10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2020

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 Number
1-32853	DUKE ENERGY CORPORATION	20-2777218

(a Delaware corporation)

550 South Tryon Street

Charlotte, North Carolina 28202-1803

704-382-3853

1-4928 DUKE ENERGY CAROLINAS, LLC 56-0205520

(a North Carolina limited liability company)

526 South Church Street

Charlotte, North Carolina 28202-1803

704-382-3853

1-15929 PROGRESS ENERGY, INC. 56-2155481

(a North Carolina corporation)

410 South Wilmington Street

Raleigh, North Carolina 27601-1748

704-382-3853

1-3382 DUKE ENERGY PROGRESS, LLC 56-0165465

(a North Carolina limited liability company)

410 South Wilmington Street

Raleigh, North Carolina 27601-1748

704-382-3853

1-3274 DUKE ENERGY FLORIDA, LLC 59-0247770

(a Florida limited liability company)

299 First Avenue North

St. Petersburg, Florida 33701

704-382-3853

1-1232 DUKE ENERGY OHIO, INC. 31-0240030

(an Ohio corporation)

139 East Fourth Street

Cincinnati, Ohio 45202

704-382-3853

1-3543 DUKE ENERGY INDIANA, LLC 35-0594457

(an Indiana limited liability company)

1000 East Main Street

Plainfield, Indiana 46168

704-382-3853

1-6196 PIEDMONT NATURAL GAS COMPANY, INC. 56-0556998

(a North Carolina corporation)

4720 Piedmont Row Drive

Charlotte, North Carolina 28210

704-364-3120

SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:

Name of each exchange on

Registrant Title of each class    Trading symbols        which registered

Duke Energy Common Stock, $0.001 par value    DUK    New York Stock Exchange LLC

Duke Energy 5.125% Junior Subordinated Debentures due    DUKH    New York Stock Exchange LLC

January 15, 2073

Duke Energy 5.625% Junior Subordinated Debentures due    DUKB    New York Stock Exchange LLC

September 15, 2078

Duke Energy Depositary Shares, each representing a 1/1,000th    DUK PR A    New York Stock Exchange LLC

interest in a share of 5.75% Series A Cumulative

Redeemable Perpetual Preferred Stock, par value

$0.001 per share

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

Duke Energy Corporation (Duke Energy)	Yes	☒	No	☐	Duke Energy Florida, LLC (Duke Energy Florida)	Yes	☒	No	☐
Duke Energy Carolinas, LLC (Duke Energy Carolinas)	Yes	☒	No	☐	Duke Energy Ohio, Inc. (Duke Energy Ohio)	Yes	☒	No	☐
Progress Energy, Inc. (Progress Energy)	Yes	☒	No	☐	Duke Energy Indiana, LLC (Duke Energy Indiana)	Yes	☒	No	☐
Duke Energy Progress, LLC (Duke Energy Progress)	Yes	☒	No	☐	Piedmont Natural Gas Company, Inc. (Piedmont)	Yes	☒	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	Yes	☒	No	☐	Duke Energy Florida	Yes	☒	No	☐
Duke Energy Carolinas	Yes	☒	No	☐	Duke Energy Ohio	Yes	☒	No	☐
Progress Energy	Yes	☒	No	☐	Duke Energy Indiana	Yes	☒	No	☐
Duke Energy Progress	Yes	☒	No	☐	Piedmont	Yes	☒	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 filer	☒	Accelerated filer	☐	Non-accelerated filer	☐	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Carolinas	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Progress Energy	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Progress	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Florida	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Ohio	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Indiana	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Piedmont	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	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	☐	No	☒	Duke Energy Florida	Yes	☐	No	☒
Duke Energy Carolinas	Yes	☐	No	☒	Duke Energy Ohio	Yes	☐	No	☒
Progress Energy	Yes	☐	No	☒	Duke Energy Indiana	Yes	☐	No	☒
Duke Energy Progress	Yes	☐	No	☒	Piedmont	Yes	☐	No	☒

Number of shares of common stock outstanding at April 30, 2020:

Registrant	Description	Shares
Duke Energy	Common stock, $0.001 par value	734,852,539

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	9
	Duke Energy Carolinas, LLC Financial Statements	14
	Progress Energy, Inc. Financial Statements	18
	Duke Energy Progress, LLC Financial Statements	22
	Duke Energy Florida, LLC Financial Statements	26
	Duke Energy Ohio, Inc. Financial Statements	30
	Duke Energy Indiana, LLC Financial Statements	34
	Piedmont Natural Gas Company, Inc. Financial Statements	38
	Combined Notes to Condensed Consolidated Financial Statements
	Note 1 – Organization and Basis of Presentation	42
	Note 2 – Business Segments	44
	Note 3 – Regulatory Matters	45
	Note 4 – Commitments and Contingencies	58
	Note 5 – Debt and Credit Facilities	61
	Note 6 – Goodwill	62
	Note 7 – Related Party Transactions	63
	Note 8 – Derivatives and Hedging	64
	Note 9 – Investments in Debt and Equity Securities	70
	Note 10 – Fair Value Measurements	75
	Note 11 – Variable Interest Entities	80
	Note 12 – Revenue	84
	Note 13 – Stockholders' Equity	87
	Note 14 – Employee Benefit Plans	88
	Note 15 – Income Taxes	89
	Note 16 – Subsequent Events	90
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	91
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	109
Item 4.	Controls and Procedures	109
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	111
Item 1A.	Risk Factors	111
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	111
Item 6.	Exhibits	112
	Signatures	115

FORWARD-LOOKING STATEMENTS

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:

◦ The impact of the COVID-19 pandemic;

◦ 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 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 United States 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, operational accidents, information technology failures or 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;

◦ The ability to obtain adequate insurance at acceptable costs;

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

FORWARD-LOOKING STATEMENTS

◦ 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 United States 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, including enhancing existing technology systems.

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.

GLOSSARY OF TERMS

Glossary of Terms 

The following terms or acronyms used in this Form 10-Q are defined below:

Term or Acronym	Definition
2013 Settlement	Revised and Restated Stipulation and Settlement Agreement approved in November 2013 among Duke Energy Florida, the Florida OPC and other customer representatives
2017 Settlement	Second Revised and Restated Settlement Agreement in 2017 among Duke Energy Florida, the Florida OPC and other customer representatives, which replaces and supplants the 2013 Settlement
ACP	Atlantic Coast Pipeline, LLC, a limited liability company owned by Dominion Energy, Inc. and Duke Energy
ACP pipeline	The approximately 600-mile proposed interstate natural gas pipeline
AFS	Available for Sale
AFUDC	Allowance for funds used during construction
AMI	Advanced Metering Infrastructure
AMT	Alternative Minimum Tax
ARO	Asset retirement obligations
Bison	Bison Insurance Company Limited
CC	Combined Cycle
CCR	Coal Combustion Residuals
CARES Act	Coronavirus Aid, Relief and Economic Security Act
Citrus County CC	Citrus County Combined Cycle Facility
Coal Ash Act	North Carolina Coal Ash Management Act of 2014
the Company	Duke Energy Corporation and its subsidiaries
Constitution	Constitution Pipeline Company, LLC
COVID-19	Coronavirus Disease 2019
CRC	Cinergy Receivables Company, LLC
Crystal River Unit 3	Crystal River Unit 3 Nuclear Plant
DEFPF	Duke Energy Florida Project Finance, LLC
DEFR	Duke Energy Florida Receivables, LLC
DEPR	Duke Energy Progress Receivables, LLC
DERF	Duke Energy Receivables Finance Company, LLC
Duke Energy	Duke Energy Corporation (collectively with its subsidiaries)
Duke Energy Ohio	Duke Energy Ohio, Inc.
Duke Energy Progress	Duke Energy Progress, LLC
Duke Energy Carolinas	Duke Energy Carolinas, LLC
Duke Energy Florida	Duke Energy Florida, LLC
Duke Energy Indiana	Duke Energy Indiana, LLC
Duke Energy Kentucky	Duke Energy Kentucky, Inc.
Duke Energy Registrants	Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont
EDIT	Excess deferred income tax
EPA	U.S. Environmental Protection Agency
EPS	Earnings Per Share
ESP	Electric Security Plan
ETR	Effective tax rate

GLOSSARY OF TERMS

Exchange Act	Securities Exchange Act of 1934
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FPSC	Florida Public Service Commission
FTR	Financial transmission rights
GAAP	Generally accepted accounting principles in the U.S.
GAAP Reported Earnings	Net Income Available to Duke Energy Corporation Common Stockholders
GAAP Reported EPS	Basic EPS Available to Duke Energy Corporation common stockholders
GWh	Gigawatt-hours
IGCC	Integrated Gasification Combined Cycle
IMR	Integrity Management Rider
IRP	Integrated Resource Plan
IRS	Internal Revenue Service
Investment Trusts	NDTF investments and grantor trusts of Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana
IURC	Indiana Utility Regulatory Commission
KPSC	Kentucky Public Service Commission
LLC	Limited Liability Company
MGP	Manufactured gas plant
MMBtu	Million British Thermal Unit
MW	Megawatt
MWh	Megawatt-hour
NCDEQ	North Carolina Department of Environmental Quality
NCUC	North Carolina Utilities Commission
NDTF	Nuclear decommissioning trust funds
NPNS	Normal purchase/normal sale
OPEB	Other Post-Retirement Benefit Obligations
ORS	South Carolina Office of Regulatory Staff
OTTI	Other-than-temporary impairment
OVEC	Ohio Valley Electric Corporation
Piedmont	Piedmont Natural Gas Company, Inc.
PPA	Purchase Power Agreement
Progress Energy	Progress Energy, Inc.
PSCSC	Public Service Commission of South Carolina
PUCO	Public Utilities Commission of Ohio
ROU assets	Right-of-use assets
Subsidiary Registrants	Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont
the Tax Act	Tax Cuts and Jobs Act
TPUC	Tennessee Public Utility Commission
U.S.	United States
VIE	Variable Interest Entity
WACC	Weighted Average Cost of Capital

FINANCIAL STATEMENTS

ITEM 1. FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Operations

(Unaudited)

	Three Months Ended
	March 31,
(in millions, except per share amounts)	2020			2019
Operating Revenues
Regulated electric	$	5,124		$	5,285
Regulated natural gas	638			728
Nonregulated electric and other	187			150
Total operating revenues	5,949			6,163
Operating Expenses
Fuel used in electric generation and purchased power	1,447			1,609
Cost of natural gas	199			327
Operation, maintenance and other	1,339			1,419
Depreciation and amortization	1,130			1,089
Property and other taxes	345			343
Impairment charges	2			—
Total operating expenses	4,462			4,787
Gains (Losses) on Sales of Other Assets and Other, net	1			(3		)
Operating Income	1,488			1,373
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	44			43
Other income and expenses, net	46			115
Total other income and expenses	90			158
Interest Expense	551			543
Income Before Income Taxes	1,027			988
Income Tax Expense	137			95
Net Income	890			893
Less: Net Loss Attributable to Noncontrolling Interests	(48		)	(7		)
Net Income Attributable to Duke Energy Corporation	938			900
Less: Preferred Dividends	39			—
Net Income Available to Duke Energy Corporation Common Stockholders	$	899		$	900
Earnings Per Share – Basic and Diluted
Net income available to Duke Energy Corporation common stockholders
Basic and Diluted	$	1.24		$	1.24
Weighted average shares outstanding
Basic	734			727
Diluted	736			727

See Notes to Condensed Consolidated Financial Statements

9

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
Net Income	$	890		$	893
Other Comprehensive Loss, net of tax(a)
Pension and OPEB adjustments	1			—
Net unrealized losses on cash flow hedges	(81		)	(17		)
Reclassification into earnings from cash flow hedges	2			1
Unrealized gains on available-for-sale securities	1			4
Other Comprehensive Loss, net of tax	(77		)	(12		)
Comprehensive Income	813			881
Less: Comprehensive Loss Attributable to Noncontrolling Interests	(62		)	(7		)
Comprehensive Income Attributable to Duke Energy	875			888
Less: Preferred Dividends	39			—
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	$	836		$	888

(a) Net of income tax impact of approximately $23 million in the first quarter of 2020 and immaterial income tax impact in the first quarter of 2019.

See Notes to Condensed Consolidated Financial Statements

10

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and cash equivalents	$	1,450		$	311
Receivables (net of allowance for doubtful accounts of $28 at 2020 and $22 at 2019)	809			1,066
Receivables of VIEs (net of allowance for doubtful accounts of $61 at 2020 and $54 at 2019)	1,828			1,994
Inventory	3,324			3,232
Regulatory assets (includes $53 at 2020 and $52 at 2019 related to VIEs)	1,770			1,796
Other (includes $300 at 2020 and $242 at 2019 related to VIEs)	1,000			764
Total current assets	10,181			9,163
Property, Plant and Equipment
Cost	149,676			147,654
Accumulated depreciation and amortization	(46,599		)	(45,773		)
Generation facilities to be retired, net	31			246
Net property, plant and equipment	103,108			102,127
Other Noncurrent Assets
Goodwill	19,303			19,303
Regulatory assets (includes $980 at 2020 and $989 at 2019 related to VIEs)	13,413			13,222
Nuclear decommissioning trust funds	7,052			8,140
Operating lease right-of-use assets, net	1,633			1,658
Investments in equity method unconsolidated affiliates	2,067			1,936
Other (includes $87 at 2020 and $110 at 2019 related to VIEs)	3,315			3,289
Total other noncurrent assets	46,783			47,548
Total Assets	$	160,072		$	158,838
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	2,364		$	3,487
Notes payable and commercial paper	3,033			3,135
Taxes accrued	493			392
Interest accrued	571			565
Current maturities of long-term debt (includes $216 at 2020 and 2019 related to VIEs)	5,077			3,141
Asset retirement obligations	802			881
Regulatory liabilities	826			784
Other	2,004			2,367
Total current liabilities	15,170			14,752
Long-Term Debt (includes $3,966 at 2020 and $3,997 at 2019 related to VIEs)	56,311			54,985
Other Noncurrent Liabilities
Deferred income taxes	9,321			8,878
Asset retirement obligations	12,497			12,437
Regulatory liabilities	14,029			15,264
Operating lease liabilities	1,414			1,432
Accrued pension and other post-retirement benefit costs	919			934
Investment tax credits	659			624
Other (includes $258 at 2020 and $228 at 2019 related to VIEs)	1,669			1,581
Total other noncurrent liabilities	40,508			41,150
Commitments and Contingencies
Equity
Preferred stock, Series A, $0.001 par value, 40 million depositary shares authorized and outstanding at 2020 and 2019	973			973
Preferred stock, Series B, $0.001 par value, 1 million shares authorized and outstanding at 2020 and 2019	989			989
Common stock, $0.001 par value, 2 billion shares authorized; 735 million shares outstanding at 2020 and 733 million shares outstanding at 2019	1			1
Additional paid-in capital	40,930			40,881
Retained earnings	4,221			4,108
Accumulated other comprehensive loss	(193		)	(130		)
Total Duke Energy Corporation stockholders' equity	46,921			46,822
Noncontrolling interests	1,162			1,129
Total equity	48,083			47,951
Total Liabilities and Equity	$	160,072		$	158,838

See Notes to Condensed Consolidated Financial Statements

11

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	890		$	893
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,301			1,238
Equity component of AFUDC	(40		)	(31		)
(Gains) Losses on sales of other assets	(1		)	3
Impairment charges	2			—
Deferred income taxes	422			97
Equity in earnings of unconsolidated affiliates	(44		)	(43		)
Payments for asset retirement obligations	(132		)	(152		)
Provision for rate refunds	(13		)	35
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	—			10
Receivables	466			388
Inventory	(92		)	(31		)
Other current assets	(131		)	98
Increase (decrease) in
Accounts payable	(657		)	(636		)
Taxes accrued	113			(107		)
Other current liabilities	(455		)	(407		)
Other assets	(25		)	(162		)
Other liabilities	(50		)	46
Net cash provided by operating activities	1,554			1,239
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,832		)	(2,536		)
Contributions to equity method investments	(77		)	(94		)
Purchases of debt and equity securities	(1,392		)	(860		)
Proceeds from sales and maturities of debt and equity securities	1,347			851
Other	(68		)	(74		)
Net cash used in investing activities	(3,022		)	(2,713		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	1,954			2,737
Issuance of preferred stock	—			974
Issuance of common stock	40			13
Payments for the redemption of long-term debt	(292		)	(1,201		)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	1,784			135
Payments for the redemption of short-term debt with original maturities greater than 90 days	(17		)	(239		)
Notes payable and commercial paper	(198		)	(304		)
Contributions from noncontrolling interests	103			6
Dividends paid	(707		)	(649		)
Other	(74		)	(39		)
Net cash provided by financing activities	2,593			1,433
Net increase (decrease) in cash, cash equivalents and restricted cash	1,125			(41		)
Cash, cash equivalents and restricted cash at beginning of period	573			591
Cash, cash equivalents and restricted cash at end of period	$	1,698		$	550
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	934		$	811
Non-cash dividends	27			27

See Notes to Condensed Consolidated Financial Statements

12

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

												Accumulated Other Comprehensive
												(Loss) Income
															Net Unrealized						Total
												Net			(Losses) Gains						Duke Energy
			Common			Additional						Losses on			on Available-			Pension and			Corporation
	Preferred		Stock	Common		Paid-in			Retained			Cash Flow			for-Sale-			OPEB			Stockholders'			Noncontrolling			Total
(in millions)	Stock		Shares	Stock		Capital			Earnings			Hedges			Securities			Adjustments			Equity			Interests			Equity
Balance at December 31, 2018	$	—	727	$	1	$	40,795		$	3,113		$	(14	)	$	(3	)	$	(75	)	$	43,817		$	17		$	43,834
Net income (loss)	—		—	—		—			900			—			—			—			900			(7		)	893
Other comprehensive (loss) income	—		—	—		—			—			(16		)	4			—			(12		)	—			(12		)
Preferred stock, Series A, issuances, net of issuance costs(a)	974		—	—		—			—			—			—			—			974			—			974
Common stock issuances, including dividend reinvestment and employee benefits	—		1	—		28			—			—			—			—			28			—			28
Common stock dividends	—		—	—		—			(676		)	—			—			—			(676		)	—			(676		)
Other(b)	—		—	—		—			23			(6		)	(1		)	(17		)	(1		)	5			4
Balance at March 31, 2019	$	974	728	$	1	$	40,823		$	3,360		$	(36	)	$	—		$	(92	)	$	45,030		$	15		$	45,045
Balance at December 31, 2019	$	1,962	733	$	1	$	40,881		$	4,108		$	(51	)	$	3		$	(82	)	$	46,822		$	1,129		$	47,951
Net income (loss)	—		—	—		—			899			—			—			—			899			(48		)	851
Other comprehensive (loss) income	—		—	—		—			—			(65		)	1			1			(63		)	(14		)	(77		)
Common stock issuances, including dividend reinvestment and employee benefits	—		2	—		50			—			—			—			—			50			—			50
Common stock dividends	—		—	—		—			(695		)	—			—			—			(695		)	—			(695		)
Contributions from noncontrolling interest in subsidiaries	—		—	—		—			—			—			—			—			—			103			103
Distributions to noncontrolling interest in subsidiaries	—		—	—		—			—			—			—			—			—			(7		)	(7		)
Other(c)	—		—	—		(1		)	(91		)	—			—			—			(92		)	(1		)	(93		)
Balance at March 31, 2020	$	1,962	735	$	1	$	40,930		$	4,221		$	(116	)	$	4		$	(81	)	$	46,921		$	1,162		$	48,083

(a) Duke Energy issued 40 million depositary shares of preferred stock, Series A.

(b) Amounts in Retained Earnings and Accumulated Other Comprehensive (Loss) Income primarily represent impacts to accumulated other comprehensive income due to implementation of a new accounting standard related to Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.

(c) Amounts in Retained earnings primarily represent impacts due to implementation of a new accounting standard related to Current Estimated Credit Losses. See Note 1 for additional discussion.

See Notes to Condensed Consolidated Financial Statements

13

FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020		2019
Operating Revenues	$	1,748	$	1,744
Operating Expenses
Fuel used in electric generation and purchased power	453		472
Operation, maintenance and other	386		440
Depreciation and amortization	343		317
Property and other taxes	81		80
Impairment charges	2		—
Total operating expenses	1,265		1,309
Gains on Sales of Other Assets and Other, net	1		—
Operating Income	484		435
Other Income and Expenses, net	43		31
Interest Expense	123		110
Income Before Income Taxes	404		356
Income Tax Expense	65		63
Net Income and Comprehensive Income	$	339	$	293

See Notes to Condensed Consolidated Financial Statements

14

FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and cash equivalents	$	16		$	18
Receivables (net of allowance for doubtful accounts of $3 at 2020 and 2019)	212			324
Receivables of VIEs (net of allowance for doubtful accounts of $8 at 2020 and $7 at 2019)	616			642
Receivables from affiliated companies	87			114
Notes receivable from affiliated companies	436			—
Inventory	1,067			996
Regulatory assets	524			550
Other	31			21
Total current assets	2,989			2,665
Property, Plant and Equipment
Cost	49,534			48,922
Accumulated depreciation and amortization	(16,884		)	(16,525		)
Net property, plant and equipment	32,650			32,397
Other Noncurrent Assets
Regulatory assets	3,427			3,360
Nuclear decommissioning trust funds	3,717			4,359
Operating lease right-of-use assets, net	132			123
Other	1,136			1,149
Total other noncurrent assets	8,412			8,991
Total Assets	$	44,051		$	44,053
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	605		$	954
Accounts payable to affiliated companies	225			210
Notes payable to affiliated companies	—			29
Taxes accrued	132			46
Interest accrued	144			115
Current maturities of long-term debt	457			458
Asset retirement obligations	197			206
Regulatory liabilities	275			255
Other	479			611
Total current liabilities	2,514			2,884
Long-Term Debt	12,050			11,142
Long-Term Debt Payable to Affiliated Companies	300			300
Other Noncurrent Liabilities
Deferred income taxes	3,968			3,921
Asset retirement obligations	5,552			5,528
Regulatory liabilities	5,766			6,423
Operating lease liabilities	112			102
Accrued pension and other post-retirement benefit costs	82			84
Investment tax credits	230			231
Other	640			627
Total other noncurrent liabilities	16,350			16,916
Commitments and Contingencies
Equity
Member's equity	12,844			12,818
Accumulated other comprehensive loss	(7		)	(7		)
Total equity	12,837			12,811
Total Liabilities and Equity	$	44,051		$	44,053

See Notes to Condensed Consolidated Financial Statements

15

FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	339		$	293
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	414			388
Equity component of AFUDC	(14		)	(9		)
Gains on sales of other assets	(1		)	—
Impairment charges	2			—
Deferred income taxes	22			64
Payments for asset retirement obligations	(41		)	(65		)
Provision for rate refunds	—			19
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	—			1
Receivables	156			124
Receivables from affiliated companies	27			94
Inventory	(72		)	(59		)
Other current assets	96			(35		)
Increase (decrease) in
Accounts payable	(253		)	(266		)
Accounts payable to affiliated companies	15			18
Taxes accrued	87			(91		)
Other current liabilities	(108		)	(70		)
Other assets	(60		)	(31		)
Other liabilities	(11		)	(7		)
Net cash provided by operating activities	598			368
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(724		)	(721		)
Purchases of debt and equity securities	(607		)	(405		)
Proceeds from sales and maturities of debt and equity securities	607			405
Notes receivable from affiliated companies	(436		)	—
Other	(18		)	(9		)
Net cash used in investing activities	(1,178		)	(730		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	910			25
Payments for the redemption of long-term debt	(2		)	(1		)
Notes payable to affiliated companies	(29		)	306
Distributions to parent	(300		)	—
Other	(1		)	(1		)
Net cash provided by financing activities	578			329
Net decrease in cash and cash equivalents	(2		)	(33		)
Cash and cash equivalents at beginning of period	18			33
Cash and cash equivalents at end of period	$	16		$	—
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	254		$	221

See Notes to Condensed Consolidated Financial Statements

16

FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

				Accumulated Other
				Comprehensive
				Loss
	Member's			Net Losses on			Total
(in millions)	Equity			Cash Flow Hedges			Equity
Balance at December 31, 2018	$	11,689		$	(6	)	$	11,683
Net income	293			—			293
Other	—			(1		)	(1		)
Balance at March 31, 2019	$	11,982		$	(7	)	$	11,975
Balance at December 31, 2019	$	12,818		$	(7	)	$	12,811
Net income	339			—			339
Distributions to parent	(300		)	—			(300		)
Other(a)	(13		)	—			(13		)
Balance at March 31, 2020	$	12,844		$	(7	)	$	12,837

(a) Amounts primarily represent impacts due to implementation of a new accounting standard related to Current Estimated Credit Losses. See Note 1 for additional discussion.

