30, 2019, based on the expected filing of Duke Energy's 2018 income tax return in the second quarter of 2019.

At this time AMT credits, which are among the certain tax credits treated as refundable under the Tax Act, are subject to sequestration. In the first quarter of 2018, the company revised the December 31, 2017, estimate of the income tax effects of the Tax Act and recorded a $76 million valuation allowance against these AMT credits based on additional interpretative guidance from the Internal Revenue Service related to the Tax Act. See Note 22 to the Consolidated Financial Statements in the Annual Report on Form 10-K/A for the year ended December 31, 2017, for information on the U.S. Securities and Exchange Commission staff's guidance on accounting for the Tax Act (Staff Accounting Bulletin No. 118 (SAB 118), Income Tax Accounting Implications of the Tax Cuts and Jobs Act).

During the three months endedSeptember 30, 2018, the company revised the December 31, 2017 estimate of the income tax effects of the Tax Act, in accordance with SAB 118, by recording a $3 million benefit for the remeasurement of its deferred tax assets and deferred tax liabilities primarily related to the guidance on bonus depreciation issued by the Internal Revenue Service in August of 2018 affecting the computation of the company's 2017 Federal income tax liability. The majority of Duke Energy’s operations are regulated and it is expected that the Subsidiary Registrants will ultimately pass on the savings associated with the amount representing the remeasurement of deferred tax balances related to regulated operations to customers. For Duke Energy's regulated operations, where the reduction is expected to be returned to customers in future rates, the remeasurement has been deferred as a regulatory liability. For the three months ended September 30, 2018, Duke Energy recorded a regulatory liability of $57 million, representing the revaluation of those deferred tax balances. The Subsidiary Registrants continue to respond to requests from regulators in various jurisdictions to determine the timing and magnitude of savings they will pass on to customers.

For the nine months ended September 30, 2018, the company has revised the December 31, 2017, estimates of the income tax effects of the Tax Act, in accordance with SAB 118, by recording an expense of $73 million. Additional tax returns will be filed in the quarter ending December 31, 2018, and Duke Energy expects to make refinements of estimates recorded in the three months ending September 30, 2018. These refinements are not expected to be material to the financial statements. Duke Energy anticipates finalizing and recording any resulting adjustments within the measurement period allowed, which will be no later than the quarter ending December 31, 2018.

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				Nine Months Ended
	September 30,				September 30,
	2018		2017		2018		2017
Duke Energy	13.7	%	27.6	%	17.0	%	30.4	%
Duke Energy Carolinas	22.6	%	32.9	%	22.3	%	34.1	%
Progress Energy	18.8	%	29.1	%	17.0	%	31.9	%
Duke Energy Progress	20.6	%	31.7	%	18.4	%	32.4	%
Duke Energy Florida	15.0	%	34.8	%	16.3	%	36.1	%
Duke Energy Ohio	16.0	%	33.3	%	16.0	%	34.4	%
Duke Energy Indiana	22.7	%	38.3	%	24.7	%	39.0	%
Piedmont	34.4	%	47.6	%	20.6	%	36.1	%

The decrease in the effective tax rate (ETR) for Duke Energy and the Subsidiary Registrants for the three months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act. The decrease in the ETR for Duke Energy and the Subsidiary Registrants for the nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal and state excess deferred taxes, partially offset by a valuation allowance against AMT credits discussed above.

The decrease in the ETR for Duke Energy Carolinas for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and amortization of state excess deferred taxes partially offset by favorable tax return true ups in the prior year.

The decrease in the ETR for Progress Energy for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal and state excess deferred taxes.

The decrease in the ETR for Duke Energy Progress for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and amortization of state excess deferred taxes.

The decrease in the ETR for Duke Energy Florida for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal excess deferred taxes.

The decrease in the ETR for Duke Energy Ohio for the three and nine months ended September 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act and the amortization of federal excess deferred taxes.

The decrease in the ETR for Duke Energy Indiana for the three and nine months endedSeptember 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act.

The decrease in the ETR for Piedmont for the three months ended September 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act partially offset by favorable research credits in relation to pretax losses. The decrease in the ETR for Piedmont for the nine months ended September 30, 2018, is primarily due to the lower statutory federal corporate tax rate under the Tax Act.

XML

Subsequent Events

9 Months Ended

Sep. 30, 2018

Subsequent Events [Abstract]

Subsequent Events

SUBSEQUENT EVENTS

For information on subsequent events related to regulatory matters and commitments and contingencies see Notes 3 and 4, respectively.

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 4 hurricane, the most powerful storm to hit the Florida Panhandle in recorded history. The storm caused significant damage and more than a million power outages within the service territories of Duke Energy Florida, Duke Energy Carolinas and Duke Energy Progress. Duke Energy has not completed the final accumulation of total estimated storm restoration costs incurred; however, the preliminary estimate is approximately$235 million of operation and maintenance expenses and approximately $185 million in capital costs. Given the magnitude of the storm, Duke Energy Carolinas and Duke Energy Progress intend to request approval to defer the incremental costs incurred to a regulatory asset for recovery in the next base rate cases, and Duke Energy Florida will recover these storm costs consistent with the provisions in its 2017 Second Revised and Restated Settlement Agreement.

XML

Organization and Basis of Presentation (Policy)

9 Months Ended

Sep. 30, 2018

Policy Text Block [Line Items]

Basis of Presentation

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles in the U.S. (GAAP) 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 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/A for the year ended December 31, 2017.

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.

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.

Cash, Cash Equivalents, and Restricted Cash

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

Duke Energy, Progress Energy and Duke Energy Florida have restricted cash balances related primarily to collateral assets, escrow deposits and variable interest entities (VIEs). See Note 12 for additional information. Restricted cash amounts are included in Other within Current Assets and Other Noncurrent Assets.

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.

New Accounting Standards

NEW ACCOUNTING STANDARDS

The new accounting standards adopted for 2018 and 2017 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 standards had the most significant impact on the Duke Energy results of operations, cash flows and financial position for the nine months endedSeptember 30, 2018.

Revenue from Contracts with Customers. In May 2014, the Financial Accounting Standards Board (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 expected in exchange for those goods or services. The amendments also required 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. The majority of Duke Energy’s revenue is in scope of the new guidance. Other revenue arrangements, such as alternative revenue programs and certain purchase power agreements (PPAs) and lighting agreements accounted for as leases, are excluded from the scope of this guidance and, therefore, are accounted for and evaluated for separate presentation and disclosure under other relevant accounting guidance.

Duke Energy elected the modified retrospective method of adoption effective January 1, 2018. Under the modified retrospective method of adoption, prior year reported results are not restated. Adoption of this standard did not result in a material change in the timing or pattern of revenue recognition and a cumulative-effect adjustment was not recorded at January 1, 2018. Duke Energy utilized certain practical expedients including applying this guidance to open contracts at the date of adoption, expensing costs to obtain a contract where the amortization period of the asset would have been one year or less, ignoring the effects of a significant financing when the period between transfer of the good or service and payment is one year or less and recognizing revenues for certain contracts under the invoice practical expedient, which allows revenue recognition to be consistent with invoiced amounts (including unbilled estimates) provided certain criteria are met, including consideration of whether the invoiced amounts reasonably represent the value provided to customers.

In preparation for adoption, Duke Energy identified material revenue streams and reviewed representative contracts and tariffs, including those associated with certain long-term customer contracts such as wholesale contracts, PPAs and other customer arrangements. Duke Energy also monitored the activities of the power and utilities industry revenue recognition task force and has reviewed published positions on specific industry issues to evaluate the impact, if any, on Duke Energy’s specific contracts and conclusions.

Duke Energy applied the available practical expedient to portfolios of tariffs and contracts with similar characteristics. The vast majority of sales, including energy provided to retail customers, are from tariff offerings that provide natural gas or electricity without a defined contractual term ("at-will"). In most circumstances, revenue from contracts with customers is equivalent to the electricity or natural gas supplied and billed in that period (including unbilled estimates). As such, adoption of the new rules did not result in a shift in the timing or pattern of revenue recognition for such sales. While there have been changes to the captions and descriptions of revenues in Duke Energy’s financial statements, the most significant impact as a result of adopting the standard are additional disclosures around the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers. See Note 13 for further information.

Financial Instruments Classification and Measurement. On January 1, 2018, Duke Energy adopted FASB guidance, which revised the classification and measurement of certain financial instruments. The adopted guidance changes the presentation of realized and unrealized gains and losses in certain equity securities that were previously recorded in accumulated other comprehensive income (AOCI). These gains and losses are now recorded in net income. 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. This guidance had a 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' equity securities are deferred as regulatory assets or liabilities pursuant to accounting guidance for regulated operations. The resulting adjustment of unrealized gains and losses in AOCI to retained earnings was immaterial. The primary impact to Duke Energy as a result of implementing this guidance is adding disclosure requirements to present separately the financial assets and financial liabilities by measurement category and form of financial asset. See Notes 10 and 11 for further information.

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 Condensed Consolidated Statements of Cash Flows. Under the updated guidance, restricted cash and restricted cash equivalents are included within beginning-of-period and end-of-period cash and cash equivalents on the Condensed Consolidated Statements of Cash Flows. Duke Energy adopted this guidance on January 1, 2018. The guidance has been applied using a retrospective transition method to each period presented. The adoption by Duke Energy of the revised guidance resulted in a change to the amount of Cash, cash equivalents and restricted cash explained when reconciling the beginning-of-period and end-of-period total amounts shown on the Condensed Consolidated Statements of Cash Flows. In addition, a reconciliation has been provided of Cash, cash equivalents and restricted cash reported within the Condensed Consolidated Balance Sheets that sums to the total of the same such amounts in the Condensed Consolidated Statements of Cash Flows. Prior to adoption, the Duke Energy Registrants reflected changes in noncurrent restricted cash within Cash Flows from Investing Activities and changes in current restricted cash within Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows.

In August 2016, the FASB issued accounting guidance addressing diversity in practice for eight separate cash flow issues. The guidance requires entities to classify distributions received from equity method investees using either the cumulative earnings approach or the nature of the distribution approach. Duke Energy adopted this guidance on January 1, 2018, and elected the nature of distribution approach. This approach requires all distributions received to be categorized based on legal documentation describing the nature of the activities generating the distribution. Cash inflows resulting in a return on investment (surplus) will be reflected in Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows, whereas cash inflows resulting in a return of investment (capital) will be reflected in Cash Flows from Investing Activities on the Condensed Consolidated Statements of Cash Flows. The guidance has been applied using the retrospective transition method to each period presented. There are no changes to the Condensed Consolidated Statements of Cash Flows for the periods presented as a result of this accounting change.

Retirement Benefits. In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic costs related to benefit plans. Previous guidance required the aggregation of all the components of net periodic costs on the Condensed Consolidated Statement of Operations and did 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 is included within Operating Income within the same line as other compensation expenses. All other components of net periodic costs are 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 previous guidance, which permitted all components of net periodic costs to be eligible for capitalization.

Duke Energy adopted this guidance on January 1, 2018. Under previous guidance, Duke Energy presented the total non-capitalized net periodic costs within Operation, maintenance and other on the Condensed Consolidated Statements of Operations. The adoption of this guidance resulted in a retrospective change to reclassify the presentation of the non-service cost (benefit) components of net periodic costs to Other income and expenses. Duke Energy utilized the practical expedient for retrospective presentation. The change in components of net periodic costs eligible for capitalization is applicable prospectively. Since Duke Energy’s service cost component is greater than the total net periodic costs, the change results in increased capitalization of net periodic costs, higher Operation, maintenance and other and higher Other income and expenses. The resulting prospective impact to Duke Energy is an immaterial increase in Net Income. See Note 15 for further information.

For Duke Energy, the retrospective change resulted in higher Operation, maintenance and other and higher Other income and expenses, net, of $156 million, $131 million and $96 million for the years ended December 31, 2017, 2016 and 2015, respectively. There was no change to Net Income for these prior periods.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by Duke Energy, as of September 30, 2018.

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. The guidance will be applied using a modified retrospective approach. Upon adoption, agreements considered leases for the use of certain aircraft, space on communication towers, industrial equipment, fleet vehicles, fuel transportation (barges and railcars), land and office space will be recognized on the balance sheet. Duke Energy expects to elect certain of the following practical expedients upon adoption:

Practical Expedient	Description	Election
Package of transition practical expedients (for leases commenced prior to adoption date and must be adopted as a package)	Do not need to 1) reassess whether any expired or existing contracts are/or contain leases, 2) reassess the lease classification for any expired or existing leases and 3) reassess initial direct costs for any existing leases.	Duke Energy plans to elect this practical expedient.
Short-term lease expedient (elect by class of underlying asset)	Elect as an accounting policy to not apply the recognition requirements to short-term leases by asset class.	Duke Energy plans to elect this practical expedient for all asset classes.
Lease and non-lease components (elect by class of underlying asset)	Elect as an accounting policy to not separate non-lease components from lease components and instead account for each lease and associated non-lease component as a single lease component by asset class.	Duke Energy is currently assessing the election of this practical expedient.
Hindsight expedient (when determining lease term)	Elect to use hindsight to determine the lease term.	Duke Energy plans to elect this practical expedient.
Existing and expired land easements not previously accounted for as leases	Elect to not evaluate existing or expired easements under the new guidance and carry forward current accounting treatment.	Duke Energy plans to elect this practical expedient.
Comparative reporting requirements for initial adoption	Elect to apply transition requirements at adoption date, recognize cumulative effect adjustment to retained earnings in period of adoption and not apply ASC 842 to comparative periods, including disclosures.	Duke Energy plans to elect this practical expedient.
Lessor expedient (elect by class of underlying asset)	Elect as an accounting policy to aggregate non-lease components with the related lease component when specified conditions are met by asset class. Account for the combined component based on its predominant characteristic (revenue or operating lease).	Duke Energy is currently assessing the election of this practical expedient.

Duke Energy is currently evaluating the financial statement impact of adopting this standard and is continuing to monitor industry implementation issues, including leases within asset retirement obligations, pipeline laterals and renewable energy PPAs. In arrangements where Duke Energy is the lessee, it expects an increase in assets and liabilities on its balance sheet along with the addition of required disclosures of key lease information. However, the ultimate lessee impact of the new standard has not yet been determined. Duke Energy does not expect a material change to its financial statements from adoption of the new standard for contracts where it is the lessor. System enhancements, including additional processes and controls, will be required to facilitate the identification, tracking and reporting of potential leases based upon requirements of the new lease standard. Duke Energy is implementing a third-party software tool to help with the adoption and ongoing accounting under the new standard.

Environmental Costs

Costs are typically expensed as Operation, maintenance and other on the Condensed Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.

Liabilities are recorded when losses become probable and are reasonably estimable.

Derivatives

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.

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 on the Duke Energy Registrant's Condensed Consolidated Statements of Operations and Comprehensive Income.

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 securities within the Investment Trusts are considered OTTIs and are recognized immediately and deferred to regulatory accounts where appropriate.

Unrealized gains and losses on all other AFS 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.

Revenue from Contract with Customer

certain excise taxes and franchise fees 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 as part of revenues. Duke Energy elects to account for all other taxes net of revenues.

Duke Energy recognizes revenue consistent with amounts billed under tariff offerings or at contractually agreed upon rates based on actual physical delivery of electric or natural gas service, including estimated volumes delivered when billings have not yet occurred.

UNBILLED REVENUE

Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy or 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 and meter reading schedules, and the impact of weather normalization or margin decoupling mechanisms.

Additionally, Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail accounts receivable, including receivables for unbilled revenues, to an affiliate, CRC and accounts for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana.

Earnings Per Share

Basic Earnings Per Share (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 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.

Stock-based Compensation

Stock-based compensation awarded to employees or outside directors is measured at the service inception date or grant date. The fair value of the award is expensed or capitalized over the requisite service period.

XML

Organization and Basis of Presentation (Tables)

9 Months Ended

Sep. 30, 2018

Organization And Basis Of Presentation [Line Items]

Schedule of Cash, Cash Equivalents and Restricted Cash

The following table presents the components of cash, cash equivalents and restricted cash included in the Condensed Consolidated Balance Sheets.

	September 30, 2018						December 31, 2017
					Duke						Duke
	Duke		Progress		Energy		Duke		Progress		Energy
	Energy		Energy		Florida		Energy		Energy		Florida
Current Assets
Cash and cash equivalents	$	303	$	43	$	20	$	358	$	40	$	13
Other	139		14		14		138		40		40
Other Noncurrent Assets
Other	7		6		—		9		7		—
Total cash, cash equivalents and restricted cash	$	449	$	63	$	34	$	505	$	87	$	53

Schedule of Utility Inventory

The components of inventory are presented in the tables below.

	September 30, 2018
			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	$	2,283	$	758	$	1,071	$	748	$	323	$	87	$	294	$	1
Coal	515		176		187		99		88		14		138		—
Natural gas, oil and other fuel	342		42		215		109		106		34		2		50
Total inventory	$	3,140	$	976	$	1,473	$	956	$	517	$	135	$	434	$	51

	December 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	$	2,293	$	744	$	1,118	$	774	$	343	$	82	$	309	$	2
Coal	603		192		255		139		116		17		139		—
Natural gas, oil and other fuel	354		35		219		104		115		34		2		64
Total inventory	$	3,250	$	971	$	1,592	$	1,017	$	574	$	133	$	450	$	66

Schedule of Excise Taxes

Excise taxes accounted for on a gross basis within both Operating Revenues and Property and other taxes on the Condensed Consolidated Statements of Operations were as follows.

	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Duke Energy	$	114	$	107	$	308	$	289
Duke Energy Carolinas	10		9		27		27
Progress Energy	71		67		181		168
Duke Energy Progress	5		5		15		14
Duke Energy Florida	66		62		166		154
Duke Energy Ohio	26		24		81		75
Duke Energy Indiana	6		6		17		16
Piedmont	1		1		2		3

Schedule of New Accounting Pronouncements

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. The guidance will be applied using a modified retrospective approach. Upon adoption, agreements considered leases for the use of certain aircraft, space on communication towers, industrial equipment, fleet vehicles, fuel transportation (barges and railcars), land and office space will be recognized on the balance sheet. Duke Energy expects to elect certain of the following practical expedients upon adoption:

Practical Expedient	Description	Election
Package of transition practical expedients (for leases commenced prior to adoption date and must be adopted as a package)	Do not need to 1) reassess whether any expired or existing contracts are/or contain leases, 2) reassess the lease classification for any expired or existing leases and 3) reassess initial direct costs for any existing leases.	Duke Energy plans to elect this practical expedient.
Short-term lease expedient (elect by class of underlying asset)	Elect as an accounting policy to not apply the recognition requirements to short-term leases by asset class.	Duke Energy plans to elect this practical expedient for all asset classes.
Lease and non-lease components (elect by class of underlying asset)	Elect as an accounting policy to not separate non-lease components from lease components and instead account for each lease and associated non-lease component as a single lease component by asset class.	Duke Energy is currently assessing the election of this practical expedient.
Hindsight expedient (when determining lease term)	Elect to use hindsight to determine the lease term.	Duke Energy plans to elect this practical expedient.
Existing and expired land easements not previously accounted for as leases	Elect to not evaluate existing or expired easements under the new guidance and carry forward current accounting treatment.	Duke Energy plans to elect this practical expedient.
Comparative reporting requirements for initial adoption	Elect to apply transition requirements at adoption date, recognize cumulative effect adjustment to retained earnings in period of adoption and not apply ASC 842 to comparative periods, including disclosures.	Duke Energy plans to elect this practical expedient.
Lessor expedient (elect by class of underlying asset)	Elect as an accounting policy to aggregate non-lease components with the related lease component when specified conditions are met by asset class. Account for the combined component based on its predominant characteristic (revenue or operating lease).	Duke Energy is currently assessing the election of this practical expedient.

XML

Business Segments (Tables)

9 Months Ended

Sep. 30, 2018

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 September 30, 2018
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	6,253	$	232	$	127		$	6,612	$	16		$	—		$	6,628
Intersegment revenues	7		24		—			31		18			(49		)	—
Total revenues	$	6,260	$	256	$	127		$	6,643	$	34		$	(49	)	$	6,628
Segment income (loss)(a)(b)(c)	$	1,167	$	17	$	(62	)	$	1,122	$	(44	)	$	—		$	1,078
Add back noncontrolling interests																(16		)
Income from discontinued operations, net of tax																4
Net income																$	1,066
Segment assets	$	123,847	$	11,806	$	4,212		$	139,865	$	3,115		$	185		$	143,165

	Three Months Ended September 30, 2017
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	6,122	$	249	$	95		$	6,466	$	16		$	—		$	6,482
Intersegment revenues	7		23		—			30		19			(49		)	—
Total revenues	$	6,129	$	272	$	95		$	6,496	$	35		$	(49	)	$	6,482
Segment income (loss)(b)(d)(e)	$	1,020	$	19	$	(49	)	$	990	$	(34	)	$	—		$	956
Add back noncontrolling interests																1
Loss from discontinued operations, net of tax																(2		)
Net income																$	955

(a) All segments include adjustments to the December 31, 2017 estimate of the income tax effects of the Tax Act. See Note 17 for additional information.

(b) Other includes costs to achieve the Piedmont acquisition.

(c) Commercial Renewables includes an impairment charge related to goodwill. See Note 7 for additional information.

(d) Electric Utilities and Infrastructure includes an impairment charge related to the unrecovered Levy Nuclear Project costs at Duke Energy Florida.

(e) Commercial Renewables includes impairment charges related to certain wind projects.

	Nine Months Ended September 30, 2018
	Electric		Gas					Total
	Utilities and		Utilities and		Commercial			Reportable
(in millions)	Infrastructure		Infrastructure		Renewables			Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	16,783	$	1,229	$	347		$	18,359	$	47		$	—		$	18,406
Intersegment revenues	23		72		—			95		54			(149		)	—
Total revenues	$	16,806	$	1,301	$	347		$	18,454	$	101		$	(149	)	$	18,406
Segment income (loss)(a)(b)(c)(d)(e)(f)	$	2,492	$	161	$	(4	)	$	2,649	$	(446	)	$	—		$	2,203
Add back noncontrolling interests																(12		)
Loss from discontinued operations, net of tax																(1		)
Net income																$	2,190

	Nine Months Ended September 30, 2017
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	16,211	$	1,175	$	333	$	17,719	$	47		$	—		$	17,766
Intersegment revenues	23		68		—		91		56			(147		)	—
Total revenues	$	16,234	$	1,243	$	333	$	17,810	$	103		$	(147	)	$	17,766
Segment income (loss)(c)(g)(h)	$	2,384	$	179	$	2	$	2,565	$	(205	)	$	—		$	2,360
Add back noncontrolling interests															5
Loss from discontinued operations, net of tax															(4		)
Net income															$	2,361

(a) All segments include adjustments to the December 31, 2017 estimate of the income tax effects of the Tax Act. See Note 17 for additional information.

(b) Electric Utilities and Infrastructure includes regulatory and legislative impairment charges related to rate case orders, settlements or other actions of regulators or legislative bodies. See Note 3 for additional information.

(c) Other includes costs to achieve the Piedmont acquisition.

(d) Gas Utilities and Infrastructure includes an impairment of the investment in Constitution Pipeline Company, LLC (Constitution). See Note 3 for additional information.

(e) Other includes the loss on the sale of the retired Beckjord Generating Station (Beckjord) described below and a valuation allowance recorded against the alternative minimum tax credits subject to sequestration. See Note 17 for additional information on the valuation allowance.

(f) Commercial Renewables includes an impairment charge related to goodwill. See Note 7 for additional information.

(g) Electric Utilities and Infrastructure includes an impairment charge related to the unrecovered Levy Nuclear Project costs at Duke Energy Florida.

(h) Commercial Renewables includes impairment charges related to certain wind projects.

Duke Energy Ohio [Member]

Segment Reporting Information [Line Items]

Business Segment Data

	Three Months Ended September 30, 2018
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations			Consolidated
Total revenues	$	373	$	84	$	457	$	12	$	—		$	469
Segment income/Net income	$	85	$	12	$	97	$	3	$	—		$	100
Segment assets	$	5,484	$	2,775	$	8,259	$	39	$	(2	)	$	8,296

	Three Months Ended September 30, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	371	$	90	$	461	$	10		$	471
Segment income (loss)	$	50	$	14	$	64	$	(8	)	$	56
Loss from discontinued operations, net of tax										(1		)
Net income										$	55

	Nine Months Ended September 30, 2018
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	1,055	$	361	$	1,416	$	36		$	1,452
Segment income (loss)/Net income(a)	$	157	$	64	$	221	$	(100	)	$	121

	Nine Months Ended September 30, 2017
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Consolidated
Total revenues	$	1,036	$	360	$	1,396	$	30		$	1,426
Segment income (loss)	$	96	$	56	$	152	$	(24	)	$	128
Loss from discontinued operations, net of tax										(1		)
Net income										$	127

(a)    Other includes the loss on the sale of Beckjord.