See Notes to Condensed Consolidated Financial Statements

17

FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
Operating Revenues	$	2,422		$	2,572
Operating Expenses
Fuel used in electric generation and purchased power	763			925
Operation, maintenance and other	554			567
Depreciation and amortization	452			455
Property and other taxes	135			137
Total operating expenses	1,904			2,084
Losses on Sales of Other Assets and Other, net	(1		)	—
Operating Income	517			488
Other Income and Expenses, net	32			31
Interest Expense	206			219
Income Before Income Taxes	343			300
Income Tax Expense	60			52
Net Income	283			248
Less: Net Loss Attributable to Noncontrolling Interests	—			(1		)
Net Income Attributable to Parent	$	283		$	249
Net Income	$	283		$	248
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	—			1
Net unrealized gains on cash flow hedges	1			2
Unrealized gains on available-for-sale securities	1			—
Other Comprehensive Income, net of tax	2			3
Comprehensive Income	285			251
Less: Comprehensive Loss Attributable to Noncontrolling Interests	—			(1		)
Comprehensive Income Attributable to Parent	$	285		$	252

See Notes to Condensed Consolidated Financial Statements

18

FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and cash equivalents	$	52		$	48
Receivables (net of allowance for doubtful accounts of $8 at 2020 and $7 at 2019)	159			220
Receivables of VIEs (net of allowance for doubtful accounts of $12 at 2020 and $9 at 2019)	745			830
Receivables from affiliated companies	49			76
Notes receivable from affiliated companies	—			164
Inventory	1,463			1,423
Regulatory assets (includes $53 at 2020 and $52 at 2019 related to VIEs)	954			946
Other (includes $13 at 2020 and $39 at 2019 related to VIEs)	196			210
Total current assets	3,618			3,917
Property, Plant and Equipment
Cost	55,788			55,070
Accumulated depreciation and amortization	(17,461		)	(17,159		)
Generation facilities to be retired, net	31			246
Net property, plant and equipment	38,358			38,157
Other Noncurrent Assets
Goodwill	3,655			3,655
Regulatory assets (includes $980 at 2020 and $989 at 2019 related to VIEs)	6,489			6,346
Nuclear decommissioning trust funds	3,335			3,782
Operating lease right-of-use assets, net	762			788
Other	1,121			1,049
Total other noncurrent assets	15,362			15,620
Total Assets	$	57,338		$	57,694
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	730		$	1,104
Accounts payable to affiliated companies	329			310
Notes payable to affiliated companies	2,300			1,821
Taxes accrued	117			46
Interest accrued	214			228
Current maturities of long-term debt (includes $54 at 2020 and 2019 related to VIEs)	1,828			1,577
Asset retirement obligations	421			485
Regulatory liabilities	347			330
Other	821			902
Total current liabilities	7,107			6,803
Long-Term Debt (includes $1,603 at 2020 and $1,632 at 2019 related to VIEs)	17,377			17,907
Long-Term Debt Payable to Affiliated Companies	150			150
Other Noncurrent Liabilities
Deferred income taxes	4,537			4,462
Asset retirement obligations	6,020			5,986
Regulatory liabilities	4,708			5,225
Operating lease liabilities	678			697
Accrued pension and other post-retirement benefit costs	480			488
Other	404			383
Total other noncurrent liabilities	16,827			17,241
Commitments and Contingencies
Equity
Common Stock, $0.01 par value, 100 shares authorized and outstanding at 2020 and 2019	—			—
Additional paid-in capital	9,143			9,143
Retained earnings	6,747			6,465
Accumulated other comprehensive loss	(16		)	(18		)
Total Progress Energy, Inc. stockholders' equity	15,874			15,590
Noncontrolling interests	3			3
Total equity	15,877			15,593
Total Liabilities and Equity	$	57,338		$	57,694

See Notes to Condensed Consolidated Financial Statements

19

FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	283		$	248
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	552			546
Equity component of AFUDC	(14		)	(15		)
Losses on sales of other assets	1			—
Deferred income taxes	80			82
Payments for asset retirement obligations	(79		)	(75		)
Provision for rate refunds	2			6
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	1			1
Receivables	149			187
Receivables from affiliated companies	27			122
Inventory	(40		)	(18		)
Other current assets	43			35
Increase (decrease) in
Accounts payable	(211		)	(196		)
Accounts payable to affiliated companies	19			(94		)
Taxes accrued	71			26
Other current liabilities	(128		)	(196		)
Other assets	(41		)	(111		)
Other liabilities	(56		)	(7		)
Net cash provided by operating activities	659			541
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(972		)	(1,012		)
Purchases of debt and equity securities	(651		)	(409		)
Proceeds from sales and maturities of debt and equity securities	643			405
Notes receivable from affiliated companies	164			(31		)
Other	(39		)	(45		)
Net cash used in investing activities	(855		)	(1,092		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			1,295
Payments for the redemption of long-term debt	(283		)	(1,132		)
Notes payable to affiliated companies	479			370
Other	(1		)	1
Net cash provided by financing activities	195			534
Net decrease in cash, cash equivalents and restricted cash	(1		)	(17		)
Cash, cash equivalents and restricted cash at beginning of period	126			112
Cash, cash equivalents and restricted cash at end of period	$	125		$	95
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	310		$	310

See Notes to Condensed Consolidated Financial Statements

20

FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

						Accumulated Other Comprehensive Loss
						Net			Net Unrealized						Total Progress
	Additional					Losses on			Losses on			Pension and			Energy, Inc.
	Paid-in		Retained			Cash Flow			Available-for-			OPEB			Stockholders'			Noncontrolling			Total
	Capital		Earnings			Hedges			Sale Securities			Adjustments			Equity			Interests			Equity
Balance at December 31, 2018	$	9,143	$	5,131		$	(12	)	$	(1	)	$	(7	)	$	14,254		$	3		$	14,257
Net income (loss)	—		249			—			—			—			249			(1		)	248
Other comprehensive income	—		—			2			—			1			3			—			3
Other(a)	—		6			(4		)	—			(2		)	—			—			—
Balance at March 31, 2019	$	9,143	$	5,386		$	(14	)	$	(1	)	$	(8	)	$	14,506		$	2		$	14,508
Balance at December 31, 2019	$	9,143	$	6,465		$	(10	)	$	(1	)	$	(7	)	$	15,590		$	3		$	15,593
Net income	—		283			—			—			—			283			—			283
Other comprehensive income	—		—			1			1			—			2			—			2
Other	—		(1		)	—			—			—			(1		)	—			(1		)
Balance at March 31, 2020	$	9,143	$	6,747		$	(9	)	$	—		$	(7	)	$	15,874		$	3		$	15,877

(a) Amounts in Retained Earnings and Accumulated Other Comprehensive Loss primarily represent impacts to accumulated other comprehensive income due to implementation of a new accounting standard related to Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.

See Notes to Condensed Consolidated Financial Statements

21

FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
Operating Revenues	$	1,338		$	1,484
Operating Expenses
Fuel used in electric generation and purchased power	405			515
Operation, maintenance and other	305			335
Depreciation and amortization	287			290
Property and other taxes	47			44
Total operating expenses	1,044			1,184
Losses on Sales of Other Assets and Other, net	(1		)	—
Operating Income	293			300
Other Income and Expenses, net	22			24
Interest Expense	69			77
Income Before Income Taxes	246			247
Income Tax Expense	42			44
Net Income and Comprehensive Income	$	204		$	203

See Notes to Condensed Consolidated Financial Statements

22

FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and cash equivalents	$	32		$	22
Receivables (net of allowance for doubtful accounts of $2 at 2020 and $3 at 2019)	77			123
Receivables of VIEs (net of allowance for doubtful accounts of $7 at 2020 and $5 at 2019)	410			489
Receivables from affiliated companies	50			52
Inventory	956			934
Regulatory assets	503			526
Other	48			60
Total current assets	2,076			2,206
Property, Plant and Equipment
Cost	34,898			34,603
Accumulated depreciation and amortization	(12,114		)	(11,915		)
Generation facilities to be retired, net	31			246
Net property, plant and equipment	22,815			22,934
Other Noncurrent Assets
Regulatory assets	4,392			4,152
Nuclear decommissioning trust funds	2,644			3,047
Operating lease right-of-use assets, net	377			387
Other	682			651
Total other noncurrent assets	8,095			8,237
Total Assets	$	32,986		$	33,377
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	319		$	629
Accounts payable to affiliated companies	208			203
Notes payable to affiliated companies	229			66
Taxes accrued	43			17
Interest accrued	90			110
Current maturities of long-term debt	1,006			1,006
Asset retirement obligations	421			485
Regulatory liabilities	263			236
Other	429			478
Total current liabilities	3,008			3,230
Long-Term Debt	7,903			7,902
Long-Term Debt Payable to Affiliated Companies	150			150
Other Noncurrent Liabilities
Deferred income taxes	2,446			2,388
Asset retirement obligations	5,442			5,408
Regulatory liabilities	3,790			4,232
Operating lease liabilities	344			354
Accrued pension and other post-retirement benefit costs	235			238
Investment tax credits	135			137
Other	83			92
Total other noncurrent liabilities	12,475			12,849
Commitments and Contingencies
Equity
Member's Equity	9,450			9,246
Total Liabilities and Equity	$	32,986		$	33,377

See Notes to Condensed Consolidated Financial Statements

23

FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	204		$	203
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	331			336
Equity component of AFUDC	(10		)	(14		)
Losses on sales of other assets	1			—
Deferred income taxes	43			33
Payments for asset retirement obligations	(75		)	(68		)
Provision for rate refunds	2			6
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(2		)	(3		)
Receivables	133			87
Receivables from affiliated companies	2			(5		)
Inventory	(22		)	(5		)
Other current assets	54			96
Increase (decrease) in
Accounts payable	(220		)	(196		)
Accounts payable to affiliated companies	5			(57		)
Taxes accrued	26			(4		)
Other current liabilities	(73		)	(109		)
Other assets	(51		)	(47		)
Other liabilities	(8		)	(7		)
Net cash provided by operating activities	340			246
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(466		)	(548		)
Purchases of debt and equity securities	(550		)	(315		)
Proceeds from sales and maturities of debt and equity securities	540			308
Notes receivable from affiliated companies	—			(38		)
Other	(16		)	(20		)
Net cash used in investing activities	(492		)	(613		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			1,270
Payments for the redemption of long-term debt	(1		)	(601		)
Notes payable to affiliated companies	163			(294		)
Other	—			(1		)
Net cash provided by financing activities	162			374
Net increase in cash and cash equivalents	10			7
Cash and cash equivalents at beginning of period	22			23
Cash and cash equivalents at end of period	$	32		$	30
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	87		$	117

See Notes to Condensed Consolidated Financial Statements

24

FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Member's
(in millions)	Equity
Balance at December 31, 2018	$	8,441
Net income	203
Balance at March 31, 2019	$	8,644
Balance at December 31, 2019	$	9,246
Net income	204
Balance at March 31, 2020	$	9,450

See Notes to Condensed Consolidated Financial Statements

25

FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020		2019
Operating Revenues	$	1,080	$	1,086
Operating Expenses
Fuel used in electric generation and purchased power	358		410
Operation, maintenance and other	245		230
Depreciation and amortization	165		165
Property and other taxes	88		93
Total operating expenses	856		898
Operating Income	224		188
Other Income and Expenses, net	10		13
Interest Expense	84		82
Income Before Income Taxes	150		119
Income Tax Expense	30		23
Net Income	$	120	$	96
Other Comprehensive Income, net of tax
Unrealized gains on available-for-sale securities	1		1
Comprehensive Income	$	121	$	97

See Notes to Condensed Consolidated Financial Statements

26

FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and cash equivalents	$	12		$	17
Receivables (net of allowance for doubtful accounts of $6 at 2020 and $3 at 2019)	80			96
Receivables of VIEs (net of allowance for doubtful accounts of $5 at 2020 and $4 at 2019)	335			341
Notes receivable from affiliated companies	—			173
Inventory	508			489
Regulatory assets (includes $53 at 2020 and $52 at 2019 related to VIEs)	451			419
Other (includes $13 at 2020 and $39 at 2019 related to VIEs)	37			58
Total current assets	1,423			1,593
Property, Plant and Equipment
Cost	20,880			20,457
Accumulated depreciation and amortization	(5,339		)	(5,236		)
Net property, plant and equipment	15,541			15,221
Other Noncurrent Assets
Regulatory assets (includes $980 at 2020 and $989 at 2019 related to VIEs)	2,097			2,194
Nuclear decommissioning trust funds	691			734
Operating lease right-of-use assets, net	386			401
Other	329			311
Total other noncurrent assets	3,503			3,640
Total Assets	$	20,467		$	20,454
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	411		$	474
Accounts payable to affiliated companies	111			131
Notes payable to affiliated companies	305			—
Taxes accrued	74			43
Interest accrued	79			75
Current maturities of long-term debt (includes $54 at 2020 and 2019 related to VIEs)	322			571
Regulatory liabilities	84			94
Other	383			415
Total current liabilities	1,769			1,803
Long-Term Debt (includes $1,278 at 2020 and $1,307 at 2019 related to VIEs)	7,384			7,416
Other Noncurrent Liabilities
Deferred income taxes	2,192			2,179
Asset retirement obligations	578			578
Regulatory liabilities	918			993
Operating lease liabilities	334			343
Accrued pension and other post-retirement benefit costs	214			218
Other	169			136
Total other noncurrent liabilities	4,405			4,447
Commitments and Contingencies
Equity
Member's equity	6,909			6,789
Accumulated other comprehensive loss	—			(1		)
Total equity	6,909			6,788
Total Liabilities and Equity	$	20,467		$	20,454

See Notes to Condensed Consolidated Financial Statements

27

FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	120		$	96
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	219			207
Equity component of AFUDC	(4		)	(1		)
Deferred income taxes	34			45
Payments for asset retirement obligations	(5		)	(7		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3			2
Receivables	15			55
Receivables from affiliated companies	—			(6		)
Inventory	(19		)	(13		)
Other current assets	7			(35		)
Increase (decrease) in
Accounts payable	11			—
Accounts payable to affiliated companies	(20		)	(62		)
Taxes accrued	31			20
Other current liabilities	(58		)	(84		)
Other assets	13			(63		)
Other liabilities	(46		)	(1		)
Net cash provided by operating activities	301			153
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(506		)	(422		)
Purchases of debt and equity securities	(101		)	(95		)
Proceeds from sales and maturities of debt and equity securities	103			97
Notes receivable from affiliated companies	173			—
Other	(23		)	(25		)
Net cash used in investing activities	(354		)	(445		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			25
Payments for the redemption of long-term debt	(282		)	(81		)
Notes payable to affiliated companies	305			291
Other	(1		)	2
Net cash provided by financing activities	22			237
Net decrease in cash, cash equivalents and restricted cash	(31		)	(55		)
Cash, cash equivalents and restricted cash at beginning of period	56			75
Cash, cash equivalents and restricted cash at end of period	$	25		$	20
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	223		$	193

See Notes to Condensed Consolidated Financial Statements

28

FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

			Accumulated
			Other
			Comprehensive
			Income (Loss)
			Net Unrealized
			Gains on
	Member's		Available-for-Sale			Total
(in millions)	Equity		Securities			Equity
Balance at December 31, 2018	$	6,097	$	(2	)	$	6,095
Net income	96		—			96
Other comprehensive income	—		1			1
Balance at March 31, 2019	$	6,193	$	(1	)	$	6,192
Balance at December 31, 2019	$	6,789	$	(1	)	$	6,788
Net income	120		—			120
Other comprehensive income	—		1			1
Balance at March 31, 2020	$	6,909	$	—		$	6,909

See Notes to Condensed Consolidated Financial Statements

29

FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020		2019
Operating Revenues
Regulated electric	$	346	$	355
Regulated natural gas	152		176
Total operating revenues	498		531
Operating Expenses
Fuel used in electric generation and purchased power	87		93
Cost of natural gas	37		54
Operation, maintenance and other	123		132
Depreciation and amortization	68		64
Property and other taxes	83		84
Total operating expenses	398		427
Operating Income	100		104
Other Income and Expenses, net	3		9
Interest Expense	24		30
Income Before Income Taxes	79		83
Income Tax Expense	14		14
Net Income and Comprehensive Income	$	65	$	69

See Notes to Condensed Consolidated Financial Statements

30

FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and cash equivalents	$	14		$	17
Receivables (net of allowance for doubtful accounts of $5 at 2020 and $4 at 2019)	84			84
Receivables from affiliated companies	52			92
Inventory	121			135
Regulatory assets	33			49
Other	11			21
Total current assets	315			398
Property, Plant and Equipment
Cost	10,401			10,241
Accumulated depreciation and amortization	(2,883		)	(2,843		)
Net property, plant and equipment	7,518			7,398
Other Noncurrent Assets
Goodwill	920			920
Regulatory assets	567			549
Operating lease right-of-use assets, net	21			21
Other	56			52
Total other noncurrent assets	1,564			1,542
Total Assets	$	9,397		$	9,338
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	227		$	288
Accounts payable to affiliated companies	68			68
Notes payable to affiliated companies	399			312
Taxes accrued	170			219
Interest accrued	30			30
Asset retirement obligations	3			1
Regulatory liabilities	66			64
Other	68			75
Total current liabilities	1,031			1,057
Long-Term Debt	2,595			2,594
Long-Term Debt Payable to Affiliated Companies	25			25
Other Noncurrent Liabilities
Deferred income taxes	942			922
Asset retirement obligations	78			79
Regulatory liabilities	760			763
Operating lease liabilities	20			21
Accrued pension and other post-retirement benefit costs	101			100
Other	97			94
Total other noncurrent liabilities	1,998			1,979
Commitments and Contingencies
Equity
Common Stock, $8.50 par value, 120 million shares authorized; 90 million shares outstanding at 2020 and 2019	762			762
Additional paid-in capital	2,776			2,776
Retained earnings	210			145
Total equity	3,748			3,683
Total Liabilities and Equity	$	9,397		$	9,338

See Notes to Condensed Consolidated Financial Statements

31

FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	65		$	69
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	69			65
Equity component of AFUDC	(1		)	(3		)
Deferred income taxes	14			20
Payments for asset retirement obligations	—			(1		)
Provision for rate refunds	3			4
(Increase) decrease in
Receivables	1			5
Receivables from affiliated companies	40			35
Inventory	14			15
Other current assets	8			(6		)
Increase (decrease) in
Accounts payable	(19		)	(5		)
Accounts payable to affiliated companies	—			(8		)
Taxes accrued	(49		)	(45		)
Other current liabilities	2			14
Other assets	(2		)	(10		)
Other liabilities	(8		)	(4		)
Net cash provided by operating activities	137			145
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(217		)	(233		)
Notes receivable from affiliated companies	—			(463		)
Other	(10		)	(11		)
Net cash used in investing activities	(227		)	(707		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			794
Notes payable to affiliated companies	87			(236		)
Net cash provided by financing activities	87			558
Net decrease in cash and cash equivalents	(3		)	(4		)
Cash and cash equivalents at beginning of period	17			21
Cash and cash equivalents at end of period	$	14		$	17
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	66		$	68

See Notes to Condensed Consolidated Financial Statements

32

FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

			Additional		Retained
	Common		Paid-in		Earnings			Total
(in millions)	Stock		Capital		(Deficit)			Equity
Balance at December 31, 2018	$	762	$	2,776	$	(93	)	$	3,445
Net income	—		—		69			69
Balance at March 31, 2019	$	762	$	2,776	$	(24	)	$	3,514
Balance at December 31, 2019	$	762	$	2,776	$	145		$	3,683
Net income	—		—		65			65
Balance at March 31, 2020	$	762	$	2,776	$	210		$	3,748

See Notes to Condensed Consolidated Financial Statements

33

FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020		2019
Operating Revenues	$	692	$	768
Operating Expenses
Fuel used in electric generation and purchased power	194		257
Operation, maintenance and other	186		189
Depreciation and amortization	132		131
Property and other taxes	22		19
Total operating expenses	534		596
Losses on Sales of Other Assets and Other, net	—		(3		)
Operating Income	158		169
Other Income and Expenses, net	10		19
Interest Expense	43		43
Income Before Income Taxes	125		145
Income Tax Expense	26		35
Net Income and Comprehensive Income	$	99	$	110

See Notes to Condensed Consolidated Financial Statements

34

FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and cash equivalents	$	15		$	25
Receivables (net of allowance for doubtful accounts of $3 at 2020 and 2019)	50			60
Receivables from affiliated companies	76			79
Notes receivable from affiliated companies	543			—
Inventory	538			517
Regulatory assets	78			90
Other	36			60
Total current assets	1,336			831
Property, Plant and Equipment
Cost	16,481			16,305
Accumulated depreciation and amortization	(5,349		)	(5,233		)
Net property, plant and equipment	11,132			11,072
Other Noncurrent Assets
Regulatory assets	1,098			1,082
Operating lease right-of-use assets, net	57			57
Other	214			234
Total other noncurrent assets	1,369			1,373
Total Assets	$	13,837		$	13,276
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	157		$	201
Accounts payable to affiliated companies	66			87
Notes payable to affiliated companies	—			30
Taxes accrued	81			49
Interest accrued	60			58
Current maturities of long-term debt	503			503
Asset retirement obligations	181			189
Regulatory liabilities	46			55
Other	92			112
Total current liabilities	1,186			1,284
Long-Term Debt	3,950			3,404
Long-Term Debt Payable to Affiliated Companies	150			150
Other Noncurrent Liabilities
Deferred income taxes	1,158			1,150
Asset retirement obligations	645			643
Regulatory liabilities	1,672			1,685
Operating lease liabilities	54			55
Accrued pension and other post-retirement benefit costs	148			148
Investment tax credits	170			164
Other	30			18
Total other noncurrent liabilities	3,877			3,863
Commitments and Contingencies
Equity
Member's Equity	4,674			4,575
Total Liabilities and Equity	$	13,837		$	13,276