XML

Regulatory Matters (Tables)

9 Months Ended

Sep. 30, 2018

Regulated Operations [Abstract]

Schedule of Potential Plant Retirements

The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement due to a lack of requisite environmental control equipment. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of September 30, 2018, 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	$	132
Progress Energy and Duke Energy Florida
Crystal River Units 1 and 2(b)	766	100
Duke Energy Indiana
Gallagher Units 2 and 4(c)	280	123
Total Duke Energy	1,631	$	355

(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 expects to retire these coal units by the end of 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 2016 settlement of Edwardsport IGCC matters.

XML

Commitments and Contingencies (Table)

9 Months Ended

Sep. 30, 2018

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	$	57
Duke Energy Carolinas	17
Duke Energy Ohio	30
Piedmont	2

Reserve, Environmental Cost [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 Accounts Payable within Current Liabilities and Other within Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets.

	Nine Months Ended September 30, 2018
				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	$	81		$	10		$	15		$	3		$	12		$	47		$	5		$	2
Provisions/adjustments	7			3			2			3			(1		)	3			1			—
Cash reductions	(20		)	(2		)	(5		)	(1		)	(4		)	(12		)	(1		)	—
Balance at end of period	$	68		$	11		$	12		$	5		$	7		$	38		$	5		$	2

	Nine Months Ended September 30, 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	(1		)	2			1			—		1			(3		)	(2		)	1
Cash reductions	(13		)	(2		)	(3		)	—		(3		)	(7		)	(1		)	—
Balance at end of period	$	84		$	10		$	16		$	3	$	12		$	49		$	7		$	2

Reserve, Legal [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 related to the termination of an EPC contract discussed above. 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)	September 30, 2018		December 31, 2017
Reserves for Legal Matters
Duke Energy	$	63	$	88
Duke Energy Carolinas	11		30
Progress Energy	50		55
Duke Energy Progress	11		13
Duke Energy Florida	23		24
Piedmont	1		2

XML

Debt and Credit Facilities (Tables)

9 Months Ended

Sep. 30, 2018

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments

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

(in millions)	Maturity Date	Interest Rate			September 30, 2018
Unsecured Debt
Progress Energy	March 2019	7.050	%		$	450
Duke Energy (Parent)	September 2019	5.050	%		500
Piedmont	September 2019	2.848	%	(b)	350
First Mortgage Bonds
Duke Energy Carolinas	November 2018	7.000	%		500
Duke Energy Progress	January 2019	5.300	%		600
Duke Energy Ohio	April 2019	5.450	%		450
Other(a)					605
Current maturities of long-term debt					$	3,455

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

(b)    Debt issuance has a floating interest rate.

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

				Nine Months Ended September 30, 2018
						Duke		Duke		Duke		Duke
	Maturity	Interest		Duke		Energy		Energy		Energy		Energy
Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Progress		Florida
Unsecured Debt
March 2018(a)	April 2025	3.950	%	$	250	$	250	$	—	$	—	$	—
May 2018(b)	May 2021	2.819	%	500		500		—		—		—
September 2018(c)	September 2078	5.625	%	500		500		—		—		—
First Mortgage Bonds
March 2018(d)	March 2023	3.050	%	500		—		500		—		—
March 2018(d)	March 2048	3.950	%	500		—		500		—		—
June 2018(e)	July 2028	3.800	%	600		—		—		—		600
June 2018(e)	July 2048	4.200	%	400		—		—		—		400
August 2018(f)	September 2023	3.375	%	300		—		—		300		—
August 2018(f)	September 2028	3.700	%	500		—		—		500		—
Total issuances				$	4,050	$	1,250	$	1,000	$	800	$	1,000

(a) Debt issued to pay down short-term debt.

(b) Debt issued to pay down short-term debt. Debt issuance has a floating interest rate.

(c) Callable after September 2023 at par. Debt issued to pay down short-term debt and for general corporate purposes.

(d) Debt issued to repay at maturity a $300 million first mortgage bond due April 2018, pay down intercompany short-term debt and for general corporate purposes.

(e) Debt issued to repay a portion of intercompany short-term debt under money-pool borrowing arrangement and for general corporate purposes.

(f) Debt issued to repay short-term debt and for general corporate purposes.

Schedule Of Line Of Credit Facilities

The table below includes the current borrowing sublimits and available capacity under the Master Credit Facility.

	September 30, 2018
				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		$	2,650		$	1,750		$	1,400		$	650	$	450		$	600		$	500
Reduction to backstop issuances
Commercial paper(b)	(2,519		)	(988		)	(872		)	(150		)	—		(216		)	(293		)	—
Outstanding letters of credit	(55		)	(47		)	(4		)	(2		)	—		—			—			(2		)
Tax-exempt bonds	(81		)	—			—			—			—		—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—		—			—			—
Available capacity under the Master Credit Facility	$	4,845		$	1,615		$	624		$	998		$	650	$	234		$	226		$	498

(a) Represents the sublimit of each borrower.

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

XML

Asset Retirement Obligations (Tables)

9 Months Ended

Sep. 30, 2018

Asset Retirement Obligation [Abstract]

Schedule of Asset Retirement Obligations

The following table presents the AROs recorded on the Condensed Consolidated Balance Sheets.

	September 30, 2018
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Decommissioning of Nuclear Power Facilities(a)	$	5,367	$	2,031	$	3,181	$	2,650	$	531	$	—	$	—	$	—
Closure of Ash Impoundments	4,575		1,623		2,175		2,154		20		52		725		—
Other	314		58		79		37		42		46		19		15
Total ARO	$	10,256	$	3,712	$	5,435	$	4,841	$	593	$	98	$	744	$	15
Less: current portion	902		292		475		470		4		7		128		—
Total noncurrent ARO	$	9,354	$	3,420	$	4,960	$	4,371	$	589	$	91	$	616	$	15

(a)    Duke Energy amount includes purchase accounting adjustments related to the merger with Progress Energy.

Schedule of Change in Asset Retirement Obligation

The following table presents the change in liability associated with AROs for the Duke Energy Registrants.

				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Balance at December 31, 2017(a)	$	10,175		$	3,610		$	5,414		$	4,673		$	742		$	84		$	781		$	15
Accretion expense(b)	319			133			168			145			23			3			22			—
Liabilities settled(c)	(431		)	(198		)	(186		)	(155		)	(31		)	(5		)	(42		)	—
Liabilities incurred in the current year	34			8			—			—			—			—			25			—
Revisions in estimates of cash flows(d)	159			159			39			178			(141		)	16			(42		)	—
Balance at September 30, 2018	$	10,256		$	3,712		$	5,435		$	4,841		$	593		$	98		$	744		$	15

(a) Primarily relates to decommissioning nuclear power facilities, closure of ash impoundments, asbestos removal, closure of landfills at fossil generation facilities, retirement of natural gas mains and removal of renewable energy generation assets.

(b) For the nine months ended September 30, 2018, substantially all accretion expense relates to Duke Energy's regulated operations and has been deferred in accordance with regulatory accounting treatment.

(c) Primarily relates to ash impoundment closures and nuclear decommissioning of Crystal River Unit 3.

(d) Primarily relates to increases in groundwater monitoring estimates for closure of ash impoundments, partially offset by modifications to the timing of expected cash flows and a reduction for nuclear decommissioning at Crystal River Unit 3 compared to original estimates.

XML

Goodwill (Tables)

9 Months Ended

Sep. 30, 2018

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill By Reportable Operating Segment

The following table presents the goodwill by reportable operating segment included on Duke Energy's Condensed Consolidated Balance Sheets at September 30, 2018, and December 31, 2017.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables			Total
Goodwill balance at December 31, 2017	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(29		)	$	(29	)
Goodwill balance at December 31, 2017, adjusted for accumulated impairment charges	$	17,379	$	1,924	$	93		$	19,396
Goodwill balance at September 30, 2018	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(122		)	(122		)
Goodwill balance at September 30, 2018, adjusted for accumulated impairment charges	$	17,379	$	1,924	$	—		$	19,303

XML

Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2018

Related Party Transaction [Line Items]

Schedule of Related Party Transactions, Other Revenue and Expense

Material amounts related to transactions with related parties included on the Condensed Consolidated Statements of Operations and Comprehensive Income are presented in the following table.

	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	214	$	206	$	647	$	645
Indemnification coverages(b)	6		5		17		17
JDA revenue(c)	13		9		66		42
JDA expense(c)	61		39		134		91
Intercompany natural gas purchases(d)	3		3		11		5
Progress Energy
Corporate governance and shared service expenses(a)	$	216	$	207	$	613	$	555
Indemnification coverages(b)	8		10		25		29
JDA revenue(c)	61		39		134		91
JDA expense(c)	13		9		66		42
Intercompany natural gas purchases(d)	20		19		58		57
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	138	$	112	$	382	$	321
Indemnification coverages(b)	3		4		9		11
JDA revenue(c)	61		39		134		91
JDA expense(c)	13		9		66		42
Intercompany natural gas purchases(d)	20		19		58		57
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	78	$	95	$	231	$	234
Indemnification coverages(b)	5		6		16		18
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	85	$	90	$	264	$	275
Indemnification coverages(b)	1		1		3		3
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	105	$	94	$	302	$	281
Indemnification coverages(b)	2		2		6		6
Piedmont
Corporate governance and shared service expenses(a)	$	39	$	11	$	115	$	25
Indemnification coverages(b)	1		1		2		2
Intercompany natural gas sales(d)	23		22		69		62

(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 primarily 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 Joint Dispatch Agreement (JDA), which allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power and expenses from the purchase of power pursuant to the JDA are recorded in Operating Revenues and Fuel used in electric generation and purchased power, respectively, on the Condensed Consolidated Statements of Operations and Comprehensive Income.

(d) Piedmont provides long-term natural gas delivery service to certain Duke Energy Carolinas and Duke Energy Progress natural gas-fired generation facilities. Piedmont records the sales in Operating revenues, and Duke Energy Carolinas and Duke Energy Progress record the related purchases as a component of Fuel used in electric generation and purchased power on their respective Condensed Consolidated Statements of Operations and Comprehensive Income. These intercompany revenues and expenses are eliminated in consolidation.

The following table presents expenses for the three and nine months ended September 30, 2018, and 2017, which are included in Cost of natural gas on Piedmont's Condensed Consolidated Statements of Operations and Comprehensive Income.

		Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	Type of expense	2018		2017		2018		2017
Cardinal	Transportation Costs	$	2	$	2	$	5	$	6
Pine Needle	Natural Gas Storage Costs	2		2		6		6
Hardy Storage	Natural Gas Storage Costs	2		2		7		7
Total		$	6	$	6	$	18	$	19

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
September 30, 2018
Intercompany income tax receivable	$	32	$	196	$	80	$	—	$	—	$	22	$	11
Intercompany income tax payable	—		—		—		77		9		—		—
December 31, 2017
Intercompany income tax receivable	$	—	$	168	$	—	$	44	$	22	$	—	$	7
Intercompany income tax payable	44		—		21		—		—		35		—

XML

Derivatives and Hedging (Tables)

9 Months Ended

Sep. 30, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Notional Amounts of Outstanding Derivative Positions

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.

	September 30, 2018
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	170	—	—	—	—	170	—
Natural gas (millions of dekatherms)	744	119	167	158	9	1	457

	December 31, 2017
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Indiana	Piedmont
Electricity (gigawatt-hours)	34	—	—	—	—	34	—
Natural gas (millions of dekatherms)	770	105	183	133	50	2	480

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

	September 30, 2018
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	411	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,127		400		500		250		250		27
Total notional amount(a)	$	1,538	$	400	$	500	$	250	$	250	$	27

	December 31, 2017
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges(a)	$	660	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	927		400		500		250		250		27
Total notional amount	$	1,587	$	400	$	500	$	250	$	250	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $411 million in cash flow hedges and $200 million in undesignated contracts as of September 30, 2018, and $660 million in cash flow hedges as of December 31, 2017.

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	September 30, 2018
			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	$	46	$	2	$	3	$	2	$	1	$	8	$	29	$	4
Noncurrent	1		—		—		—		—		—		—		—
Total Derivative Assets – Commodity Contracts	$	47	$	2	$	3	$	2	$	1	$	8	$	29	$	4
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	6	$	5	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	6		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		—		—		—		—		—		—
Noncurrent	17		—		—		—		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	30	$	5	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Assets	$	77	$	7	$	3	$	2	$	1	$	8	$	29	$	4

Derivative Liabilities	September 30, 2018
			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	$	26	$	14	$	5	$	5	$	—	$	—	$	—	$	7
Noncurrent	177		14		17		8		—		—		—		146
Total Derivative Liabilities – Commodity Contracts	$	203	$	28	$	22	$	13	$	—	$	—	$	—	$	153
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	2	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Not Designated as Hedging Instruments
Current	7		—		6		3		3		1		—		—
Noncurrent	13		—		9		8		2		3		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	22	$	—	$	15	$	11	$	5	$	4	$	—	$	—
Total Derivative Liabilities	$	225	$	28	$	37	$	24	$	5	$	4	$	—	$	153

Derivative Assets	December 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	$	34	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Noncurrent	1		—		1		1		—		—		—		—
Total Derivative Assets – Commodity Contracts	$	35	$	2	$	3	$	2	$	1	$	1	$	27	$	2
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	1	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	15		—		—		—		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	16	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Assets	$	51	$	2	$	3	$	2	$	1	$	1	$	27	$	2

Derivative Liabilities	December 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	$	36	$	6	$	18	$	8	$	10	$	—	$	—	$	11
Noncurrent	146		4		10		4		—		—		—		131
Total Derivative Liabilities – Commodity Contracts	$	182	$	10	$	28	$	12	$	10	$	—	$	—	$	142
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	29	$	25	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	6		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	1		—		1		—		—		1		—		—
Noncurrent	12		—		7		6		2		4		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	48	$	25	$	8	$	6	$	2	$	5	$	—	$	—
Total Derivative Liabilities	$	230	$	35	$	36	$	18	$	12	$	5	$	—	$	142

Offsetting Assets

Derivative Assets	December 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	$	35	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Gross amounts offset	—		—		—		—		—		—		—		—
Net amounts presented in Current Assets: Other	$	35	$	2	$	2	$	1	$	1	$	1	$	27	$	2
Noncurrent
Gross amounts recognized	$	16	$	—	$	1	$	1	$	—	$	—	$	—	$	—
Gross amounts offset	—		—		—		—		—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	16	$	—	$	1	$	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	September 30, 2018
				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	$	53		$	7		$	3		$	2		$	1	$	8	$	29	$	4
Gross amounts offset	(4		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Assets: Other	$	49		$	5		$	1		$	—		$	1	$	8	$	29	$	4
Noncurrent
Gross amounts recognized	$	24		$	—		$	—		$	—		$	—	$	—	$	—	$	—
Gross amounts offset	(1		)	—			—			—			—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	23		$	—		$	—		$	—		$	—	$	—	$	—	$	—

Offsetting Liabilities

Derivative Liabilities	September 30, 2018
				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	$	35		$	14		$	11		$	8		$	3	$	1	$	—	$	7
Gross amounts offset	(4		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Liabilities: Other	$	31		$	12		$	9		$	6		$	3	$	1	$	—	$	7
Noncurrent
Gross amounts recognized	$	190		$	14		$	26		$	16		$	2	$	3	$	—	$	146
Gross amounts offset	(1		)	—			(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	189		$	14		$	25		$	15		$	2	$	3	$	—	$	146

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	December 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	$	66		$	31		$	19		$	8		$	10	$	1	$	—	$	11
Gross amounts offset	(3		)	(2		)	(2		)	(2		)	—		—		—		—
Net amounts presented in Current Liabilities: Other	$	63		$	29		$	17		$	6		$	10	$	1	$	—	$	11
Noncurrent
Gross amounts recognized	$	164		$	4		$	17		$	10		$	2	$	4	$	—	$	131
Gross amounts offset	(1		)	—			(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	163		$	4		$	16		$	9		$	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.

	September 30, 2018
			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	$	48	$	26	$	23	$	22	$	—
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	48		26		23		22		—

	December 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	$	59	$	35	$	25	$	15	$	10
Fair value of collateral already posted	—		—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	59		35		25		15		10

XML

Investments in Debt and Equity Securities (Tables)

9 Months Ended

Sep. 30, 2018

Debt Securities, Available-for-sale [Line Items]

Debt Securities, Trading, and Equity Securities, FV-NI

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	75	$	—	$	—	$	115
Equity securities	3,117		48		5,272		2,805		27		4,914
Corporate debt securities	5		10		595		17		2		570
Municipal bonds	—		7		346		4		3		344
U.S. government bonds	5		25		974		11		7		1,027
Other debt securities	—		3		141		—		1		118
Total NDTF Investments	$	3,127	$	93	$	7,403	$	2,837	$	40	$	7,088
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	15
Equity securities	51		—		115		59		—		123
Corporate debt securities	—		1		64		1		—		57
Municipal bonds	1		1		85		2		1		83
U.S. government bonds	—		1		59		—		—		41
Other debt securities	—		1		43		—		1		44
Total Other Investments	$	52	$	4	$	387	$	62	$	2	$	363
Total Investments	$	3,179	$	97	$	7,790	$	2,899	$	42	$	7,451

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Debt Securities, Available-for-sale

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	75	$	—	$	—	$	115
Equity securities	3,117		48		5,272		2,805		27		4,914
Corporate debt securities	5		10		595		17		2		570
Municipal bonds	—		7		346		4		3		344
U.S. government bonds	5		25		974		11		7		1,027
Other debt securities	—		3		141		—		1		118
Total NDTF Investments	$	3,127	$	93	$	7,403	$	2,837	$	40	$	7,088
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	15
Equity securities	51		—		115		59		—		123
Corporate debt securities	—		1		64		1		—		57
Municipal bonds	1		1		85		2		1		83
U.S. government bonds	—		1		59		—		—		41
Other debt securities	—		1		43		—		1		44
Total Other Investments	$	52	$	4	$	387	$	62	$	2	$	363
Total Investments	$	3,179	$	97	$	7,790	$	2,899	$	42	$	7,451

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Available-for-sale Securities

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	75	$	—	$	—	$	115
Equity securities	3,117		48		5,272		2,805		27		4,914
Corporate debt securities	5		10		595		17		2		570
Municipal bonds	—		7		346		4		3		344
U.S. government bonds	5		25		974		11		7		1,027
Other debt securities	—		3		141		—		1		118
Total NDTF Investments	$	3,127	$	93	$	7,403	$	2,837	$	40	$	7,088
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	15
Equity securities	51		—		115		59		—		123
Corporate debt securities	—		1		64		1		—		57
Municipal bonds	1		1		85		2		1		83
U.S. government bonds	—		1		59		—		—		41
Other debt securities	—		1		43		—		1		44
Total Other Investments	$	52	$	4	$	387	$	62	$	2	$	363
Total Investments	$	3,179	$	97	$	7,790	$	2,899	$	42	$	7,451

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	100
Due after one through five years	492
Due after five through 10 years	561
Due after 10 years	1,154
Total	$	2,307

Schedule of Realized Gain (Loss)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	19	$	85
Realized losses	16		60
AFS:
Realized gains	4		14
Realized losses	7		32

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	37	$	170
Realized losses	25		124

Duke Energy Carolinas [Member]

Debt Securities, Available-for-sale [Line Items]

Debt Securities, Trading, and Equity Securities, FV-NI

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	32
Equity securities	1,692		29		2,890		1,531		12		2,692
Corporate debt securities	2		7		372		9		2		359
Municipal bonds	—		2		80		—		1		60
U.S. government bonds	1		14		439		3		4		503
Other debt securities	—		3		137		—		1		112
Total NDTF Investments	$	1,695	$	55	$	3,936	$	1,543	$	20	$	3,758

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Debt Securities, Available-for-sale

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	32
Equity securities	1,692		29		2,890		1,531		12		2,692
Corporate debt securities	2		7		372		9		2		359
Municipal bonds	—		2		80		—		1		60
U.S. government bonds	1		14		439		3		4		503
Other debt securities	—		3		137		—		1		112
Total NDTF Investments	$	1,695	$	55	$	3,936	$	1,543	$	20	$	3,758

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Available-for-sale Securities

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	32
Equity securities	1,692		29		2,890		1,531		12		2,692
Corporate debt securities	2		7		372		9		2		359
Municipal bonds	—		2		80		—		1		60
U.S. government bonds	1		14		439		3		4		503
Other debt securities	—		3		137		—		1		112
Total NDTF Investments	$	1,695	$	55	$	3,936	$	1,543	$	20	$	3,758

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	12
Due after one through five years	161
Due after five through 10 years	289
Due after 10 years	566
Total	$	1,028

Schedule of Realized Gain (Loss)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	11	$	47
Realized losses	8		30
AFS:
Realized gains	4		13
Realized losses	6		24

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	20	$	110
Realized losses	13		76

Progress Energy [Member]

Debt Securities, Available-for-sale [Line Items]

Debt Securities, Trading, and Equity Securities, FV-NI

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	57	$	—	$	—	$	83
Equity securities	1,425		19		2,382		1,274		15		2,222
Corporate debt securities	3		3		223		8		—		211
Municipal bonds	—		5		266		4		2		284
U.S. government bonds	4		11		535		8		3		524
Other debt securities	—		—		4		—		—		6
Total NDTF Investments	$	1,432	$	38	$	3,467	$	1,294	$	20	$	3,330
Other Investments
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	12
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	66	$	2	$	—	$	59
Total Investments	$	1,433	$	38	$	3,533	$	1,296	$	20	$	3,389

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Debt Securities, Available-for-sale

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	57	$	—	$	—	$	83
Equity securities	1,425		19		2,382		1,274		15		2,222
Corporate debt securities	3		3		223		8		—		211
Municipal bonds	—		5		266		4		2		284
U.S. government bonds	4		11		535		8		3		524
Other debt securities	—		—		4		—		—		6
Total NDTF Investments	$	1,432	$	38	$	3,467	$	1,294	$	20	$	3,330
Other Investments
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	12
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	66	$	2	$	—	$	59
Total Investments	$	1,433	$	38	$	3,533	$	1,296	$	20	$	3,389

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Available-for-sale Securities

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	57	$	—	$	—	$	83
Equity securities	1,425		19		2,382		1,274		15		2,222
Corporate debt securities	3		3		223		8		—		211
Municipal bonds	—		5		266		4		2		284
U.S. government bonds	4		11		535		8		3		524
Other debt securities	—		—		4		—		—		6
Total NDTF Investments	$	1,432	$	38	$	3,467	$	1,294	$	20	$	3,330
Other Investments
Cash and cash equivalents	$	—	$	—	$	18	$	—	$	—	$	12
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	66	$	2	$	—	$	59
Total Investments	$	1,433	$	38	$	3,533	$	1,296	$	20	$	3,389

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	83
Due after one through five years	268
Due after five through 10 years	217
Due after 10 years	508
Total	$	1,076

Schedule of Realized Gain (Loss)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	8	$	38
Realized losses	8		30
AFS:
Realized gains	—		1
Realized losses	1		8

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	16	$	58
Realized losses	12		47

Duke Energy Progress [Member]

Debt Securities, Available-for-sale [Line Items]

Debt Securities, Trading, and Equity Securities, FV-NI

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	42	$	—	$	—	$	50
Equity securities	1,101		14		1,913		980		12		1,795
Corporate debt securities	2		2		162		6		—		149
Municipal bonds	—		5		265		4		2		283
U.S. government bonds	3		8		352		5		2		310
Other debt securities	—		—		2		—		—		4
Total NDTF Investments	$	1,106	$	29	$	2,736	$	995	$	16	$	2,591
Other Investments
Cash and cash equivalents	$	—	$	—	$	8	$	—	$	—	$	1
Total Other Investments	$	—	$	—	$	8	$	—	$	—	$	1
Total Investments	$	1,106	$	29	$	2,744	$	995	$	16	$	2,592

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Debt Securities, Available-for-sale

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	42	$	—	$	—	$	50
Equity securities	1,101		14		1,913		980		12		1,795
Corporate debt securities	2		2		162		6		—		149
Municipal bonds	—		5		265		4		2		283
U.S. government bonds	3		8		352		5		2		310
Other debt securities	—		—		2		—		—		4
Total NDTF Investments	$	1,106	$	29	$	2,736	$	995	$	16	$	2,591
Other Investments
Cash and cash equivalents	$	—	$	—	$	8	$	—	$	—	$	1
Total Other Investments	$	—	$	—	$	8	$	—	$	—	$	1
Total Investments	$	1,106	$	29	$	2,744	$	995	$	16	$	2,592

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Available-for-sale Securities

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	42	$	—	$	—	$	50
Equity securities	1,101		14		1,913		980		12		1,795
Corporate debt securities	2		2		162		6		—		149
Municipal bonds	—		5		265		4		2		283
U.S. government bonds	3		8		352		5		2		310
Other debt securities	—		—		2		—		—		4
Total NDTF Investments	$	1,106	$	29	$	2,736	$	995	$	16	$	2,591
Other Investments
Cash and cash equivalents	$	—	$	—	$	8	$	—	$	—	$	1
Total Other Investments	$	—	$	—	$	8	$	—	$	—	$	1
Total Investments	$	1,106	$	29	$	2,744	$	995	$	16	$	2,592

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	40
Due after one through five years	200
Due after five through 10 years	156
Due after 10 years	385
Total	$	781

Schedule of Realized Gain (Loss)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	7	$	32
Realized losses	7		27
AFS:
Realized gains	—		1
Realized losses	1		6

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	14	$	49
Realized losses	11		41

Duke Energy Florida [Member]

Debt Securities, Available-for-sale [Line Items]

Debt Securities, Trading, and Equity Securities, FV-NI

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	15	$	—	$	—	$	33
Equity securities	324		5		469		294		3		427
Corporate debt securities	1		1		61		2		—		62
Municipal bonds	—		—		1		—		—		1
U.S. government bonds	1		3		183		3		1		214
Other debt securities	—		—		2		—		—		2
Total NDTF Investments(b)	$	326	$	9	$	731	$	299	$	4	$	739
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	1
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	48	$	2	$	—	$	48
Total Investments	$	327	$	9	$	779	$	301	$	4	$	787

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

(b) During the nine months endedSeptember 30, 2018, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of the Crystal River Unit 3 nuclear plant.