See Notes to Condensed Consolidated Financial Statements

35

FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	99		$	110
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	133			132
Equity component of AFUDC	(6		)	(4		)
Losses on sale of other assets	—			3
Deferred income taxes	16			28
Payments for asset retirement obligations	(12		)	(11		)
(Increase) decrease in
Receivables	15			4
Receivables from affiliated companies	3			20
Inventory	(21		)	(13		)
Other current assets	25			19
Increase (decrease) in
Accounts payable	(13		)	8
Accounts payable to affiliated companies	(21		)	(11		)
Taxes accrued	43			20
Other current liabilities	(27		)	(15		)
Other assets	(4		)	12
Other liabilities	8			6
Net cash provided by operating activities	238			308
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(210		)	(208		)
Purchases of debt and equity securities	(5		)	(6		)
Proceeds from sales and maturities of debt and equity securities	2			4
Notes receivable from affiliated companies	(543		)	—
Other	(6		)	(11		)
Net cash used in investing activities	(762		)	(221		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	544			—
Payments for the redemption of long-term debt	—			(60		)
Notes payable to affiliated companies	(30		)	(31		)
Net cash provided by (used in) financing activities	514			(91		)
Net decrease in cash and cash equivalents	(10		)	(4		)
Cash and cash equivalents at beginning of period	25			24
Cash and cash equivalents at end of period	$	15		$	20
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	70		$	76

See Notes to Condensed Consolidated Financial Statements

36

FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Member's
(in millions)	Equity
Balance at December 31, 2018	$	4,339
Net income	110
Balance at March 31, 2019	$	4,449
Balance at December 31, 2019	$	4,575
Net income	99
Balance at March 31, 2020	$	4,674

See Notes to Condensed Consolidated Financial Statements

37

FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020		2019
Operating Revenues	$	512	$	579
Operating Expenses
Cost of natural gas	162		273
Operation, maintenance and other	80		80
Depreciation and amortization	45		42
Property and other taxes	12		12
Total operating expenses	299		407
Operating Income	213		172
Other Income and Expenses, net	12		6
Interest Expense	27		22
Income Before Income Taxes	198		156
Income Tax Expense	20		34
Net Income and Comprehensive Income	$	178	$	122

See Notes to Condensed Consolidated Financial Statements

38

FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and cash equivalents	$	4		$	—
Receivables (net of allowance for doubtful accounts of $9 at 2020 and $6 at 2019)	191			241
Receivables from affiliated companies	13			10
Inventory	39			72
Regulatory assets	96			73
Other	13			28
Total current assets	356			424
Property, Plant and Equipment
Cost	8,653			8,446
Accumulated depreciation and amortization	(1,703		)	(1,681		)
Net property, plant and equipment	6,950			6,765
Other Noncurrent Assets
Goodwill	49			49
Regulatory assets	263			290
Operating lease right-of-use assets, net	23			24
Investments in equity method unconsolidated affiliates	84			83
Other	132			121
Total other noncurrent assets	551			567
Total Assets	$	7,857		$	7,756
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	145		$	215
Accounts payable to affiliated companies	12			3
Notes payable to affiliated companies	486			476
Taxes accrued	36			24
Interest accrued	32			33
Regulatory liabilities	91			81
Other	54			67
Total current liabilities	856			899
Long-Term Debt	2,385			2,384
Other Noncurrent Liabilities
Deferred income taxes	742			708
Asset retirement obligations	17			17
Regulatory liabilities	1,087			1,131
Operating lease liabilities	22			23
Accrued pension and other post-retirement benefit costs	7			3
Other	121			148
Total other noncurrent liabilities	1,996			2,030
Commitments and Contingencies
Equity
Common stock, no par value: 100 shares authorized and outstanding at 2020 and 2019	1,310			1,310
Retained earnings	1,310			1,133
Total equity	2,620			2,443
Total Liabilities and Equity	$	7,857		$	7,756

See Notes to Condensed Consolidated Financial Statements

39

FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31,
(in millions)	2020			2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	178		$	122
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	46			42
Equity component of AFUDC	(5		)	—
Deferred income taxes	12			23
Equity in earnings from unconsolidated affiliates	(2		)	(2		)
Provision for rate refunds	(18		)	7
(Increase) decrease in
Receivables	65			27
Receivables from affiliated companies	(3		)	12
Inventory	33			45
Other current assets	(9		)	22
Increase (decrease) in
Accounts payable	(76		)	(44		)
Accounts payable to affiliated companies	9			(4		)
Taxes accrued	12			(49		)
Other current liabilities	(12		)	15
Other assets	1			(3		)
Other liabilities	(1		)	(5		)
Net cash provided by operating activities	230			208
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(231		)	(209		)
Other	(5		)	(2		)
Net cash used in investing activities	(236		)	(211		)
CASH FLOWS FROM FINANCING ACTIVITIES
Notes payable to affiliated companies	10			3
Net cash provided by financing activities	10			3
Net increase in cash and cash equivalents	4			—
Cash and cash equivalents at beginning of period	—			—
Cash and cash equivalents at end of period	$	4		$	—
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	114		$	92

See Notes to Condensed Consolidated Financial Statements

40

FINANCIAL STATEMENTS

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, 2018	$	1,160	$	931		$	2,091
Net income	—		122			122
Balance at March 31, 2019	$	1,160	$	1,053		$	2,213
Balance at December 31, 2019	$	1,310	$	1,133		$	2,443
Net income	—		178			178
Other	—		(1		)	(1		)
Balance at March 31, 2020	$	1,310	$	1,310		$	2,620

See Notes to Condensed Consolidated Financial Statements

41

FINANCIAL STATEMENTS 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

Duke Energy

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Carolinas

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Progress Energy

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Progress

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Florida

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Ohio

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Indiana

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Piedmont

•

•

•

•

•

•

•

•

•

•

•

•

•

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

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with 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 and should be read in conjunction with the Consolidated Financial Statements in the Duke Energy Registrants’ combined Annual Report on Form 10-K for the year ended December 31, 2019.

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.

BASIS OF CONSOLIDATION

These Condensed Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and subsidiaries or VIEs where the respective Duke Energy Registrants have control. See Note 11 for additional information on VIEs. These Condensed Consolidated Financial Statements also reflect the Duke Energy Registrants’ proportionate share of certain jointly owned generation and transmission facilities.

COVID-19

The COVID-19 pandemic is having a significant impact on global health and economic environments. In March 2020, the World Health Organization (WHO) declared COVID-19 a global pandemic, and President Trump proclaimed that the COVID-19 outbreak in the United States constitutes a national emergency. The COVID-19 pandemic has not had a material financial impact on the Duke Energy Registrants as of March 31, 2020; however, the extent to which the COVID-19 pandemic will impact the Duke Energy Registrants during 2020 and beyond is uncertain at this time. The Duke Energy Registrants are monitoring developments closely. See Notes 3, 5, 11, 12 and 15 for information on COVID-19 and steps taken to mitigate the impacts to our business and customers.

NONCONTROLLING INTEREST

Duke Energy maintains a controlling financial interest in certain less than wholly owned nonregulated subsidiaries. As a result, Duke Energy consolidates these subsidiaries and presents the third-party investors' portion of Duke Energy's net income (loss), net assets and comprehensive income (loss) as noncontrolling interest. Noncontrolling interest is included as a component of equity on the Condensed Consolidated Balance Sheet.

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FINANCIAL STATEMENTS ORGANIZATION AND BASIS OF PRESENTATION

Several operating agreements of Duke Energy's subsidiaries with noncontrolling interest are subject to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements that vary throughout the lives of the subsidiaries. Therefore, Duke Energy and the other investors' (the owners) interests in the subsidiaries are not fixed, and the subsidiaries apply the Hypothetical Liquidation at Book Value (HLBV) method in allocating income or loss and other comprehensive income or loss (all measured on a pretax basis) to the owners. The HLBV method measures the amounts that each owner would hypothetically claim at each balance sheet reporting date, including tax benefits realized by the owners, upon a hypothetical liquidation of the subsidiary at the net book value of its underlying assets. The change in the amount that each owner would hypothetically receive at the reporting date compared to the amount it would have received on the previous reporting date represents the amount of income or loss allocated to each owner for the reporting period. Duke Energy has received $103 million for the sale of noncontrolling interests to tax equity members for the three months ended March 31, 2020. Duke Energy allocated approximately $49 million and $7 million of losses to noncontrolling tax equity members utilizing the HLBV method for the three months ended March 31, 2020, and March 31, 2019, respectively.

Other operating agreements of Duke Energy's subsidiaries with noncontrolling interest allocate profit and loss based on their pro rata shares of the ownership interest in the respective subsidiary. Therefore, Duke Energy allocates net income or loss and other comprehensive income or loss of these subsidiaries to the owners based on their pro rata shares.

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 VIEs. See Note 11 for additional information. Restricted cash amounts are included in Other within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets. The following table presents the components of cash, cash equivalents and restricted cash included in the Condensed Consolidated Balance Sheets.

	March 31, 2020						December 31, 2019
					Duke						Duke
	Duke		Progress		Energy		Duke		Progress		Energy
	Energy		Energy		Florida		Energy		Energy		Florida
Current Assets
Cash and cash equivalents	$	1,450	$	52	$	12	$	311	$	48	$	17
Other	185		13		13		222		39		39
Other Noncurrent Assets
Other	63		60		—		40		39		—
Total cash, cash equivalents and restricted cash	$	1,698	$	125	$	25	$	573	$	126	$	56

INVENTORY

Provisions for inventory write-offs were not material at March 31, 2020, and December 31, 2019. The components of inventory are presented in the tables below.

	March 31, 2020
			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	$	2,280	$	759	$	1,018	$	678	$	340	$	83	$	319	$	5
Coal	742		268		246		167		79		10		218		—
Natural gas, oil and other fuel	302		40		199		111		89		28		1		34
Total inventory	$	3,324	$	1,067	$	1,463	$	956	$	508	$	121	$	538	$	39

	December 31, 2019
			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	$	2,297	$	768	$	1,038	$	686	$	351	$	79	$	318	$	5
Coal	586		187		186		138		48		15		198		—
Natural gas, oil and other fuel	349		41		199		110		90		41		1		67
Total inventory	$	3,232	$	996	$	1,423	$	934	$	489	$	135	$	517	$	72

NEW ACCOUNTING STANDARDS

The following new accounting standard was adopted by the Duke Energy Registrants in 2020.

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FINANCIAL STATEMENTS ORGANIZATION AND BASIS OF PRESENTATION

Current Expected Credit Losses. In June 2016, the FASB issued new accounting guidance for credit losses. Duke Energy adopted the new accounting guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year results. Duke Energy did not adopt any practical expedients.

Duke Energy recognizes allowances for credit losses based on management's estimate of losses expected to be incurred over the lives of certain assets or guarantees. Management monitors credit quality, changes in expected credit losses and the appropriateness of the allowance for credit losses on a forward-looking basis. Management reviews the risk of loss periodically as part of the existing assessment of collectability of receivables.

Duke Energy reviews the credit quality of its counterparties as part of its regular risk management process and requires credit enhancements, such as deposits or letters of credit, as appropriate and as allowed by regulators.

Duke Energy recorded cumulative effects of changes in accounting principles related to the adoption of new credit loss standard, for allowances for credit losses of trade and other receivables, insurance receivables and financial guarantees. These amounts are included in the Condensed Consolidated Balance Sheets in Receivables, Receivables of VIEs, Other Noncurrent Assets and Other Noncurrent Liabilities. See Notes 4 and 12 for more information.

Duke Energy recorded an adjustment for the cumulative effect of a change in accounting principle due to the adoption of this standard on January 1, 2020, as shown in the table below:

	January 1, 2020
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Piedmont
Total pretax impact to Retained Earnings	$	120	$	16	$	2	$	1	$	1	$	1

The following new accounting standard has been issued but not yet adopted by the Duke Energy Registrants as of March 31, 2020.

Reference Rate Reform. In March 2020, the FASB issued new accounting guidance for reference rate reform. This guidance is elective and provides expedients to facilitate financial reporting for the anticipated transition away from the London Inter-bank Offered Rate (LIBOR) and other interbank reference rates by the end of 2021. The optional expedients are effective for modification of existing contracts or new arrangements executed between March 12, 2020, through December 31, 2022.

Duke Energy has variable-rate debt and manages interest rate risk by entering into financial contracts including interest rate swaps that are generally indexed to LIBOR. Impacted financial arrangements extending beyond 2021 may require contractual amendment or termination to fully adapt to a post-LIBOR environment. Duke Energy is assessing these financial arrangements and is evaluating the use of optional expedients outlined in the new accounting guidance. Alternative index provisions are also being assessed and incorporated into new financial arrangements that extend beyond 2021.

2. BUSINESS SEGMENTS

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 primarily includes Duke Energy's regulated electric utilities in the Carolinas, Florida and the Midwest. 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. The Commercial Renewables segment 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, Duke Energy’s wholly owned captive insurance company, Bison, and Duke Energy's interest in National Methanol Company.

44

FINANCIAL STATEMENTS BUSINESS SEGMENTS

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

	Three Months Ended March 31, 2020
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Total
Unaffiliated revenues	$	5,174	$	640	$	129	$	5,943	$	6		$	—		$	5,949
Intersegment revenues	9		24		—		33		17			(50		)	—
Total revenues	$	5,183	$	664	$	129	$	5,976	$	23		$	(50	)	$	5,949
Segment income (loss)(a)	$	705	$	249	$	57	$	1,011	$	(112	)	$	—		$	899
Add: Noncontrolling interests(b)															(48		)
Add: Preferred stock dividend															39
Net income															$	890
Segment assets	$	134,838	$	14,098	$	6,184	$	155,120	$	4,964		$	(12	)	$	160,072

	Three Months Ended March 31, 2019
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Total
Unaffiliated revenues	$	5,321	$	732	$	106	$	6,159	$	4		$	—		$	6,163
Intersegment revenues	8		24		—		32		17			(49		)	—
Total revenues	$	5,329	$	756	$	106	$	6,191	$	21		$	(49	)	$	6,163
Segment income (loss)	$	750	$	226	$	13	$	989	$	(89	)	$	—		$	900
Add: Noncontrolling interests(b)															(7		)
Net income															$	893

(a) Other includes a $98 million reversal, included in Operations, maintenance and other on the Condensed Consolidated Statements of Operations, of 2018 severance costs due to the partial settlement of the Duke Energy Carolina's 2019 North Carolina rate case. See Note 3 for additional information.

(b) Includes the allocation of losses to noncontrolling tax equity members. See Note 1 for additional information.

Duke Energy Ohio

Duke Energy Ohio has two reportable segments, Electric Utilities and Infrastructure and Gas Utilities and Infrastructure. The remainder of Duke Energy Ohio's operations is presented as Other.

	Three Months Ended March 31, 2020
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Total
Total revenues	$	346	$	152	$	498	$	—		$	—		$	498
Segment income/Net (loss) income	$	30	$	36	$	66	$	(1	)	$	—		$	65
Segment assets	$	6,238	$	3,135	$	9,373	$	26		$	(2	)	$	9,397

	Three Months Ended March 31, 2019
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Total
Total revenues	$	355	$	176	$	531	$	—		$	531
Segment income/Net (loss) income	$	36	$	35	$	71	$	(2	)	$	69

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.

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FINANCIAL STATEMENTS REGULATORY MATTERS

Duke Energy Carolinas and Duke Energy Progress

COVID-19 Filings

North Carolina

On March 10, 2020, Governor Roy Cooper issued Executive Order No. 116 declaring a state of emergency due to the COVID-19 pandemic. In an effort to help mitigate the financial impacts of the COVID-19 pandemic on their customers, on March 19, 2020, Duke Energy Carolinas and Duke Energy Progress filed a request with the NCUC seeking authorization to waive: (1) any late payment charges incurred by a residential or nonresidential customer, effective March 21, 2020; (2) the application of fees for checks returned for insufficient funds for residential and nonresidential customers; (3) the reconnection charge when a residential or nonresidential customer seeks to have service restored for those customers whose service was recently disconnected for nonpayment and to work with customers regarding the other requirements to restore service, including re-establishment of credit; and (4) the fees and charges associated with the use of credit cards or debit cards to pay residential electric utility bills, effective March 21, 2020. The NCUC granted the companies’ request on March 20, 2020.

On March 31, 2020, the governor issued Executive Order No. 124, which, in addition to requiring the steps in the NCUC order noted above, stated that nothing in Executive Order No. 124 shall relieve a customer of its obligation to pay bills for receipt of utility services provided. Executive Order No. 124 remains in effect for 60 days unless otherwise rescinded or replaced with a superseding Executive Order.

On March 31, 2020, the Carolina Utility Customers Association (CUCA) filed a petition with the NCUC to temporarily suspend minimum demand charges for commercial and industrial customers. On April 2, 2020, the NCUC issued an order requiring the North Carolina Public Staff (Public Staff) and Duke Energy Carolinas, Duke Energy Progress and other utilities to file responses. On April 9, 2020, Duke Energy Carolinas and Duke Energy Progress filed responses to CUCA’s petition opposing CUCA’s request. The companies assert that voiding commission-approved tariffs and allowing all commercial and industrial customers on the requested rate schedules to avoid paying a portion of their bills is not legally permissible and would result in these costs unfairly being shifted to other customers that are already paying their respective fair share of similar fixed components. Pursuant to the NCUC’s April 2 order, reply comments were filed by CUCA, the Public Staff and Duke Energy Carolinas and Duke Energy Progress on April 15, 2020. A final order from the NCUC deciding CUCA's request is pending. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

South Carolina

On March 13, 2020, Governor Henry McMaster issued Executive Order No. 2020-08 declaring a state of emergency due to the COVID-19 pandemic. The governor also issued a letter on March 14, 2020, to the ORS Executive Director regarding the suspension of disconnection of essential utility services for nonpayment. On March 16, 2020, citing the governor’s letter, the ORS filed a request asking the PSCSC to grant waivers so that utilities could suspend disconnections of utility services for nonpayment. Duke Energy Carolinas and Duke Energy Progress supported such motion. On March 18, 2020, the PSCSC issued an order approving such waivers, and also approved waivers for regulations related to late fees and reconnect fees. The PSCSC's order also required utilities to track the financial impacts of actions taken pursuant to such waivers for possible reporting to the PSCSC.

On April 30, 2020, the ORS requested the PSCSC grant a waiver of the applicable regulations to allow customers the flexibility to obtain deferred payment plans longer than 6 months for past-due amounts. On May 5, 2020, Duke Energy Carolinas and Duke Energy Progress filed responsive comments stating that while utility bills will remain due, Duke Energy Carolinas and Duke Energy Progress do not plan to immediately reinstitute disconnection upon the expiration of the state of emergency and intend to work through a potential grace period as economic recovery begins. Duke Energy Carolinas and Duke Energy Progress also concurred with the observation of the ORS that reduced usage is impacting the fixed cost recovery and revenue assumptions included in rates. Those costs include not only ongoing operational and financing costs necessary to serve customers, but also the borrowings necessary to support extended payment arrangements that will be an important part of emerging from the COVID-19 pandemic. Duke Energy Carolinas and Duke Energy Progress will continue to track such costs, lost revenues and potential cost savings for future evaluation by the PSCSC.

Additionally, on May 8, 2020, the ORS filed a motion for the PSCSC to solicit comments from utilities and interested stakeholders regarding measures to be taken to mitigate impacts of COVID-19 on utility customers and require recordkeeping. In a detailed motion, the ORS specifically asked the PSCSC to: (1) solicit input from utilities regarding the temporary mitigation measures to address COVID-19; (2) request utilities to inform the PSCSC of the plans utilities have to return to normalized operations; (3) require utilities to track revenue impacts, incremental costs and savings related to COVID-19 and file the findings with the PSCSC on a quarterly basis; and (4) include any other matters that the PSCSC believes should be addressed. The ORS requests that such comments be filed within 30 days of a PSCSC order approving the motion. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

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% increase in annual base revenues. The request for rate increase was driven by capital investments subsequent to the previous base rate case, including the William States Lee Combined Cycle Facility, grid improvement projects, AMI, investments in customer service technologies, costs of complying with CCR regulations and the Coal Ash Act and recovery of costs related to licensing and development of the William States Lee III Nuclear Station.

On February 28, 2018, Duke Energy Carolinas 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% and a capital structure of 52% equity and 48% debt.

On June 22, 2018, the NCUC issued an order approving the Stipulation of Partial Settlement and requiring a revenue reduction.

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FINANCIAL STATEMENTS REGULATORY MATTERS

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 also filed Notices of Appeal to the North Carolina Supreme Court. On August 8, 2018, the Public Staff filed a Notice of Cross Appeal to the North Carolina Supreme Court, which contends the commission’s June 22, 2018, 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. On November 29, 2018, the North Carolina Attorney General's Office filed a motion with the North Carolina Supreme Court requesting the court consolidate the Duke Energy Carolinas and Duke Energy Progress appeals and enter an order adopting the parties’ proposed briefing schedule as set out in the filing. On November 29, 2018, the North Carolina Supreme Court adopted a schedule for briefing set forth in the motion to consolidate the Duke Energy Carolinas and Duke Energy Progress appeals. Appellant briefs were filed on April 26, 2019. The Appellee response briefs were filed on September 25, 2019. Oral arguments before the North Carolina Supreme Court were held on March 11, 2020. Duke Energy Carolinas cannot predict the outcome of this matter.

2019 North Carolina Rate Case

On September 30, 2019, Duke Energy Carolinas filed an application with the NCUC for a net rate increase for retail customers of approximately $291 million, which represented an approximate 6% increase in annual base revenues. The gross rate case revenue increase request was $445 million, which was offset by an EDIT rider of $154 million to return to customers North Carolina and federal EDIT resulting from recent reductions in corporate tax rates. The request for rate increase was driven by major capital investments subsequent to the previous base rate case, coal ash pond closure costs, accelerated coal plant depreciation and deferred 2018 storm costs. Duke Energy Carolinas requested rates be effective no later than August 1, 2020. The NCUC established a procedural schedule with an evidentiary hearing to begin on March 23, 2020. On March 16, 2020, in consideration of public health and safety as a result of the COVID-19 pandemic, Duke Energy Carolinas filed a motion with the NCUC seeking a suspension of the procedural schedule in the rate case, including issuing discovery requests, and postponement of the evidentiary hearing for 60 days. Also on March 16, 2020, the NCUC issued an Order Postponing Hearing and Addressing Procedural Matters, which postponed the evidentiary hearing until further order by the commission.

On March 25, 2020, Duke Energy Carolinas and the Public Staff filed an Agreement and Stipulation of Partial Settlement, which is subject to review and approval of the NCUC, resolving certain issues in the base rate proceeding. Major components of the settlement included:

• Removal of deferred storm costs from the rate case;

• Filing a petition seeking to securitize the deferred storm costs within 120 days of a commission order in this rate case regarding the reasonableness and prudency of the storm costs;

• Agreement of certain assumptions to demonstrate the quantifiable benefits to customers of a securitization financing; and

• Agreement on certain accounting matters, including recovery of employee incentives, severance, aviation costs and executive compensation.