Debt Securities, Available-for-sale

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	15	$	—	$	—	$	33
Equity securities	324		5		469		294		3		427
Corporate debt securities	1		1		61		2		—		62
Municipal bonds	—		—		1		—		—		1
U.S. government bonds	1		3		183		3		1		214
Other debt securities	—		—		2		—		—		2
Total NDTF Investments(b)	$	326	$	9	$	731	$	299	$	4	$	739
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	1
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	48	$	2	$	—	$	48
Total Investments	$	327	$	9	$	779	$	301	$	4	$	787

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

(b) During the nine months endedSeptember 30, 2018, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of the Crystal River Unit 3 nuclear plant.

Available-for-sale Securities

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF
Cash and cash equivalents	$	—	$	—	$	15	$	—	$	—	$	33
Equity securities	324		5		469		294		3		427
Corporate debt securities	1		1		61		2		—		62
Municipal bonds	—		—		1		—		—		1
U.S. government bonds	1		3		183		3		1		214
Other debt securities	—		—		2		—		—		2
Total NDTF Investments(b)	$	326	$	9	$	731	$	299	$	4	$	739
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	1
Municipal bonds	1		—		48		2		—		47
Total Other Investments	$	1	$	—	$	48	$	2	$	—	$	48
Total Investments	$	327	$	9	$	779	$	301	$	4	$	787

(a) Where regulatory accounting is applied, realized and unrealized gains and losses are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

(b) During the nine months endedSeptember 30, 2018, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of the Crystal River Unit 3 nuclear plant.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	43
Due after one through five years	68
Due after five through 10 years	61
Due after 10 years	123
Total	$	295

Schedule of Realized Gain (Loss)

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months endedSeptember 30, 2018, and from sales of AFS securities for the three and nine months ended September 30, 2017, were as follows.

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2018		September 30, 2018
FV-NI:
Realized gains	$	1	$	6
Realized losses	1		3
AFS:
Realized gains	—		—
Realized losses	—		2

	Three Months Ended		Nine Months Ended
(in millions)	September 30, 2017		September 30, 2017
Realized gains	$	2	$	9
Realized losses	1		6

Duke Energy Indiana [Member]

Debt Securities, Available-for-sale [Line Items]

Debt Securities, Trading, and Equity Securities, FV-NI

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are measured at FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
Investments
Equity securities	$	40	$	—	$	78	$	49	$	—	$	97
Corporate debt securities	—		—		8		—		—		3
Municipal bonds	—		1		32		—		1		28
Total Investments	$	40	$	1	$	118	$	49	$	1	$	128

(a) Realized and unrealized gains and losses where regulatory accounting is applied are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Debt Securities, Available-for-sale

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are measured at FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
Investments
Equity securities	$	40	$	—	$	78	$	49	$	—	$	97
Corporate debt securities	—		—		8		—		—		3
Municipal bonds	—		1		32		—		1		28
Total Investments	$	40	$	1	$	118	$	49	$	1	$	128

(a) Realized and unrealized gains and losses where regulatory accounting is applied are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Available-for-sale Securities

The following table presents the estimated fair value of investments in debt and equity securities; equity investments are measured at FV-NI and debt investments are classified as AFS.

	September 30, 2018(a)						December 31, 2017
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
Investments
Equity securities	$	40	$	—	$	78	$	49	$	—	$	97
Corporate debt securities	—		—		8		—		—		3
Municipal bonds	—		1		32		—		1		28
Total Investments	$	40	$	1	$	118	$	49	$	1	$	128

(a) Realized and unrealized gains and losses where regulatory accounting is applied are deferred as regulatory assets or liabilities, and there is no impact to net income or other comprehensive income until the gain or loss is amortized or collected.

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

(in millions)	September 30, 2018
Due in one year or less	$	2
Due after one through five years	20
Due after five through 10 years	5
Due after 10 years	13
Total	$	40

XML

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2018

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 tables below for all Duke Energy Registrants exclude cash collateral, which is disclosed in Note 9. See Note 10 for additional information related to investments by major security type for the Duke Energy Registrants.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 2			Level 3			Not Categorized
NDTF equity securities	$	5,272		$	5,203	$	—		$	—		$	69
NDTF debt securities	2,131			510		1,621			—			—
Other equity securities	115			115		—			—			—
Other debt securities	272			78		194			—			—
Derivative assets	77			4		36			37			—
Total assets	7,867			5,910		1,851			37			69
Derivative liabilities	(225		)	—		(72		)	(153		)	—
Net assets (liabilities)	$	7,642		$	5,910	$	1,779		$	(116	)	$	69

	December 31, 2017
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	4,914		$	4,840		$	—		$	—		$	74
NDTF debt securities	2,174			635			1,539			—			—
Other equity securities	123			123			—			—			—
Other debt securities	241			57			184			—			—
Derivative assets	51			3			20			28			—
Total assets	7,503			5,658			1,743			28			74
Derivative liabilities	(230		)	(2		)	(86		)	(142		)	—
Net assets (liabilities)	$	7,273		$	5,656		$	1,657		$	(114	)	$	74

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 Cost of natural gas on the Duke Energy Registrants' Condensed Consolidated Statements of Operations and Comprehensive Income. Amounts included in changes of net assets on the Duke Energy Registrants' Condensed Consolidated Balance Sheets are included in regulatory assets or liabilities. All derivative assets and liabilities are presented on a net basis.

	Three Months Ended September 30, 2018								Three Months Ended September 30, 2017
(in millions)	Investments		Derivatives (net)			Total			Investments		Derivatives (net)			Total
Balance at beginning of period	$	—	$	(97	)	$	(97	)	$	—	$	(91	)	$	(91	)
Purchases, sales, issuances and settlements:
Settlements	—		(14		)	(14		)	—		(12		)	(12		)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	—		(5		)	(5		)	—		10			10
Balance at end of period	$	—	$	(116	)	$	(116	)	$	—	$	(93	)	$	(93	)

	Nine Months Ended September 30, 2018								Nine Months Ended September 30, 2017
(in millions)	Investments		Derivatives (net)			Total			Investments			Derivatives (net)			Total
Balance at beginning of period	$	—	$	(114	)	$	(114	)	$	5		$	(166	)	$	(161	)
Total pretax realized or unrealized gains included in comprehensive income	—		—			—			1			—			1
Purchases, sales, issuances and settlements:
Purchases	—		56			56			—			55			55
Sales	—		—			—			(6		)	—			(6		)
Settlements	—		(43		)	(43		)	—			(30		)	(30		)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	—		(15		)	(15		)	—			48			48
Balance at end of period	$	—	$	(116	)	$	(116	)	$	—		$	(93	)	$	(93	)

Quantitative Information Table - Level 3

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

	September 30, 2018
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
Financial Transmission Rights (FTRs)	$	8		RTO auction pricing	FTR price – per megawatt-hour (MWh)	$	1.03		-	$	4.10
Duke Energy Indiana
FTRs	29			RTO auction pricing	FTR price – per MWh	(2.32		)	-	8.11
Piedmont
Natural gas contracts	(153		)	Discounted cash flow	Forward natural gas curves – price per million British thermal unit (MMBtu)	1.74			-	3.41
Duke Energy
Total Level 3 derivatives	$	(116	)

	December 31, 2017
	Fair Value
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy Ohio
FTRs	$	1		RTO auction pricing	FTR price – per MWh	$	0.07		-	$	1.41
Duke Energy Indiana
FTRs	27			RTO auction pricing	FTR price – per MWh	(0.77		)	-	7.44
Piedmont
Natural gas contracts	(142		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	2.10			-	2.88
Duke Energy
Total Level 3 derivatives	$	(114	)

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.

	September 30, 2018				December 31, 2017
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy(a)	$	53,962	$	53,949	$	52,279	$	55,331
Duke Energy Carolinas	10,395		10,887		10,103		11,372
Progress Energy	18,912		19,825		17,837		20,000
Duke Energy Progress	8,154		8,231		7,357		7,992
Duke Energy Florida	7,371		7,749		7,095		7,953
Duke Energy Ohio	2,066		2,136		2,067		2,249
Duke Energy Indiana	3,783		4,178		3,783		4,464
Piedmont	2,138		2,175		2,037		2,209

(a) Book value of long-term debt includes $1.6 billion as of September 30, 2018, and $1.7 billion as of December 31, 2017, of unamortized debt discount and premium, net in purchase accounting adjustments related to the mergers with Progress Energy and Piedmont that are excluded from fair value of long-term debt.

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.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	2,890		$	2,821	$	—		$	69
NDTF debt securities	1,046			122		924			—
Derivative assets	7			—		7			—
Total assets	3,943			2,943		931			69
Derivative liabilities	(28		)	—		(28		)	—
Net assets	$	3,915		$	2,943	$	903		$	69

	December 31, 2017
(in millions)	Total Fair Value			Level 1			Level 2			Not Categorized
NDTF equity securities	$	2,692		$	2,618		$	—		$	74
NDTF debt securities	1,066			204			862			—
Derivative assets	2			—			2			—
Total assets	3,760			2,822			864			74
Derivative liabilities	(35		)	(1		)	(34		)	—
Net assets	$	3,725		$	2,821		$	830		$	74

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.

	Investments
	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2018		2017		2018		2017
Balance at beginning of period	$	—	$	—	$	—	$	3
Total pretax realized or unrealized gains included in comprehensive income	—		—		—		1
Purchases, sales, issuances and settlements:
Sales	—		—		—		(4		)
Balance at end of period	$	—	$	—	$	—	$	—

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1			Level 2
NDTF equity securities	$	2,382		$	2,382	$	—		$	2,222		$	2,222		$	—
NDTF debt securities	1,085			388		697			1,108			431			677
Other debt securities	66			18		48			59			12			47
Derivative assets	3			—		3			3			1			2
Total assets	3,536			2,788		748			3,392			2,666			726
Derivative liabilities	(37		)	—		(37		)	(36		)	(1		)	(35		)
Net assets	$	3,499		$	2,788	$	711		$	3,356		$	2,665		$	691

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1			Level 2
NDTF equity securities	$	1,913		$	1,913	$	—		$	1,795		$	1,795		$	—
NDTF debt securities	823			254		569			796			243			553
Other debt securities	8			8		—			1			1			—
Derivative assets	2			—		2			2			1			1
Total assets	2,746			2,175		571			2,594			2,040			554
Derivative liabilities	(24		)	—		(24		)	(18		)	(1		)	(17		)
Net assets	$	2,722		$	2,175	$	547		$	2,576		$	2,039		$	537

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	469		$	469	$	—		$	427		$	427	$	—
NDTF debt securities	262			134		128			312			188		124
Other debt securities	48			—		48			48			1		47
Derivative assets	1			—		1			1			—		1
Total assets	780			603		177			788			616		172
Derivative liabilities	(5		)	—		(5		)	(12		)	—		(12		)
Net assets	$	775		$	603	$	172		$	776		$	616	$	160

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 table provides recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value			Level 2			Level 3		Total Fair Value			Level 2			Level 3
Derivative assets	$	8		$	—		$	8	$	1		$	—		$	1
Derivative liabilities	(4		)	(4		)	—		(5		)	(5		)	—
Net assets (liabilities)	$	4		$	(4	)	$	8	$	(4	)	$	(5	)	$	1

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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	9		$	3		$	1		$	5
Purchases, sales, issuances and settlements:
Purchases	—			—			7			3
Settlements	(1		)	(1		)	(2		)	(3		)
Total gains (losses) included on the Condensed Consolidated Balance Sheet	—			—			2			(3		)
Balance at end of period	$	8		$	2		$	8		$	2

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.

	September 30, 2018								December 31, 2017
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Total Fair Value		Level 1		Level 2		Level 3
Other equity securities	$	78	$	78	$	—	$	—	$	97	$	97	$	—	$	—
Other debt securities	40		—		40		—		31		—		31		—
Derivative assets	29		—		—		29		27		—		—		27
Total assets	$	147	$	78	$	40	$	29	$	155	$	97	$	31	$	27

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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	44		$	51		$	27		$	16
Purchases, sales, issuances and settlements:
Purchases	—			—			49			52
Settlements	(13		)	(11		)	(41		)	(27		)
Total losses included on the Condensed Consolidated Balance Sheet	(2		)	(12		)	(6		)	(13		)
Balance at end of period	$	29		$	28		$	29		$	28

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.

	September 30, 2018
(in millions)	Total Fair Value			Level 1		Level 3
Derivative assets	$	4		$	4	$	—
Derivative liabilities	(153		)	—		(153		)
Net (liabilities) assets	$	(149	)	$	4	$	(153	)

	December 31, 2017
(in millions)	Total Fair Value			Level 1		Level 3
Other debt securities	$	1		$	1	$	—
Derivative assets	2			2		—
Total assets	3			3		—
Derivative liabilities	(142		)	—		(142		)
Net (liabilities) assets	$	(139	)	$	3	$	(142	)

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 September 30,						Nine Months Ended September 30,
(in millions)	2018			2017			2018			2017
Balance at beginning of period	$	(150	)	$	(145	)	$	(142	)	$	(187	)
Total (losses) gains and settlements	(3		)	22			(11		)	64
Balance at end of period	$	(153	)	$	(123	)	$	(153	)	$	(123	)

XML

Variable Interest Entities (Tables)

9 Months Ended

Sep. 30, 2018

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 and associated restricted receivables described above.

	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
(in millions)	CRC		DERF		DEPR		DEFR
Expiration date	December 2020		December 2020		February 2021		April 2021
Credit facility amount	$	325	$	450	$	300	$	225
Amounts borrowed at September 30, 2018	325		450		300		225
Amounts borrowed at December 31, 2017	325		450		300		225
Restricted Receivables at September 30, 2018	504		795		635		456
Restricted Receivables at December 31, 2017	545		640		459		317

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.

	September 30, 2018
	Duke Energy								Duke		Duke
	Pipeline		Commercial		Other				Energy		Energy
(in millions)	Investments(a)		Renewables		VIEs		Total		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—	$	—	$	56	$	94
Investments in equity method unconsolidated affiliates	729		190		47		966		—		—
Total assets	$	729	$	190	$	47	$	966	$	56	$	94
Other current liabilities	—		—		3		3		—		—
Deferred income taxes	14		—		—		14		—		—
Other noncurrent liabilities	—		—		11		11		—		—
Total liabilities	$	14	$	—	$	14	$	28	$	—	$	—
Net assets	$	715	$	190	$	33	$	938	$	56	$	94

(a) See Pipeline Investments table below for further details regarding Investments in equity method unconsolidated affiliates.

	December 31, 2017
	Duke Energy										Duke		Duke
	Pipeline			Commercial		Other					Energy		Energy
(in millions)	Investments			Renewables		VIEs		Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	—	$	—	$	—		$	87	$	106
Investments in equity method unconsolidated affiliates	697			180		42		919			—		—
Other noncurrent assets	17			—		—		17			—		—
Total assets	$	714		$	180	$	42	$	936		$	87	$	106
Taxes accrued	(29		)	—		—		(29		)	—		—
Other current liabilities	—			—		4		4			—		—
Deferred income taxes	42			—		—		42			—		—
Other noncurrent liabilities	—			—		12		12			—		—
Total liabilities	$	13		$	—	$	16	$	29		$	—	$	—
Net assets	$	701		$	180	$	26	$	907		$	87	$	106

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)	September 30, 2018		December 31, 2017
Receivables of VIEs	$	7	$	4
Regulatory Assets: Current	52		51
Current Assets: Other	14		40
Other Noncurrent Assets: Regulatory assets	1,055		1,091
Current Liabilities: Other	3		10
Current maturities of long-term debt	53		53
Long-Term Debt	1,111		1,164

Commercial 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)	September 30, 2018			December 31, 2017
Current Assets: Other	$	203		$	174
Property, plant and equipment, cost	4,025			3,923
Accumulated depreciation and amortization	(695		)	(591		)
Other Noncurrent Assets: Other	268			50
Current maturities of long-term debt	175			170
Long-Term Debt	1,604			1,700
Other Noncurrent Liabilities: Deferred income taxes	—			(148		)
Other Noncurrent Liabilities: Other	225			241

Pipeline Investments [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

The table below presents Duke Energy's ownership interest and investment balances in these joint ventures.

			VIE Investment Amount (in millions)
	Ownership		September 30,		December 31,
Entity Name	Interest		2018		2017
ACP	47	%	$	704	$	397
Sabal Trail(a)	7.5	%	—		219
Constitution(b)	24	%	25		81
Total			$	729	$	697

(a) At December 31, 2017, Sabal Trail was considered a VIE due to having insufficient equity to finance their own activities without subordinated financial support. However, Sabal Trail is now a fully operational, well capitalized entity. As a result, Sabal Trail has sufficient equity to finance its own activities, and therefore, is no longer considered a VIE. Duke Energy's investment in Sabal Trail was $112 million at September 30, 2018.

(b) During the nine months ended September 30, 2018, Duke Energy recorded an OTTI of $55 million related to Constitution within Equity in earnings of unconsolidated affiliates on Duke Energy's Condensed Consolidated Statements of Income. See Note 3 for additional information.

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
	2018		2017		2018		2017
Anticipated credit loss ratio	0.5	%	0.5	%	0.3	%	0.3	%
Discount rate	2.9	%	2.1	%	2.9	%	2.1	%
Receivable turnover rate	13.6	%	13.5	%	10.9	%	10.7	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Receivables sold	$	218	$	273	$	326	$	312
Less: Retained interests	56		87		94		106
Net receivables sold	$	162	$	186	$	232	$	206

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

	Duke Energy Ohio								Duke Energy Indiana
	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
(in millions)	2018		2017		2018		2017		2018		2017		2018		2017
Sales
Receivables sold	$	450	$	438	$	1,478	$	1,392	$	754	$	720	$	2,140	$	2,047
Loss recognized on sale	4		2		10		7		5		3		12		9
Cash flows
Cash proceeds from receivables sold	$	449	$	434	$	1,499	$	1,421	$	743	$	713	$	2,140	$	2,064
Collection fees received	—		1		1		1		—		—		1		1
Return received on retained interests	2		—		5		2		3		2		7		5

XML

Revenue (Tables)

9 Months Ended

Sep. 30, 2018

Revenue from Contract with Customer [Abstract]

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction

Estimated remaining performance obligations are as follows:

	Remaining Performance Obligations
(in millions)	2018		2019		2020		2021		2022		Thereafter		Total
Piedmont	$	18	$	71	$	70	$	65	$	64	$	462	$	750

Supplemental requirements contracts that include contracted blocks of energy and capacity at contractually fixed prices have the following estimated remaining performance obligations:

	Remaining Performance Obligations
(in millions)	2018		2019		2020		2021		2022		Thereafter		Total
Progress Energy	$	24	$	112	$	121	$	80	$	82	$	81	$	500
Duke Energy Progress	2		9		9		9		9		18		56
Duke Energy Florida	22		103		112		71		73		63		444
Duke Energy Indiana	2		9		10		5		—		—		26

Disaggregation of Revenue

Disaggregated revenues are presented as follows:

	Three Months Ended September 30, 2018
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	2,729	$	823	$	1,425	$	572	$	853	$	203	$	279	$	—
General	1,763		635		800		373		427		112		218		—
Industrial	835		352		246		177		69		33		202		—
Wholesale	589		132		372		335		37		3		81		—
Other revenues	225		109		134		90		44		20		29		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	6,141	$	2,051	$	2,977	$	1,547	$	1,430	$	371	$	809	$	—
Gas Utilities and Infrastructure
Residential	$	116	$	—	$	—	$	—	$	—	$	59	$	—	$	57
Commercial	66		—		—		—		—		20		—		46
Industrial	28		—		—		—		—		3		—		24
Power Generation	—		—		—		—		—		—		—		13
Other revenues	23		—		—		—		—		1		—		22
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	233	$	—	$	—	$	—	$	—	$	83	$	—	$	162
Commercial Renewables
Revenue from contracts with customers	$	61	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	16	$	—	$	—	$	—	$	—	$	12	$	—	$	—
Total revenue from contracts with customers	$	6,451	$	2,051	$	2,977	$	1,547	$	1,430	$	466	$	809	$	162
Other revenue sources(a)	$	177	$	39	$	68	$	35	$	32	$	3	$	10	$	10
Total revenues	$	6,628	$	2,090	$	3,045	$	1,582	$	1,462	$	469	$	819	$	172

	Nine Months Ended September 30, 2018
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	7,264	$	2,263	$	3,636	$	1,540	$	2,096	$	564	$	802	$	—
General	4,619		1,608		2,109		972		1,137		318		584		—
Industrial	2,235		893		678		481		197		96		567		—
Wholesale	1,737		366		1,140		1,019		121		5		226		—
Other revenues	558		261		359		222		137		57		66		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	16,413	$	5,391	$	7,922	$	4,234	$	3,688	$	1,040	$	2,245	$	—
Gas Utilities and Infrastructure
Residential	$	682	$	—	$	—	$	—	$	—	$	236	$	—	$	446
Commercial	354		—		—		—		—		97		—		257
Industrial	107		—		—		—		—		13		—		93
Power Generation	—		—		—		—		—		—		—		40
Other revenues	101		—		—		—		—		13		—		88
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	1,244	$	—	$	—	$	—	$	—	$	359	$	—	$	924
Commercial Renewables
Revenue from contracts with customers	$	141	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	47	$	—	$	—	$	—	$	—	$	36	$	—	$	—
Total Revenue from contracts with customers	$	17,845	$	5,391	$	7,922	$	4,234	$	3,688	$	1,435	$	2,245	$	924
Other revenue sources(a)	$	561	$	134	$	197	$	99	$	92	$	17	$	43	$	16
Total revenues	$	18,406	$	5,525	$	8,119	$	4,333	$	3,780	$	1,452	$	2,288	$	940

(a) Other revenue sources include revenues from leases, derivatives and alternative revenue programs that are not considered revenues from contracts with customers. Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over or under collection of related revenues.

Schedule Of Unbilled Revenues With Restricted Receivables

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

(in millions)	September 30, 2018		December 31, 2017
Duke Energy	$	802	$	944
Duke Energy Carolinas	278		342
Progress Energy	283		228
Duke Energy Progress	163		143
Duke Energy Florida	120		85
Duke Energy Ohio	2		4
Duke Energy Indiana	25		21
Piedmont	3		86

These receivables for unbilled revenues are shown in the table below.

(in millions)	September 30, 2018		December 31, 2017
Duke Energy Ohio	$	68	$	104
Duke Energy Indiana	121		132

XML

Common Stock (Tables)

9 Months Ended

Sep. 30, 2018

Equity [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 September 30,				Nine Months Ended September 30,
(in millions, except per-share amounts)	2018		2017		2018		2017
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$	1,077	$	954	$	2,199	$	2,356
Weighted average shares outstanding – basic	713		700		705		700
Equity Forwards	1		—		1		—
Weighted average shares outstanding – diluted	714		700		706		700
Earnings per share from continuing operations attributable to Duke Energy common stockholders
Basic	$	1.51	$	1.36	$	3.12	$	3.37
Diluted	$	1.51	$	1.36	$	3.11	$	3.37
Potentially dilutive items excluded from the calculation(a)	2		2		2		2
Dividends declared per common share	$	0.9275	$	0.89	$	2.7075	$	2.60

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

XML

Stock-Based Compensation (Tables)

9 Months Ended

Sep. 30, 2018

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Schedule Of Stock-Based Compensation Expense

The following table presents information related to Duke Energy's stock–based compensation.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2018		2017		2018		2017
Restricted stock unit awards	$	10	$	10	$	32	$	30
Performance awards	13		7		27		20
Pretax stock-based compensation cost	$	23	$	17	$	59	$	50
Stock-based compensation cost capitalized	$	1	$	1	$	3	$	2
Stock-based compensation expense	$	22	$	16	$	56	$	48
Tax benefit associated with stock-based compensation expense	$	5	$	6	$	13	$	18

XML

Employee Benefit Plans (Tables)

9 Months Ended

Sep. 30, 2018

Defined Benefit Plan Disclosure [Line Items]

Defined Contribution Plan Disclosures

The following table includes 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 September 30,
2018	$	49	$	15	$	13	$	9	$	4	$	—	$	3	$	4
2017	43		14		12		9		4		1		2		2
Nine Months Ended September 30,
2018	$	167	$	53	$	45	$	31	$	14	$	2	$	8	$	10
2017	147		49		42		30		13		3		7		5

Qualified Pension Plan [Member]

Defined Benefit Plan Disclosure [Line Items]

Schedule of Defined Benefit Plans Disclosures

The following table presents contributions made by the Duke Energy Registrants to their qualified defined benefit pension plans during the nine months ended September 30, 2018.

			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana
Contributions	$	141	$	46	$	45	$	25	$	20	$	8

Components of Net Periodic Pension Costs

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

	Three Months Ended September 30, 2018
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	47		$	15		$	13		$	7		$	5		$	2		$	2		$	2
Interest cost on projected benefit obligation	74			18			24			10			13			4			6			3
Expected return on plan assets	(140		)	(37		)	(45		)	(21		)	(23		)	(7		)	(10		)	(6		)
Amortization of actuarial loss	33			7			11			6			6			1			2			3
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(3		)
Net periodic pension costs	$	6		$	1		$	2		$	2		$	1		$	—		$	—		$	(1	)

	Three Months Ended September 30, 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			4			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	)	$	1		$	2

	Nine Months Ended September 30, 2018
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	137		$	45		$	39		$	22		$	16		$	4		$	7		$	6
Interest cost on projected benefit obligation	224			54			70			31			38			13			18			9
Expected return on plan assets	(420		)	(111		)	(133		)	(63		)	(69		)	(21		)	(31		)	(18		)
Amortization of actuarial loss	99			21			33			16			18			3			6			9
Amortization of prior service credit	(24		)	(6		)	(3		)	(1		)	(1		)	—			—			(9		)
Net periodic pension costs	$	16		$	3		$	6		$	5		$	2		$	(1	)	$	—		$	(3	)

	Nine Months Ended September 30, 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	$	120		$	36		$	36		$	18		$	15		$	3		$	6		$	9
Interest cost on projected benefit obligation	246			60			75			36			39			14			21			9
Expected return on plan assets	(408		)	(106		)	(129		)	(63		)	(63		)	(21		)	(33		)	(18		)
Amortization of actuarial loss	108			24			42			18			21			3			9			9
Amortization of prior service credit	(18		)	(6		)	(3		)	—			—			—			—			(3		)
Other	6			—			3			1			—			—			—			1
Net periodic pension costs	$	54		$	8		$	24		$	10		$	12		$	(1	)	$	3		$	7

Non-Qualified Pension Plan [Member]

Defined Benefit Plan Disclosure [Line Items]

Components of Net Periodic Pension Costs

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

	Three Months Ended September 30, 2018
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	3	$	—	$	1	$	—	$	—
Amortization of actuarial loss	2		—		—		—		—
Net periodic pension costs	$	5	$	—	$	1	$	—	$	—

	Three Months Ended September 30, 2017
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	4	$	—	$	1	$	1	$	1
Amortization of actuarial loss	2		—		1		—		—
Net periodic pension costs	$	6	$	—	$	2	$	1	$	1

	Nine Months Ended September 30, 2018
				Duke				Duke		Duke
	Duke			Energy		Progress		Energy		Energy
(in millions)	Energy			Carolinas		Energy		Progress		Florida
Service cost	$	1		$	1	$	—	$	—	$	—
Interest cost on projected benefit obligation	9			—		3		1		1
Amortization of actuarial loss	6			—		—		—		—
Amortization of prior service (credit) cost	(1		)	—		1		—		—
Net periodic pension costs	$	15		$	1	$	4	$	1	$	1

	Nine Months Ended September 30, 2017
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida
Interest cost on projected benefit obligation	$	10	$	1	$	3	$	2	$	2
Amortization of actuarial loss	6		—		3		—		—
Net periodic pension costs	$	16	$	1	$	6	$	2	$	2

Other Post-Retirement Benefit Plans [Member]

Defined Benefit Plan Disclosure [Line Items]

Components of Net Periodic Pension Costs

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

	Three Months Ended September 30, 2018
				Duke						Duke		Duke			Duke		Duke
	Duke			Energy			Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress		Florida			Ohio		Indiana		Piedmont
Service cost	$	2		$	—		$	—		$	—	$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	7			2			3			2		1			—		1		—
Expected return on plan assets	(4		)	(2		)	—			—		—			—		—		—
Amortization of actuarial loss	2			1			—			—		—			—		1		—
Amortization of prior service credit	(5		)	(1		)	(2		)	—		(1		)	—		—		—
Net periodic other post-retirement benefit costs	$	2		$	—		$	1		$	2	$	—		$	—	$	2	$	—

	Three Months Ended September 30, 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			—		1		—
Expected return on plan assets	(3		)	(2		)	—			—			—			—		—		—
Amortization of actuarial loss	2			—			5			3			2			—		—		—
Amortization of prior service credit	(29		)	(2		)	(21		)	(14		)	(8		)	—		—		—
Net periodic other post-retirement benefit costs	$	(20	)	$	(2	)	$	(12	)	$	(9	)	$	(4	)	$	—	$	1	$	—

	Nine Months Ended September 30, 2018
				Duke						Duke		Duke			Duke		Duke
	Duke			Energy			Progress			Energy		Energy			Energy		Energy
(in millions)	Energy			Carolinas			Energy			Progress		Florida			Ohio		Indiana		Piedmont
Service cost	$	5		$	1		$	—		$	—	$	—		$	—	$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	21			5			9			5		4			1		3		—
Expected return on plan assets	(10		)	(6		)	—			—		—			—		—		—
Amortization of actuarial loss	5			2			1			—		—			—		3		—
Amortization of prior service credit	(15		)	(3		)	(6		)	—		(4		)	—		—		(1		)
Net periodic other post-retirement benefit costs	$	6		$	(1	)	$	4		$	5	$	—		$	1	$	6	$	(1	)

	Nine Months Ended September 30, 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	$	3		$	—		$	—		$	—		$	—		$	—		$	—	$	—
Interest cost on accumulated post-retirement benefit obligation	27			6			11			6			6			—			1		—
Expected return on plan assets	(10		)	(6		)	—			—			—			—			—		—
Amortization of actuarial loss (gain)	6			(2		)	15			9			6			(1		)	—		—
Amortization of prior service credit	(87		)	(6		)	(63		)	(41		)	(23		)	—			—		—
Net periodic other post-retirement benefit costs	$	(61	)	$	(8	)	$	(37	)	$	(26	)	$	(11	)	$	(1	)	$	1	$	—

XML

Income Taxes (Tables)

9 Months Ended

Sep. 30, 2018

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				Nine Months Ended
	September 30,				September 30,
	2018		2017		2018		2017
Duke Energy	13.7	%	27.6	%	17.0	%	30.4	%
Duke Energy Carolinas	22.6	%	32.9	%	22.3	%	34.1	%
Progress Energy	18.8	%	29.1	%	17.0	%	31.9	%
Duke Energy Progress	20.6	%	31.7	%	18.4	%	32.4	%
Duke Energy Florida	15.0	%	34.8	%	16.3	%	36.1	%
Duke Energy Ohio	16.0	%	33.3	%	16.0	%	34.4	%
Duke Energy Indiana	22.7	%	38.3	%	24.7	%	39.0	%
Piedmont	34.4	%	47.6	%	20.6	%	36.1	%

XML

Organization and Basis of Presentation (Other Current Assets) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Current Assets, Other [Member]
Organization And Basis Of Presentation [Line Items]
Tax receivable	$ 655	$ 260

XML

Organization and Basis of Presentation (Schedule of Cash and Cash Equivalents) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016
Current Assets
Cash and cash equivalents	$ 303	$ 358
Other	139	138
Other Noncurrent Assets
Other	7	9
Total cash, cash equivalents and restricted cash	449	505	$ 427	$ 541
Progress Energy [Member]
Current Assets
Cash and cash equivalents	43	40
Other	14	40
Other Noncurrent Assets
Other	6	7
Total cash, cash equivalents and restricted cash	63	87	56	110
Duke Energy Florida [Member]
Current Assets
Cash and cash equivalents	20	13
Other	14	40
Other Noncurrent Assets
Total cash, cash equivalents and restricted cash	$ 34	$ 53	$ 28	$ 69

XML

Organization and Basis of Presentation (Schedule of Inventory) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Public Utilities, Inventory [Line Items]
Inventory	$ 3,140	$ 3,250
Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	2,283	2,293
Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	515	603
Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	342	354
Duke Energy Carolinas [Member]
Public Utilities, Inventory [Line Items]
Inventory	976	971
Duke Energy Carolinas [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	758	744
Duke Energy Carolinas [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	176	192
Duke Energy Carolinas [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	42	35
Progress Energy [Member]
Public Utilities, Inventory [Line Items]
Inventory	1,473	1,592
Progress Energy [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	1,071	1,118
Progress Energy [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	187	255
Progress Energy [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	215	219
Duke Energy Progress [Member]
Public Utilities, Inventory [Line Items]
Inventory	956	1,017
Duke Energy Progress [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	748	774
Duke Energy Progress [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	99	139
Duke Energy Progress [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	109	104
Duke Energy Florida [Member]
Public Utilities, Inventory [Line Items]
Inventory	517	574
Duke Energy Florida [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	323	343
Duke Energy Florida [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	88	116
Duke Energy Florida [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	106	115
Duke Energy Ohio [Member]
Public Utilities, Inventory [Line Items]
Inventory	135	133
Duke Energy Ohio [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	87	82
Duke Energy Ohio [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	14	17
Duke Energy Ohio [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	34	34
Duke Energy Indiana [Member]
Public Utilities, Inventory [Line Items]
Inventory	434	450
Duke Energy Indiana [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	294	309
Duke Energy Indiana [Member] | Coal [Member]
Public Utilities, Inventory [Line Items]
Inventory	138	139
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	51	66
Piedmont Natural Gas [Member] | Materials and supplies [Member]
Public Utilities, Inventory [Line Items]
Inventory	1	2
Piedmont Natural Gas [Member] | Natural gas, oil and other fuel [Member]
Public Utilities, Inventory [Line Items]
Inventory	$ 50	$ 64

XML

Organization and Basis of Presentation (Schedule of Excise Taxes) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	$ 114	$ 107	$ 308	$ 289
Duke Energy Carolinas [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	10	9	27	27
Progress Energy [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	71	67	181	168
Duke Energy Progress [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	5	5	15	14
Duke Energy Florida [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	66	62	166	154
Duke Energy Ohio [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	26	24	81	75
Duke Energy Indiana [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	6	6	17	16
Piedmont Natural Gas [Member]
Organization And Basis Of Presentation [Line Items]
Excise taxes collected	$ 1	$ 1	$ 2	$ 3

XML

Organization and Basis of Presentation (New Accounting Standards) (Details) - Accounting Standards Update 2017-07 [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating income and expenses, net [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New accounting pronouncement, quantified affect	$ 156	$ 131	$ 96
Nonoperating income and expenses, net [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New accounting pronouncement, quantified affect	$ 156	$ 131	$ 96

XML

Business Segments (Narrative) (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018 USD ($)	Sep. 30, 2017 USD ($)	Sep. 30, 2018 USD ($) segment	Sep. 30, 2017 USD ($)
Segment Reporting Information [Line Items]
Pretax loss on disposal	$ (10)	$ (6)	$ 87	$ (24)
Operation, maintenance and other	1,584	1,476	4,592	4,385
Duke Energy Ohio [Member]
Segment Reporting Information [Line Items]
Pretax loss on disposal		(1)	106	(1)
Operation, maintenance and other	$ 76	$ 125	$ 337	$ 388
Number of reportable segments | segment			2
Beckjord [Member]
Segment Reporting Information [Line Items]
Pretax loss on disposal			$ 106
Operation, maintenance and other			$ 1
National Methanol Company [Member]
Segment Reporting Information [Line Items]
Ownership percentage	17.50%		17.50%

XML

Business Segments (Business Segment Data) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Segment Reporting Information [Line Items]
Operating revenues	$ 6,628	$ 6,482	$ 18,406	$ 17,766
Segment income (loss)	1,078	956	2,203	2,360
Add back noncontrolling interests	(16)	1	(12)	5
Income (Loss) From Discontinued Operations, net of tax	4	(2)	(1)	(4)
Net Income	1,066	955	2,190	2,361
Net income (attributable to parent)	1,082	954	2,202	2,356
Segment assets	143,165		143,165		$ 137,914
Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	6,253	6,122	16,783	16,211
Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	232	249	1,229	1,175
Commercial Renewables [Member]
Segment Reporting Information [Line Items]
Operating revenues	127	95	347	333
Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	6,612	6,466	18,359	17,719
Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	16	16	47	47
Operating Segments [Member]
Segment Reporting Information [Line Items]
Segment income (loss)	1,122	990	2,649	2,565
Segment assets	139,865		139,865
Operating Segments [Member] | Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	6,260	6,129	16,806	16,234
Segment income (loss)	1,167	1,020	2,492	2,384
Segment assets	123,847		123,847
Operating Segments [Member] | Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	256	272	1,301	1,243
Segment income (loss)	17	19	161	179
Segment assets	11,806		11,806
Operating Segments [Member] | Commercial Renewables [Member]
Segment Reporting Information [Line Items]
Operating revenues	127	95	347	333
Segment income (loss)	(62)	(49)	(4)	2
Segment assets	4,212		4,212
Operating Segments [Member] | Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	6,643	6,496	18,454	17,810
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	(49)	(49)	(149)	(147)
Segment assets	185		185
Intersegment Eliminations [Member] | Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	7	7	23	23
Intersegment Eliminations [Member] | Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	24	23	72	68
Intersegment Eliminations [Member] | Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	31	30	95	91
Intersegment Eliminations [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	18	19	54	56
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Segment income (loss)	(44)	(34)	(446)	(205)
Segment assets	3,115		3,115
Corporate, Non-Segment [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	34	35	101	103
Duke Energy Ohio [Member]
Segment Reporting Information [Line Items]
Operating revenues	469	471	1,452	1,426
Segment income (loss)	100	56	121	128
Income (Loss) From Discontinued Operations, net of tax		(1)		(1)
Net Income				127
Net income (attributable to parent)	100	55	121	127
Segment assets	8,296		8,296		$ 7,875
Duke Energy Ohio [Member] | Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	373	371	1,055	1,036
Duke Energy Ohio [Member] | Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Operating revenues	84	90	361	360
Duke Energy Ohio [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	457	461	1,416	1,396
Segment income (loss)	97	64	221	152
Segment assets	8,259		8,259
Duke Energy Ohio [Member] | Operating Segments [Member] | Electric Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Segment income (loss)	85	50	157	96
Segment assets	5,484		5,484
Duke Energy Ohio [Member] | Operating Segments [Member] | Gas Utilities and Infrastructure [Member]
Segment Reporting Information [Line Items]
Segment income (loss)	12	14	64	56
Segment assets	2,775		2,775
Duke Energy Ohio [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Segment assets	(2)		(2)
Duke Energy Ohio [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	12	10	36	30
Segment income (loss)	3	$ (8)	(100)	$ (24)
Segment assets	$ 39		$ 39