On May 6, 2020, Duke Energy Carolinas, Duke Energy Progress and the Public Staff filed a joint motion requesting that the NCUC issue an order scheduling one consolidated evidentiary hearing to consider the companies’ applications for net rate increases. The joint motion suggests, health and safety permitting, that the commission consider the possibility of holding the consolidated hearing in July. If the NCUC grants the joint motion, Duke Energy Carolinas expects the NCUC to issue an order on its net rate increase by the end of the year. Duke Energy Carolinas cannot predict the outcome of this matter.

2018 South Carolina Rate Case

On November 8, 2018, Duke Energy Carolinas filed an application with the PSCSC for a rate increase for retail customers of approximately $168 million, which represented an approximate 10% increase in retail revenues. The request for rate increase was driven by capital investments and environmental compliance progress made by Duke Energy Carolinas since its previous rate case, including the further implementation of Duke Energy Carolinas’ generation modernization program, which consists of retiring, replacing and upgrading generation plants, investments in customer service technologies and continued investments in base work to maintain its transmission and distribution systems. The request included net tax benefits resulting from the Tax Act of $66 million to reflect the change in ongoing tax expense, primarily from the reduction in the federal income tax rate from 35% to 21%. The request also included $46 million to return EDIT resulting from the federal tax rate change and deferred revenues since January 2018 related to the change and benefits of $17 million from a reduction in North Carolina state income taxes allocable to South Carolina (EDIT Rider).

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FINANCIAL STATEMENTS REGULATORY MATTERS

Duke Energy Carolinas also requested approval of its proposed Grid Improvement Plan (GIP), adjustments to its Prepaid Advantage Program and a variety of accounting orders related to ongoing costs for environmental compliance, including recovery over a five-year period of $242 million of deferred coal ash related compliance costs, grid investments between rate changes, incremental depreciation expense, a result of new depreciation rates from the depreciation study approved in the 2017 North Carolina Rate Case above, and the balance of development costs associated with the cancellation of the Lee Nuclear Project. Finally, Duke Energy Carolinas sought approval to establish a reserve and accrual for end-of-life nuclear costs for nuclear fuel and materials and supplies. On March 8, 2019, the ORS moved to establish a new and separate hearing docket to review and consider the GIP proposed by Duke Energy Carolinas. Subsequently, on March 12, 2019, the ORS and Duke Energy Carolinas executed a Stipulation resolving the ORS’s motion. The Stipulation provided that costs incurred for the GIP after January 1, 2019, would be deferred with a return, subject to evaluation in a future rate proceeding. The Stipulation was approved by the PSCSC on June 19, 2019. On December 16, 2019, Duke Energy Carolinas and Duke Energy Progress filed a Joint Petition to Establish an Informational Docket for Review and Consideration of Grid Improvement Plans through which Duke Energy Carolinas and Duke Energy Progress would provide interested stakeholders information on the companies' grid activities. The PSCSC requested parties comment on procedural matters by January 31, 2020; accordingly, various groups filed comments, none of which opposed an informational docket. Duke Energy Carolinas cannot predict the outcome of this matter.

After hearings in March 2019, the PSCSC issued an order on May 21, 2019, which included a return on equity of 9.5% and a capital structure of 53% equity and 47% debt. The order also included the following material components:

• Approval of cancellation of the Lee Nuclear Project, with Duke Energy Carolinas maintaining the Combined Operating License;

• Approval of recovery of $125 million (South Carolina retail portion) of Lee Nuclear Project development costs (including AFUDC through December 2017) over a 12-year period, but denial of a return on the deferred balance of costs;

• Approval of recovery of $96 million of coal ash costs over a five-year period with a return at Duke Energy Carolinas' WACC;

• Denial of recovery of $115 million of certain coal ash costs deemed to be related to the Coal Ash Act and incremental to the federal CCR rule;

• Approval of a $66 million decrease to base rates to reflect the change in ongoing tax expense, primarily the reduction in the federal income tax rate from 35% to 21%;

• Approval of a $45 million decrease through the EDIT Rider to return EDIT resulting from the federal tax rate change and deferred revenues since January 2018 related to the change, to be returned in accordance with the Average Rate Assumption Method (ARAM) for protected EDIT, over a 20-year period for unprotected EDIT associated with Property, Plant and Equipment, over a five-year period for unprotected EDIT not associated with Property, Plant and Equipment and over a five-year period for the deferred revenues; and

• Approval of a $17 million decrease through the EDIT Rider related to reductions in the North Carolina state income tax rate from 6.9% to 2.5% to be returned over a five-year period.

As a result of the order, revised customer rates were effective June 1, 2019. On May 31, 2019, Duke Energy Carolinas filed a Petition for Rehearing or Reconsideration of that order contending substantial rights of Duke Energy Carolinas were prejudiced by unlawful, arbitrary and capricious rulings by the commission on certain issues presented in the proceeding. On June 19, 2019, the PSCSC issued a Directive denying Duke Energy Carolinas' request to rehear or reconsider the commission's rulings on certain issues presented in the proceeding including coal ash remediation and disposal costs, return on equity and the recovery of a return on deferred operation and maintenance expenses. An order detailing the commission's decision in the Directive was issued on October 18, 2019. Duke Energy Carolinas filed a notice of appeal on November 15, 2019, with the Supreme Court of South Carolina. On November 20, 2019, the South Carolina Energy Users Committee filed a Notice of Appeal and the ORS filed a Notice of Cross Appeal with the Supreme Court of South Carolina. On February 12, 2020, Duke Energy Carolinas and the ORS filed a joint motion to extend briefing schedule deadlines, which was approved by the Supreme Court of South Carolina on February 20, 2020. On March 10, 2020, the ORS filed a consent motion requesting withdrawal of their appeal. Initial briefs were filed on April 21, 2020. Response briefs and reply briefs are due July 6, 2020, and August 11, 2020, respectively. Also on April 21, 2020, the South Carolina Energy User's Committee filed a brief arguing that the PSCSC erred in allowing Duke Energy Carolinas' recovery of costs related to the Lee Nuclear Station. Based on legal analysis and the filing of the appeal, Duke Energy Carolinas has not recorded an adjustment for its deferred coal ash costs. 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% increase in annual base revenues. Subsequent to the filing, Duke Energy Progress adjusted the requested amount to $420 million, representing an approximate 13% increase. The request for rate increase was 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 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% and a capital structure of 52% equity and 48% debt. On February 23, 2018, the NCUC issued an order approving the stipulation.

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FINANCIAL STATEMENTS REGULATORY MATTERS

On May 15, 2018, the Public Staff filed a Notice of Cross Appeal to the North Carolina Supreme Court from the NCUC's February 23, 2018, order. The Public Staff contends the NCUC’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 also filed Notices of Appeal to the North Carolina Supreme Court from the February 23, 2018, order. On November 29, 2018, the North Carolina Attorney General's Office filed a motion with the North Carolina Supreme Court requesting the court consolidate the Duke Energy Progress and Duke Energy Carolinas appeals and enter an order adopting the parties’ proposed briefing schedule as set out in the filing. Appellant briefs were filed on April 26, 2019. The Appellee response briefs were filed on September 25, 2019. Oral arguments before the North Carolina Supreme Court were held on March 11, 2020. Duke Energy Progress cannot predict the outcome of this matter.

2019 North Carolina Rate Case

On October 30, 2019, Duke Energy Progress filed an application with the NCUC for a net rate increase for retail customers of approximately $464 million, which represented an approximate 12.3% increase in annual base revenues. The gross rate case revenue increase request was $586 million, which was offset by riders of $122 million, primarily an EDIT rider of $120 million to return to customers North Carolina and federal EDIT resulting from recent reductions in corporate tax rates. The request for rate increase was driven by major capital investments subsequent to the previous base rate case, coal ash pond closure costs, accelerated coal plant depreciation and deferred 2018 storm costs. Duke Energy Progress seeks to defer and recover incremental Hurricane Dorian storm costs in this proceeding and requests rates be effective no later than September 1, 2020. As a result of the COVID-19 pandemic, on March 24, 2020, the NCUC suspended the procedural schedule and postponed the previously scheduled evidentiary hearing on this matter indefinitely. On April 7, 2020, the NCUC issued an order partially resuming the procedural schedule requiring intervenors to file direct testimony on April 13, 2020. Public Staff filed supplemental direct testimony on April 23, 2020. Duke Energy Progress filed rebuttal testimony on May 4, 2020. On May 6, 2020, Duke Energy Progress, Duke Energy Carolinas and the Public Staff filed a joint motion requesting that the NCUC issue an order scheduling one consolidated evidentiary hearing to consider the companies’ applications for net rate increases. The joint motion suggests, health and safety permitting, that the commission consider the possibility of holding the consolidated hearing in July. If the NCUC grants the joint motion, Duke Energy Progress expects the NCUC to issue an order on its net rate increase by the end of the year. Duke Energy Progress cannot predict the outcome of this matter.

Hurricane Dorian

Hurricane Dorian reached the Carolinas in September 2019 as a Category 2 hurricane making landfall within Duke Energy Progress’ service territory. Approximately 270,000 North Carolina customers and 30,000 South Carolina customers were impacted by the slow-moving storm that brought high winds, tornadoes and heavy rain. With storm-response mobilization occurring in preparation for the storm and the assistance of mutual aid partners, full restoration was accomplished within four days for all customers able to receive service. Total estimated incremental operation and maintenance expenses incurred to repair and restore the system are approximately $177 million with an additional $4 million in capital investments made for restoration efforts. Approximately $151 million and $179 million of the operation and maintenance expenses are deferred in Regulatory assets within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of March 31, 2020, and December 31, 2019, respectively. A request for an accounting order to defer incremental storm costs associated with Hurricane Dorian was included in Duke Energy Progress' October 30, 2019, general rate case filing with the NCUC. Duke Energy Progress cannot predict the outcome of this matter.

On February 7, 2020, a petition was filed with the PSCSC in the 2019 storm deferrals docket requesting deferral of approximately $22 million in operation and maintenance expenses to an existing storm deferral balance previously approved by the PSCSC. The PSCSC voted to approve the request on March 4, 2020, and issued a final order on April 7, 2020.

2018 South Carolina Rate Case

On November 8, 2018, Duke Energy Progress filed an application with the PSCSC for a rate increase for retail customers of approximately $59 million, which represented an approximate 10.3% increase in annual base revenues. The request for rate increase was driven by capital investments and environmental compliance progress made by Duke Energy Progress since its previous rate case, including the further implementation of Duke Energy Progress’ generation modernization program, which consists of retiring, replacing and upgrading generation plants, investments in customer service technologies and continued investments in base work to maintain its transmission and distribution systems. The request included a decrease resulting from the Tax Act of $17 million to reflect the change in ongoing tax expense, primarily the reduction in the federal income tax rate from 35% to 21%. The request also included $10 million to return EDIT resulting from the federal tax rate change and deferred revenues since January 2018 related to the change (EDIT Rider) and a $12 million increase due to the expiration of EDITs related to reductions in North Carolina state income taxes allocable to South Carolina.

Duke Energy Progress also requested approval of its proposed GIP, approval of a Prepaid Advantage Program and a variety of accounting orders related to ongoing costs for environmental compliance, including recovery over a five-year period of $51 million of deferred coal ash related compliance costs, AMI deployment, grid investments between rate changes and regulatory asset treatment related to the retirement of a generating plant located in Asheville, North Carolina. Finally, Duke Energy Progress sought approval to establish a reserve and accrual for end-of-life nuclear costs for materials and supplies and nuclear fuel. On March 8, 2019, the ORS moved to establish a new and separate hearing docket to review and consider the GIP proposed by Duke Energy Progress. Subsequently, on March 12, 2019, the ORS and Duke Energy Carolinas executed a Stipulation resolving the ORS’s motion, and Duke Energy Progress agreed to the Stipulation, as did other parties in the rate case. The Stipulation provided that costs incurred for the GIP after January 1, 2019, would be deferred with a return, with all costs subject to evaluation in a future rate proceeding, and that Duke Energy Progress would refile for consideration of the GIP in a new docket for resolution by January 1, 2020. The Stipulation was approved by the PSCSC on June 19, 2019. On December 16, 2019, Duke Energy Progress and Duke Energy Carolinas filed a Joint Petition to Establish an Informational Docket for Review and Consideration of Grid Improvement Plans through which Duke Energy Progress and Duke Energy Carolinas would provide interested stakeholders information on the companies' grid activities. The PSCSC requested parties comment on procedural matters by January 31, 2020; accordingly, various groups filed comments, none of which opposed an informational docket. Duke Energy Progress cannot predict the outcome of this matter.

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After hearings in April 2019, the PSCSC issued an order on May 21, 2019, which included a return on equity of 9.5% and a capital structure of 53% equity and 47% debt. The order also included the following material components:

• Approval of recovery of $4 million of coal ash costs over a five-year period with a return at Duke Energy Progress' WACC;

• Denial of recovery of $65 million of certain coal ash costs deemed to be related to the Coal Ash Act and incremental to the federal CCR rule;

• Approval of a $17 million decrease to base rates to reflect the change in ongoing tax expense, primarily the reduction in the federal income tax rate from 35% to 21%;

• Approval of a $12 million decrease through the EDIT Tax Savings Rider resulting from the federal tax rate change and deferred revenues since January 2018 related to the change, to be returned in accordance with ARAM for protected EDIT, over a 20-year period for unprotected EDIT associated with Property, Plant and Equipment, over a five-year period for unprotected EDIT not associated with Property, Plant and Equipment and over a three-year period for the deferred revenues; and

• Approval of a $12 million increase due to the expiration of EDIT related to reductions in the North Carolina state income tax rate from 6.9% to 2.5%.

As a result of the order, revised customer rates were effective June 1, 2019. On May 31, 2019, Duke Energy Progress filed a Petition for Rehearing or Reconsideration of that order contending substantial rights of Duke Energy Progress were prejudiced by unlawful, arbitrary and capricious rulings by the commission on certain issues presented in the proceeding. On June 19, 2019, the PSCSC issued a Directive denying Duke Energy Progress' request to rehear or reconsider the commission's rulings on certain issues presented in the proceeding including coal ash remediation and disposal costs, return on equity and the recovery of a return on deferred operation and maintenance expenses, but allowing additional litigation-related costs. As a result of the Directive allowing litigation-related costs, customer rates were revised effective July 1, 2019. An order detailing the commission's decision in the Directive was issued on October 18, 2019. Duke Energy Progress filed a notice of appeal on November 15, 2019, with the Supreme Court of South Carolina. The ORS filed a Notice of Cross Appeal on November 20, 2019. On February 12, 2020, Duke Energy Progress and the ORS filed a joint motion to extend briefing schedule deadlines, which was approved by the Supreme Court of South Carolina on February 20, 2020. On March 10, 2020, the ORS filed a consent motion requesting withdrawal of their appeal. Initial briefs were filed on April 21, 2020. Response briefs and reply briefs are due July 6, 2020, and August 11, 2020, respectively. Based on legal analysis and the filing of the appeal, Duke Energy Progress has not recorded an adjustment for its deferred coal ash costs. Duke Energy Progress cannot predict the outcome of this matter.

Western Carolinas Modernization Plan

On November 4, 2015, Duke Energy Progress announced a Western Carolinas Modernization Plan, which included retirement of the existing Asheville coal-fired plant, the construction of two 280‑MW combined-cycle natural gas plants having dual-fuel capability, with the option to build a third natural gas simple cycle unit in 2023 based upon the outcome of initiatives to reduce the region's power demand. The plan also included upgrades to existing transmission lines and substations, installation of solar generation and a pilot battery storage project.

Duke Energy Progress retired the 376-MW Asheville coal-fired plant on January 29, 2020, at which time the net book value, including associated ash basin closure costs, of $214 million was transferred from Generation facilities to be retired, net to Regulatory assets within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

On March 28, 2016, the NCUC issued an order approving a Certificate of Public Convenience and Necessity (CPCN) for the new combined-cycle natural gas plants with an estimated cost of $893 million, but required Duke Energy Progress to refile for CPCN approval for the contingent simple cycle unit.

On December 27, 2019, Asheville Combined Cycle Power Block 1 and the common systems that serve both combined cycle units went into commercial operation. Power Block 1 consists of the Unit 5 Combustion Turbine and Unit 6 Steam Turbine Generator (which together form the first combined cycle unit approved in the CPCN Order). Power Block 2 consists of the Unit 7 Combustion Turbine and Unit 8 Steam Turbine Generator (which together form the second combined cycle unit approved in the CPCN Order). Duke Energy Progress placed the Unit 7 Combustion Turbine portion of Power Block 2 into commercial operation in simple-cycle mode on January 15, 2020. The Unit 8 Steam Turbine Generator went into commercial operation on April 5, 2020.

On October 8, 2018, Duke Energy Progress filed an application with the NCUC for a CPCN to construct the Hot Springs Microgrid Solar and Battery Storage Facility. On March 22, 2019, Duke Energy Progress and the Public Staff filed a Joint Proposed Order. On May 10, 2019, the NCUC issued an Order Granting Certificate of Public Convenience and Necessity with Conditions. On November 19, 2019, Duke Energy Progress filed a semiannual progress report for its Hot Springs Microgrid Solar and Battery Storage Facility. As required by an NCUC order issued December 6, 2019, an updated progress report was filed on January 15, 2020. An evidentiary hearing was held on March 5, 2020. Construction is expected to begin in the second quarter of 2020 with commercial operation expected to begin in December 2020.

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Duke Energy Florida

COVID-19 Filings

On March 1, 2020, Governor Ron DeSantis issued Executive Order No. 20-51 directing the State Health Officer of Florida to declare a public health emergency in Florida related to the COVID-19 pandemic. The governor then issued a second Executive Order No. 20-52 on March 9, 2020, in which he declared a state of emergency in Florida and directed the Director of the Division of Emergency Management to implement the state’s Comprehensive Emergency Management Plan. The governor issued additional Executive Orders – Nos. 2020-68, 2020-69, 2020-71, 2020-72 and 2020-83 – in response to the ongoing health care emergency that, among other things, suspended the in-person public meeting requirements for state agencies and local governments and directed the state surgeon general to issue public health advisories to limit potential exposure to COVID-19, advising against gatherings of 10 or more persons. On March 19, 2020, Duke Energy Florida filed a request to modify its tariff to allow it to waive late fees for customers, and on April 6, 2020, the FPSC issued an order approving the request. Duke Energy Florida had already voluntarily waived reconnect fees and credit card fees, and is not disconnecting customers for nonpayment. On April 2, 2020, Duke Energy Florida filed a petition with the FPSC to accelerate a $78 million fuel cost refund to customers in the month of May 2020. Typically, the refund would be made over the course of 2021. The FPSC approved the petition on April 28, 2020.

Storm Restoration Cost Recovery

In October 2018, Duke Energy Florida’s service territory suffered damage when Hurricane Michael made landfall as a Category 5 hurricane with maximum sustained winds of 160 mph. The storm caused catastrophic damage from wind and storm surge, particularly from Panama City Beach to Mexico Beach, resulting in widespread outages and significant damage to transmission and distribution facilities across the central Florida Panhandle. In response to Hurricane Michael, Duke Energy Florida restored service to approximately 72,000 customers. Total estimated incremental operation and maintenance and capital costs are $311 million. Approximately $106 million and $107 million of the costs are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2020, and December 31, 2019, respectively. Approximately $205 million and $204 million of costs are included in Regulatory assets within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of March 31, 2020, and December 31, 2019, respectively, representing recoverable costs under the FPSC’s storm rule and Duke Energy Florida's OATT formula rates.

Duke Energy Florida filed a petition with the FPSC on April 30, 2019, to recover the retail portion of estimated incremental storm restoration costs for Hurricane Michael. On June 11, 2019, the FPSC approved the petition for recovery of estimated incremental storm restoration costs related to Hurricane Michael. The FPSC also approved the stipulation Duke Energy Florida filed, which will allow Duke Energy Florida to use the tax savings resulting from the Tax Act to recover these storm costs in lieu of implementing a storm surcharge. Approved storm costs are currently expected to be fully recovered by approximately year-end 2021. On November 22, 2019, Duke Energy Florida filed a petition for approval of actual retail recoverable storm restoration costs related to Hurricane Michael in the amount of $191 million plus interest. An Order Establishing Procedure was issued on January 30, 2020, and hearings are scheduled to begin September 15, 2020. Duke Energy Florida cannot predict the outcome of this matter.

Hurricane Dorian

In September 2019, Duke Energy Florida’s service territory was threatened by Hurricane Dorian with landfall as a possible Category 5 hurricane. For several days, various forecasts and models predicted significant impact to Duke Energy Florida’s service territory; accordingly, Duke Energy Florida incurred costs to secure necessary resources to be prepared for that potential impact. Although Hurricane Dorian never made landfall in Florida, its effects were still felt, and outages did occur. Preparations were required so that, if Hurricane Dorian had made landfall and impacts had been more severe, Duke Energy Florida would have been prepared to restore its customers’ power in a timely fashion.

On December 19, 2019, Duke Energy Florida filed a petition with the FPSC to recover $169 million, the estimated retail portion of these costs, consistent with the provisions in the 2017 Settlement. On February 24, 2020, the commission approved the request for recovery over a 12-month period with rates effective in March 2020 and subject to true up. The final actual amount will be filed later in 2020 and the FPSC will hold a hearing to determine the final amount of incremental costs. Duke Energy Florida cannot predict the outcome of this matter. Approximately $147 million and $167 million of these costs are included in Regulatory assets within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of March 31, 2020, and December 31, 2019, respectively, representing recoverable costs under the FPSC’s storm rule and Duke Energy Florida's OATT formula rates.

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 Settlement. The Hamilton Project, which was placed into service on December 22, 2018, had an annual retail revenue requirement of $15 million. 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, and revised customer rates became effective in January 2019. On April 2, 2019, the commission approved both solar projects as filed. The Columbia Project, which has a projected annual revenue requirement of $14 million, was placed in service in March 2020 and revised customer rates became effective in April 2020.

On March 25, 2019, Duke Energy Florida petitioned the FPSC to include in base rates the revenue requirements for its next wave of solar generation projects, the Trenton, Lake Placid and DeBary Solar Projects, as authorized by the 2017 Settlement. The annual retail revenue requirement for the Trenton and Lake Placid Projects was $13 million and $8 million, respectively, and they were placed into service in December 2019 with rates taking effect in January 2020. The DeBary Project has a projected annual revenue requirement of $11 million and a projected in-service date in the second quarter of 2020. The associated rate increase would take place with the first month’s billing cycle after each solar generation project goes into service. On July 22, 2019, the FPSC issued an order approving Duke Energy Florida's request.

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FINANCIAL STATEMENTS REGULATORY MATTERS

Crystal River Unit 3 Accelerated Decommissioning Filing

On May 29, 2019, Duke Energy Florida entered into a Decommissioning Services Agreement for the accelerated decommissioning of the Crystal River Unit 3 nuclear power station located in Citrus County, Florida, with ADP CR3, LLC and ADP SF1, LLC, each of which is a wholly owned subsidiary of Accelerated Decommissioning Partners, LLC, a joint venture between NorthStar Group Services, Inc. and Orano USA LLC. Closing of this agreement is contingent upon the approval of the U.S. Nuclear Regulatory Commission (NRC) and FPSC. If approved, the decommissioning will be accelerated starting in 2020 and continuing through 2027, rather than the expected time frame under SAFSTOR of starting in 2067 and ending in 2074. Duke Energy Florida expects that the assets of the Nuclear Decommissioning Trust Fund will be sufficient to cover the contract price. On July 10, 2019, Duke Energy Florida petitioned the FPSC for approval of the agreement. On April 1, 2020, the NRC issued an order approving the license transfer application. Following the NRC order, on April 15, 2020, the FPSC issued its Second Order Modifying Order Establishing Procedure in which hearings are scheduled to begin July 7, 2020. Duke Energy Florida cannot predict the outcome of this matter.