XML

Regulatory Matters (Narrative) (Details) customer in Millions, $ in Millions			1 Months Ended						3 Months Ended		9 Months Ended		12 Months Ended
	Oct. 03, 2018	Jul. 31, 2018 USD ($)	Sep. 30, 2018 USD ($) customer	Jul. 31, 2018 USD ($)	May 31, 2018 USD ($)	Feb. 28, 2018 USD ($)	Jun. 30, 2017 USD ($)	Dec. 31, 2015 USD ($)	Sep. 30, 2018 USD ($) customer	Sep. 30, 2017 USD ($)	Sep. 30, 2018 USD ($) customer MW	Sep. 30, 2017 USD ($)	Dec. 31, 2017 USD ($)	Jun. 30, 2018 USD ($)
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other									$ 1,584.0	$ 1,476.0	$ 4,592.0	$ 4,385.0
Impairment and related charges									124.0	207.0	339.0	216.0
Loss before income taxes									(1,230.0)	(1,321.0)	(2,640.0)	(3,400.0)
Accretion expense											319.0
Public utilities, property, plant and equipment, net			$ 89,865.0						89,865.0		89,865.0		$ 86,391.0
Regulated operating revenue, electric, non-nuclear									6,216.0	6,091.0	$ 16,678.0	16,122.0
Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW											1,631
Public utilities, property, plant and equipment, net			$ 355.0						$ 355.0		$ 355.0
Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			47.00%						47.00%		47.00%
Long-term purchase commitment, period											20 years
Sabal Trail Transmission Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			$ 3,200.0						$ 3,200.0		$ 3,200.0
Joint owner ownership percentage			7.50%						7.50%		7.50%
Long-term purchase commitment, period											25 years
Constitution Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			24.00%						24.00%		24.00%
Estimated contributions			$ 229.0						$ 229.0		$ 229.0
Equity method investment, OTTI											$ 55.0
Dominion Resources [Member] | Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			48.00%						48.00%		48.00%
Southern Company Gas [Member] | Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			5.00%						5.00%		5.00%
Spectra Energy Partners [Member] | Sabal Trail Transmission Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			50.00%						50.00%		50.00%
NextEra Energy [Member] | Sabal Trail Transmission Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			42.50%						42.50%		42.50%
Williams Partners L.P. [Member] | Constitution Pipeline [Member]
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage			41.00%						41.00%		41.00%
Minimum [Member] | Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			$ 6,500.0						$ 6,500.0		$ 6,500.0			$ 6,000.0
Maximum [Member] | Atlantic Coast Pipeline (ACP) [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			$ 7,000.0						$ 7,000.0		$ 7,000.0			$ 6,500.0
Hurricane Florence Storm Damage [Member]
Public Utilities, General Disclosures [Line Items]
Customers experiencing outages | customer			1.8						1.8		1.8
Operation, maintenance and other			$ 455.0
Estimated capital cost			85.0						$ 85.0		$ 85.0
FERC 494 Refund of Regional Transmission Enhancement Projects [Member] | FERC [Member]
Public Utilities, General Disclosures [Line Items]
Customer refundable fees, refund payments											47.0
Progress Energy Merger FERC Mitigation [Member] | FERC [Member]
Public Utilities, General Disclosures [Line Items]
Penalty assessed											3.5
Duke Energy Carolinas [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other									514.0	494.0	1,464.0	1,472.0
Impairment and related charges									1.0		191.0
Loss before income taxes									(641.0)	(695.0)	(1,204.0)	(1,531.0)
Accretion expense											133.0
Public utilities, property, plant and equipment, net			28,550.0						28,550.0		28,550.0		27,876.0
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			$ 650.0						$ 650.0		650.0
Approved rate increase (decrease), amount											$ 600.0
Joint owner ownership percentage			13.00%						13.00%		13.00%
Duke Energy Carolinas [Member] | Hurricane Florence Storm Damage [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other			$ 35.0
Estimated capital cost			10.0						$ 10.0		$ 10.0
Duke Energy Carolinas [Member] | 2017 North Carolina Rate Case [Member] | NCUC [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other						$ 4.0
Requested rate increase (decrease), amount											$ 647.0
Requested rate increase, percentage											13.60%
Requested return on equity, percent											9.90%
Public utilities, requested equity capital structure, percentage											52.00%
Public utilities, requested debt capital structure, percentage											48.00%
Penalty assessed											$ 70.0
Estimated future coal ash costs			201.0						201.0		201.0
Utilities operating expenses, impairments									150.0
Loss before income taxes											14.0
Duke Energy Carolinas [Member] | 2017 North Carolina Rate Case [Member] | NCUC [Member] | Asset retirement obligations - coal ash [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory assets			554.0						554.0		$ 554.0
Regulatory asset, amortization period											5 years
Duke Energy Carolinas [Member] | 2017 North Carolina Rate Case [Member] | NCUC [Member] | Deferred Project Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory assets			347.0						347.0		$ 347.0
Regulatory asset, amortization period											12 years
Duke Energy Carolinas [Member] | 2017 North Carolina Rate Case [Member] | William State Lee Iii Nuclear Station [Member] | NCUC [Member]
Public Utilities, General Disclosures [Line Items]
Utilities operating expenses, impairments											$ 29.0
Duke Energy Carolinas [Member] | FERC Formula Rate Matter [Member] | FERC [Member]
Public Utilities, General Disclosures [Line Items]
Customer refundable fees, refund payments											25.0
Duke Energy Carolinas [Member] | 2018 Sale of Hydro Plants [Member] | NCUC [Member]
Public Utilities, General Disclosures [Line Items]
Estimated loss on asset sale					$ 40.0
Duke Energy Carolinas [Member] | 2018 PSCSC Petitions [Member] | PSCSC [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount				$ 33.0
Progress Energy [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other									680.0	588.0	1,913.0	1,697.0
Impairment and related charges									1.0	135.0	34.0	137.0
Loss before income taxes									(500.0)	(484.0)	(1,096.0)	(1,205.0)
Accretion expense											168.0
Public utilities, property, plant and equipment, net			33,558.0						33,558.0		33,558.0		31,887.0
Duke Energy Progress [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other									431.0	365.0	1,187.0	1,069.0
Impairment and related charges											33.0
Loss before income taxes									(272.0)	(360.0)	(652.0)	(809.0)
Accretion expense											145.0
Public utilities, property, plant and equipment, net			19,995.0						19,995.0		$ 19,995.0		19,101.0
Duke Energy Progress [Member] | Asheville Plant [Member] | Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW											376
Public utilities, property, plant and equipment, net			352.0						352.0		$ 352.0		385.0
Duke Energy Progress [Member] | Hurricane Florence Storm Damage [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other			420.0
Estimated capital cost			75.0						75.0		75.0
Duke Energy Progress [Member] | 2017 North Carolina Rate Case [Member] | NCUC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											$ 477.0
Requested rate increase, percentage											14.90%
Requested return on equity, percent											9.90%
Public utilities, requested equity capital structure, percentage											52.00%
Public utilities, requested debt capital structure, percentage											48.00%
Penalty assessed											$ 30.0
Estimated future coal ash costs			129.0						129.0		129.0
Utilities operating expenses, impairments													25.0
Requested rate increase (decrease), amended amount											$ 420.0
Requested rate increase (decrease) amended, percentage											13.00%
Estimated storm costs - capital and operation maintenance			116.0						116.0		$ 116.0
Loss before income taxes											68.0
Duke Energy Progress [Member] | 2017 North Carolina Rate Case [Member] | NCUC [Member] | Asset retirement obligations - coal ash [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory assets			234.0						234.0		$ 234.0
Regulatory asset, amortization period											5 years
Excluded deferred coal ash costs			9.5						9.5		$ 9.5
Duke Energy Progress [Member] | 2017 North Carolina Rate Case [Member] | NCUC [Member] | Storm Costs [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											$ 80.0
Regulatory asset, amortization period											5 years
Approved rate increase (decrease), amount											$ 51.0
Duke Energy Progress [Member] | 2016 South Carolina Rate Case Settlement [Member] | PSCSC [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount											$ 56.0
Accretion expense													18.5
Approved return on equity percentage											10.10%
Duke Energy Progress [Member] | 2016 South Carolina Rate Case Settlement Year 1 Increase [Member] | PSCSC [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount											$ 38.0
Duke Energy Progress [Member] | 2016 South Carolina Rate Case Settlement Year 2 Increase [Member] | PSCSC [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount											18.5
Duke Energy Progress [Member] | Western Carolinas Modernization Plan [Member] | NCUC [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost			893.0						893.0		$ 893.0
Regulatory asset, amortization period											10 years
Duke Energy Progress [Member] | Shearon Harris Nuclear Expansion [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory assets													47.0
Regulatory asset, amortization period											8 years
Wholesale debt return amortization period											15 years
Duke Energy Progress [Member] | 2018 PSCSC Petitions [Member] | PSCSC [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount				$ 20.0
Duke Energy Progress [Member] | FERC Form 1 Reporting Matter [Member] | FERC [Member]
Public Utilities, General Disclosures [Line Items]
Customer refundable fees, refund payments											$ 14.0
Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other									245.0	220.0	719.0	623.0
Impairment and related charges									1.0	135.0	1.0	137.0
Loss before income taxes									(286.0)	(184.0)	(614.0)	(576.0)
Accretion expense											23.0
Public utilities, property, plant and equipment, net			13,561.0						13,561.0		13,561.0		12,783.0
Duke Energy Florida [Member] | Storm Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory assets			258.0						258.0		258.0
Duke Energy Florida [Member] | Citrus County Station [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost of new utility plant, including AFUDC			$ 1,500.0						$ 1,500.0		$ 1,500.0
Duke Energy Florida [Member] | Storm Restoration Cost Recovery [Member] | FPSC [Member]
Public Utilities, General Disclosures [Line Items]
Customers experiencing outages | customer			1.3						1.3		1.3
Estimated storm costs - capital and operation maintenance			$ 510.0						$ 510.0		$ 510.0
Duke Energy Florida [Member] | Federal Tax Act Impacts [Member] | FPSC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											(151.0)
Tax act annual savings											84.0
Tax act excess deferred tax amortization requested rate decrease, amount											67.0
Duke Energy Florida [Member] | Federal Tax Act Impacts Revenue Requirement [Member] | FPSC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											201.0
Duke Energy Florida [Member] | Federal Tax Act Impacts Revenue Requirement [Member] | FPSC [Member] | Storm Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory assets			151.0						151.0		151.0
Duke Energy Florida [Member] | Federal Tax Act Impacts Revenue Requirement [Member] | Crystal River Units 3 and 4 [Member] | FPSC [Member]
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net			50.0						50.0		50.0
Duke Energy Florida [Member] | Citrus County Combined Cycle Facility [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											200.0
Duke Energy Florida [Member] | 2017 Second Revised and Restated Stipulation and Settlement Agreement [Member] | Hamilton Project [Member] | FPSC [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount		$ (15.2)
Duke Energy Florida [Member] | 2017 Second Revised and Restated Stipulation and Settlement Agreement [Member] | Columbia Project [Member] | FPSC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ (14.0)
Duke Energy Ohio [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other									76.0	125.0	337.0	388.0
Impairment and related charges												1.0
Loss before income taxes									(119.0)	(84.0)	(144.0)	(195.0)
Accretion expense											3.0
Public utilities, property, plant and equipment, net			6,493.0						6,493.0		6,493.0		6,041.0
Regulated operating revenue, electric, non-nuclear									373.0	371.0	1,055.0	1,036.0
Duke Energy Ohio [Member] | 2017 Ohio Electric Base Rate Case [Member] | PUCO [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											$ 15.0
Requested return on equity, percent											10.40%
Public utilities, requested equity capital structure, percentage											50.75%
Public utilities, requested debt capital structure, percentage											49.25%
Approved rate increase (decrease), amount											$ (20.0)
Requested rate increase (decrease), amended amount											$ (19.0)
Requested rate increase (decrease) amended, percentage											9.84%
Duke Energy Ohio [Member] | 2017 Ohio Electric Base Rate Case [Member] | PUCO [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											$ (18.0)
Requested return on equity, percent											9.22%
Duke Energy Ohio [Member] | 2017 Ohio Electric Base Rate Case [Member] | PUCO [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											$ (29.0)
Requested return on equity, percent											10.24%
Requested rider revenue increase											$ 10.0
Duke Energy Ohio [Member] | Energy Efficiency Cost Recovery [Member] | PUCO [Member]
Public Utilities, General Disclosures [Line Items]
Regulated operating revenue, electric, non-nuclear								$ 20.0
Duke Energy Ohio [Member] | Energy Efficiency Cost Recovery [Member] | PUCO [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount											38.0
Approved rate increase (decrease), one-time waiver amount											56.0
Duke Energy Ohio [Member] | Natural Gas Pipeline Extension [Member] | OPSB [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost excluding AFUDC			163.0						163.0		163.0
Duke Energy Ohio [Member] | Natural Gas Pipeline Extension [Member] | OPSB [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated capital cost excluding AFUDC			245.0						245.0		245.0
Duke Energy Ohio [Member] | Duke Energy Kentucky Electric Rate Case [Member] | KPSC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											$ 49.0
Requested rate increase, percentage											15.00%
Approved rate increase (decrease), amount											$ 8.4
Requested rate increase (decrease), amended amount											$ (30.1)
Requested rate increase (decrease) amended, percentage											9.00%
Approved return on equity percentage											9.725%
Public utilities, approved equity capital structure, percentage											49.00%
Total allocable capitalization			650.0						650.0		$ 650.0
Incremental rider revenue											13.0
Duke Energy Ohio [Member] | Duke Energy Kentucky Gas Base Rate Case [Member] | KPSC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											$ 10.5
Requested rate increase, percentage											11.10%
Requested rate increase (decrease), amended amount											$ (5.2)
Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other									198.0	177.0	576.0	546.0
Impairment and related charges									30.0		30.0
Loss before income taxes									(154.0)	(196.0)	(421.0)	(521.0)
Accretion expense											22.0
Public utilities, property, plant and equipment, net			10,467.0						10,467.0		10,467.0		10,286.0
Duke Energy Indiana [Member] | Benton County Wind Farm Dispute [Member]
Public Utilities, General Disclosures [Line Items]
Litigation settlement, amount awarded to other party							$ 29.0
Duke Energy Indiana [Member] | Edwardsport Integrated Gasification Combined Cycle Plant [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount											(10.0)
Impairment and related charges									32.0
Decrease in regulatory assets											$ 30.0
Duke Energy Indiana [Member] | FERC Transmission Rates [Member] | FERC [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage											12.38%
Approved return on equity percentage adder											0.50%
Duke Energy Indiana [Member] | FERC Complaint [Member] | FERC [Member]
Public Utilities, General Disclosures [Line Items]
Requested return on equity, percent											8.67%
Duke Energy Indiana [Member] | FERC Complaint 1 [Member] | FERC [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage											10.32%
Duke Energy Indiana [Member] | FERC Complaint 2 [Member] | FERC [Member]
Public Utilities, General Disclosures [Line Items]
Requested return on equity, percent											9.70%
Duke Energy Indiana [Member] | Federal Tax Act Impacts Tranche 1 [Member] | IURC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											$ (7.0)
Duke Energy Indiana [Member] | Federal Tax Act Impacts Tranche 2 [Member] | IURC [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount											(35.0)
Piedmont Natural Gas [Member]
Public Utilities, General Disclosures [Line Items]
Operation, maintenance and other									85.0	73.0	252.0	226.0
Impairment and related charges												7.0
Loss before income taxes									32.0	$ 21.0	(102.0)	$ (119.0)
Public utilities, property, plant and equipment, net			5,712.0						5,712.0		5,712.0		$ 5,246.0
Piedmont Natural Gas [Member] | NCUC IMR Petition filed October 2018 [Member] | NCUC [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount									(9.5)
Piedmont Natural Gas [Member] | NCUC IMR Petition filed May 2018 [Member] | NCUC [Member]
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount									(5.7)
Storm Costs [Member] | Duke Energy Florida [Member] | Storm Restoration Cost Recovery [Member] | FPSC [Member]
Public Utilities, General Disclosures [Line Items]
Allowed storm allowance			$ 132.0						$ 132.0		$ 132.0
Subsequent Event [Member] | Piedmont Natural Gas [Member] | South Carolina Rate Stabilization Adjustment Filing [Member] | PSCSC [Member]
Public Utilities, General Disclosures [Line Items]
Approved return on equity percentage	10.20%

XML

Regulatory Matters (Schedule of Net Carrying Value Of Facilities and Megawatt Capacity) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018 USD ($) MW	Dec. 31, 2017 USD ($)
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net	$ 89,865	$ 86,391
Duke Energy Carolinas [Member]
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net	28,550	27,876
Progress Energy [Member]
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net	33,558	31,887
Duke Energy Florida [Member]
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net	13,561	12,783
Duke Energy Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net	$ 10,467	$ 10,286
Generation Facilities To Be Retired [Member]
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	1,631
Public utilities, property, plant and equipment, net	$ 355
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	$ 132
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	766
Public utilities, property, plant and equipment, net	$ 100
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	766
Public utilities, property, plant and equipment, net	$ 100
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	$ 123

XML

Commitments and Contingencies (Narrative) (Details)	1 Months Ended	9 Months Ended
	Jul. 31, 2018 USD ($)	Sep. 30, 2018 USD ($) plant claim T	Dec. 31, 2017 USD ($)
Valuation and Qualifying Accounts [Abstract]
Loss contingency accrual		$ 63,000,000	$ 88,000,000
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
Groundwater Contamination Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Goodwill payment		$ 5,000
Water bill stipend period		25 years
Duke Energy Carolinas [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency accrual		$ 11,000,000	30,000,000
Duke Energy Carolinas [Member] | Groundwater Contamination Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency accrual		4,000,000
Duke Energy Carolinas [Member] | Asbestos-related Injuries and Damages Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Asbestos-related injuries and damages reserves		461,000,000	489,000,000
Reinsurance retention policy, excess retention, amount reinsured		764,000,000
Probable insurance recoveries		$ 553,000,000	585,000,000
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 | claim		160
Asbestos-related injuries and damages reserves		$ 43,000,000
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 | claim		63
Asbestos-related injuries and damages reserves		$ 19,000,000
Progress Energy [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency accrual		50,000,000	55,000,000
Duke Energy Progress [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency accrual		11,000,000	13,000,000
Duke Energy Progress [Member] | Groundwater Contamination Claims [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency accrual		2,000,000
Duke Energy Progress [Member] | Spent Nuclear Fuels [Member]
Valuation and Qualifying Accounts [Abstract]
Gain contingency, unrecorded amount			48,000,000
Litigation settlement, amount awarded from other party		$ 48,000,000
Duke Energy Progress [Member] | Gypsum Supply Agreements [Member]
Valuation and Qualifying Accounts [Abstract]
Minimum amount of gypsum to be supplied | T		50,000
Estimate of possible losses		$ 90,000,000
Duke Energy Florida [Member]
Valuation and Qualifying Accounts [Abstract]
Loss contingency accrual		23,000,000	24,000,000
Duke Energy Florida [Member] | Spent Nuclear Fuels [Member]
Valuation and Qualifying Accounts [Abstract]
Gain contingency, unrecorded amount			$ 25,000,000
Litigation settlement, amount awarded from other party		21,000,000
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		510,000,000
Loss contingency, damages awarded, value		30,000,000
Gain contingency, dismissed amount		54,000,000
Loss contingency damages awarded and interest, value		34,000,000
Loss contingency, damages paid, 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

XML

Commitments and Contingencies (Schedule of Environmental Loss Contingencies) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	$ 81	$ 98
Provisions/adjustments	7	(1)
Cash reductions	(20)	(13)
Balance at end of period	68	84
Environmental exit costs, reasonably possible additional loss	57
Duke Energy Carolinas [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	10	10
Provisions/adjustments	3	2
Cash reductions	(2)	(2)
Balance at end of period	11	10
Environmental exit costs, reasonably possible additional loss	17
Progress Energy [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	15	18
Provisions/adjustments	2	1
Cash reductions	(5)	(3)
Balance at end of period	12	16
Duke Energy Progress [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	3	3
Provisions/adjustments	3
Cash reductions	(1)
Balance at end of period	5	3
Duke Energy Florida [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	12	14
Provisions/adjustments	(1)	1
Cash reductions	(4)	(3)
Balance at end of period	7	12
Duke Energy Ohio [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	47	59
Provisions/adjustments	3	(3)
Cash reductions	(12)	(7)
Balance at end of period	38	49
Environmental exit costs, reasonably possible additional loss	30
Duke Energy Indiana [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	5	10
Provisions/adjustments	1	(2)
Cash reductions	(1)	(1)
Balance at end of period	5	7
Piedmont Natural Gas [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	2	1
Provisions/adjustments		1
Cash reductions	0
Balance at end of period	2	$ 2
Environmental exit costs, reasonably possible additional loss	$ 2

XML

Commitments and Contingencies (Schedule of Legal Reserves) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Loss Contingencies [Line Items]
Reserves for legal matters	$ 63	$ 88
Duke Energy Carolinas [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	11	30
Progress Energy [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	50	55
Duke Energy Progress [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	11	13
Duke Energy Florida [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	23	24
Piedmont Natural Gas [Member]
Loss Contingencies [Line Items]
Reserves for legal matters	$ 1	$ 2

XML

Debt and Credit Facilities (Narrative) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2018	Aug. 31, 2018
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size	$ 8,000,000,000
Line of credit facility, expiration date	Mar. 16, 2023
Three Year Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size	$ 1,000,000,000.0
Outstanding balance	500,000,000
Duke Energy Carolinas [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size	1,750,000,000
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	1,400,000,000
Piedmont Natural Gas [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Facility size	500,000,000
Debt Maturing September 2019, 2.848% Coupon [Member] | Piedmont Natural Gas [Member] | Unsecured Debt [Member]
Debt Instrument [Line Items]
Facility size	350,000,000	$ 250,000,000
Outstanding balance	$ 350,000,000

XML

Debt and Credit Facilities (Summary of Debt Issuances) (Details) - USD ($)	1 Months Ended	9 Months Ended
	Apr. 30, 2018	Sep. 30, 2018	Sep. 30, 2017
Debt Instrument [Line Items]
Debt issuances		$ 4,050,000,000
Repayments of long-term debt		2,278,000,000	$ 2,035,000,000
Parent Company [Member]
Debt Instrument [Line Items]
Debt issuances		1,250,000,000
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Debt issuances		1,000,000,000
Repayments of long-term debt		704,000,000	115,000,000
Duke Energy Carolinas [Member] | First Mortgage Bonds Maturing April 2018, 5.100% Coupon
Debt Instrument [Line Items]
Repayments of long-term debt	$ 300,000,000
Duke Energy Progress [Member]
Debt Instrument [Line Items]
Debt issuances		800,000,000
Repayments of long-term debt		2,000,000	270,000,000
Duke Energy Florida [Member]
Debt Instrument [Line Items]
Debt issuances		1,000,000,000
Repayments of long-term debt		717,000,000	$ 341,000,000
Unsecured Debt [Member] | March 2018 Debt Issuance 3.950% Coupon Due 2025 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 250,000,000
Interest rate		3.95%
Unsecured Debt [Member] | May 2018 Debt Issuance 2.819% Coupon Due 2021 [Member] [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500,000,000
Interest rate		2.819%
Unsecured Debt [Member] | September 2018 Debt Issuance 5.625% Coupon Due 2078 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500,000,000
Interest rate		5.625%
Unsecured Debt [Member] | Parent Company [Member] | March 2018 Debt Issuance 3.950% Coupon Due 2025 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 250,000,000
Unsecured Debt [Member] | Parent Company [Member] | May 2018 Debt Issuance 2.819% Coupon Due 2021 [Member] [Member]
Debt Instrument [Line Items]
Debt issuances		500,000,000
Unsecured Debt [Member] | Parent Company [Member] | September 2018 Debt Issuance 5.625% Coupon Due 2078 [Member]
Debt Instrument [Line Items]
Debt issuances		500,000,000
First Mortgage [Member] | March 2018 Debt Issuance 3.050% Coupon Due 2023 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500,000,000
Interest rate		3.05%
First Mortgage [Member] | March 2018 Debt Issuance 3.950% Coupon Due 2048 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500,000,000
Interest rate		3.95%
First Mortgage [Member] | June 2018 Debt issuance 3.80% coupon Due 2028 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 600,000,000
Interest rate		3.80%
First Mortgage [Member] | June 2018 Debt Issuance 4.20 Coupon Due 2048 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 400,000,000
Interest rate		4.20%
First Mortgage [Member] | August 2018 Debt Issuance 3.375% Coupon Due 2023 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 300,000,000
Interest rate		3.375%
First Mortgage [Member] | August 2018 Debt Issuance 3.700% Coupon Due 2028 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500,000,000
Interest rate		3.70%
First Mortgage [Member] | Duke Energy Carolinas [Member] | March 2018 Debt Issuance 3.050% Coupon Due 2023 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 500,000,000
First Mortgage [Member] | Duke Energy Carolinas [Member] | March 2018 Debt Issuance 3.950% Coupon Due 2048 [Member]
Debt Instrument [Line Items]
Debt issuances		500,000,000
First Mortgage [Member] | Duke Energy Progress [Member] | August 2018 Debt Issuance 3.375% Coupon Due 2023 [Member]
Debt Instrument [Line Items]
Debt issuances		300,000,000
First Mortgage [Member] | Duke Energy Progress [Member] | August 2018 Debt Issuance 3.700% Coupon Due 2028 [Member]
Debt Instrument [Line Items]
Debt issuances		500,000,000
First Mortgage [Member] | Duke Energy Florida [Member] | June 2018 Debt issuance 3.80% coupon Due 2028 [Member]
Debt Instrument [Line Items]
Debt issuances		600,000,000
First Mortgage [Member] | Duke Energy Florida [Member] | June 2018 Debt Issuance 4.20 Coupon Due 2048 [Member]
Debt Instrument [Line Items]
Debt issuances		$ 400,000,000

XML

Debt and Credit Facilities (Summary of Current Maturities of Long-term Debt) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 3,455	$ 3,244
Other debt obligations [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 605
Parent Company [Member] | Unsecured Debt [Member] | Debt Maturing September 2019, 5.050% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	5.05%
Current maturities of long-term debt	$ 500
Progress Energy [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 1,322	771
Progress Energy [Member] | Unsecured Debt [Member] | Debt Maturing March 2019, 7.050% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	7.05%
Current maturities of long-term debt	$ 450
Piedmont Natural Gas [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 350	250
Piedmont Natural Gas [Member] | Unsecured Debt [Member] | Debt Maturing September 2019, 2.848% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	2.848%
Current maturities of long-term debt	$ 350
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 506	1,205
Duke Energy Carolinas [Member] | First Mortgage Bonds [Member] | Bonds Maturing November 2018, 7.000% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	7.00%
Current maturities of long-term debt	$ 500
Duke Energy Progress [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 603	3
Duke Energy Progress [Member] | First Mortgage Bonds [Member] | Bonds Maturing January 2019, 5.300% Coupon [Member]
Debt Instrument [Line Items]
Interest rate	5.30%
Current maturities of long-term debt	$ 600
Duke Energy Ohio [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 452	$ 3
Duke Energy Ohio [Member] | First Mortgage Bonds [Member] | Bonds Maturing April 2019, 5.450% Coupon [Member] [Member]
Debt Instrument [Line Items]
Interest rate	5.45%
Current maturities of long-term debt	$ 450

XML

Debt and Credit Facilities (Schedule of Line of Credit Facilities) (Details) - Revolving Credit Facility [Member]	Sep. 30, 2018 USD ($)
Line of Credit Facility [Line Items]
Facility size	$ 8,000,000,000
Commercial paper	(2,519,000,000)
Outstanding letters of credit	(55,000,000)
Tax exempt bonds	(81,000,000)
Coal ash set-aside	(500,000,000)
Available capacity	4,845,000,000
Parent Company [Member]
Line of Credit Facility [Line Items]
Facility size	2,650,000,000
Commercial paper	(988,000,000)
Outstanding letters of credit	(47,000,000)
Available capacity	1,615,000,000
Duke Energy Carolinas [Member]
Line of Credit Facility [Line Items]
Facility size	1,750,000,000
Commercial paper	(872,000,000)
Outstanding letters of credit	(4,000,000)
Coal ash set-aside	(250,000,000)
Available capacity	624,000,000
Duke Energy Progress [Member]
Line of Credit Facility [Line Items]
Facility size	1,400,000,000
Commercial paper	(150,000,000)
Outstanding letters of credit	(2,000,000)
Coal ash set-aside	(250,000,000)
Available capacity	998,000,000
Duke Energy Florida [Member]
Line of Credit Facility [Line Items]
Facility size	650,000,000
Available capacity	650,000,000
Duke Energy Ohio [Member]
Line of Credit Facility [Line Items]
Facility size	450,000,000
Commercial paper	(216,000,000)
Available capacity	234,000,000
Duke Energy Indiana [Member]
Line of Credit Facility [Line Items]
Facility size	600,000,000
Commercial paper	(293,000,000)
Tax exempt bonds	(81,000,000)
Available capacity	226,000,000
Piedmont Natural Gas [Member]
Line of Credit Facility [Line Items]
Facility size	500,000,000
Outstanding letters of credit	(2,000,000)
Available capacity	498,000,000
Proceeds Loaned To Subsidiary Registrants [Member] | Parent Company [Member]
Line of Credit Facility [Line Items]
Commercial paper	$ (625,000,000)

XML

Asset Retirement Obligations (ARO by Category) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Asset Retirement Obligations [Line Items]
Total ARO	$ 10,256	$ 10,175
Less: current portion	902	689
Total noncurrent ARO	9,354	9,486
Duke Energy Carolinas [Member]
Asset Retirement Obligations [Line Items]
Total ARO	3,712	3,610
Less: current portion	292	337
Total noncurrent ARO	3,420	3,273
Progress Energy [Member]
Asset Retirement Obligations [Line Items]
Total ARO	5,435	5,414
Less: current portion	475	295
Total noncurrent ARO	4,960	5,119
Duke Energy Progress [Member]
Asset Retirement Obligations [Line Items]
Total ARO	4,841	4,673
Less: current portion	470	295
Total noncurrent ARO	4,371	4,378
Duke Energy Florida [Member]
Asset Retirement Obligations [Line Items]
Total ARO	593	742
Less: current portion	4
Total noncurrent ARO	589	742
Duke Energy Ohio [Member]
Asset Retirement Obligations [Line Items]
Total ARO	98	84
Less: current portion	7	3
Total noncurrent ARO	91	81
Duke Energy Indiana [Member]
Asset Retirement Obligations [Line Items]
Total ARO	744	781
Less: current portion	128	54
Total noncurrent ARO	616	727
Piedmont Natural Gas [Member]
Asset Retirement Obligations [Line Items]
Total ARO	15	15
Total noncurrent ARO	15	$ 15
Decommissioning of Nuclear Power Facilities [Member]
Asset Retirement Obligations [Line Items]
Total ARO	5,367
Decommissioning of Nuclear Power Facilities [Member] | Duke Energy Carolinas [Member]
Asset Retirement Obligations [Line Items]
Total ARO	2,031
Decommissioning of Nuclear Power Facilities [Member] | Progress Energy [Member]
Asset Retirement Obligations [Line Items]
Total ARO	3,181
Decommissioning of Nuclear Power Facilities [Member] | Duke Energy Progress [Member]
Asset Retirement Obligations [Line Items]
Total ARO	2,650
Decommissioning of Nuclear Power Facilities [Member] | Duke Energy Florida [Member]
Asset Retirement Obligations [Line Items]
Total ARO	531
Closure of Ash Impoundments [Member]
Asset Retirement Obligations [Line Items]
Total ARO	4,575
Closure of Ash Impoundments [Member] | Duke Energy Carolinas [Member]
Asset Retirement Obligations [Line Items]
Total ARO	1,623
Closure of Ash Impoundments [Member] | Progress Energy [Member]
Asset Retirement Obligations [Line Items]
Total ARO	2,175
Closure of Ash Impoundments [Member] | Duke Energy Progress [Member]
Asset Retirement Obligations [Line Items]
Total ARO	2,154
Closure of Ash Impoundments [Member] | Duke Energy Florida [Member]
Asset Retirement Obligations [Line Items]
Total ARO	20
Closure of Ash Impoundments [Member] | Duke Energy Ohio [Member]
Asset Retirement Obligations [Line Items]
Total ARO	52
Closure of Ash Impoundments [Member] | Duke Energy Indiana [Member]
Asset Retirement Obligations [Line Items]
Total ARO	725
Other [Member]
Asset Retirement Obligations [Line Items]
Total ARO	314
Other [Member] | Duke Energy Carolinas [Member]
Asset Retirement Obligations [Line Items]
Total ARO	58
Other [Member] | Progress Energy [Member]
Asset Retirement Obligations [Line Items]
Total ARO	79
Other [Member] | Duke Energy Progress [Member]
Asset Retirement Obligations [Line Items]
Total ARO	37
Other [Member] | Duke Energy Florida [Member]
Asset Retirement Obligations [Line Items]
Total ARO	42
Other [Member] | Duke Energy Ohio [Member]
Asset Retirement Obligations [Line Items]
Total ARO	46
Other [Member] | Duke Energy Indiana [Member]
Asset Retirement Obligations [Line Items]
Total ARO	19
Other [Member] | Piedmont Natural Gas [Member]
Asset Retirement Obligations [Line Items]
Total ARO	$ 15

XML

Asset Retirement Obligations (ARO Rollforward) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018 USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	$ 10,175
Accretion expense	319
Liabilities settled	(431)
Liabilities incurred in the current year	34
Revision in estimates of cash flows	159
Balance at end of period	10,256
Duke Energy Carolinas [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	3,610
Accretion expense	133
Liabilities settled	(198)
Liabilities incurred in the current year	8
Revision in estimates of cash flows	159
Balance at end of period	3,712
Progress Energy [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	5,414
Accretion expense	168
Liabilities settled	(186)
Revision in estimates of cash flows	39
Balance at end of period	5,435
Duke Energy Progress [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	4,673
Accretion expense	145
Liabilities settled	(155)
Revision in estimates of cash flows	178
Balance at end of period	4,841
Duke Energy Florida [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	742
Accretion expense	23
Liabilities settled	(31)
Revision in estimates of cash flows	(141)
Balance at end of period	593
Duke Energy Ohio [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	84
Accretion expense	3
Liabilities settled	(5)
Revision in estimates of cash flows	16
Balance at end of period	98
Duke Energy Indiana [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	781
Accretion expense	22
Liabilities settled	(42)
Liabilities incurred in the current year	25
Revision in estimates of cash flows	(42)
Balance at end of period	744
Piedmont Natural Gas [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at beginning of period	15
Balance at end of period	$ 15

XML

Goodwill (Rollforward of Goodwill) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Goodwill [Line Items]
Goodwill balance	$ 19,425	$ 19,425
Accumulated impairment charges	(122)	(29)
Goodwill balance, adjusted for accumulated impairment charges	19,303	19,396
Electric Utilities and Infrastructure [Member]
Goodwill [Line Items]
Goodwill balance	17,379	17,379
Goodwill balance, adjusted for accumulated impairment charges	17,379	17,379
Gas Utilities and Infrastructure [Member]
Goodwill [Line Items]
Goodwill balance	1,924	1,924
Goodwill balance, adjusted for accumulated impairment charges	1,924	1,924
Commercial Renewables [Member]
Goodwill [Line Items]
Goodwill balance	122	122
Accumulated impairment charges	$ (122)	(29)
Goodwill balance, adjusted for accumulated impairment charges		$ 93

XML

Goodwill (Narrative) (Details) - USD ($)	3 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Goodwill [Line Items]
Goodwill	$ 19,303,000,000	$ 19,396,000,000
Accumulated impairment charges	122,000,000	29,000,000
Electric Utilities and Infrastructure [Member]
Goodwill [Line Items]
Goodwill	17,379,000,000	17,379,000,000
Gas Utilities and Infrastructure [Member]
Goodwill [Line Items]
Goodwill	1,924,000,000	1,924,000,000
Commercial Renewables [Member]
Goodwill [Line Items]
Goodwill		93,000,000
Accumulated impairment charges	122,000,000	29,000,000
Goodwill impairment	93,000,000
Duke Energy Ohio [Member]
Goodwill [Line Items]
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 [Line Items]
Goodwill	596,000,000	596,000,000
Duke Energy Ohio [Member] | Gas Utilities and Infrastructure [Member]
Goodwill [Line Items]
Goodwill	324,000,000	324,000,000
Progress Energy [Member]
Goodwill [Line Items]
Goodwill	3,655,000,000	3,655,000,000
Accumulated impairment charges	0	0
Piedmont Natural Gas [Member]
Goodwill [Line Items]
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		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
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	$ 214	$ 206	$ 647	$ 645
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	17	17
Duke Energy Carolinas [Member] | JDA [Member] | Duke Energy Progress [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	13	9	66	42
Related party transaction, expenses from transactions with related party	61	39	134	91
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	3	3	11	5
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	216	207	613	555
Progress Energy [Member] | Indemnification coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	8	10	25	29
Progress Energy [Member] | JDA [Member] | Duke Energy Carolinas [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	61	39	134	91
Related party transaction, expenses from transactions with related party	13	9	66	42
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	20	19	58	57
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	138	112	382	321
Duke Energy Progress [Member] | Indemnification coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	3	4	9	11
Duke Energy Progress [Member] | JDA [Member] | Duke Energy Carolinas [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	61	39	134	91
Related party transaction, expenses from transactions with related party	13	9	66	42
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	20	19	58	57
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	78	95	231	234
Duke Energy Florida [Member] | Indemnification coverages [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	5	6	16	18
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	85	90	264	275
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	3	3
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	105	94	302	281
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	6	6
Piedmont Natural Gas [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party				62
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	39	11	115	25
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	1	2	$ 2
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	$ 23	$ 22	$ 69

XML

Related Party Transactions (Equity Method Investments) (Details) - Piedmont Natural Gas [Member] - Equity Method Investee [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 6	$ 6	$ 18	$ 19
Cardinal Pipeline Company, LLC [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	2	2	5	6
Pine Needle LNG Company, LLC [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	2	2	6	6
Hardy Storage Company, LLC [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 2	$ 2	$ 7	$ 7

XML

Related Party Transactions (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Piedmont Natural Gas [Member] | Equity Method Investee [Member]
Related Party Transaction [Line Items]
Accounts payable, related parties	$ 2	$ 2

XML

Related Party Transactions (Intercompany Income Taxes) (Details) - Affiliated Entity [Member] - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Duke Energy Carolinas [Member]
Related Party Transaction [Line Items]
Income taxes receivable	$ 32
Income tax payable		$ 44
Progress Energy [Member]
Related Party Transaction [Line Items]
Income taxes receivable	196	168
Duke Energy Progress [Member]
Related Party Transaction [Line Items]
Income taxes receivable	80
Income tax payable		21
Duke Energy Florida [Member]
Related Party Transaction [Line Items]
Income taxes receivable		44
Income tax payable	77
Duke Energy Ohio [Member]
Related Party Transaction [Line Items]
Income taxes receivable		22
Income tax payable	9
Duke Energy Indiana [Member]
Related Party Transaction [Line Items]
Income taxes receivable	22
Income tax payable		35
Piedmont Natural Gas [Member]
Related Party Transaction [Line Items]
Income taxes receivable	$ 11	$ 7

XML

Derivatives and Hedging (Notional Amounts of Derivative Instruments) (Details) Mcf in Millions, $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2018 USD ($) GWh Mcf	Dec. 31, 2017 USD ($) GWh Mcf
Commodity Contracts [Member] | Electricity [Member]
Derivative [Line Items]
Notional amount, energy measure (in gigawatt-hours) | GWh	170	34
Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	744	770
Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 1,538	$ 1,587
Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	411	660
Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	1,127	927
Variable Interest Entity, Primary Beneficiary [Member] | Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	411	$ 660
Variable Interest Entity, Primary Beneficiary [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 200
Duke Energy Carolinas [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	119	105
Duke Energy Carolinas [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 400	$ 400
Duke Energy Carolinas [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 400	$ 400
Progress Energy [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	167	183
Progress Energy [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 500	$ 500
Progress Energy [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 500	$ 500
Duke Energy Progress [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	158	133
Duke Energy Progress [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 250	$ 250
Duke Energy Progress [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 250	$ 250
Duke Energy Florida [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	9	50
Duke Energy Florida [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 250	$ 250
Duke Energy Florida [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	250	250
Duke Energy Ohio [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	27	27
Duke Energy Ohio [Member] | Not Designated as Hedging Instrument [Member] | Interest Rate Contracts [Member]
Derivative [Line Items]
Notional amount	$ 27	$ 27
Duke Energy Indiana [Member] | Commodity Contracts [Member] | Electricity [Member]
Derivative [Line Items]
Notional amount, energy measure (in gigawatt-hours) | GWh	170	34
Duke Energy Indiana [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	1	2
Piedmont Natural Gas [Member] | Commodity Contracts [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	457	480

XML

Derivatives and Hedging (Location and Fair Value Amounts of Derivatives Reflected in the Condensed Consolidated Balance Sheets) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	$ 77	$ 51
Location and fair value amounts of derivatives (Liability)	225	230
Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	53	35
Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	24	16
Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	35	66
Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	190	164
Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	47	35
Location and fair value amounts of derivatives (Liability)	203	182
Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	30	16
Location and fair value amounts of derivatives (Liability)	22	48
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)	6	1
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)	6	15
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)	2	29
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
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)	46	34
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
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)	26	36
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)	177	146
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
Not 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)	17
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)	7	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)	13	12
Duke Energy Carolinas [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	7	2
Location and fair value amounts of derivatives (Liability)	28	35
Duke Energy Carolinas [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	7	2
Duke Energy Carolinas [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	14	31
Duke Energy Carolinas [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	14	4
Duke Energy Carolinas [Member] | Commodity 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)	28	10
Duke Energy Carolinas [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	5
Location and fair value amounts of derivatives (Liability)		25
Duke Energy Carolinas [Member] | Designated As Hedging Instrument [Member] | Interest Rate Contracts [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	5
Duke Energy Carolinas [Member] | 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)		25
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)	2	2
Duke Energy Carolinas [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	6
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)	14	4
Progress Energy [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	3
Location and fair value amounts of derivatives (Liability)	37	36
Progress Energy [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	2
Progress Energy [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		1
Progress Energy [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	11	19
Progress Energy [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	26	17
Progress Energy [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	3
Location and fair value amounts of derivatives (Liability)	22	28
Progress Energy [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	15	8
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)	3	2
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)		1
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)	5	18
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)	17	10
Progress Energy [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)	6	1
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)	9	7
Duke Energy Progress [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	2
Location and fair value amounts of derivatives (Liability)	24	18
Duke Energy Progress [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	1
Duke Energy Progress [Member] | Noncurrent Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		1
Duke Energy Progress [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	8	8
Duke Energy Progress [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	16	10
Duke Energy Progress [Member] | Commodity 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)	13	12
Duke Energy Progress [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	11	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)	2	1
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)	0	1
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)	5	8
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)	8	4
Duke Energy Progress [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)	3
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)	8	6
Duke Energy Florida [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	1
Location and fair value amounts of derivatives (Liability)	5	12
Duke Energy Florida [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	1
Duke Energy Florida [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	3	10
Duke Energy Florida [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	2	2
Duke Energy Florida [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	1
Location and fair value amounts of derivatives (Liability)		10
Duke Energy Florida [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	5	2
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)	1	1
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)	0	10
Duke Energy Florida [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)	3
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)	2	2
Duke Energy Ohio [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	8	1
Location and fair value amounts of derivatives (Liability)	4	5
Duke Energy Ohio [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	8	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)	3	4
Duke Energy Ohio [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	8	1
Duke Energy Ohio [Member] | Interest Rate Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	4	5
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)	8	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)	3	4
Duke Energy Indiana [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	29	27
Duke Energy Indiana [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	29	27
Duke Energy Indiana [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	29	27
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)	29	27
Piedmont Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	4	2
Location and fair value amounts of derivatives (Liability)	153	142
Piedmont Natural Gas [Member] | Current Assets, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	4	2
Piedmont Natural Gas [Member] | Current Liabilities, Other [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	7	11
Piedmont Natural Gas [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	146	131
Piedmont Natural Gas [Member] | Commodity Contracts [Member]
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	4	2
Location and fair value amounts of derivatives (Liability)	153	142
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)	4	2
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)	7	11
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)	$ 146	$ 131

XML

Derivatives and Hedging (Schedule of Offsetting Assets) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	$ 77	$ 51
Net amounts recognized on the Condensed Consolidated Balance Sheet	77	51
Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	53	35
Gross amounts offset	(4)
Net amounts recognized on the Condensed Consolidated Balance Sheet	49	35
Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	24	16
Gross amounts offset	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	23	16
Duke Energy Carolinas [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	7	2
Net amounts recognized on the Condensed Consolidated Balance Sheet	7	2
Duke Energy Carolinas [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	7	2
Gross amounts offset	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	5	2
Progress Energy [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	3	3
Net amounts recognized on the Condensed Consolidated Balance Sheet	3	3
Progress Energy [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	3	2
Gross amounts offset	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	2
Progress Energy [Member] | Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized		1
Net amounts recognized on the Condensed Consolidated Balance Sheet		1
Duke Energy Progress [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2	2
Net amounts recognized on the Condensed Consolidated Balance Sheet	2	2
Duke Energy Progress [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2	1
Gross amounts offset	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet		1
Duke Energy Progress [Member] | Noncurrent Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized		1
Net amounts recognized on the Condensed Consolidated Balance Sheet		1
Duke Energy Florida [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	1	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	1
Duke Energy Florida [Member] | Current 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 Ohio [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	8	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	8	1
Duke Energy Ohio [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	8	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	8	1
Duke Energy Indiana [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	29	27
Net amounts recognized on the Condensed Consolidated Balance Sheet	29	27
Duke Energy Indiana [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	29	27
Net amounts recognized on the Condensed Consolidated Balance Sheet	29	27
Piedmont Natural Gas [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	4	2
Net amounts recognized on the Condensed Consolidated Balance Sheet	4	2
Piedmont Natural Gas [Member] | Current Assets, Other [Member]
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	4	2
Net amounts recognized on the Condensed Consolidated Balance Sheet	$ 4	$ 2

XML

Derivatives and Hedging (Schedule of Offsetting Liabilities) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	$ 225	$ 230
Net amounts recognized on the Condensed Consolidated Balance Sheet	225	230
Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	35	66
Gross amounts offset	(4)	(3)
Net amounts recognized on the Condensed Consolidated Balance Sheet	31	63
Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	190	164
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	189	163
Duke Energy Carolinas [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	28	35
Net amounts recognized on the Condensed Consolidated Balance Sheet	28	35
Duke Energy Carolinas [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	14	31
Gross amounts offset	(2)	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	12	29
Duke Energy Carolinas [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	14	4
Net amounts recognized on the Condensed Consolidated Balance Sheet	14	4
Progress Energy [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	37	36
Net amounts recognized on the Condensed Consolidated Balance Sheet	37	36
Progress Energy [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	11	19
Gross amounts offset	(2)	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	9	17
Progress Energy [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	26	17
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	25	16
Duke Energy Progress [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	24	18
Net amounts recognized on the Condensed Consolidated Balance Sheet	24	18
Duke Energy Progress [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	8	8
Gross amounts offset	(2)	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	6	6
Duke Energy Progress [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	16	10
Gross amounts offset	(1)	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	15	9
Duke Energy Florida [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	5	12
Net amounts recognized on the Condensed Consolidated Balance Sheet	5	12
Duke Energy Florida [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	3	10
Net amounts recognized on the Condensed Consolidated Balance Sheet	3	10
Duke Energy Florida [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	2	2
Net amounts recognized on the Condensed Consolidated Balance Sheet	2	2
Duke Energy Ohio [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	4	5
Net amounts recognized on the Condensed Consolidated Balance Sheet	4	5
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	3	4
Net amounts recognized on the Condensed Consolidated Balance Sheet	3	4
Piedmont Natural Gas [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	153	142
Net amounts recognized on the Condensed Consolidated Balance Sheet	153	142
Piedmont Natural Gas [Member] | Other Current Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	7	11
Net amounts recognized on the Condensed Consolidated Balance Sheet	7	11
Piedmont Natural Gas [Member] | Other Noncurrent Liabilities [Member]
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	146	131
Net amounts recognized on the Condensed Consolidated Balance Sheet	$ 146	$ 131

XML

Derivatives and Hedging (Derivative Instruments with Credit-Risk Related Contingent Features and Cash Collateral) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
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	$ 48	$ 59
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	48	59
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	26	35
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	26	35
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	23	25
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	23	25
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	22	15
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	$ 22	15
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		10
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered		$ 10

XML

Investments in Debt and Equity Securities (All Debt and Equity Securities Through OCI and FV-NI - ASU 2016-01) (Details) $ in Millions	Sep. 30, 2018 USD ($)
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	$ 3,179
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	97
Debt securities, available-for-sale, and equity securities, FV-NI	7,790
Ndtf [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	3,127
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	93
Cash and cash equivalents	75
Debt securities, available-for-sale, and equity securities, FV-NI	7,403
Other Classification [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	52
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	4
Cash and cash equivalents	21
Debt securities, available-for-sale, and equity securities, FV-NI	387
Duke Energy Carolinas [Member] | Ndtf [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	1,695
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	55
Cash and cash equivalents	18
Debt securities, available-for-sale, and equity securities, FV-NI	3,936
Progress Energy [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	1,433
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	38
Debt securities, available-for-sale, and equity securities, FV-NI	3,533
Progress Energy [Member] | Ndtf [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	1,432
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	38
Cash and cash equivalents	57
Debt securities, available-for-sale, and equity securities, FV-NI	3,467
Progress Energy [Member] | Other Classification [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	1
Cash and cash equivalents	18
Debt securities, available-for-sale, and equity securities, FV-NI	66
Duke Energy Progress [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	1,106
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	29
Debt securities, available-for-sale, and equity securities, FV-NI	2,744
Duke Energy Progress [Member] | Ndtf [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	1,106
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	29
Cash and cash equivalents	42
Debt securities, available-for-sale, and equity securities, FV-NI	2,736
Duke Energy Progress [Member] | Other Classification [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Cash and cash equivalents	8
Debt securities, available-for-sale, and equity securities, FV-NI	8
Duke Energy Florida [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	327
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	9
Debt securities, available-for-sale, and equity securities, FV-NI	779
Duke Energy Florida [Member] | Ndtf [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	326
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	9
Cash and cash equivalents	15
Debt securities, available-for-sale, and equity securities, FV-NI	731
Duke Energy Florida [Member] | Other Classification [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	1
Debt securities, available-for-sale, and equity securities, FV-NI	48
Duke Energy Indiana [Member]
Schedule Of Available For Sale Securities And Other Trading Assets [Line Items]
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized gain	40
Debt securities, available-for-sale, and equity securities, FV-NI, unrealized loss	1
Debt securities, available-for-sale, and equity securities, FV-NI	$ 118

XML

Investments in Debt and Equity Securities (Equity Securities, FV-NI - ASU 2016-01) (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018 USD ($)	Sep. 30, 2018 USD ($)
Equity Securities, FV-NI, Realized Gain (Loss) [Abstract]
Equity securities, FV-NI, realized gain	$ 19	$ 85
Equity securities, FV-NI, realized loss	16	60
Ndtf [Member]
Equity Securities, FV-NI, Accumulated Unrealized Gain (Loss) [Abstract]
Equity securities, FV-NI, unrealized gain	3,117	3,117
Equity securities, FV-NI, unrealized loss	48	48
Equity securities, FV-NI	5,272	5,272
Other Classification [Member]
Equity Securities, FV-NI, Accumulated Unrealized Gain (Loss) [Abstract]
Equity securities, FV-NI, unrealized gain	51	51
Equity securities, FV-NI	115	115
Duke Energy Carolinas [Member]
Equity Securities, FV-NI, Realized Gain (Loss) [Abstract]
Equity securities, FV-NI, realized gain	11	47
Equity securities, FV-NI, realized loss	8	30
Duke Energy Carolinas [Member] | Ndtf [Member]
Equity Securities, FV-NI, Accumulated Unrealized Gain (Loss) [Abstract]
Equity securities, FV-NI, unrealized gain	1,692	1,692
Equity securities, FV-NI, unrealized loss	29	29
Equity securities, FV-NI	2,890	2,890
Progress Energy [Member]
Equity Securities, FV-NI, Realized Gain (Loss) [Abstract]
Equity securities, FV-NI, realized gain	8	38
Equity securities, FV-NI, realized loss	8	30
Progress Energy [Member] | Ndtf [Member]
Equity Securities, FV-NI, Accumulated Unrealized Gain (Loss) [Abstract]
Equity securities, FV-NI, unrealized gain	1,425	1,425
Equity securities, FV-NI, unrealized loss	19	19
Equity securities, FV-NI	2,382	2,382
Duke Energy Progress [Member]
Equity Securities, FV-NI, Realized Gain (Loss) [Abstract]
Equity securities, FV-NI, realized gain	7	32
Equity securities, FV-NI, realized loss	7	27
Duke Energy Progress [Member] | Ndtf [Member]
Equity Securities, FV-NI, Accumulated Unrealized Gain (Loss) [Abstract]
Equity securities, FV-NI, unrealized gain	1,101	1,101
Equity securities, FV-NI, unrealized loss	14	14
Equity securities, FV-NI	1,913	1,913
Duke Energy Florida [Member]
Equity Securities, FV-NI, Realized Gain (Loss) [Abstract]
Equity securities, FV-NI, realized gain	1	6
Equity securities, FV-NI, realized loss	1	3
Duke Energy Florida [Member] | Ndtf [Member]
Equity Securities, FV-NI, Accumulated Unrealized Gain (Loss) [Abstract]
Equity securities, FV-NI, unrealized gain	324	324
Equity securities, FV-NI, unrealized loss	5	5
Equity securities, FV-NI	469	469
Duke Energy Indiana [Member]
Equity Securities, FV-NI, Accumulated Unrealized Gain (Loss) [Abstract]
Equity securities, FV-NI, unrealized gain	40	40
Equity securities, FV-NI	78	78
Duke Energy Indiana [Member] | Other Classification [Member]
Equity Securities, FV-NI, Accumulated Unrealized Gain (Loss) [Abstract]
Equity securities, FV-NI	$ 78	$ 78