Duke Energy Ohio

Duke Energy Ohio COVID-19 Filing

In response to the COVID-19 pandemic, on March 9, 2020, Governor Mike DeWine issued Executive Order No. 2020-01D declaring a state of emergency in the State of Ohio. The PUCO issued an order directing utilities to cease disconnections for nonpayment and waive late payment and reconnection fees and to minimize direct customer contact. The PUCO also directed utilities to maintain flexible payment plans and tariff interpretations to assist customers during this crisis and to seek any regulatory waivers, if necessary. In response, Duke Energy Ohio has ceased all disconnections except for safety-related concerns and is waiving late payment and reconnection fees. On March 19, 2020, Duke Energy Ohio filed its compliance plan with the PUCO and sought waiver of several regulations to minimize direct customer contact.

On April 16, 2020, Duke Energy Ohio filed an application for a Reasonable Arrangement to temporarily lower the minimum bill for demand-metered commercial and industrial customers. The proposal is conditioned on full recovery via Duke Energy Ohio's existing Economic Competitiveness Fund Rider (Rider ECF), which has been used by Duke Energy Ohio in the past for other reasonable arrangements with customers. On April 24, 2020, the Staff of the PUCO filed its recommendation finding Duke Energy Ohio’s application is reasonable and that the PUCO should approve it. Duke Energy Ohio cannot predict the outcome of this matter.

On May 11, 2020, Duke Energy Ohio filed with the PUCO a request seeking deferral of incremental costs incurred, as well as specific miscellaneous lost revenues. The request seeks to use existing bad debts and uncollectible riders already in place for both electric and natural gas operations. Duke Energy Ohio would subsequently file for rider recovery at a later date. Duke Energy Ohio cannot predict the outcome of this matter.

Duke Energy Kentucky COVID-19

In response to the COVID-19 pandemic, on March 6, 2020, Governor Andy Beshear issued Executive Order No. 2020-215 declaring a state of emergency in the Commonwealth of Kentucky. The KPSC issued an order directing utilities to cease disconnections for nonpayment and waive late payment and reconnection fees. The KPSC also directed utilities to maintain flexible payment plans and tariff interpretations to assist customers during this crisis and to seek any regulatory waivers if necessary. Duke Energy Kentucky had already voluntarily ceased all disconnections except for safety-related concerns and was waiving late payment and reconnection fees.

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 ESP. 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 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 term of the ESP would be from June 1, 2018, to May 31, 2025, and included 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. The Stipulation established a regulatory model for the next seven years via the approval of the ESP and continued the current model for procuring supply for non-shopping customers, including recovery mechanisms. On December 19, 2018, the PUCO approved the Stipulation without material modification. Several parties, including the Office of the Ohio Consumers' Counsel (OCC), filed applications for rehearing. On February 6, 2019, the PUCO granted the parties rehearing. The PUCO issued its Second Entry on Rehearing on July 17, 2019, upholding its December 19, 2018 order and denying all assignments of error raised by the non-stipulating parties. On October 11, 2019, the OCC filed its Third Application for Rehearing arguing the PUCO erred in finding OCC’s Second Application for Rehearing as improper. Duke Energy Ohio filed its Memorandum Contra on October 21, 2019. The PUCO denied OCC's Third Application for Rehearing as a matter of law. On September 13, 2019, Interstate Gas Supply/Retail Supply Association filed appeals to the Supreme Court of Ohio claiming the PUCO’s order was in error because it approved unsupported charges to competitive suppliers and cost subsidies shopping customers pay for non-shopping customers. On September 16, 2019, the OCC filed an appeal challenging the PUCO’s approval of OVEC recovery through Duke Energy Ohio's Price Stability Rider (Rider PSR) alleging the FPA pre-empts the commission’s jurisdiction and that the record does not support finding that Rider PSR results in a limitation on shopping. Appellant briefs were filed on January 6, 2020. Appellee briefs were scheduled to be filed on March 16, 2020. On March 13, 2020, the Supreme Court of Ohio granted OCC's motion to withdraw its appeal related to OVEC recovery. On April 22, 2020, the Supreme Court of Ohio dismissed all remaining appeals of PUCO's December 19, 2018 order approving the stipulation. The case has been resolved.

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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 requested an estimated annual increase of approximately $15 million and a return on equity of 10.4%. The application also included 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% and 10.24%. On April 13, 2018, Duke Energy Ohio filed a Motion to consolidate this proceeding with several other cases 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 included a $19 million decrease in annual base distribution revenue with a return on equity unchanged from the current rate of 9.84% based upon a capital structure of 50.75% equity and 49.25% debt. Upon approval of new rates, Duke Energy Ohio's rider for recovering its initial SmartGrid implementation ended as these costs would be recovered through base rates. The Stipulation also renewed 14 existing riders, some of which were included in the company's ESP, and added 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). 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 reduced electric revenue by approximately $20 million on an annualized basis. On December 19, 2018, the PUCO approved the Stipulation without material modification. New base rates were implemented effective January 2, 2019. Several parties, including the OCC, filed applications for rehearing. On February 6, 2019, the PUCO granted the parties rehearing. The PUCO issued its Second Entry on Rehearing on July 17, 2019, upholding its December 19, 2018 order and denying all assignments of error raised by the non-stipulating parties. On October 11, 2019, the OCC filed its Third Application for Rehearing arguing the PUCO erred in finding OCC’s Second Application for Rehearing as improper. Duke Energy Ohio filed its Memorandum Contra on October 21, 2019. The PUCO denied OCC's Third Application for Rehearing as a matter of law. On September 13, 2019, Interstate Gas Supply/Retail Supply Association filed appeals to the Supreme Court of Ohio claiming the PUCO’s order was in error because it approved unsupported charges to competitive suppliers and cost subsidies shopping customers pay for non-shopping customers. On September 16, 2019, the OCC filed an appeal challenging the PUCO’s approval of OVEC recovery through Rider PSR alleging the FPA pre-empts the commission’s jurisdiction and that the record does not support finding that Rider PSR results in a limitation on shopping. Appellant briefs were filed on January 6, 2020. Appellee briefs were scheduled to be filed on March 16, 2020. On March 13, 2020, the Supreme Court of Ohio granted OCC's motion to withdraw its appeal related to OVEC recovery. On April 22, 2020, the Supreme Court of Ohio dismissed all remaining appeals of PUCO's December 19, 2018 order approving the stipulation. The case has been resolved.

Ohio Valley Electric Corporation

On March 31, 2017, Duke Energy Ohio filed for approval to adjust its existing Rider PSR to pass through net costs related to its contractual entitlement to capacity and energy from the generating assets owned by OVEC. Duke Energy Ohio sought deferral authority for net costs incurred from April 1, 2017, until the new rates under Rider PSR were put into effect. 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 activated Rider PSR for recovery of net costs incurred from January 1, 2018, through May 2025. On December 19, 2018, the PUCO approved the Stipulation without material modification. The PSR rider became effective April 1, 2019. Several parties, including the OCC, filed applications for rehearing. On February 6, 2019, the PUCO granted the parties rehearing. The PUCO issued its Second Entry on Rehearing on July 17, 2019, upholding its December 19, 2018 order and denying all assignments of error raised by the non-stipulating parties. On October 11, 2019, the OCC filed its Third Application for Rehearing arguing the PUCO erred in finding OCC’s Second Application for Rehearing as improper. Duke Energy Ohio filed its Memorandum Contra on October 21, 2019. The PUCO denied OCC's Third Application for Rehearing as a matter of law. On September 13, 2019, Interstate Gas Supply/Retail Supply Association filed appeals to the Supreme Court of Ohio claiming the PUCO’s order was in error because it approved unsupported charges to competitive suppliers and cost subsidies shopping customers pay for non-shopping customers. On September 16, 2019, the OCC filed an appeal challenging the PUCO’s approval of OVEC recovery through Rider PSR alleging the FPA pre-empts the commission’s jurisdiction and that the record does not support finding that Rider PSR results in a limitation on shopping. Appellant briefs were filed on January 6, 2020. Appellee briefs were scheduled to be filed on March 16, 2020. On March 13, 2020, the Supreme Court of Ohio granted OCC's motion to withdraw its appeal related to OVEC recovery. On April 22, 2020, the Supreme Court of Ohio dismissed all remaining appeals of PUCO's December 19, 2018 order approving the stipulation. The case has been resolved.

On July 23, 2019, an Ohio bill was signed into law that became effective January 1, 2020. Among other things, the bill allows for recovery of prudently incurred costs, net of any revenues, for Ohio investor-owned utilities that are participants under the OVEC power agreement. The recovery shall be through a non-bypassable rider that is to replace any existing recovery mechanism approved by the PUCO and will remain in place through 2030. The amounts recoverable from customers will be subject to an annual cap, with incremental costs that exceed such cap eligible for deferral and recovery subject to review. See Note 13 for additional discussion of Duke Energy Ohio's ownership interest in OVEC.

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FINANCIAL STATEMENTS REGULATORY MATTERS

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. On April 10, 2019, the PUCO issued an Entry on Rehearing denying the rehearing applications. On February 26, 2020, the PUCO issued an order directing utilities to wind down their demand-side management programs by September 30, 2020, and to terminate the programs by December 31, 2020, in response to changes in Ohio law that eliminated Ohio's energy efficiency mandates. On March 27, 2020, Duke Energy Ohio filed an Application for Rehearing seeking clarification on the final true-up and reconciliation process after 2020. On April 22, 2020, the PUCO granted rehearing for further consideration.

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 for 2017 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 OCC'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.

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 currently estimates the pipeline development costs and construction activities will range from $163 million to $245 million in direct costs (excluding overheads and AFUDC). 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. In April 2018, Duke Energy Ohio filed a motion with OPSB to establish a procedural schedule and filed supplemental information supporting its application. On December 18, 2018, the OPSB established a procedural schedule that included a local public hearing on March 21, 2019. An evidentiary hearing began on April 9, 2019, and concluded on April 11, 2019. Briefs were filed on May 13, 2019, and reply briefs were filed on June 10, 2019. On November 21, 2019, the OPSB approved Duke Energy Ohio's application subject to 41 conditions on construction. Applications for rehearing were filed by several stakeholders on December 23, 2019, arguing that the OPSB approval was incorrect. Duke Energy Ohio filed a memorandum contra on January 2, 2020. On February 20, 2020, the OPSB denied the rehearing requests. Construction of the pipeline extension is expected to be completed before the 2021/2022 winter season. On April 15, 2020, Joint Appellants filed a notice of appeal at the Supreme Court of Ohio of the OPSB’s decision approving Duke Energy Ohio’s Central Corridor application. On April 16, 2020, several of the Joint Appellants filed a motion for a Stay asking the court to suspend the OPSB’s order. On April 27, 2020, Duke Energy Ohio and the OPSB each filed a motion in opposition to the Stay. If the Stay is granted, Duke Energy Ohio cannot continue working during the appeal process. Duke Energy Ohio cannot predict the outcome of this matter.

2012 Natural Gas Rate Case/MGP Cost Recovery

As part of its 2012 natural gas base rate case, Duke Energy Ohio has approval to defer and recover costs related to environmental remediation at two sites (East End and West End) that housed former MGP operations. Duke Energy Ohio has made annual applications for recovery of these deferred costs. Duke Energy Ohio has collected approximately $55 million in environmental remediation costs between 2009 through 2012 through a separate rider, Rider MGP, which is currently suspended. Duke Energy Ohio has made annual applications with the PUCO to recover its incremental remediation costs consistent with the PUCO’s directive in Duke Energy Ohio’s 2012 natural gas rate case. To date, the PUCO has not ruled on Duke Energy Ohio’s annual applications for the calendar years 2013 through 2017. On September 28, 2018, the staff of the PUCO issued a report recommending a disallowance of approximately $12 million of the $26 million in MGP remediation costs incurred between 2013 through 2017 that staff believes are not eligible for recovery. Staff interprets the PUCO’s 2012 Order granting Duke Energy Ohio recovery of MGP remediation as limiting the recovery to work directly on the East End and West End sites. On October 30, 2018, Duke Energy Ohio filed reply comments objecting to the staff’s recommendations and explaining, among other things, the obligation Duke Energy Ohio has under Ohio law to remediate all areas impacted by the former MGPs and not just physical property that housed the former plants and equipment. To date, the PUCO has not ruled on Duke Energy Ohio’s applications. On March 29, 2019, Duke Energy Ohio filed its annual application to recover incremental remediation expense for the calendar year 2018 seeking recovery of approximately $20 million in remediation costs. On July 12, 2019, the staff recommended a disallowance of approximately $11 million for work that staff believes occurred in areas not authorized for recovery. Additionally, staff recommended that any discussion pertaining to Duke Energy Ohio's recovery of ongoing MGP costs should be directly tied to or netted against insurance proceeds collected by Duke Energy Ohio. An evidentiary hearing began on November 18, 2019, and concluded on November 21, 2019. Initial briefs were filed on January 17, 2020, and reply briefs were filed on February 14, 2020. Duke Energy Ohio cannot predict the outcome of this matter.

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FINANCIAL STATEMENTS REGULATORY MATTERS

On March 31, 2020, Duke Energy Ohio filed its annual application to recover incremental remediation expense for the calendar year 2019 seeking recovery of approximately $39 million in remediation costs incurred during 2019. Duke Energy Ohio cannot predict the outcome of this matter.

The 2012 PUCO order also contained conditional deadlines for completing the MGP environmental investigation and remediation costs at the MGP sites. Subsequent to the order, the deadline was extended to December 31, 2019. On May 10, 2019, Duke Energy Ohio filed an application requesting a continuation of its existing deferral authority for MGP remediation and investigation that must occur after December 31, 2019. On September 13, 2019, intervenor comments were filed opposing Duke Energy Ohio's request for continuation of existing deferral authority and on October 2, 2019, Duke Energy Ohio filed reply comments. Duke Energy Ohio cannot predict the outcome of this matter.

Duke Energy Kentucky Electric Base Rate Case

On September 3, 2019, Duke Energy Kentucky filed a rate case with the KPSC requesting an increase in electric base rates of approximately $46 million, which represents an approximate 12.5% increase across all customer classes. The request for rate increase is driven by increased investment in utility plant since the last electric base rate case in 2017. Duke Energy Kentucky seeks to implement a Storm Deferral Mechanism that will enable Duke Energy Kentucky to defer actual costs incurred for major storms that are over or under amounts in base rates. In response to large customers’ desire to have access to renewable resources, Duke Energy Kentucky is proposing a Green Source Advantage tariff designed for those large customers that wish to invest in renewable energy resources to meet sustainability goals. Duke Energy Kentucky is proposing an electric vehicle (EV) infrastructure pilot and modest incentives to assist customers in investing in EV technologies. Additionally, Duke Energy Kentucky is proposing to build an approximate 3.4-MW distribution battery energy storage system to be attached to Duke Energy Kentucky’s distribution system providing frequency regulation and enhanced reliability to Kentucky customers. The commission issued a procedural schedule with two rounds of discovery and opportunities for intervenor and rebuttal testimony. The Kentucky Attorney General filed its testimony recommending an increase of approximately $26 million. On January 31, 2020, Duke Energy Kentucky filed rebuttal testimony updating its rate increase calculations to approximately $44 million. Hearings were held on February 19-20, 2020, with briefing completed March 20, 2020. On April 27, 2020, the KPSC issued its decision approving a $24 million increase for Duke Energy Kentucky with a 9.25% return on equity. The KPSC denied Duke Energy Kentucky’s major storm deferral mechanism and EV and battery storage pilots. The KPSC approved Duke Energy Kentucky’s Green Source Advantage tariff. New customer rates were effective on May 1, 2020. Duke Energy Kentucky is evaluating the order and whether to seek rehearing. Duke Energy Kentucky cannot predict the outcome of this matter.

Duke Energy Indiana

COVID-19

In response to the COVID-19 pandemic, on March 6, 2020, Governor Eric Holcomb issued Executive Order No. 20-02, which by law expired in 30 days unless extended, declaring a public health disaster emergency in the state of Indiana. On April 3, 2020, the governor then issued Executive Order No. 20-17 which renewed the public health disaster emergency declaration for an additional 30 days to May 5, 2020. On May 1, 2020, Executive Order No, 20-25 further renewed the public health disaster emergency an additional 30 days to June 4, 2020. All other Executive Orders issued since March 6, 2020, (Nos. 20-04 – 20-16) were renewed for the same 30-day period, provided they were supplements to Executive Order No. 20-02. Executive Order No. 20-05 was issued on March 19, 2020, requiring utilities in the state to suspend disconnections of utility service. Duke Energy Indiana had already voluntarily suspended all disconnections and is waiving late payment fees and check return fees. The utility is also waiving credit card fees for residential customers.

On May 8, 2020, Duke Energy Indiana, along with other Indiana utilities, filed a request with the IURC for approval of deferral treatment for costs and revenue reductions associated with the COVID-19 pandemic. The utilities requested initial deferral approval in July 2020, with individual subdockets for each utility to be established for consideration of utility-specific cost and revenue impacts, cost recovery timing and customer payment plans. The same day, the Indiana Office of Utility Consumer Counselor filed a petition asking the IURC to continue to suspend disconnections, allow the utilities accounting deferrals and require tacking of cost savings. Duke Energy Indiana cannot predict the outcome of thIs matter.

2019 Indiana Rate Case

On July 2, 2019, Duke Energy Indiana filed a general rate case with the IURC, its first general rate case in 16 years, for a rate increase for retail customers of approximately $395 million. The request for rate increase is driven by strategic investments to generate cleaner electricity, improve reliability and serve a growing customer base. The request is premised upon a Duke Energy Indiana rate base of $10.2 billion as of December 31, 2018, and adjusted for projected changes through December 31, 2020. On September 9, 2019, Duke Energy Indiana revised its revenue request from $395 million to $393 million and filed updated testimony for the Retail Rate Case. The updated filing reflects a clarification in the presentation of Utility Receipts Tax, a $2 million reduction in the revenue requirement for revenues that will remain in riders and changes to allocation of revenue requirements within rate classes. The Utility Receipts Tax is currently embedded in base rates and rider rates. The proposed treatment is to include the Utility Receipts Tax as a line item on the customer bill rather than included in rates. The request is an approximate 15% increase in retail revenues and approximately 17% when including estimated Utility Receipts Tax. The rebuttal case, filed on December 4, 2019, updated the requested revenue requirement to result in a 15.6% or $396 million average retail rate increase, including the impacts of the Utility Receipts Tax. Hearings concluded on February 7, 2020, and rates are expected to be effective mid-2020. Duke Energy Indiana cannot predict the outcome of these matters.

The IURC determined to take two issues out of the rate case and place them in separate subdocket proceedings due to the complexity of the rate case. The commission moved the request for approval of an electric transportation pilot and future coal ash recovery issues to separate subdockets. Coal ash expenditures prior to 2019 are still included in the rate case. Duke Energy Indiana filed testimony on April 15, 2020, in the coal ash subdocket requesting recovery for the post-2018 coal ash basin closure costs for plans that have been approved by the Indiana Department of Environmental Management as well as continuing deferral, with carrying costs, on the balance. An evidentiary hearing is scheduled to begin on September 14, 2020, and an order is expected in the first quarter of 2021. Duke Energy Indiana cannot predict the outcome of this matter.

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FINANCIAL STATEMENTS REGULATORY MATTERS

Piedmont

COVID-19 Filings

North Carolina

On March 10, 2020, Governor Roy Cooper issued Executive Order No. 116 declaring a state of emergency due to the COVID-19 pandemic. In an effort to help mitigate the financial impacts of the COVID-19 pandemic on their customers, on March 19, 2020, Piedmont filed a request with the NCUC seeking authorization to waive: (1) any late payment charges incurred by a residential or nonresidential customer, effective March 21, 2020; (2) the application of fees for checks returned for insufficient funds for residential and nonresidential customers; (3) the reconnection charge when a residential or nonresidential customer seeks to have service restored for those customers whose service was recently disconnected for nonpayment and to work with customers regarding the other requirements to restore service, including re-establishment of credit; and (4) the fees and charges associated with the use of credit cards or debit cards to pay residential electric utility bills, effective March 21, 2020. The NCUC granted Piedmont’s request on March 20, 2020.

On March 31, 2020, the governor issued Executive Order No. 124, which, in addition to requiring the steps in the NCUC order noted above, stated that nothing in Executive Order No. 124 shall relieve a customer of its obligation to pay bills for receipt of utility services provided. Executive Order No. 124 remains in effect for 60 days unless otherwise rescinded or replaced with a superseding Executive Order.

South Carolina

On March 13, 2020, Governor Henry McMaster issued Executive Order No. 2020-08 declaring a state of emergency due to the COVID-19 pandemic. The governor also issued a letter on March 14, 2020, to the ORS Executive Director regarding the suspension of disconnection of essential utility services for nonpayment. On March 16, 2020, citing the governor’s letter, the ORS filed a request asking the PSCSC to grant waivers so that utilities could suspend disconnections of utility services for nonpayment. Piedmont supported such motion. On March 18, 2020, the PSCSC issued an order approving such waivers, and also approved waivers for regulations related to late fees and reconnect fees. The PSCSC's order also required utilities to track the financial impacts of actions taken pursuant to such waivers for possible reporting to the PSCSC.

On April 30, 2020, the ORS requested the PSCSC grant a waiver of the applicable regulations to allow customers the flexibility to obtain deferred payment plans longer than 6 months for past-due amounts. On May 5, 2020, Piedmont filed responsive comments stating that while utility bills will remain due, Piedmont does not plan to immediately reinstitute disconnection upon the expiration of the state of emergency and intends to work through a potential grace period as economic recovery begins. Piedmont also concurred with the observation of the ORS that reduced usage is impacting the fixed cost recovery and revenue assumptions included in rates. Those costs include not only ongoing operational and financing costs necessary to serve customers, but also the borrowings necessary to support extended payment arrangements that will be an important part of emerging from the COVID-19 pandemic. Piedmont will continue to track such costs, lost revenues and potential cost savings for future evaluation by the PSCSC.

Additionally, on May 8, 2020, the ORS filed a motion for the PSCSC to solicit comments from utilities and interested stakeholders regarding measures to be taken to mitigate impacts of COVID-19 on utility customers and require recordkeeping. In a detailed motion, the ORS specifically asked the PSCSC to: (1) solicit input from utilities regarding the temporary mitigation measures to address COVID-19; (2) request utilities to inform the PSCSC of the plans utilities have to return to normalized operations; (3) require utilities to track revenue impacts, incremental costs and savings related to COVID-19 and file the findings with the PSCSC on a quarterly basis; and (4) include any other matters that the PSCSC believes should be addressed. The ORS requests that such comments be filed within 30 days of a PSCSC order approving the motion. Piedmont cannot predict the outcome of this matter.