XML

Investments in Debt Securities and Equity Securities (Available-for-sale, OCI - ASU 2016-01) (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018 USD ($)	Sep. 30, 2018 USD ($)
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	$ 2,307	$ 2,307
Debt Securities, Available-for-sale, Realized Gain (Loss) [Abstract]
Debt securities, available-for-sale, realized gain	4	14
Debt securities, available-for-sale, realized loss	7	32
Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	2,131	2,131
Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	272	272
Corporate debt securities [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	5	5
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	10	10
Debt securities, available-for-sale	595	595
Corporate debt securities [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	1	1
Debt securities, available-for-sale	64	64
Municipal bonds [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	0	0
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	7	7
Debt securities, available-for-sale	346	346
Municipal bonds [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	1	1
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	1	1
Debt securities, available-for-sale	85	85
US treasury and government [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	5	5
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	25	25
Debt securities, available-for-sale	974	974
US treasury and government [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	1	1
Debt securities, available-for-sale	59	59
Other debt obligations [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	3	3
Debt securities, available-for-sale	141	141
Other debt obligations [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	1	1
Debt securities, available-for-sale	43	43
Duke Energy Carolinas [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	1,028	1,028
Debt Securities, Available-for-sale, Realized Gain (Loss) [Abstract]
Debt securities, available-for-sale, realized gain	4	13
Debt securities, available-for-sale, realized loss	6	24
Duke Energy Carolinas [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	1,046	1,046
Duke Energy Carolinas [Member] | Corporate debt securities [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	2	2
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	7	7
Debt securities, available-for-sale	372	372
Duke Energy Carolinas [Member] | Municipal bonds [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	0	0
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	2	2
Debt securities, available-for-sale	80	80
Duke Energy Carolinas [Member] | US treasury and government [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	1	1
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	14	14
Debt securities, available-for-sale	439	439
Duke Energy Carolinas [Member] | Other debt obligations [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	0	0
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	3	3
Debt securities, available-for-sale	137	137
Progress Energy [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	1,076	1,076
Debt Securities, Available-for-sale, Realized Gain (Loss) [Abstract]
Debt securities, available-for-sale, realized gain	0	1
Debt securities, available-for-sale, realized loss	1	8
Progress Energy [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	1,085	1,085
Progress Energy [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	66	66
Progress Energy [Member] | Corporate debt securities [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	3	3
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	3	3
Debt securities, available-for-sale	223	223
Progress Energy [Member] | Municipal bonds [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	0	0
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	5	5
Debt securities, available-for-sale	266	266
Progress Energy [Member] | Municipal bonds [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	1	1
Debt securities, available-for-sale	48	48
Progress Energy [Member] | US treasury and government [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	4	4
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	11	11
Debt securities, available-for-sale	535	535
Progress Energy [Member] | Other debt obligations [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	4	4
Duke Energy Progress [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	781	781
Debt Securities, Available-for-sale, Realized Gain (Loss) [Abstract]
Debt securities, available-for-sale, realized gain	0	1
Debt securities, available-for-sale, realized loss	1	6
Duke Energy Progress [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	823	823
Duke Energy Progress [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	8	8
Duke Energy Progress [Member] | Corporate debt securities [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	2	2
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	2	2
Debt securities, available-for-sale	162	162
Duke Energy Progress [Member] | Municipal bonds [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	0	0
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	5	5
Debt securities, available-for-sale	265	265
Duke Energy Progress [Member] | US treasury and government [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	3	3
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	8	8
Debt securities, available-for-sale	352	352
Duke Energy Progress [Member] | Other debt obligations [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	0	0
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	0	0
Debt securities, available-for-sale	2	2
Duke Energy Florida [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	295	295
Debt Securities, Available-for-sale, Realized Gain (Loss) [Abstract]
Debt securities, available-for-sale, realized loss	0	2
Duke Energy Florida [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	262	262
Duke Energy Florida [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	48	48
Duke Energy Florida [Member] | Corporate debt securities [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	1	1
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	1	1
Debt securities, available-for-sale	61	61
Duke Energy Florida [Member] | Municipal bonds [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	0	0
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	0	0
Debt securities, available-for-sale	1	1
Duke Energy Florida [Member] | Municipal bonds [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	1	1
Debt securities, available-for-sale	48	48
Duke Energy Florida [Member] | US treasury and government [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	1	1
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	3	3
Debt securities, available-for-sale	183	183
Duke Energy Florida [Member] | Other debt obligations [Member] | Ndtf [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized gain, before tax	0	0
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	0	0
Debt securities, available-for-sale	2	2
Duke Energy Indiana [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	40	40
Duke Energy Indiana [Member] | Other Classification [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	40	40
Duke Energy Indiana [Member] | Corporate debt securities [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale	8	8
Duke Energy Indiana [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain (Loss), before Tax [Abstract]
Debt securities, available-for-sale, accumulated gross unrealized loss, before tax	1	1
Debt securities, available-for-sale	$ 32	$ 32

XML

Investments in Debt and Equity Securities (Available-For-Sale Investments) (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2017	Dec. 31, 2017
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			$ 2,899
Gross Unrealized Holding Losses			42
Estimated Fair Value			7,451
Realized Gains	$ 37	$ 170
Realized Losses	25	124
Ndtf [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			2,837
Gross Unrealized Holding Losses			40
Estimated Fair Value			7,088
Ndtf [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			115
Ndtf [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			2,805
Gross Unrealized Holding Losses			27
Estimated Fair Value			4,914
Ndtf [Member] | Corporate debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			17
Gross Unrealized Holding Losses			2
Estimated Fair Value			570
Ndtf [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			4
Gross Unrealized Holding Losses			3
Estimated Fair Value			344
Ndtf [Member] | US treasury and government [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			11
Gross Unrealized Holding Losses			7
Estimated Fair Value			1,027
Ndtf [Member] | Other debt obligations [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Losses			1
Estimated Fair Value			118
Other Classification [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			62
Gross Unrealized Holding Losses			2
Estimated Fair Value			363
Other Classification [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			15
Other Classification [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			59
Estimated Fair Value			123
Other Classification [Member] | Corporate debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			1
Estimated Fair Value			57
Other Classification [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			2
Gross Unrealized Holding Losses			1
Estimated Fair Value			83
Other Classification [Member] | US treasury and government [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			41
Other Classification [Member] | Other debt obligations [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Losses			1
Estimated Fair Value			44
Duke Energy Carolinas [Member]
Debt Securities, Available-for-sale [Line Items]
Realized Gains	20	110
Realized Losses	13	76
Duke Energy Carolinas [Member] | Ndtf [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			1,543
Gross Unrealized Holding Losses			20
Estimated Fair Value			3,758
Duke Energy Carolinas [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			32
Duke Energy Carolinas [Member] | Ndtf [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			1,531
Gross Unrealized Holding Losses			12
Estimated Fair Value			2,692
Duke Energy Carolinas [Member] | Ndtf [Member] | Corporate debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			9
Gross Unrealized Holding Losses			2
Estimated Fair Value			359
Duke Energy Carolinas [Member] | Ndtf [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Losses			1
Estimated Fair Value			60
Duke Energy Carolinas [Member] | Ndtf [Member] | US treasury and government [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			3
Gross Unrealized Holding Losses			4
Estimated Fair Value			503
Duke Energy Carolinas [Member] | Ndtf [Member] | Other debt obligations [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Losses			1
Estimated Fair Value			112
Progress Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			1,296
Gross Unrealized Holding Losses			20
Estimated Fair Value			3,389
Realized Gains	16	58
Realized Losses	12	47
Progress Energy [Member] | Ndtf [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			1,294
Gross Unrealized Holding Losses			20
Estimated Fair Value			3,330
Progress Energy [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			83
Progress Energy [Member] | Ndtf [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			1,274
Gross Unrealized Holding Losses			15
Estimated Fair Value			2,222
Progress Energy [Member] | Ndtf [Member] | Corporate debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			8
Estimated Fair Value			211
Progress Energy [Member] | Ndtf [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			4
Gross Unrealized Holding Losses			2
Estimated Fair Value			284
Progress Energy [Member] | Ndtf [Member] | US treasury and government [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			8
Gross Unrealized Holding Losses			3
Estimated Fair Value			524
Progress Energy [Member] | Ndtf [Member] | Other debt obligations [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			6
Progress Energy [Member] | Other Classification [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			2
Estimated Fair Value			59
Progress Energy [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			12
Progress Energy [Member] | Other Classification [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			2
Estimated Fair Value			47
Duke Energy Progress [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			995
Gross Unrealized Holding Losses			16
Estimated Fair Value			2,592
Realized Gains	14	49
Realized Losses	11	41
Duke Energy Progress [Member] | Ndtf [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			995
Gross Unrealized Holding Losses			16
Estimated Fair Value			2,591
Duke Energy Progress [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			50
Duke Energy Progress [Member] | Ndtf [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			980
Gross Unrealized Holding Losses			12
Estimated Fair Value			1,795
Duke Energy Progress [Member] | Ndtf [Member] | Corporate debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			6
Estimated Fair Value			149
Duke Energy Progress [Member] | Ndtf [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			4
Gross Unrealized Holding Losses			2
Estimated Fair Value			283
Duke Energy Progress [Member] | Ndtf [Member] | US treasury and government [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			5
Gross Unrealized Holding Losses			2
Estimated Fair Value			310
Duke Energy Progress [Member] | Ndtf [Member] | Other debt obligations [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			4
Duke Energy Progress [Member] | Other Classification [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			1
Duke Energy Progress [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			1
Duke Energy Florida [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			301
Gross Unrealized Holding Losses			4
Estimated Fair Value			787
Realized Gains	2	9
Realized Losses	$ 1	$ 6
Duke Energy Florida [Member] | Ndtf [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			299
Gross Unrealized Holding Losses			4
Estimated Fair Value			739
Duke Energy Florida [Member] | Ndtf [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			33
Duke Energy Florida [Member] | Ndtf [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			294
Gross Unrealized Holding Losses			3
Estimated Fair Value			427
Duke Energy Florida [Member] | Ndtf [Member] | Corporate debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			2
Estimated Fair Value			62
Duke Energy Florida [Member] | Ndtf [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			1
Duke Energy Florida [Member] | Ndtf [Member] | US treasury and government [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			3
Gross Unrealized Holding Losses			1
Estimated Fair Value			214
Duke Energy Florida [Member] | Ndtf [Member] | Other debt obligations [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			2
Duke Energy Florida [Member] | Other Classification [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			2
Estimated Fair Value			48
Duke Energy Florida [Member] | Other Classification [Member] | Cash and Cash Equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			1
Duke Energy Florida [Member] | Other Classification [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			2
Estimated Fair Value			47
Duke Energy Indiana [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			49
Gross Unrealized Holding Losses			1
Estimated Fair Value			128
Duke Energy Indiana [Member] | Equity Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Gains			49
Estimated Fair Value			97
Duke Energy Indiana [Member] | Corporate debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Estimated Fair Value			3
Duke Energy Indiana [Member] | Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Gross Unrealized Holding Losses			1
Estimated Fair Value			$ 28

XML

Investments in Debt and Equity Securities (Maturities) (Details) $ in Millions	Sep. 30, 2018 USD ($)
Debt Instrument [Line Items]
Due in one year or less	$ 100
Due after one through five years	492
Due after five through 10 years	561
Due after 10 years	1,154
Total	2,307
Duke Energy Carolinas [Member]
Debt Instrument [Line Items]
Due in one year or less	12
Due after one through five years	161
Due after five through 10 years	289
Due after 10 years	566
Total	1,028
Progress Energy [Member]
Debt Instrument [Line Items]
Due in one year or less	83
Due after one through five years	268
Due after five through 10 years	217
Due after 10 years	508
Total	1,076
Duke Energy Progress [Member]
Debt Instrument [Line Items]
Due in one year or less	40
Due after one through five years	200
Due after five through 10 years	156
Due after 10 years	385
Total	781
Duke Energy Florida [Member]
Debt Instrument [Line Items]
Due in one year or less	43
Due after one through five years	68
Due after five through 10 years	61
Due after 10 years	123
Total	295
Duke Energy Indiana [Member]
Debt Instrument [Line Items]
Due in one year or less	2
Due after one through five years	20
Due after five through 10 years	5
Due after 10 years	13
Total	$ 40

XML

Fair Value Measurements (Fair Value Measurement Amounts for Assets and Liabilities) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	$ 2,307
Derivative assets	77	$ 51
Total assets	7,867	7,503
Derivative liabilities	(225)	(230)
Net assets (liabilities)	7,642	7,273
Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	4	3
Total assets	5,910	5,658
Derivative liabilities	0	(2)
Net assets (liabilities)	5,910	5,656
Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	36	20
Total assets	1,851	1,743
Derivative liabilities	(72)	(86)
Net assets (liabilities)	1,779	1,657
Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	37	28
Total assets	37	28
Derivative liabilities	(153)	(142)
Net assets (liabilities)	(116)	(114)
Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	69	74
Net assets (liabilities)	69	74
Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	5,272
Debt securities, available-for-sale	2,131
Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	5,203
Debt securities, available-for-sale	510
Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	1,621
Ndtf [Member] | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	69
Investments, fair value disclosures		74
Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	115
Debt securities, available-for-sale	272
Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	115
Debt securities, available-for-sale	78
Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	194
Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		4,914
Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		4,840
Equity Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		123
Equity Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		123
Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		2,174
Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		635
Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		1,539
Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		241
Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		57
Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		184
Duke Energy Carolinas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	1,028
Derivative assets	7	2
Total assets	3,943	3,760
Derivative liabilities	(28)	(35)
Net assets (liabilities)	3,915	3,725
Duke Energy Carolinas [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	0
Total assets	2,943	2,822
Derivative liabilities	0	(1)
Net assets (liabilities)	2,943	2,821
Duke Energy Carolinas [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	7	2
Total assets	931	864
Derivative liabilities	(28)	(34)
Net assets (liabilities)	903	830
Duke Energy Carolinas [Member] | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	69	74
Net assets (liabilities)	69	74
Duke Energy Carolinas [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	2,890
Debt securities, available-for-sale	1,046
Duke Energy Carolinas [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	2,821
Debt securities, available-for-sale	122
Duke Energy Carolinas [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	924
Duke Energy Carolinas [Member] | Ndtf [Member] | Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	69
Investments, fair value disclosures		74
Duke Energy Carolinas [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		2,692
Duke Energy Carolinas [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		2,618
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		1,066
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		204
Duke Energy Carolinas [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		862
Progress Energy [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	1,076
Derivative assets	3	3
Total assets	3,536	3,392
Derivative liabilities	(37)	(36)
Net assets (liabilities)	3,499	3,356
Progress Energy [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	0	1
Total assets	2,788	2,666
Derivative liabilities	0	(1)
Net assets (liabilities)	2,788	2,665
Progress Energy [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	3	2
Total assets	748	726
Derivative liabilities	(37)	(35)
Net assets (liabilities)	711	691
Progress Energy [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	2,382
Debt securities, available-for-sale	1,085
Progress Energy [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	2,382
Debt securities, available-for-sale	388
Progress Energy [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	697
Progress Energy [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	66
Progress Energy [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	18
Progress Energy [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	48
Progress Energy [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		2,222
Progress Energy [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		2,222
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		1,108
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		431
Progress Energy [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		677
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		59
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		12
Progress Energy [Member] | Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		47
Duke Energy Progress [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	781
Derivative assets	2	2
Total assets	2,746	2,594
Derivative liabilities	(24)	(18)
Net assets (liabilities)	2,722	2,576
Duke Energy Progress [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	0	1
Total assets	2,175	2,040
Derivative liabilities	0	(1)
Net assets (liabilities)	2,175	2,039
Duke Energy Progress [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	2	1
Total assets	571	554
Derivative liabilities	(24)	(17)
Net assets (liabilities)	547	537
Duke Energy Progress [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	1,913
Debt securities, available-for-sale	823
Duke Energy Progress [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	1,913
Debt securities, available-for-sale	254
Duke Energy Progress [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	569
Duke Energy Progress [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	8
Duke Energy Progress [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	8
Duke Energy Progress [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		1,795
Duke Energy Progress [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		1,795
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		796
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		243
Duke Energy Progress [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		553
Duke Energy Progress [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		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, fair value disclosures		1
Duke Energy Florida [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	295
Derivative assets	1	1
Total assets	780	788
Derivative liabilities	(5)	(12)
Net assets (liabilities)	775	776
Duke Energy Florida [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	603	616
Net assets (liabilities)	603	616
Duke Energy Florida [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	1	1
Total assets	177	172
Derivative liabilities	(5)	(12)
Net assets (liabilities)	172	160
Duke Energy Florida [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	469
Debt securities, available-for-sale	262
Duke Energy Florida [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	469
Debt securities, available-for-sale	134
Duke Energy Florida [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	128
Duke Energy Florida [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	48
Duke Energy Florida [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	48
Duke Energy Florida [Member] | Equity Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		427
Duke Energy Florida [Member] | Equity Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		427
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		312
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		188
Duke Energy Florida [Member] | Debt Securities [Member] | Ndtf [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		124
Duke Energy Florida [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		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, fair value disclosures		1
Duke Energy Florida [Member] | Debt Securities [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		47
Duke Energy Ohio [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	8	1
Derivative liabilities	(4)	(5)
Net assets (liabilities)	4	(4)
Duke Energy Ohio [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative liabilities	(4)	(5)
Net assets (liabilities)	(4)	(5)
Duke Energy Ohio [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	8	1
Net assets (liabilities)	8	1
Duke Energy Indiana [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	78
Debt securities, available-for-sale	40
Derivative assets	29	27
Total assets	147	155
Duke Energy Indiana [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	0
Total assets	78	97
Duke Energy Indiana [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	40	31
Duke Energy Indiana [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	29	27
Total assets	29	27
Duke Energy Indiana [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	78
Debt securities, available-for-sale	40
Duke Energy Indiana [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	78
Duke Energy Indiana [Member] | Other Classification [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	40
Duke Energy Indiana [Member] | Equity Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		97
Duke Energy Indiana [Member] | Equity Securities [Member] | Other Classification [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		97
Duke Energy Indiana [Member] | Debt Securities [Member] | Other Classification [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		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, fair value disclosures		31
Piedmont Natural Gas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	4	2
Total assets		3
Derivative liabilities	(153)	(142)
Net assets (liabilities)	(149)	(139)
Piedmont Natural Gas [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	4	2
Total assets		3
Net assets (liabilities)	4	3
Piedmont Natural Gas [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative liabilities	(153)	(142)
Net assets (liabilities)	$ (153)	(142)
Piedmont Natural Gas [Member] | Debt Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		1
Piedmont Natural Gas [Member] | Debt Securities [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Investments, fair value disclosures		$ 1

XML

Fair Value Measurements (Reconciliation of Assets and Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value measurement, transfers between activity levels	$ 0	$ 0	$ 0	$ 0
Derivatives (net)
Balance at beginning of period	(97,000,000)	(91,000,000)	(114,000,000)	(166,000,000)
Purchases, sales, issuances and settlements:
Purchases			56,000,000	55,000,000
Settlements	(14,000,000)	(12,000,000)	(43,000,000)	(30,000,000)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	(5,000,000)	10,000,000	(15,000,000)	48,000,000
Balance at end of period	(116,000,000)	(93,000,000)	(116,000,000)	(93,000,000)
Investments and Derivatives, Net
Balance at beginning of period	(97,000,000)	(91,000,000)	(114,000,000)	(161,000,000)
Total pretax realized or unrealized gains included in comprehensive income				1,000,000
Purchases, sales, issuances and settlements:
Purchases			56,000,000	55,000,000
Sales				(6,000,000)
Settlements	(14,000,000)	(12,000,000)	(43,000,000)	(30,000,000)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	(5,000,000)	10,000,000	(15,000,000)	48,000,000
Balance at end of period	(116,000,000)	(93,000,000)	(116,000,000)	(93,000,000)
Investments [Member]
Investments
Balance at beginning of period		0		5,000,000
Total pretax realized or unrealized gains included in comprehensive income				1,000,000
Purchases, sales, issuances and settlements:
Sales				(6,000,000)
Duke Energy Carolinas [Member] | Investments [Member]
Investments
Balance at beginning of period				3,000,000
Total pretax realized or unrealized gains included in comprehensive income				1,000,000
Purchases, sales, issuances and settlements:
Sales				(4,000,000)
Duke Energy Ohio [Member]
Derivatives (net)
Balance at beginning of period	9,000,000	3,000,000	1,000,000	5,000,000
Purchases, sales, issuances and settlements:
Purchases	0		7,000,000	3,000,000
Settlements	(1,000,000)	(1,000,000)	(2,000,000)	(3,000,000)
Total (losses) gains included on the Condensed Consolidated Balance Sheet			2,000,000	(3,000,000)
Balance at end of period	8,000,000	2,000,000	8,000,000	2,000,000
Duke Energy Indiana [Member]
Derivatives (net)
Balance at beginning of period	44,000,000	51,000,000	27,000,000	16,000,000
Purchases, sales, issuances and settlements:
Purchases	0	0	49,000,000	52,000,000
Settlements	(13,000,000)	(11,000,000)	(41,000,000)	(27,000,000)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	(2,000,000)	(12,000,000)	(6,000,000)	(13,000,000)
Balance at end of period	29,000,000	28,000,000	29,000,000	28,000,000
Piedmont Natural Gas [Member]
Derivatives (net)
Balance at beginning of period	(150,000,000)	(145,000,000)	(142,000,000)	(187,000,000)
Purchases, sales, issuances and settlements:
Total gains (losses) and settlements	(3,000,000)	22,000,000	(11,000,000)	64,000,000
Balance at end of period	$ (153,000,000)	$ (123,000,000)	$ (153,000,000)	$ (123,000,000)

XML

Fair Value Measurements (Quantitative Level 3 Fair Value Disclosures) (Details) $ in Millions	Sep. 30, 2018 USD ($) $ / MWh $ / MMBTU	Jun. 30, 2018 USD ($)	Dec. 31, 2017 USD ($)	Sep. 30, 2017 USD ($) $ / MWh $ / MMBTU	Jun. 30, 2017 USD ($)	Dec. 31, 2016 USD ($)
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability)	$ (116)	$ (97)	$ (114)	$ (93)	$ (91)	$ (166)
Duke Energy Ohio [Member]
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability)	8	9	1	$ 2	3	5
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | Valuation, Market Approach [Member]
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability)	$ 8		1
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | Minimum [Member] | Valuation, Market Approach [Member]
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	1.03			0.07
Duke Energy Ohio [Member] | Financial Transmission Rights [Member] | Maximum [Member] | Valuation, Market Approach [Member]
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	4.10			1.41
Duke Energy Indiana [Member]
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability)	$ 29	44	27	$ 28	51	16
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | Valuation, Market Approach [Member]
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability)	$ 29		27
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | Minimum [Member] | Valuation, Market Approach [Member]
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	(2.32)			(0.77)
Duke Energy Indiana [Member] | Financial Transmission Rights [Member] | Maximum [Member] | Valuation, Market Approach [Member]
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	8.11			7.44
Piedmont Natural Gas [Member]
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability)	$ (153)	$ (150)	(142)	$ (123)	$ (145)	$ (187)
Piedmont Natural Gas [Member] | Derivative Financial Instruments, Liabilities [Member] | Discounted Cash Flow [Member]
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability)	$ (153)		$ (142)
Piedmont Natural Gas [Member] | Derivative Financial Instruments, Liabilities [Member] | Minimum [Member] | Discounted Cash Flow [Member]
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MMBTU	1.74			2.10
Piedmont Natural Gas [Member] | Derivative Financial Instruments, Liabilities [Member] | Maximum [Member] | Discounted Cash Flow [Member]
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MMBTU	3.41			2.88

XML

Fair Value Measurements (Other Fair Value Disclosure) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	$ 53,962	$ 52,279
Long-term debt, fair value	53,949	55,331
Piedmont Natural Gas and Progress Energy [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized debt discount (premium), net	1,600	1,700
Duke Energy Carolinas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	10,395	10,103
Long-term debt, fair value	10,887	11,372
Progress Energy [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	18,912	17,837
Long-term debt, fair value	19,825	20,000
Duke Energy Progress [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	8,154	7,357
Long-term debt, fair value	8,231	7,992
Duke Energy Florida [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	7,371	7,095
Long-term debt, fair value	7,749	7,953
Duke Energy Ohio [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	2,066	2,067
Long-term debt, fair value	2,136	2,249
Duke Energy Indiana [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	3,783	3,783
Long-term debt, fair value	4,178	4,464
Piedmont Natural Gas [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	2,138	2,037
Long-term debt, fair value	$ 2,175	$ 2,209

XML

Variable Interest Entities (Narrative) (Details) - USD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable interest entity, financial or other support, amount	$ 0	$ 0
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	$ 3,000,000
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 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	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Variable Interest Entities [Line Items]
Long-Term Debt	$ 50,507	$ 49,035
Duke Energy Carolinas [Member]
Variable Interest Entities [Line Items]
Long-Term Debt	9,589	8,598
Duke Energy Progress [Member]
Variable Interest Entities [Line Items]
Long-Term Debt	7,401	7,204
Duke Energy Florida [Member]
Variable Interest Entities [Line Items]
Long-Term Debt	$ 7,102	6,327
Cinergy Receivables [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Line of credit facility, expiration date	Dec. 01, 2020
Facility size	$ 325
Long-Term Debt	325	325
Accounts receivable from securitization	$ 504	545
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, 2020
Facility size	$ 450
Long-Term Debt	450	450
Accounts receivable from securitization	$ 795	640
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, 2021
Facility size	$ 300
Long-Term Debt	300	300
Accounts receivable from securitization	$ 635	459
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, 2021
Facility size	$ 225
Long-Term Debt	225	225
Accounts receivable from securitization	$ 456	$ 317

XML

Variable Interest Entities (Schedule of Consolidated VIEs) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory assets, current	$ 1,906	$ 1,437
Other, current assets	1,092	634
Regulatory assets, noncurrent	12,616	12,442
Property, plant and equipment, cost	132,677	127,507
Accumulated depreciation and amortization	(43,200)	(41,537)
Other noncurrent assets	3,112	2,960
Current Liabilities: Other	1,703	1,865
Current maturities of long-term debt	3,455	3,244
Long-Term Debt	50,507	49,035
Deferred income taxes	7,765	6,621
Noncurrent Liabilities: Other	1,477	1,581
Duke Energy Carolinas [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory assets, current	435	299
Other, current assets	55	19
Regulatory assets, noncurrent	3,188	2,853
Property, plant and equipment, cost	44,086	42,939
Accumulated depreciation and amortization	(15,536)	(15,063)
Other noncurrent assets	1,009	979
Current Liabilities: Other	419	486
Current maturities of long-term debt	506	1,205
Long-Term Debt	9,589	8,598
Deferred income taxes	3,639	3,413
Noncurrent Liabilities: Other	508	566
Duke Energy Progress [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory assets, current	677	352
Other, current assets	112	97
Regulatory assets, noncurrent	3,822	3,507
Property, plant and equipment, cost	31,091	29,583
Accumulated depreciation and amortization	(11,484)	(10,903)
Other noncurrent assets	653	599
Current Liabilities: Other	353	376
Current maturities of long-term debt	603	3
Long-Term Debt	7,401	7,204
Deferred income taxes	2,076	1,883
Noncurrent Liabilities: Other	48	45
Duke Energy Florida [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory assets, current	445	389
Other, current assets	27	86
Regulatory assets, noncurrent	2,165	2,503
Property, plant and equipment, cost	18,722	17,730
Accumulated depreciation and amortization	(5,161)	(4,947)
Other noncurrent assets	315	284
Current Liabilities: Other	315	334
Current maturities of long-term debt	269	768
Long-Term Debt	7,102	6,327
Deferred income taxes	2,012	1,761
Noncurrent Liabilities: Other	56	108
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	7	4
Regulatory assets, current	52	51
Other, current assets	14	40
Regulatory assets, noncurrent	1,055	1,091
Current Liabilities: Other	3	10
Current maturities of long-term debt	53	53
Long-Term Debt	1,111	1,164
DERF [Member] | Duke Energy Carolinas [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Receivables of VIEs	795	640
Long-Term Debt	450	450
DEPR [Member] | Duke Energy Progress [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Receivables of VIEs	635	459
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]
Receivables of VIEs	456	317
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]
Receivables of VIEs	504	545
Long-Term Debt	325	325
Commercial Renewables [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Other, current assets	203	174
Property, plant and equipment, cost	4,025	3,923
Accumulated depreciation and amortization	(695)	(591)
Other noncurrent assets	268	50
Current maturities of long-term debt	175	170
Long-Term Debt	1,604	1,700
Deferred income taxes		(148)
Noncurrent Liabilities: Other	$ 225	$ 241

XML

Variable Interest Entities (Schedule of Non-Consolidated VIEs) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	$ 1,328	$ 1,175
Other noncurrent assets	3,112	2,960
Taxes accrued	674	551
Current Liabilities: Other	1,703	1,865
Deferred income taxes	7,765	6,621
Noncurrent Liabilities: Other	1,477	1,581
Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	966	919
Other noncurrent assets		17
Total assets	966	936
Taxes accrued		(29)
Current Liabilities: Other	3	4
Deferred income taxes	14	42
Noncurrent Liabilities: Other	11	12
Total liabilities	28	29
Net assets	938	907
Pipeline Investments [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	729	697
Other noncurrent assets		17
Total assets	729	714
Taxes accrued		(29)
Deferred income taxes	14	42
Total liabilities	14	13
Net assets	715	701
Commercial Renewables [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	190	180
Total assets	190	180
Net assets	190	180
Other VIEs [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	47	42
Total assets	47	42
Current Liabilities: Other	3	4
Noncurrent Liabilities: Other	11	12
Total liabilities	14	16
Net assets	33	26
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	71	133
Other noncurrent assets	62	21
Taxes accrued	159	190
Current Liabilities: Other	67	71
Deferred income taxes	790	781
Noncurrent Liabilities: Other	113	108
Duke Energy Ohio [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	56	87
Total assets	56	87
Net assets	56	87
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	98	125
Other noncurrent assets	233	189
Taxes accrued	44	95
Current Liabilities: Other	109	104
Deferred income taxes	988	925
Noncurrent Liabilities: Other	31	18
Duke Energy Indiana [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Receivables from affiliated companies	94	106
Total assets	94	106
Net assets	$ 94	$ 106

XML

Variable Interest Entities (Pipeline Investments) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Variable Interest Entities [Line Items]
Investments in joint ventures	$ 1,328	$ 1,175
Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Variable interest entity, nonconsolidated, carrying amount, liabilities	28	29
Investments in joint ventures	966	919
Piedmont Natural Gas [Member]
Variable Interest Entities [Line Items]
Investments in joint ventures	$ 63	61
Atlantic Coast Pipeline [Member]
Variable Interest Entities [Line Items]
Ownership percentage	47.00%
Atlantic Coast Pipeline [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Equity method investment, line of credit facility, maximum borrowing capacity		3,400
Investments in joint ventures	$ 704	397
Atlantic Coast Pipeline [Member] | Variable Interest Entity, Not Primary Beneficiary [Member] | Revolving Credit Facility [Member]
Variable Interest Entities [Line Items]
Variable interest entity, entity maximum loss exposure, percent	47.00%
Variable interest entity, nonconsolidated, carrying amount, liabilities	$ 486
Sabal Trail Transmission Pipeline [Member]
Variable Interest Entities [Line Items]
Investments in joint ventures	$ 112
Ownership percentage	7.50%
Sabal Trail Transmission Pipeline [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in joint ventures		219
Constitution Pipeline [Member]
Variable Interest Entities [Line Items]
Ownership percentage	24.00%
Constitution Pipeline [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Equity method investment, OTTI	$ 55
Investments in joint ventures	25	81
Pipeline Investments [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entities [Line Items]
Investments in joint ventures	$ 729	$ 697

XML

Variable Interest Entities (Fair Value Assumptions) (Details) - Variable Interest Entity, Not Primary Beneficiary [Member] - Cinergy Receivables [Member]	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Anticipated credit loss ratio	0.50%	0.50%
Discount rate	2.90%	2.10%
Receivable turnover rate	13.60%	13.50%
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Anticipated credit loss ratio	0.30%	0.30%
Discount rate	2.90%	2.10%
Receivable turnover rate	10.90%	10.70%

XML

Variable Interest Entities (Receivables Sold) (Details) - Variable Interest Entity, Not Primary Beneficiary [Member] - Cinergy Receivables [Member] - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables sold	$ 218	$ 273
Less: Retained interests	56	87
Net receivables sold	162	186
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables sold	326	312
Less: Retained interests	94	106
Net receivables sold	$ 232	$ 206

XML

Variable Interest Entities (Sales and Cash Flows) (Details) - Variable Interest Entity, Not Primary Beneficiary [Member] - Cinergy Receivables [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Duke Energy Ohio [Member]
Variable Interest Entities [Line Items]
Receivables sold	$ 450	$ 438	$ 1,478	$ 1,392
Loss recognized on sale	4	2	10	7
Cash proceeds from receivables sold	449	434	1,499	1,421
Collection fees received		1	1	1
Return received on retained interests	2		5	2
Duke Energy Indiana [Member]
Variable Interest Entities [Line Items]
Receivables sold	754	720	2,140	2,047
Loss recognized on sale	5	3	12	9
Cash proceeds from receivables sold	743	713	2,140	2,064
Collection fees received			1	1
Return received on retained interests	$ 3	$ 2	$ 7	$ 5

XML

Revenue (Narrative) (Details) - USD ($)	3 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2018
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contracts with customers	$ 6,451,000,000	$ 17,845,000,000
Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2014-09 [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contracts with customers		$ 0

XML

Revenue (Remaining Performance Obligations) (Details) $ in Millions	Sep. 30, 2018 USD ($)
Progress Energy [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 24
Revenue, remaining performance obligation, expected timing of satisfaction, period	3 months
Progress Energy [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 112
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Progress Energy [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 121
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Progress Energy [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 80
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Progress Energy [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 82
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Progress Energy [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 81
Progress Energy [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	500
Duke Energy Progress [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 2
Revenue, remaining performance obligation, expected timing of satisfaction, period	3 months
Duke Energy Progress [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 9
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Progress [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 9
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Progress [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 9
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Progress [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 9
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Progress [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 18
Duke Energy Progress [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	56
Duke Energy Florida [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 22
Revenue, remaining performance obligation, expected timing of satisfaction, period	3 months
Duke Energy Florida [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 103
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Florida [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 112
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Florida [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 71
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Florida [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 73
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Florida [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 63
Duke Energy Florida [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	444
Duke Energy Indiana [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 2
Revenue, remaining performance obligation, expected timing of satisfaction, period	3 months
Duke Energy Indiana [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 9
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Indiana [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 10
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Indiana [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 5
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Indiana [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 26
Piedmont Natural Gas [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 18
Piedmont Natural Gas [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	3 months
Piedmont Natural Gas [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 71
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Piedmont Natural Gas [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 70
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Piedmont Natural Gas [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 65
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Piedmont Natural Gas [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 64
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Piedmont Natural Gas [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 462
Piedmont Natural Gas [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 750

XML

Revenue (Disaggregation of Revenue) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 6,451		$ 17,845
Revenue from sources other than contracts with customers	177		561
Total operating revenues	6,628	$ 6,482	18,406	$ 17,766
Electric Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6,141		16,413
Total operating revenues	6,253	6,122	16,783	16,211
Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,729		7,264
Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | General [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,763		4,619
Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	835		2,235
Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Wholesale [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	589		1,737
Electric Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	225		558
Gas Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	233		1,244
Total operating revenues	232	249	1,229	1,175
Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	116		682
Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	66		354
Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	28		107
Gas Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	23		101
Commercial Renewables [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	61		141
Total operating revenues	127	95	347	333
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	16		47
Total operating revenues	16	16	47	47
Duke Energy Carolinas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,051		5,391
Revenue from sources other than contracts with customers	39		134
Total operating revenues	2,090	2,136	5,525	5,581
Duke Energy Carolinas [Member] | Electric Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,051		5,391
Duke Energy Carolinas [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	823		2,263
Duke Energy Carolinas [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | General [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	635		1,608
Duke Energy Carolinas [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	352		893
Duke Energy Carolinas [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Wholesale [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	132		366
Duke Energy Carolinas [Member] | Electric Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	109		261
Progress Energy [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,977		7,922
Revenue from sources other than contracts with customers	68		197
Total operating revenues	3,045	2,864	8,119	7,435
Progress Energy [Member] | Electric Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,977		7,922
Progress Energy [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,425		3,636
Progress Energy [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | General [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	800		2,109
Progress Energy [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	246		678
Progress Energy [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Wholesale [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	372		1,140
Progress Energy [Member] | Electric Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	134		359
Duke Energy Progress [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,547		4,234
Revenue from sources other than contracts with customers	35		99
Total operating revenues	1,582	1,460	4,333	3,878
Duke Energy Progress [Member] | Electric Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,547		4,234
Duke Energy Progress [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	572		1,540
Duke Energy Progress [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | General [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	373		972
Duke Energy Progress [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	177		481
Duke Energy Progress [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Wholesale [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	335		1,019
Duke Energy Progress [Member] | Electric Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	90		222
Duke Energy Florida [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,430		3,688
Revenue from sources other than contracts with customers	32		92
Total operating revenues	1,462	1,401	3,780	3,551
Duke Energy Florida [Member] | Electric Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,430		3,688
Duke Energy Florida [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	853		2,096
Duke Energy Florida [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | General [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	427		1,137
Duke Energy Florida [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	69		197
Duke Energy Florida [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Wholesale [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	37		121
Duke Energy Florida [Member] | Electric Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	44		137
Duke Energy Ohio [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	466		1,435
Revenue from sources other than contracts with customers	3		17
Total operating revenues	469	471	1,452	1,426
Duke Energy Ohio [Member] | Electric Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	371		1,040
Total operating revenues	373	371	1,055	1,036
Duke Energy Ohio [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	203		564
Duke Energy Ohio [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | General [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	112		318
Duke Energy Ohio [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	33		96
Duke Energy Ohio [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Wholesale [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3		5
Duke Energy Ohio [Member] | Electric Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	20		57
Duke Energy Ohio [Member] | Gas Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	83		359
Total operating revenues	84	90	361	360
Duke Energy Ohio [Member] | Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	59		236
Duke Energy Ohio [Member] | Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	20		97
Duke Energy Ohio [Member] | Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3		13
Duke Energy Ohio [Member] | Gas Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1		13
Duke Energy Ohio [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	12		36
Duke Energy Indiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	809		2,245
Revenue from sources other than contracts with customers	10		43
Total operating revenues	819	802	2,288	2,302
Duke Energy Indiana [Member] | Electric Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	809		2,245
Duke Energy Indiana [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	279		802
Duke Energy Indiana [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | General [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	218		584
Duke Energy Indiana [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	202		567
Duke Energy Indiana [Member] | Electric Utilities and Infrastructure [Member] | Electricity, US Regulated [Member] | Wholesale [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	81		226
Duke Energy Indiana [Member] | Electric Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	29		66
Piedmont Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	162		924
Revenue from sources other than contracts with customers	10		16
Total operating revenues	172	$ 183	940	$ 884
Piedmont Natural Gas [Member] | Gas Utilities and Infrastructure [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	162		924
Piedmont Natural Gas [Member] | Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	57		446
Piedmont Natural Gas [Member] | Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	46		257
Piedmont Natural Gas [Member] | Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	24		93
Piedmont Natural Gas [Member] | Gas Utilities and Infrastructure [Member] | Natural Gas, US Regulated [Member] | Power Generation [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	13		40
Piedmont Natural Gas [Member] | Gas Utilities and Infrastructure [Member] | Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 22		$ 88

XML

Revenue (Unbilled Revenues) (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	$ 802	$ 944
Duke Energy Carolinas [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	278	342
Progress Energy [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	283	228
Duke Energy Progress [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	163	143
Duke Energy Florida [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	120	85
Duke Energy Ohio [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	2	4
Duke Energy Indiana [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	25	21
Piedmont Natural Gas [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	3	86
Cinergy Receivables [Member] | Duke Energy Ohio [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	68	104
Cinergy Receivables [Member] | Duke Energy Indiana [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled receivables	$ 121	$ 132

XML

Common Stock (Earnings Per Share Data) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Equity [Abstract]
Income from continuing operations attributable to Duke Energy common stockholders excluding impact of participating securities	$ 1,077	$ 954	$ 2,199	$ 2,356
Average shares, basic	713	700	705	700
Equity Forwards, shares	1		1
Average shares, diluted	714	700	706	700
EPS, basic (usd per share)	$ 1.51	$ 1.36	$ 3.12	$ 3.37
EPS, diluted (usd per share)	$ 1.51	$ 1.36	$ 3.11	$ 3.37
Number of stock options and performance and unvested stock awards excluded from the dilutive securities calculation	2	2	2	2
Dividends declared per share (usd per share)	$ 0.9275	$ 0.89	$ 2.7075	$ 2.60

XML

Common Stock (Equity Securities Offering) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		1 Months Ended	3 Months Ended	9 Months Ended
	Feb. 20, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2018
Forward Contract Indexed to Issuer's Equity [Line Items]
Maximum value of shares to be issued under ATM program	$ 1,000
Proceeds from the issuance of common stock				$ 834
Forward contract indexed to issuer's equity, shares				1.1
Stock issued during period, shares, DRIP				1.7
Stock issued during period, value, DRIP				$ 134
ATM [Member]
Forward Contract Indexed to Issuer's Equity [Line Items]
Settlement alternative, shares				2.6
ATM [Member] | Wells Fargo Bank [Member]
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares offered		1.3
Forward contract indexed to issuer's equity, forward rate per share		$ 72.02
ATM [Member] | Citibank [Member]
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares offered		1.3
Forward contract indexed to issuer's equity, forward rate per share		$ 78.71
Equity Forwards [Member]
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares offered			21.3
Forward contract indexed to issuer's equity, forward rate per share			$ 74.07
Sales price			$ 75
Settlement alternative, shares			21.3
Shares, Issued		10.6
Proceeds from the issuance of common stock		$ 781

XML

Stock-Based Compensation (Schedule of Stock-Based Compensation Expense) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation cost	$ 23	$ 17	$ 59	$ 50
Stock-based compensation costs capitalized	1	1	3	2
Stock-based compensation expense	22	16	56	48
Tax benefit associated with stock-based compensation expense	5	6	13	18
Restricted Stock Units Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation cost	10	10	32	30
Performance Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pretax stock-based compensation cost	$ 13	$ 7	$ 27	$ 20

XML

Employee Benefit Plans (Plan Contributions) (Details) - Qualified Pension Plan [Member] - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	$ 141	$ 8
Duke Energy Carolinas [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	46
Progress Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	45
Duke Energy Progress [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	25
Duke Energy Florida [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	20
Duke Energy Indiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	$ 8
Duke Energy Ohio [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer		$ 4

XML

Employee Benefit Plans (Components of Net Periodic Pension Costs) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Qualified Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	$ 47	$ 40	$ 137	$ 120
Interest cost on projected benefit obligation	74	82	224	246
Expected return on plan assets	(140)	(136)	(420)	(408)
Amortization of actuarial loss (gain)	33	36	99	108
Amortization of prior service (credit) cost	(8)	(6)	(24)	(18)
Other		2		6
Net periodic costs	6	18	16	54
Qualified Pension Plan [Member] | Duke Energy Carolinas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	15	12	45	36
Interest cost on projected benefit obligation	18	20	54	60
Expected return on plan assets	(37)	(35)	(111)	(106)
Amortization of actuarial loss (gain)	7	8	21	24
Amortization of prior service (credit) cost	(2)	(2)	(6)	(6)
Net periodic costs	1	3	3	8
Qualified Pension Plan [Member] | Progress Energy [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	13	12	39	36
Interest cost on projected benefit obligation	24	25	70	75
Expected return on plan assets	(45)	(43)	(133)	(129)
Amortization of actuarial loss (gain)	11	14	33	42
Amortization of prior service (credit) cost	(1)	(1)	(3)	(3)
Other		1		3
Net periodic costs	2	8	6	24
Qualified Pension Plan [Member] | Duke Energy Progress [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	7	6	22	18
Interest cost on projected benefit obligation	10	12	31	36
Expected return on plan assets	(21)	(21)	(63)	(63)
Amortization of actuarial loss (gain)	6	6	16	18
Amortization of prior service (credit) cost			(1)
Other				1
Net periodic costs	2	3	5	10
Qualified Pension Plan [Member] | Duke Energy Florida [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	5	5	16	15
Interest cost on projected benefit obligation	13	13	38	39
Expected return on plan assets	(23)	(21)	(69)	(63)
Amortization of actuarial loss (gain)	6	7	18	21
Amortization of prior service (credit) cost			(1)
Net periodic costs	1	4	2	12
Qualified Pension Plan [Member] | Duke Energy Ohio [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	2	1	4	3
Interest cost on projected benefit obligation	4	4	13	14
Expected return on plan assets	(7)	(7)	(21)	(21)
Amortization of actuarial loss (gain)	1	1	3	3
Net periodic costs		(1)	(1)	(1)
Qualified Pension Plan [Member] | Duke Energy Indiana [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	2	2	7	6
Interest cost on projected benefit obligation	6	7	18	21
Expected return on plan assets	(10)	(11)	(31)	(33)
Amortization of actuarial loss (gain)	2	3	6	9
Net periodic costs		1		3
Qualified Pension Plan [Member] | Piedmont Natural Gas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	2	3	6	9
Interest cost on projected benefit obligation	3	3	9	9
Expected return on plan assets	(6)	(6)	(18)	(18)
Amortization of actuarial loss (gain)	3	3	9	9
Amortization of prior service (credit) cost	(3)	(1)	(9)	(3)
Other				1
Net periodic costs	(1)	2	(3)	7
Non-Qualified Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost			1
Interest cost on projected benefit obligation	3	4	9	10
Amortization of actuarial loss (gain)	2	2	6	6
Amortization of prior service (credit) cost			(1)
Net periodic costs	5	6	15	16
Non-Qualified Pension Plan [Member] | Duke Energy Carolinas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost			1
Interest cost on projected benefit obligation				1
Net periodic costs			1	1
Non-Qualified Pension Plan [Member] | Progress Energy [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Interest cost on projected benefit obligation	1	1	3	3
Amortization of actuarial loss (gain)		1		3
Amortization of prior service (credit) cost			1
Net periodic costs	1	2	4	6
Non-Qualified Pension Plan [Member] | Duke Energy Progress [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Interest cost on projected benefit obligation		1	1	2
Net periodic costs		1	1	2
Non-Qualified Pension Plan [Member] | Duke Energy Florida [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Interest cost on projected benefit obligation		1	1	2
Net periodic costs		1	1	2
Other Post-Retirement Benefit Plans [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	2	1	5	3
Interest cost on projected benefit obligation	7	9	21	27
Expected return on plan assets	(4)	(3)	(10)	(10)
Amortization of actuarial loss (gain)	2	2	5	6
Amortization of prior service (credit) cost	(5)	(29)	(15)	(87)
Net periodic costs	2	(20)	6	(61)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Carolinas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost			1
Interest cost on projected benefit obligation	2	2	5	6
Expected return on plan assets	(2)	(2)	(6)	(6)
Amortization of actuarial loss (gain)	1		2	(2)
Amortization of prior service (credit) cost	(1)	(2)	(3)	(6)
Net periodic costs		(2)	(1)	(8)
Other Post-Retirement Benefit Plans [Member] | Progress Energy [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Interest cost on projected benefit obligation	3	4	9	11
Amortization of actuarial loss (gain)		5	1	15
Amortization of prior service (credit) cost	(2)	(21)	(6)	(63)
Net periodic costs	1	(12)	4	(37)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Progress [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Interest cost on projected benefit obligation	2	2	5	6
Amortization of actuarial loss (gain)		3		9
Amortization of prior service (credit) cost		(14)		(41)
Net periodic costs	2	(9)	5	(26)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Florida [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Interest cost on projected benefit obligation	1	2	4	6
Amortization of actuarial loss (gain)		2		6
Amortization of prior service (credit) cost	(1)	(8)	(4)	(23)
Net periodic costs		(4)		(11)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Ohio [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Interest cost on projected benefit obligation			1
Amortization of actuarial loss (gain)				(1)
Net periodic costs			1	(1)
Other Post-Retirement Benefit Plans [Member] | Duke Energy Indiana [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Interest cost on projected benefit obligation	1	1	3	1
Amortization of actuarial loss (gain)	1		3
Net periodic costs	$ 2	$ 1	6	$ 1
Other Post-Retirement Benefit Plans [Member] | Piedmont Natural Gas [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Amortization of prior service (credit) cost			(1)
Net periodic costs			$ (1)

XML

Employee Benefit Plans (Employee Savings Plans) (Details) - Employee Savings Plan [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	$ 49	$ 43	$ 167	$ 147
Duke Energy Carolinas [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	15	14	53	49
Progress Energy [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	13	12	45	42
Duke Energy Progress [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	9	9	31	30
Duke Energy Florida [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	4	4	14	13
Duke Energy Ohio [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions		1	2	3
Duke Energy Indiana [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	3	2	8	7
Piedmont Natural Gas [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer contributions	$ 4	$ 2	$ 10	$ 5

XML

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Mar. 31, 2018	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Reclassification of ATM credit carryforwards	$ 573
Provisional adjustments for TCJA	3	$ 76	$ 73
Regulatory liability representing revaluation of deferred tax balances	$ 57

XML

Income Taxes (Effective Tax Rates) (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
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	13.70%	27.60%	17.00%	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	22.60%	32.90%	22.30%	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	18.80%	29.10%	17.00%	31.90%
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	20.60%	31.70%	18.40%	32.40%
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	15.00%	34.80%	16.30%	36.10%
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	16.00%	33.30%	16.00%	34.40%
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	22.70%	38.30%	24.70%	39.00%
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	34.40%	47.60%	20.60%	36.10%

XML

Subsequent Events (Narrative) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
	Oct. 10, 2018	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Subsequent Event [Line Items]
Operation, maintenance and other		$ 1,584	$ 1,476	$ 4,592	$ 4,385
Hurricane Michael Storm Damage [Member] | Estimated Impact [Member]
Subsequent Event [Line Items]
Operation, maintenance and other	$ 235
Estimated capital cost	$ 185