Tennessee

On March 12, 2020, Governor Bill Lee issued Executive Order No. 14 declaring a state of emergency due to the COVID-19 pandemic. In an effort to help mitigate the financial impacts of the COVID-19 pandemic on their customers, on March 20, 2020, Piedmont filed a request with the TPUC seeking authorization to waive, effective March 21, 2020: (1) any late payment charges incurred by a residential or nonresidential customer; (2) the application of fees for checks returned for insufficient funds for residential and nonresidential customers; and (3) the reconnection charge when a residential or nonresidential customer seeks to have service restored for those customers whose service was recently disconnected for nonpayment and to work with customers regarding the other requirements to restore service, including re-establishment of credit. The TPUC granted Piedmont’s request by Order issued March 31,2020. The Order also stated that customers were not relieved of their obligation to pay for utility services received.

North Carolina Integrity Management Rider Filing

In April 2020, Piedmont filed a petition with the NCUC under the IMR mechanism to collect an additional $15 million in annual revenues, effective June 2020, based on the eligible capital investments closed to integrity and safety projects over the six-month period ending March 31, 2020. Piedmont cannot predict the outcome of this matter.

Tennessee Integrity Management Rider Filing

In November 2019, Piedmont filed a petition with the TPUC under the IMR mechanism to collect an additional $2 million in annual revenues, effective January 2020, based on the eligible capital investments closed to integrity and safety projects over the 12-month period ending October 31, 2019. An evidentiary hearing occurred on May 11, 2020. Upon approval from the TPUC, the revenue adjustment will be implemented, retroactive to January 2020. Piedmont cannot predict the outcome of this matter.

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FINANCIAL STATEMENTS REGULATORY MATTERS

OTHER REGULATORY MATTERS

Atlantic Coast Pipeline, LLC

On September 2, 2014, Duke Energy, Dominion Energy, Inc. (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 be responsible for building and operating the ACP pipeline and holds a leading ownership percentage in ACP of 53%, following the purchase in March 2020 of Southern Company Gas' 5% ownership interest. Duke Energy owns a 47% interest, which is accounted for as an equity method investment through its Gas Utilities and Infrastructure segment. See Note 11 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 and, 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. Due to legal challenges not directly related to the request for a Notice to Proceed in Virginia, this request is still pending.

ACP is the subject of challenges in state and federal courts and agencies, including, among others, challenges of the project’s biological opinion (BiOp) and 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 project's air permit for a compressor station at Buckingham, Virginia, 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. Since December 2018, notable developments in these challenges include a stay in December 2018 issued by the U.S. Court of Appeals for the Fourth Circuit (Fourth Circuit) and the same court's July 26, 2019, vacatur of the project's BiOp and ITS (which stay and subsequent vacatur halted most project construction activity), a Fourth Circuit decision vacating the project's permits to cross the Monongahela and George Washington National Forests and the Appalachian Trail, the Fourth Circuit's remand to USACE of ACP's Huntington District 404 verification, the Fourth Circuit’s remand to the National Park Service of ACP’s Blue Ridge Parkway right-of-way and the most recent vacatur of the air permit for a compressor station at Buckingham, Virginia. ACP is vigorously defending these challenges and coordinating with the federal and state authorities which are the direct parties to the challenges. The Solicitor General of the United States and ACP filed petitions for certiorari to the Supreme Court of the United States on June 25, 2019, regarding the Appalachian Trail crossing and certiorari was granted on October 4, 2019. The Supreme Court hearing took place on February 24, 2020, and a ruling is expected in the second quarter of 2020.

In anticipation of the Fourth Circuit's vacatur of the BiOp and ITS, ACP and the FWS commenced work in mid-May of 2019 to set the basis for a reissued BiOp and ITS. On February 10, 2020, the FERC issued a letter to FWS requesting the re-initiation of formal consultation in support of reissuing the BiOp and ITS, and on April 14, 2020, ACP submitted the Biological Assessment, which may form the foundation for FWS' BiOp. ACP continues coordinating and working with FWS and other parties in preparation for a reissuance of the BiOp and ITS.

ACP triggered the Adverse Government Actions (AGA) clause of its agreements with its customers in December 2019. Formal negotiations have resulted in agreement on material terms, such as updated pricing and construction milestones. The modified customer agreements are expected to be executed by the third quarter of 2020.

On April 15, 2020, the United States District Court for the District of Montana granted partial summary judgment in favor of the plaintiffs in Northern Plains Resource Council v. U.S. Army Corps of Engineers (Northern Plains), vacating USACE’s Nationwide Permit 12 (NWP 12) and remanding it to USACE for consultation under the Endangered Species Act (ESA) of 1973. In Northern Plains, the court ruled that NWP 12 was unlawful because USACE did not consult under the ESA with the FWS and/or National Marine Fisheries Service prior to NWP 12’s reissuance in 2017. Because NWP 12 has been vacated and its application enjoined, USACE currently has suspended verification of any new or pending applications under NWP 12 until further court action clarifies the situation. ACP is reviewing the potential impact of this ruling to its own reliance on NWP 12 for small water body crossings along the pipeline route, as well as potential mitigation measures.

Given the legal challenges and ongoing discussions with customers, ACP expects the project to enter full in-service in the first half of 2022.

The delays resulting from the legal challenges described above have also impacted the cost for the project. Project cost is approximately $8 billion, excluding financing costs. This estimate is based on the current facts available around construction costs and timelines, and is subject to future changes as those facts develop. Abnormal weather, work delays (including delays due to judicial or regulatory action or COVID-19 social distancing) and other conditions may result in cost or schedule modifications, a suspension of AFUDC for ACP and/or impairment charges potentially material to Duke Energy's cash flows, financial position and results of operations.

Duke Energy’s investment in ACP was $1.2 billion at March 31, 2020. Duke Energy evaluated this investment for impairment at March 31, 2020, and December 31, 2019, and determined that fair value approximated carrying value and therefore no impairment was necessary. Duke Energy also has a guarantee agreement supporting its share of the ACP revolving credit facility. Duke Energy’s maximum exposure to loss under the terms of the guarantee is $845 million, which represents 47% of the outstanding borrowings under the credit facility as of March 31, 2020. See Note 13 for additional information.

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FINANCIAL STATEMENTS REGULATORY MATTERS

Constitution Pipeline Company, LLC

Duke Energy owned a 24% ownership interest in Constitution, which was accounted for as an equity method investment. Constitution was 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 was to be constructed and operated by Williams Partners L.P., which had a 41% ownership share. The remaining interest was held by Cabot Oil and Gas Corporation and WGL Holdings, Inc. In December 2014, Constitution received approval from the FERC to construct and operate the proposed pipeline. However, since April 2016, Constitution had stopped construction and discontinued capitalization of future development costs due to permitting delays and adverse rulings by regulatory agencies and courts.

In late 2019, Constitution determined that its principal shipper would not agree to an amended precedent agreement. Without such an amendment, the project would no longer be viable and, as of February 5, 2020, the Constitution partners formally resolved to initiate the dissolution of Constitution, and to terminate the Constitution Pipeline project. See Note 11 for additional information related to ownership interest and carrying value of the investment. Williams Partners L.P., as project Operator, is currently working to liquidate the project's assets.

Potential Coal Plant Retirements

The Subsidiary Registrants periodically file IRPs 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 and Indiana earlier than their current estimated useful lives. Duke Energy continues to evaluate the potential need to retire these coal-fired generating facilities earlier than the current estimated useful lives and plans to seek regulatory recovery for amounts that would not be otherwise recovered when any of these assets are retired.

The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2020, 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	$	149
Duke Energy Indiana
Gallagher Units 2 and 4(b)	280	118
Gibson Units 1-5(c)	3,132	1,708
Cayuga Units 1-2(c)	1,005	964
Total Duke Energy	5,002	$	2,939

(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 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.

(c) On July 1, 2019, Duke Energy Indiana filed its 2018 IRP with the IURC. The 2018 IRP included scenarios evaluating the potential retirement of coal-fired generating units at Gibson and Cayuga. The rate case filed July 2, 2019, includes proposed depreciation rates reflecting retirement dates from 2026 to 2038.

Duke Energy continues to evaluate the potential need to retire generating facilities earlier than the current estimated useful lives, and plans to seek regulatory recovery, as necessary, for amounts that would not be otherwise recovered when any of these assets are retired. However, such recovery, including recovery of carrying costs on remaining book values, could be subject to future approvals and therefore cannot be assured.

Duke Energy Carolinas and Duke Energy Progress are evaluating the potential for coal-fired generating unit retirements with a net carrying value of approximately $707 million and $1.2 billion, respectively, included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2020.

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, coal ash 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 Duke Energy Registrants.

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FINANCIAL STATEMENTS COMMITMENTS AND CONTINGENCIES

Remediation Activities

In addition to AROs recorded as a result of various environmental regulations, the Duke Energy Registrants are responsible for environmental remediation at various sites. These include certain properties that are part of ongoing operations and sites formerly owned or used by Duke Energy entities. These sites are in various stages of investigation, remediation and monitoring. Managed in conjunction with relevant federal, state and local agencies, remediation activities vary based upon site conditions and location, remediation requirements, complexity and sharing of responsibility. If remediation activities involve joint and several liability provisions, strict liability, or cost recovery or contribution actions, the Duke Energy Registrants could potentially be held responsible for environmental impacts caused by other potentially responsible parties and may also benefit from insurance policies or contractual indemnities that cover some or all cleanup costs. Liabilities are recorded when losses become probable and are reasonably estimable. The total costs that may be incurred cannot be estimated because the extent of environmental impact, allocation among potentially responsible parties, remediation alternatives and/or regulatory decisions have not yet been determined at all sites. Additional costs associated with remediation activities are likely to be incurred in the future and could be significant. Costs are typically expensed as Operation, maintenance and other on the Condensed Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.

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

	Three Months Ended March 31, 2020
				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	$	58		$	11		$	16		$	4	$	9	$	19		$	4	$	8
Provisions/adjustments	3			—			—			1		—		1			1		—
Cash reductions	(3		)	(1		)	(1		)	—		—		(1		)	—		—
Balance at end of period	$	58		$	10		$	15		$	5	$	9	$	19		$	5	$	8

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	$	58
Duke Energy Carolinas	11
Duke Energy Ohio	41
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. Despite a stay of the litigation from May 2019 through September 2019 to allow the parties to discuss potential resolution, no resolution was reached, and litigation resumed. In February and March 2020, the court heard arguments on numerous cross motions filed by the parties to seek legal determinations concerning several insurance related defenses raised by the insurance providers. Trial is scheduled for February 2021. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

Duke Energy Carolinas

Asbestos-related Injuries and Damages Claims

Duke Energy Carolinas has experienced numerous claims for indemnification and medical cost reimbursement related to asbestos exposure. These claims relate to damages for bodily injuries alleged to have arisen from exposure to or use of asbestos in connection with construction and maintenance activities conducted on its electric generation plants prior to 1985. As of March 31, 2020, there were 118 asserted claims for non-malignant cases with cumulative relief sought of up to $30 million, and 51 asserted claims for malignant cases with cumulative relief sought of up to $17 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.

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FINANCIAL STATEMENTS COMMITMENTS AND CONTINGENCIES

Duke Energy Carolinas has recognized asbestos-related reserves of $596 million at March 31, 2020, and $604 million at December 31, 2019. 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 Duke Energy Carolinas' best estimate for current and future asbestos claims through 2039 and are recorded on an undiscounted basis. 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 2039 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-insured 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 $747 million in excess of the self-insured retention. Receivables for insurance recoveries were $742 million at March 31, 2020, and $742 million at December 31, 2019. 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 June 18, 2018, Duke Energy Progress and Duke Energy Florida sued the U.S. in the U.S. Court of Federal Claims for damages incurred for the period 2014 through 2018. 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 in the amount of $100 million and $203 million for Duke Energy Progress and Duke Energy Florida, respectively. Discovery is ongoing and a trial is expected to occur in early 2021.

Duke Energy Indiana

Coal Ash Basin Closure Plan Appeal

On January 27, 2020, Hoosier Environmental Council filed a Petition for Administrative Review with the Indiana Office of Environmental Adjudication (the court) challenging the Indiana Department of Environmental Management’s December 10, 2019, partial approval of Duke Energy Indiana’s ash pond closure plan. On March 11, 2020, Duke Energy Indiana filed a Motion to Dismiss. On May 5, 2020, the court entered an order denying that motion. The court will schedule a trial on the merits for a future date. Duke Energy Indiana cannot predict the outcome of this matter.

Other Litigation and Legal Proceedings

The Duke Energy Registrants are involved in other legal, tax and regulatory proceedings arising in the ordinary course of business, some of which involve significant amounts. The Duke Energy Registrants believe the final disposition of these proceedings will not have a material effect on their results of operations, cash flows or financial position.

The table below presents recorded reserves based on management’s best estimate of probable loss for legal matters, excluding asbestos-related reserves discussed above. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Other Noncurrent Liabilities and Other within Current Liabilities. The reasonably possible range of loss in excess of recorded reserves is not material, other than as described above.

(in millions)	March 31, 2020		December 31, 2019
Reserves for Legal Matters
Duke Energy	$	61	$	62
Duke Energy Carolinas	3		2
Progress Energy	52		55
Duke Energy Progress	9		12
Duke Energy Florida	23		22
Piedmont	1		1

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 uncapped 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.

60

FINANCIAL STATEMENTS COMMITMENTS AND CONTINGENCIES

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 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.

As described in Note 1, Duke Energy adopted the new guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. The reserve for credit losses for insurance receivables based on adoption of the new standard is $15 million for Duke Energy and Duke Energy Carolinas. Insurance receivables are evaluated based on the risk of default and the historical losses, current conditions and expected conditions around collectability. Management evaluates the risk of default annually based on payment history, credit rating and changes in the risk of default from credit agencies.

The reserve for credit losses for financial guarantees based on adoption of the new standard is $99 million for Duke Energy. Management considers financial guarantees for evaluation under this standard based on the anticipated amount outstanding at the time of default. The reserve for credit losses is based on the evaluation of the contingent components of financial guarantees. Management evaluates the risk of default, exposure and length of time remaining in the period for each contract.

5. DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

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

					Three Months Ended March 31, 2020
							Duke		Duke		Duke
	Maturity	Interest			Duke		Energy		Energy		Energy
Issuance Date	Date	Rate			Energy		(Parent)		Carolinas		Indiana
Unsecured Debt
March 2020(a)	March 2021	1.400	%	(b)	$	1,688	$	1,688	$	—	$	—
First Mortgage Bonds
January 2020(c)	February 2030	2.450	%		500		—		500		—
January 2020(c)	August 2049	3.200	%		400		—		400		—
March 2020(d)	April 2050	2.750	%		550		—		—		550
Total issuances					$	3,138	$	1,688	$	900	$	550

(a) Debt issued in response to market volatility concerns related to the COVID-19 pandemic. Refer to Note 1 for additional information on the COVID-19 pandemic. Proceeds will be used to reduce outstanding commercial paper and for general corporate purposes.

(b) Debt issuance has a floating interest rate.

(c) Debt issued to repay at maturity $450 million first mortgage bonds due June 2020 and for general corporate purposes.

(d) Debt issued to repay at maturity $500 million first mortgage bonds due July 2020 and to pay down short-term debt.

CURRENT MATURITIES OF LONG-TERM DEBT

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

(in millions)	Maturity Date	Interest Rate			March 31, 2020
Unsecured Debt
Duke Energy (Parent)	June 2020	2.100	%		$	330
Duke Energy Progress	December 2020	2.292	%	(a)	700
Progress Energy, Inc	January 2021	4.400	%		500
Duke Energy (Parent)	March 2021	1.400	%	(a)	1,688
First Mortgage Bonds
Duke Energy Florida	April 2020	4.550	%		250
Duke Energy Carolinas	June 2020	4.300	%		450
Duke Energy Indiana	July 2020	3.750	%		500
Duke Energy Progress	September 2020	1.076	%	(a)	300
Other(b)					359
Current maturities of long-term debt					$	5,077

(a)    Debt issuance has a floating interest rate.

(b)    Includes finance lease obligations, amortizing debt and small bullet maturities.

61

FINANCIAL STATEMENTS DEBT AND CREDIT FACILITIES

AVAILABLE CREDIT FACILITIES

Master Credit Facility

In March 2020, Duke Energy amended its existing $8 billion Master Credit Facility to extend the termination date to March 2025. The Duke Energy Registrants, excluding Progress Energy, 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. This requirement expires on May 15, 2020.

The table below includes the current borrowing sublimits and available capacity under these credit facilities.

	March 31, 2020
				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		$	1,500		$	1,250		$	800		$	600		$	600		$	600
Reduction to backstop issuances
Commercial paper(b)	(2,540		)	(1,140		)	(300		)	(275		)	(167		)	(243		)	(150		)	(265		)
Outstanding letters of credit	(49		)	(42		)	(4		)	(2		)	—			—			—			(1		)
Tax-exempt bonds	(81		)	—			—			—			—			—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—			—
Available capacity under the Master Credit Facility	$	4,830		$	1,468		$	946		$	723		$	633		$	357		$	369		$	334

(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.

Other Credit Facilities

	March 31, 2020
(in millions)	Facility size		Amount drawn
Duke Energy (Parent) Three-Year Revolving Credit Facility(a)	$	1,000	$	1,000
Duke Energy Progress Term Loan Facility	700		700

(a) In March 2020, Duke Energy (Parent) drew down the remaining $500 million.

6. GOODWILL

Duke Energy

The following table presents the goodwill by reportable segment included on Duke Energy's Condensed Consolidated Balance Sheets at March 31, 2020, and December 31, 2019.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables			Total
Goodwill balance	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(122		)	(122		)
Goodwill, 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 March 31, 2020, and December 31, 2019.

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FINANCIAL STATEMENTS GOODWILL

Progress Energy

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

Piedmont

Piedmont's Goodwill is included in the Gas Utilities and Infrastructure segment and there are no accumulated impairment charges.

7. 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 March 31,
(in millions)	2020		2019
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	134	$	212
Indemnification coverages(b)	5		5
Joint Dispatch Agreement (JDA) revenue(c)	7		23
JDA expense(c)	24		93
Intercompany natural gas purchases(d)	6		4
Progress Energy
Corporate governance and shared service expenses(a)	$	146	$	176
Indemnification coverages(b)	9		9
JDA revenue(c)	24		93
JDA expense(c)	7		23
Intercompany natural gas purchases(d)	19		19
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	75	$	106
Indemnification coverages(b)	4		4
JDA revenue(c)	24		93
JDA expense(c)	7		23
Intercompany natural gas purchases(d)	19		19
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	70
Indemnification coverages(b)	5		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	84	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	106	$	97
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	34	$	32
Indemnification coverages(b)	1		1
Intercompany natural gas sales(d)	25		23
Natural gas storage and transportation costs(e)	6		5

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FINANCIAL STATEMENTS RELATED PARTY TRANSACTIONS

(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 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.

(e) Piedmont has related party transactions as a customer of its equity method investments in Pine Needle LNG Company, LLC, Hardy Storage Company, LLC and Cardinal Pipeline Company, LLC natural gas storage and transportation facilities. These expenses are included in Cost of natural gas on Piedmont's Condensed Consolidated Statements of Operations and Comprehensive Income.

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, such as pipeline lease arrangements, and their proportionate share of certain charged expenses. These transactions of the Subsidiary Registrants are incurred in the ordinary course of business and are eliminated in consolidation.

As discussed in Note 11, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to CRC, an affiliate formed by a subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but do include a subordinated note from CRC for a portion of the purchase price.

Intercompany Income Taxes

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

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
March 31, 2020
Intercompany income tax receivable	$	—	$	114	$	1	$	4	$	—	$	—	$	—
Intercompany income tax payable	44		—		—		—		—		6		10
December 31, 2019
Intercompany income tax receivable	$	—	$	125	$	28	$	—	$	9	$	28	$	13
Intercompany income tax payable	5		—		—		2		—		—		—

8. 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 derivatives 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.

64

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

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 accumulated other comprehensive income (loss) for the three months ended March 31, 2020, and 2019, 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 and forward-starting interest rate swaps not accounted for under regulatory accounting.

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.

	March 31, 2020
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	991	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	2,027		400		1,600		1,050		550		27
Total notional amount(a)	$	3,018	$	400	$	1,600	$	1,050	$	550	$	27

	December 31, 2019
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	993	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,277		450		800		250		550		27
Total notional amount(a)	$	2,270	$	450	$	800	$	250	$	550	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $691 million in cash flow hedges as of March 31, 2020, and $693 million in cash flow hedges as of December 31, 2019.

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.

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FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

Volumes

The tables below include volumes of outstanding commodity derivatives. Amounts disclosed represent the absolute value of notional volumes of commodity contracts excluding NPNS. The Duke Energy Registrants have netted contractual amounts where offsetting purchase and sale contracts exist with identical delivery locations and times of delivery. Where all commodity positions are perfectly offset, no quantities are shown.

	March 31, 2020
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana	Piedmont
Electricity (GWh)	6,737	—	—	—	—	977	5,760	—
Natural gas (millions of dekatherms)	709	145	158	158	—	—	4	402

	December 31, 2019
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana	Piedmont
Electricity (GWh)	15,858	—	—	—	—	1,887	13,971	—
Natural gas (millions of dekatherms)	704	130	160	160	—	—	3	411

U.S. EQUITY SECURITIES RISK

In May 2019, Duke Energy Florida entered into a Decommissioning Services Agreement for the accelerated decommissioning of Crystal River Unit 3 with ADP CR3, LLC and ADP SF1, LLC. See Note 3 for additional information on the accelerated decommissioning. Duke Energy Florida executed U.S. equity option collars within the NDTF in May 2019 to preserve the U.S. equity portfolio value in the Duke Energy Florida NDTF in the event the accelerated decommissioning is approved. These option collars were executed as a purchase of a put option and the sale of a call option on certain U.S. equity index funds. The put and call options create a collar to guarantee a minimum and maximum investment value for the Duke Energy Florida NDTF U.S. equity portfolio. The put and call options were entered into at zero-cost, with the price to purchase the puts offset entirely by the funds received to sell the calls. As of March 31, 2020, the aggregate notional amount of both the put and call options was 305,000 units in U.S. equity security index funds. The options are not designated as hedging instruments. Substantially all of Duke Energy Florida’s NDTF qualifies for regulatory accounting. With regulatory accounting, the mark-to-market gains or losses on the options are deferred as regulatory liabilities or regulatory assets, respectively. The Duke Energy Florida NDTF liquidated the options in April 2020, and received proceeds of approximately $7 million.

66

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

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	March 31, 2020
			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	$	6	$	—	$	—	$	—	$	—	$	—	$	2	$	3
Noncurrent	4		2		1		1		—		1		—		—
Total Derivative Assets – Commodity Contracts	$	10	$	2	$	1	$	1	$	—	$	1	$	2	$	3
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	$	3	$	—	$	3	$	3	$	—	$	—	$	—	$	—
Noncurrent	1		—		1		1		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	4	$	—	$	4	$	4	$	—	$	—	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Noncurrent(a)	20		—		20		—		20		—		—		—
Total Derivative Assets – Equity Securities Contracts	$	20	$	—	$	20	$	—	$	20	$	—	$	—	$	—
Total Derivative Assets	$	34	$	2	$	25	$	5	$	20	$	1	$	2	$	3

(a) Equity security contracts are current since they were set to expire in May 2020 but are classified as noncurrent assets on the Condensed Consolidated Balance Sheet because the amount is presented within the NDTF.

Derivative Liabilities	March 31, 2020
			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	$	79	$	40	$	31	$	31	$	—	$	—	$	—	$	8
Noncurrent	130		11		35		20		—		—		—		83
Total Derivative Liabilities – Commodity Contracts	$	209	$	51	$	66	$	51	$	—	$	—	$	—	$	91
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	69	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	54		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	30		—		29		—		29		1		—		—
Noncurrent	28		23		—		—		—		6		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	181	$	23	$	29	$	—	$	29	$	7	$	—	$	—
Total Derivative Liabilities	$	390	$	74	$	95	$	51	$	29	$	7	$	—	$	91

67

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

Derivative Assets	December 31, 2019
			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	$	17	$	—	$	—	$	—	$	—	$	3	$	13	$	1
Noncurrent	1		—		—		—		—		1		—		—
Total Derivative Assets – Commodity Contracts	$	18	$	—	$	—	$	—	$	—	$	4	$	13	$	1
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	6		—		6		—		6		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	6	$	—	$	6	$	—	$	6	$	—	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Current	1		—		1		—		1		—		—		—
Total Derivative Assets – Equity Securities Contracts	$	1	$	—	$	1	$	—	$	1	$	—	$	—	$	—
Total Derivative Assets	$	25	$	—	$	7	$	—	$	7	$	4	$	13	$	1

Derivative Liabilities	December 31, 2019
			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	$	67	$	33	$	26	$	26	$	—	$	—	$	1	$	7
Noncurrent	156		10		37		22		—		—		—		110
Total Derivative Liabilities – Commodity Contracts	$	223	$	43	$	63	$	48	$	—	$	—	$	1	$	117
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	19	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	21		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	8		6		1		1		—		1		—		—
Noncurrent	5		—		—		—		—		5		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	53	$	6	$	1	$	1	$	—	$	6	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Current	24		—		24		—		24		—		—		—
Total Derivative Liabilities – Equity Securities Contracts	$	24	$	—	$	24	$	—	$	24	$	—	$	—	$	—
Total Derivative Liabilities	$	300	$	49	$	88	$	49	$	24	$	6	$	1	$	117

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.

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FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

Derivative Assets	March 31, 2020
				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	$	9		$	—		$	3		$	3		$	—	$	—	$	2	$	3
Gross amounts offset	—			—			—			—			—		—		—		—
Net amounts presented in Current Assets: Other	$	9		$	—		$	3		$	3		$	—	$	—	$	2	$	3
Noncurrent
Gross amounts recognized	$	25		$	2		$	22		$	2		$	20	$	1	$	—	$	—
Gross amounts offset	(3		)	(2		)	(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	2		$	—		$	1		$	1		$	—	$	1	$	—	$	—
Net amounts presented in NDTF	$	20		$	—		$	20		$	—		$	20	$	—	$	—	$	—

Derivative Liabilities	March 31, 2020
				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	$	178		$	40		$	60		$	31		$	29	$	1	$	—	$	8
Gross amounts offset	—			—			—			—			—		—		—		—
Net amounts presented in Current Liabilities: Other	$	178		$	40		$	60		$	31		$	29	$	1	$	—	$	8
Noncurrent
Gross amounts recognized	$	212		$	34		$	35		$	20		$	—	$	6	$	—	$	83
Gross amounts offset	(3		)	(2		)	(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	209		$	32		$	34		$	19		$	—	$	6	$	—	$	83

Derivative Assets	December 31, 2019
				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	$	24		$	—	$	7		$	—	$	7		$	3	$	13	$	1
Gross amounts offset	(1		)	—		(1		)	—		(1		)	—		—		—
Net amounts presented in Current Assets: Other	$	23		$	—	$	6		$	—	$	6		$	3	$	13	$	1
Noncurrent
Gross amounts recognized	$	1		$	—	$	—		$	—	$	—		$	1	$	—	$	—
Gross amounts offset	—			—		—			—		—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	1		$	—	$	—		$	—	$	—		$	1	$	—	$	—

69

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

Derivative Liabilities	December 31, 2019
				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	$	118		$	39	$	51		$	27	$	24		$	1	$	1	$	7
Gross amounts offset	(24		)	—		(24		)	—		(24		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	94		$	39	$	27		$	27	$	—		$	1	$	1	$	7
Noncurrent
Gross amounts recognized	$	182		$	10	$	37		$	22	$	—		$	5	$	—	$	110
Gross amounts offset	—			—		—			—		—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	182		$	10	$	37		$	22	$	—		$	5	$	—	$	110

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.

	March 31, 2020
			Duke				Duke
	Duke		Energy		Progress		Energy
(in millions)	Energy		Carolinas		Energy		Progress
Aggregate fair value of derivatives in a net liability position	$	96	$	45	$	51	$	51
Fair value of collateral already posted	—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	96		45		51		51

	December 31, 2019
			Duke				Duke
	Duke		Energy		Progress		Energy
(in millions)	Energy		Carolinas		Energy		Progress
Aggregate fair value of derivatives in a net liability position	$	79	$	35	$	44	$	44
Fair value of collateral already posted	—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	79		35		44		44

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.

9. INVESTMENTS IN DEBT AND EQUITY SECURITIES

Duke Energy’s investments in debt and equity securities are primarily comprised of investments held in (i) the NDTF at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, (ii) the grantor trusts at Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana related to OPEB plans and (iii) Bison. The Duke Energy Registrants classify investments in debt securities as 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 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 recognized immediately and deferred to regulatory accounts where appropriate.

70

FINANCIAL STATEMENTS INVESTMENTS IN DEBT AND EQUITY SECURITIES

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 has a credit loss. The Duke Energy Registrants analyze all investment holdings each reporting period to determine whether a decline in fair value is related to a credit loss. If an credit loss exists, the unrealized credit loss is included in earnings. There were no material credit losses as of March 31, 2020, and December 31, 2019.

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	119	$	—	$	—	$	101
Equity securities	2,499		170		4,488		3,523		55		5,661
Corporate debt securities	26		16		642		37		1		603
Municipal bonds	10		2		404		13		—		368
U.S. government bonds	70		—		1,212		33		1		1,256
NDTF equity security contracts	20		—		20		—		—		—
Other debt securities	4		3		163		3		—		141
Total NDTF Investments	$	2,629	$	191	$	7,048	$	3,609	$	57	$	8,130
Other Investments
Cash and cash equivalents	$	—	$	—	$	78	$	—	$	—	$	52
Equity securities	31		1		95		57		—		122
Corporate debt securities	—		—		89		3		—		67
Municipal bonds	6		1		98		4		—		94
U.S. government bonds	5		—		51		2		—		41
Other debt securities	—		—		52		—		—		56
Total Other Investments	$	42	$	2	$	463	$	66	$	—	$	432
Total Investments	$	2,671	$	193	$	7,511	$	3,675	$	57	$	8,562

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	23	$	35
Realized losses	65		30
AFS:
Realized gains	20		10
Realized losses	6		11

71

FINANCIAL STATEMENTS INVESTMENTS IN DEBT AND EQUITY SECURITIES

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	33	$	—	$	—	$	21
Equity securities	1,355		81		2,498		1,914		8		3,154
Corporate debt securities	15		12		392		21		1		361
Municipal bonds	3		1		128		3		—		96
U.S. government bonds	35		—		502		16		1		578
Other debt securities	3		3		159		3		—		137
Total NDTF Investments	$	1,411	$	97	$	3,712	$	1,957	$	10	$	4,347

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	9	$	23
Realized losses	45		21
AFS:
Realized gains	12		9
Realized losses	5		10

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	86	$	—	$	—	$	80
Equity securities	1,144		89		1,990		1,609		47		2,507
Corporate debt securities	11		4		250		16		—		242
Municipal bonds	7		1		276		10		—		272
U.S. government bonds	35		—		710		17		—		678
NDTF equity security contracts	20		—		20		—		—		—
Other debt securities	1		—		4		—		—		4
Total NDTF Investments	$	1,218	$	94	$	3,336	$	1,652	$	47	$	3,783
Other Investments
Cash and cash equivalents	$	—	$	—	$	69	$	—	$	—	$	49
Municipal bonds	5		—		53		3		—		51
Total Other Investments	$	5	$	—	$	122	$	3	$	—	$	100
Total Investments	$	1,223	$	94	$	3,458	$	1,655	$	47	$	3,883

72

FINANCIAL STATEMENTS INVESTMENTS IN DEBT AND EQUITY SECURITIES

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	14	$	12
Realized losses	20		9
AFS:
Realized gains	5		1
Realized losses	1		1

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	51	$	—	$	—	$	53
Equity securities	881		79		1,631		1,258		21		2,077
Corporate debt securities	11		4		250		16		—		242
Municipal bonds	7		1		276		10		—		272
U.S. government bonds	34		—		436		16		—		403
Other debt securities	1		—		4		—		—		4
Total NDTF Investments	$	934	$	84	$	2,648	$	1,300	$	21	$	3,051
Other Investments
Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	2
Total Other Investments	$	—	$	—	$	2	$	—	$	—	$	2
Total Investments	$	934	$	84	$	2,650	$	1,300	$	21	$	3,053

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	14	$	10
Realized losses	20		8
AFS:
Realized gains	5		1
Realized losses	1		1

73

FINANCIAL STATEMENTS INVESTMENTS IN DEBT AND EQUITY SECURITIES

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	35	$	—	$	—	$	27
Equity securities	263		10		359		351		26		430
U.S. government bonds	1		—		274		1		—		275
NDTF equity security contracts	20		—		20		—		—		—
Total NDTF Investments(a)	$	284	$	10	$	688	$	352	$	26	$	732
Other Investments
Cash and cash equivalents	$	—	$	—	$	3	$	—	$	—	$	4
Municipal bonds	5		—		53		3		—		51
Total Other Investments	$	5	$	—	$	56	$	3	$	—	$	55
Total Investments	$	289	$	10	$	744	$	355	$	26	$	787

(a) During the three months ended March 31, 2020, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of Crystal River Unit 3.

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were immaterial.

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.

	March 31, 2020						December 31, 2019
	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	$	26	$	1	$	63	$	43	$	—	$	81
Corporate debt securities	—		—		4		—		—		6
Municipal bonds	1		1		36		1		—		36
U.S. government bonds	—		—		3		—		—		2
Total Investments	$	27	$	2	$	106	$	44	$	—	$	125

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were immaterial.

74

FINANCIAL STATEMENTS INVESTMENTS IN DEBT AND EQUITY SECURITIES

DEBT SECURITY MATURITIES

The table below summarizes the maturity date for debt securities.

	March 31, 2020
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana
Due in one year or less	$	333	$	25	$	302	$	26	$	276	$	3
Due after one through five years	538		234		236		227		9		17
Due after five through 10 years	465		188		214		207		7		7
Due after 10 years	1,375		734		541		506		35		16
Total	$	2,711	$	1,181	$	1,293	$	966	$	327	$	43

10. 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 as defined by GAAP. 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.

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 the 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. 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 12 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2019, for a discussion of the valuation of goodwill and intangible assets.

75

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

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 8. See Note 9 for additional information related to investments by major security type for the Duke Energy Registrants.

	March 31, 2020
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	4,488		$	4,440		$	—		$	—		$	48
NDTF debt securities	2,540			767			1,773			—			—
Other equity securities	95			95			—			—			—
Other debt securities	368			126			242			—			—
NDTF equity security contracts	20			—			20			—			—
Derivative assets	34			3			28			3			—
Total assets	7,545			5,431			2,063			3			48
Derivative liabilities	(390		)	(49		)	(250		)	(91		)	—
Net assets (liabilities)	$	7,155		$	5,382		$	1,813		$	(88	)	$	48

	December 31, 2019
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	5,684		$	5,633		$	—		$	—		$	51
NDTF debt securities	2,469			826			1,643			—			—
Other equity securities	122			122			—			—			—
Other debt securities	310			91			219			—			—
Derivative assets	25			3			7			15			—
Total assets	8,610			6,675			1,869			15			51
NDTF equity security contracts	(23		)	—			(23		)	—			—
Derivative liabilities	(277		)	(15		)	(145		)	(117		)	—
Net assets (liabilities)	$	8,310		$	6,660		$	1,701		$	(102	)	$	51

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

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	(102	)	$	(113	)
Purchases, sales, issuances and settlements:
Settlements		(9		)	(12		)
Total gains included on the Condensed Consolidated Balance Sheet		23			10
Balance at end of period		$	(88	)	$	(115	)

76

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

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.

	March 31, 2020
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	2,498		$	2,450	$	—		$	48
NDTF debt securities	1,214			182		1,032			—
Derivative assets	2			—		2			—
Total assets	3,714			2,632		1,034			48
Derivative liabilities	(74		)	—		(74		)	—
Net assets	$	3,640		$	2,632	$	960		$	48

	December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	3,154		$	3,103	$	—		$	51
NDTF debt securities	1,193			227		966			—
Total assets	4,347			3,330		966			51
Derivative liabilities	(49		)	—		(49		)	—
Net assets	$	4,298		$	3,330	$	917		$	51

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	1,990		$	1,990	$	—		$	2,530		$	2,530	$	—
NDTF debt securities	1,326			585		741			1,276			599		677
Other debt securities	122			69		53			100			49		51
NDTF equity security contracts	20			—		20			—			—		—
Derivative assets	25			—		25			7			—		7
Total assets	3,483			2,644		839			3,913			3,178		735
NDTF equity security contracts	—			—		—			(23		)	—		(23		)
Derivative liabilities	(95		)	—		(95		)	(65		)	—		(65		)
Net assets	$	3,388		$	2,644	$	744		$	3,825		$	3,178	$	647

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	1,631		$	1,631	$	—		$	2,077		$	2,077	$	—
NDTF debt securities	1,017			276		741			974			297		677
Other debt securities	2			2		—			2			2		—
Derivative assets	5			—		5			—			—		—
Total assets	2,655			1,909		746			3,053			2,376		677
Derivative liabilities	(51		)	—		(51		)	(49		)	—		(49		)
Net assets	$	2,604		$	1,909	$	695		$	3,004		$	2,376	$	628

77

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	359		$	359	$	—		$	453		$	453	$	—
NDTF debt securities	309			309		—			302			302		—
Other debt securities	56			3		53			55			4		51
NDTF equity security contracts	20			—		20			—			—		—
Derivative assets	—			—		—			7			—		7
Total assets	744			671		73			817			759		58
NDTF equity security contracts	—			—		—			(23		)	—		(23		)
Derivative liabilities	(29		)	—		(29		)	(1		)	—		(1		)
Net assets	$	715		$	671	$	44		$	793		$	759	$	34

DUKE ENERGY OHIO

The recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets were not material at March 31, 2020, and December 31, 2019.

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Total Fair Value			Level 1			Level 2		Level 3
Other equity securities	$	63	$	63	$	—	$	—	$	81		$	81		$	—	$	—
Other debt securities	43		—		43		—		44			—			44		—
Derivative assets	2		—		—		2		13			2			—		11
Total assets	$	108	$	63	$	43	$	2	$	138		$	83		$	44	$	11
Derivative liabilities	—		—		—		—		(1		)	(1		)	—		—
Net assets	$	108	$	63	$	43	$	2	$	137		$	82		$	44	$	11

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

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	11		$	22
Purchases, sales, issuances and settlements:
Settlements		(6		)	(10		)
Total losses included on the Condensed Consolidated Balance Sheet		(3		)	(7		)
Balance at end of period		$	2		$	5

78

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 3			Total Fair Value			Level 1		Level 3
Derivative assets	$	3		$	3	$	—		$	1		$	1	$	—
Derivative liabilities	(91		)	—		(91		)	(117		)	—		(117		)
Net (liabilities) assets	$	(88	)	$	3	$	(91	)	$	(116	)	$	1	$	(117	)

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

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	(117	)	$	(141	)
Total gains and settlements		26			20
Balance at end of period		$	(91	)	$	(121	)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

	March 31, 2020
												Weighted
	Fair Value											Average
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range						Range
Duke Energy Ohio
FTRs	$	1		RTO auction pricing	FTR price – per MWh	$	0.04		-	$	3.29	$	1.03
Duke Energy Indiana
FTRs	2			RTO auction pricing	FTR price – per MWh	(0.37		)	-	6.06		0.54
Piedmont
Natural gas contracts	(91		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	1.64			-	2.41		1.94
Duke Energy
Total Level 3 derivatives	$	(88	)

	December 31, 2019
												Weighted
	Fair Value											Average
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range						Range
Duke Energy Ohio
FTRs	$	4		RTO auction pricing	FTR price – per MWh	$	0.59		-	$	3.47	$	2.07
Duke Energy Indiana
FTRs	11			RTO auction pricing	FTR price – per MWh	(0.66		)	-	9.24		1.15
Piedmont
Natural gas contracts	(117		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	1.59			-	2.46		1.91
Duke Energy
Total Level 3 derivatives	$	(102	)

79

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

OTHER FAIR VALUE DISCLOSURES

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

	March 31, 2020				December 31, 2019
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy(a)	$	61,388	$	65,644	$	58,126	$	63,062
Duke Energy Carolinas	12,807		14,312		11,900		13,516
Progress Energy	19,355		21,802		19,634		22,291
Duke Energy Progress	9,059		9,798		9,058		9,934
Duke Energy Florida	7,706		8,831		7,987		9,131
Duke Energy Ohio	2,620		2,904		2,619		2,964
Duke Energy Indiana	4,603		5,433		4,057		4,800
Piedmont	2,385		2,551		2,384		2,642

(a) Book value of long-term debt includes $1.4 billion at March 31, 2020, and $1.5 billion at December 31, 2019, of unamortized debt discount and premium, net of purchase accounting adjustments related to the mergers with Progress Energy and Piedmont that are excluded from fair value of long-term debt.

At both March 31, 2020, and December 31, 2019, 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.

11. VARIABLE INTEREST ENTITIES

CONSOLIDATED VIEs

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

No financial support was provided to any of the consolidated VIEs during the three months ended March 31, 2020, and the year ended December 31, 2019, or is expected to be provided in the future that was not previously contractually required.

Receivables Financing – DERF/DEPR/DEFR

DERF, DEPR and 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 LLCs 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 are considered the primary beneficiaries and consolidate DERF, DEPR and DEFR, respectively, as they make those decisions. Due to the COVID-19 pandemic, as described in Note 1, the Duke Energy Registrants suspended customer disconnections for nonpayment. The impact of COVID-19 and the Duke Energy Registrant’s related response on customers’ ability to pay for service is uncertain, and it is reasonably possible eventual write-offs of customer receivables may increase over current estimates. See Note 3 for information about COVID-19 filings with state utility commissions.

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 approximately 75% cash and 25% 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.

80

FINANCIAL STATEMENTS VARIABLE INTEREST ENTITIES

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 is not held 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 is considered the primary beneficiary and consolidates CRC as it makes these decisions. Neither Duke Energy Ohio nor Duke Energy Indiana consolidate CRC. Due to the COVID-19 pandemic, as described in Note 1, the Duke Energy Registrants suspended customer disconnections for nonpayment. The impact of COVID-19 and the Duke Energy Registrant’s related response on customers’ ability to pay for service is uncertain, and it is reasonably possible eventual write-offs of customer receivables may increase over current estimates. See Note 3 for information about COVID-19 filings with state utility commissions.

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	February 2023		December 2022		April 2023		April 2021
Credit facility amount	$	350	$	475	$	375	$	250
Amounts borrowed at March 31, 2020	350		475		325		250
Amounts borrowed at December 31, 2019	350		474		325		250
Restricted Receivables at March 31, 2020	467		616		410		331
Restricted Receivables at December 31, 2019	522		642		489		336

Nuclear Asset-Recovery Bonds – DEFPF

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

In 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)	March 31, 2020		December 31, 2019
Receivables of VIEs	$	4	$	5
Regulatory Assets: Current	53		52
Current Assets: Other	13		39
Other Noncurrent Assets: Regulatory assets	980		989
Current Liabilities: Other	2		10
Current maturities of long-term debt	54		54
Long-Term Debt	1,028		1,057

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. Additionally, Duke Energy has VIEs associated with tax equity arrangements entered into with third-party investors in order to finance the cost of renewable assets eligible for tax credits. The activities that most significantly impacted the economic performance of these renewable energy facilities were decisions associated with siting, negotiating PPAs and Engineering, Procurement and Construction agreements, and decisions associated with ongoing operations and maintenance-related activities. Duke Energy is considered the primary beneficiary and consolidates the entities as it is responsible for all of these decisions.

81

FINANCIAL STATEMENTS VARIABLE INTEREST ENTITIES

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

(in millions)	March 31, 2020			December 31, 2019
Current Assets: Other	$	287		$	203
Property, Plant and Equipment: Cost	6,106			5,747
Accumulated depreciation and amortization	(1,094		)	(1,041		)
Other Noncurrent Assets: Other	82			106
Current maturities of long-term debt	162			162
Long-Term Debt	1,538			1,541
Other Noncurrent Liabilities: AROs	129			127
Other Noncurrent Liabilities: Other	258			228

NON-CONSOLIDATED VIEs

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

	March 31, 2020
	Duke Energy												Duke		Duke
	Pipeline			Commercial			Other						Energy		Energy
(in millions)	Investments			Renewables			VIEs			Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	(1	)	$	—		$	(1	)	$	39	$	48
Investments in equity method unconsolidated affiliates	1,243			371			—			1,614			—		—
Total assets	$	1,243		$	370		$	—		$	1,613		$	39	$	48
Taxes accrued	(1		)	—			—			(1		)	—		—
Other current liabilities	—			—			3			3			—		—
Deferred income taxes	69			—			—			69			—		—
Other noncurrent liabilities	105			—			11			116			—		—
Total liabilities	$	173		$	—		$	14		$	187		$	—	$	—
Net assets (liabilities)	$	1,070		$	370		$	(14	)	$	1,426		$	39	$	48

	December 31, 2019
	Duke Energy												Duke		Duke
	Pipeline			Commercial			Other						Energy		Energy
(in millions)	Investments			Renewables			VIEs			Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	(1	)	$	—		$	(1	)	$	64	$	77
Investments in equity method unconsolidated affiliates	1,179			300			—			1,479			—		—
Total assets	$	1,179		$	299		$	—		$	1,478		$	64	$	77
Taxes accrued	(1		)	—			—			(1		)	—		—
Other current liabilities	—			—			4			4			—		—
Deferred income taxes	59			—			—			59			—		—
Other noncurrent liabilities	—			—			11			11			—		—
Total liabilities	$	58		$	—		$	15		$	73		$	—	$	—
Net assets (liabilities)	$	1,121		$	299		$	(15	)	$	1,405		$	64	$	77

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 PPA with OVEC, which is discussed below, and various guarantees, including Duke Energy's 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 $845 million, which represents 47% of the outstanding borrowings under the credit facility as of March 31, 2020. 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.

82

FINANCIAL STATEMENTS 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		March 31,		December 31,
Entity Name	Interest		2020		2019
ACP(a)	47	%	$	1,243	$	1,179
Constitution(b)	24	%	—		—
Total			$	1,243	$	1,179

(a) Duke Energy evaluated this investment for impairment as of March 31, 2020, and December 31, 2019, and determined that fair value approximated carrying value and therefore no impairment was necessary.

(b) During the year ended December 31, 2019, Duke Energy recorded an OTTI related to Constitution. This charge resulted in the full write-down of Duke Energy's investment in Constitution.

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. In 2019, Duke Energy acquired a majority ownership in a portfolio of distributed fuel cell projects from Bloom Energy Corporation. Duke Energy is not the primary beneficiary of the assets within the portfolio and does not consolidate the assets in the portfolio.

OVEC

Duke Energy Ohio’s 9% ownership interest in OVEC is considered a non-consolidated VIE due to OVEC having insufficient equity to finance its activities without subordinated financial support. The activities that most significantly impact OVEC's economic performance include fuel strategy and supply activities and decisions associated with ongoing operations and maintenance-related activities. Duke Energy Ohio does not have the unilateral power to direct these activities, and therefore, does not consolidate OVEC.

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 Corp (FES), a subsidiary of FirstEnergy Corp. and an ICPA counterparty with a power participation ratio of 4.85%, 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. In addition, certain proposed environmental rulemaking could result in future increased OVEC cost allocations. See Note 3 for additional information.

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.

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019
Receivables sold	$	234	$	253	$	274	$	307
Less: Retained interests	39		64		48		77
Net receivables sold	$	195	$	189	$	226	$	230

83

FINANCIAL STATEMENTS VARIABLE INTEREST ENTITIES

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

	Duke Energy Ohio				Duke Energy Indiana
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(in millions)	2020		2019		2020		2019
Sales
Receivables sold	$	537	$	575	$	647	$	734
Loss recognized on sale	4		4		4		5
Cash flows
Cash proceeds from receivables sold	$	559	$	597	$	672	$	758
Return received on retained interests	2		2		2		3

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

12. REVENUE

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.

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)	2020		2021		2022		2023		2024		Thereafter		Total
Progress Energy	$	84	$	92	$	87	$	44	$	45	$	58	$	410
Duke Energy Progress	6		8		8		8		8		—		38
Duke Energy Florida	78		84		79		36		37		58		372
Duke Energy Indiana	8		5		—		—		—		—		13

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 revenues 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.

Fixed-capacity payments under long-term contracts for the Gas Utilities and Infrastructure 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)	2020		2021		2022		2023		2024		Thereafter		Total
Piedmont	$	51	$	65	$	64	$	61	$	58	$	376	$	675

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 Certificates (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.

84

FINANCIAL STATEMENTS REVENUE

Other

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

Disaggregated Revenues

Disaggregated revenues are presented as follows:

	Three Months Ended March 31, 2020
			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	$	2,261	$	756	$	1,064	$	502	$	562	$	176		$	265	$	—
General	1,492		549		648		319		329		114			181		—
Industrial	693		269		216		154		62		35			175		—
Wholesale	497		114		321		279		42		7			55		—
Other revenues	191		60		118		63		55		20			16		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,134	$	1,748	$	2,367	$	1,317	$	1,050	$	352		$	692	$	—
Gas Utilities and Infrastructure
Residential	$	362	$	—	$	—	$	—	$	—	$	97		$	—	$	264
Commercial	169		—		—		—		—		43			—		126
Industrial	41		—		—		—		—		6			—		36
Power Generation	—		—		—		—		—		—			—		11
Other revenues	30		—		—		—		—		6			—		24
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	602	$	—	$	—	$	—	$	—	$	152		$	—	$	461
Commercial Renewables
Revenue from contracts with customers	$	58	$	—	$	—	$	—	$	—	$	—		$	—	$	—
Other
Revenue from contracts with customers	$	6	$	—	$	—	$	—	$	—	$	—		$	—	$	—
Total revenue from contracts with customers	$	5,800	$	1,748	$	2,367	$	1,317	$	1,050	$	504		$	692	$	461
Other revenue sources(a)	$	149	$	—	$	55	$	21	$	30	$	(6	)	$	—	$	51
Total revenues	$	5,949	$	1,748	$	2,422	$	1,338	$	1,080	$	498		$	692	$	512

(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.

85

FINANCIAL STATEMENTS REVENUE

	Three Months Ended March 31, 2019
			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	$	2,370	$	760	$	1,114	$	536	$	578	$	189	$	306	$	—
General	1,427		496		632		306		326		103		197		—
Industrial	711		266		222		161		61		33		190		—
Wholesale	541		119		353		315		38		14		54		—
Other revenues	172		78		172		125		47		16		17		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,221	$	1,719	$	2,493	$	1,443	$	1,050	$	355	$	764	$	—
Gas Utilities and Infrastructure
Residential	$	414	$	—	$	—	$	—	$	—	$	112	$	—	$	302
Commercial	206		—		—		—		—		49		—		157
Industrial	48		—		—		—		—		7		—		42
Power Generation	—		—		—		—		—		—		—		13
Other revenues	63		—		—		—		—		8		—		56
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	731	$	—	$	—	$	—	$	—	$	176	$	—	$	570
Commercial Renewables
Revenue from contracts with customers	$	42	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	4	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total revenue from contracts with customers	$	5,998	$	1,719	$	2,493	$	1,443	$	1,050	$	531	$	764	$	570
Other revenue sources(a)	$	165	$	25	$	79	$	41	$	36	$	—	$	4	$	9
Total revenues	$	6,163	$	1,744	$	2,572	$	1,484	$	1,086	$	531	$	768	$	579

(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.

As described in Note 1, Duke Energy adopted the new guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. The following table presents the reserve for credit losses for trade and other receivables based on adoption of the new standard.

	March 31, 2020
				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, 2019	$	76		$	10		$	16		$	8		$	7		$	4	$	3	$	6
Cumulative Change in Accounting Principle	5			1			2			1			1			—		—		1
Write-Offs	(10		)	(3		)	(4		)	(2		)	(2		)	—		—		(1		)
Credit Loss Expense	18			3			6			2			5			1		—		3
Balance at March 31, 2020	$	89		$	11		$	20		$	9		$	11		$	5	$	3	$	9

Trade and other receivables are evaluated based on an estimate of the risk of loss over the life of the receivable and current and historical conditions using supportable assumptions. Management evaluates the risk of loss for trade and other receivables by comparing the historical write-off amounts to total revenue over a specified period. Historical loss rates are adjusted due to the impact of current conditions as well as forecasted conditions over a reasonable time period. The calculated write-off rate can be applied to the receivable balance for which an established reserve does not already exist. Management reviews the assumptions and risk of loss annually for trade and other receivables. Due to the COVID-19 pandemic, as described in Note 1, the Duke Energy Registrants suspended customer disconnections for nonpayment. The specific actions taken by each Duke Energy Registrant are described in Note 3. The impact of COVID-19 and Duke Energy’s related response on customers’ ability to pay for service is uncertain, and it is reasonably possible eventual write-offs of customer receivables may increase over current estimates.

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FINANCIAL STATEMENTS REVENUE

The aging of trade receivables is presented in the table below. Duke Energy considers receivables greater than 30 days outstanding past due.

	March 31, 2020
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Unbilled Receivables	$	716	$	285	$	195	$	85	$	110	$	1	$	16	$	32
0-30 days	1,584		448		585		321		262		45		24		134
30-60 days	216		69		67		44		23		9		1		18
60-90 days	65		18		20		14		6		2		1		5
90+ days	145		19		57		32		25		32		11		11
Trade and Other Receivables	$	2,726	$	839	$	924	$	496	$	426	$	89	$	53	$	200

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)	March 31, 2020		December 31, 2019
Duke Energy	$	716	$	843
Duke Energy Carolinas	285		298
Progress Energy	195		217
Duke Energy Progress	85		122
Duke Energy Florida	110		95
Duke Energy Ohio	1		1
Duke Energy Indiana	16		16
Piedmont	32		78

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 account for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 11 for further information. These receivables for unbilled revenues are shown in the table below.

(in millions)	March 31, 2020		December 31, 2019
Duke Energy Ohio	$	61	$	82
Duke Energy Indiana	94		115

13. STOCKHOLDERS' EQUITY

Basic EPS is computed by dividing net income available 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 available 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. Dividends declared on preferred stock are recorded on the Condensed Consolidated Statements of Operations as a reduction of net income to arrive at net income available to Duke Energy common stockholders. Dividends accumulated on preferred stock are an adjustment to net income used in the calculation of basic and diluted EPS.

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FINANCIAL STATEMENTS STOCKHOLDERS' EQUITY

The following table presents Duke Energy’s basic and diluted EPS calculations, the weighted average number of common shares outstanding and common and preferred share dividends declared.

	Three Months Ended March 31,
(in millions, except per share amounts)	2020		2019
Income from continuing operations available to Duke Energy common stockholders excluding impact of participating securities and including accumulated preferred stock dividends adjustment	$	911	$	898
Weighted average common shares outstanding – basic	734		727
Equity forwards	2		—
Weighted average common shares outstanding – diluted	736		727
EPS from continuing operations available to Duke Energy common stockholders
Basic and diluted	$	1.24	$	1.24
Potentially dilutive items excluded from the calculation(a)	2		2
Dividends declared per common share	$	0.945	$	0.9275
Dividends declared on Series A preferred stock per depositary share(b)	$	0.359	$	—
Dividends declared on Series B preferred stock per share(c)	$	24.917	$	—

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

(b) 5.75% Series A Cumulative Redeemable Perpetual Preferred Stock dividends are payable quarterly in arrears on the 16th day of March, June, September and December. The preferred stock has a $25 liquidation preference per depositary share.

(c) 4.875% Series B Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock dividends are payable semiannually in arrears on the 16th day of March and September. The preferred stock has a $1,000 liquidation preference per share.

Common Stock

In November 2019, Duke Energy filed a prospectus supplement and executed an Equity Distribution Agreement (EDA) under which it may sell up to $1.5 billion of its common stock through an at-the-market (ATM) offering program, including an equity forward sales component. Under the terms of the EDA, Duke Energy may issue and sell shares of common stock through September 2022. In March 2020, Duke Energy marketed approximately 940,000 shares of common stock through an equity forward transaction under the ATM with an initial forward price of $89.76 per share.

Separately, in November 2019, Duke Energy marketed an equity offering of 28.75 million shares of common stock through an Underwriting Agreement. In connection with the offering, Duke Energy entered into an equity forward sales agreement with an initial forward price of $85.99 per share.

The equity forward sales agreements require Duke Energy to either physically settle the transaction by issuing shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement, or net settle in whole or in part through the delivery or receipt of cash or shares. The settlement alternatives are at Duke Energy's election. Settlement of the forward sales agreements are expected to occur on or prior to December 31, 2020. Until settlement of the equity forwards, EPS dilution resulting from the agreements, if any, will be determined under the treasury stock method.

14. EMPLOYEE BENEFIT PLANS

DEFINED BENEFIT RETIREMENT PLANS

Duke Energy and certain subsidiaries maintain, 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.

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FINANCIAL STATEMENTS EMPLOYEE BENEFIT PLANS

QUALIFIED PENSION PLANS

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

	Three Months Ended March 31, 2020
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	41		$	12		$	12		$	6		$	5		$	1		$	2		$	1
Interest cost on projected benefit obligation	67			16			21			10			12			4			6			2
Expected return on plan assets	(143		)	(36		)	(48		)	(22		)	(25		)	(7		)	(11		)	(5		)
Amortization of actuarial loss	34			7			11			5			6			2			3			2
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(2		)
Amortization of settlement charges	2			1			1			—			—			—			—			—
Net periodic pension costs	$	(7	)	$	(2	)	$	(4	)	$	(1	)	$	(2	)	$	—		$	—		$	(2	)

	Three Months Ended March 31, 2019
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	37		$	12		$	11		$	6		$	4		$	1		$	2		$	1
Interest cost on projected benefit obligation	83			20			26			12			14			5			6			3
Expected return on plan assets	(143		)	(38		)	(44		)	(23		)	(22		)	(8		)	(11		)	(5		)
Amortization of actuarial loss	24			6			9			3			6			1			2			2
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(3		)
Net periodic pension costs	$	(7	)	$	(2	)	$	1		$	(2	)	$	2		$	(1	)	$	(1	)	$	(2	)

NON-QUALIFIED PENSION PLANS

Net periodic pension costs for non-qualified pension plans were not material for the three months ended March 31, 2020, and 2019.

OTHER POST-RETIREMENT BENEFIT PLANS

Net periodic costs for other post-retirement benefit plans were not material for the three months ended March 31, 2020, and 2019.

15. INCOME TAXES

EFFECTIVE TAX RATES

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

	Three Months Ended
	March 31,
	2020		2019
Duke Energy	13.3	%	9.6	%
Duke Energy Carolinas	16.1	%	17.7	%
Progress Energy	17.5	%	17.3	%
Duke Energy Progress	17.1	%	17.8	%
Duke Energy Florida	20.0	%	19.3	%
Duke Energy Ohio	17.7	%	16.9	%
Duke Energy Indiana	20.8	%	24.1	%
Piedmont	10.1	%	21.8	%

The increase in the ETR for Duke Energy for the three months ended March 31, 2020, was primarily due to an adjustment related to the income tax recognition for equity method investments recorded in the first quarter of 2019, partially offset by an increase in the amortization of excess deferred taxes. The equity method investment adjustment was immaterial and relates to prior years.

The decrease in the ETR for Duke Energy Carolinas for the three months ended March 31, 2020, was primarily due to an increase in the amortization of excess deferred taxes.

The decrease in the ETR for Duke Energy Indiana for the three months ended March 31, 2020, was primarily due to an increase in the amortization of excess deferred taxes.

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FINANCIAL STATEMENTS INCOME TAXES

The decrease in the ETR for Piedmont for the three months ended March 31, 2020, was primarily due to an increase in the amortization of excess deferred taxes.

OTHER TAX MATTERS

On March 27, 2020, the CARES Act was enacted. The CARES Act is an emergency economic stimulus package in response to the COVID-19 pandemic. Among other provisions, the CARES Act accelerates the remaining AMT credit refund allowances resulting in taxpayers being able to immediately claim a refund in full for any AMT credit carryforwards. As a result, the remaining AMT credit carryforwards have been reclassified to a current receivable included in Other within Current Assets on the Condensed Consolidated Balance Sheets as of March 31, 2020. The total income tax receivable related to AMT credit carryforwards is approximately $572 million. The other provisions within the CARES Act do not materially impact Duke Energy's income tax accounting. See Note 1 for information on COVID-19.

16. SUBSEQUENT EVENTS

For information on subsequent events related to regulatory matters, commitments and contingencies and derivatives and hedging, see Notes 3, 4 and 8.

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

The following combined Management’s Discussion and Analysis of Financial Condition and Results of Operations is separately filed by Duke Energy and Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont. 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 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 three months ended March 31, 2020, and with Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2019.

Executive Overview

COVID-19

The COVID-19 pandemic is having a significant impact on global health and economic environments. In the first quarter of 2020, the World Health Organization (WHO) declared COVID-19 a global pandemic, and President Trump proclaimed that the COVID-19 outbreak in the United States constitutes a national emergency. The Duke Energy Registrants are monitoring developments closely, have taken steps to mitigate the impacts to our business, and have a pandemic response plan in place to protect our employees, customers and communities. Financial impacts to Duke Energy’s first quarter 2020 results were not material. Volumes are expected to decline in the second quarter and then begin a gradual rebound thereafter. The Duke Energy Registrants are developing cost containment plans to offset revenue declines. 

• Employees. The health of our employees is of paramount importance. Power plants and electricity and natural gas delivery facilities are staffed. Employees who are not involved with power generation, power delivery, customer service or certain other functions have been performing their work duties remotely from home. Employees who need to interact with customers in-person are following the Centers for Disease Control and Prevention’s safety guidelines, including social distancing and use of face masks. Operating procedure changes include additional cleaning and disinfection procedures at our facilities.

• Customers. The Duke Energy Subsidiary Registrants voluntarily announced, in the first quarter of 2020, a suspension of disconnections for nonpayment in order to give customers experiencing financial hardship extra time to make payments. This is expected to result in an increase in future charge-offs over historical levels. In addition, several Subsidiary Registrants are waiving late payment charges and other fees for credit cards and returned checks. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters" for additional information. The COVID-19 pandemic and stay-at-home orders have impacted commercial and industrial customers, and many of them have suspended operations which is impacting the Duke Energy Registrants’ volumes. Several large industrial customers have announced plans to restart their businesses in May.

• Communities. The Duke Energy Foundation announced approximately $6 million in donations and grants as of April 30, 2020, to support hunger relief, local health and human services nonprofits, and education initiatives across the Duke Energy Registrants’ service territories.

• Balance Sheet Strength and Liquidity Assurance. See Notes 5 and 13 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities" and "Stockholders Equity," respectively, for additional information.

◦ Duke Energy issued approximately $1.5 billion of debt during the first quarter of 2020.

◦ Duke Energy entered into and borrowed approximately $1.7 billion under a 364-day Term Loan Credit Agreement.

◦ Duke Energy drew down the remaining $500 million of availability under its existing $1 billion Three-Year Revolving Credit Facility.

◦ Duke Energy issued $85 million of common stock through a forward sales agreement which is expected to settle on or prior to December 31, 2020.

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• Rate Case activity and delays. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters" for additional information.

◦ Duke Energy Carolinas and Duke Energy Progress filed general rate cases with the NCUC on September 30, 2019, and October 30, 2019, respectively, requesting rate increases go into effect in the third quarter of 2020. On March 16, 2020, the NCUC issued an Order Postponing Hearing and Addressing Procedural Matters, which postponed the Duke Energy Carolinas evidentiary hearing until further order by the commission. On March 24, 2020, the NCUC suspended the procedural schedule and postponed the previously scheduled evidentiary hearing on the Duke Energy Progress case indefinitely. On April 7, 2020, the NCUC issued an order partially resuming the procedural schedule. On May 6, 2020, Duke Energy Carolinas, Duke Energy Progress and the Public Staff filed a joint motion requesting that the NCUC issue an order scheduling one consolidated evidentiary hearing to consider the companies’ applications for net rate increases. The joint motion suggests, health and safety permitting, that the commission consider the possibility of holding the consolidated hearing in July.

◦ Duke Energy Florida filed a petition with the FPSC on April 2, 2020, to accelerate a fuel cost refund to customers in the month of May 2020. Typically, the refund would be made over the course of 2021. The FPSC approved the petition on April 28, 2020.

◦ Duke Energy Ohio filed an application on April 16, 2020, for a Reasonable Arrangement to temporarily lower the minimum bill for demand-metered commercial and industrial customers. The proposal is conditioned on full recovery via Duke Energy Ohio's existing Economic Competitiveness Fund Rider, which has been used by Duke Energy Ohio in the past for other reasonable arrangements with customers. On April 24, 2020, the Staff of the PUCO filed its recommendation finding Duke Energy Ohio’s application is reasonable and that the PUCO should approve it.

◦ Duke Energy Kentucky filed an electric rate case with the KPSC on September 3, 2019. On April 27, 2020, the KPSC issued its decision and new customer rates were effective on May 1, 2020.

◦ Duke Energy Indiana filed a general rate case with the IURC on July 2, 2019. Hearings concluded on February 7, 2020, with rates expected to be effective mid-2020. Duke Energy Indiana is awaiting an order from the IURC.

• Policymaker actions. The CARES Act was signed by President Trump on March 27, 2020. Duke Energy Registrants will benefit from certain provisions such as the AMT acceleration and deferral of certain payroll taxes. See Note 15 to the Condensed Consolidated Financial Statements, “Income Taxes” for additional information.

• ACP and other assets. At present, we have not experienced any delays in ACP construction activity related to COVID-19, but we are constantly monitoring that important project. We experienced no impairments of long-lived or intangible assets resulting from this pandemic in the first quarter 2020.

Results of Operations

Non-GAAP Measures

Management’s Discussion and Analysis includes financial information prepared in accordance with GAAP in the U.S., as well as certain non-GAAP financial measures such as adjusted earnings and adjusted EPS discussed below. Generally, a non-GAAP financial measure is a numerical measure of financial performance, financial position or cash flows that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable measure calculated and presented in accordance with GAAP. 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 EPS. Adjusted earnings and adjusted EPS represent income from continuing operations available to Duke Energy common stockholders in dollar and per share amounts, 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. The most directly comparable GAAP measures for adjusted earnings and adjusted EPS are GAAP Reported Earnings and GAAP Reported EPS, respectively.

The special item in the periods presented below includes a reversal of 2018 severance costs which were deferred as a result of the partial settlement in the Duke Energy Carolinas 2019 North Carolina rate case.

Three Months Ended March 31, 2020, as compared to March 31, 2019

GAAP Reported EPS was $1.24 for the first quarter of 2020 and the first quarter of 2019. GAAP reported earnings increased due to positive rate case impacts and growth in Commercial Renewables. This was offset by lower returns on corporate held investments and unfavorable weather.

As discussed above, management also evaluates financial performance based on adjusted EPS. Duke Energy’s first quarter 2020 adjusted EPS was $1.14 compared to $1.24 for the first quarter of 2019.

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

	Three Months Ended March 31,
	2020						2019
(in millions, except per share amounts)	Earnings			EPS			Earnings		EPS
GAAP Reported Earnings/GAAP Reported EPS	$	899		$	1.24		$	900	$	1.24
Adjustments:
Severance(a)	(75		)	(0.10		)	—		—
Adjusted Earnings/Adjusted EPS	$	824		$	1.14		$	900	$	1.24

(a)    Net of tax expense of $23 million.

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 and preferred stock dividends. 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.

Electric Utilities and Infrastructure

	Three Months Ended March 31,
(in millions)	2020		2019			Variance
Operating Revenues	$	5,183	$	5,329		$	(146	)
Operating Expenses
Fuel used in electric generation and purchased power	1,467		1,630			(163		)
Operation, maintenance and other	1,325		1,282			43
Depreciation and amortization	977		947			30
Property and other taxes	303		301			2
Impairment charges	2		—			2
Total operating expenses	4,074		4,160			(86		)
Gains (Losses) on Sales of Other Assets and Other, net	1		(3		)	4
Operating Income	1,110		1,166			(56		)
Other Income and Expenses, net	85		91			(6		)
Interest Expense	339		338			1
Income Before Income Taxes	856		919			(63		)
Income Tax Expense	151		169			(18		)
Segment Income	$	705	$	750		$	(45	)
Duke Energy Carolinas GWh sales	21,236		21,828			(592		)
Duke Energy Progress GWh sales	15,670		16,348			(678		)
Duke Energy Florida GWh sales	8,617		8,321			296
Duke Energy Ohio GWh sales	5,823		6,164			(341		)
Duke Energy Indiana GWh sales	7,606		8,033			(427		)
Total Electric Utilities and Infrastructure GWh sales	58,952		60,694			(1,742		)
Net proportional MW capacity in operation	49,561		49,725			(164		)

Three Months Ended March 31, 2020, as compared to March 31, 2019

Electric Utilities and Infrastructure’s results were driven by unfavorable weather and lower wholesale revenues, partially offset by higher revenues resulting from the South Carolina retail rate cases and Duke Energy Florida base and solar rate adjustments. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• a $147 million decrease in fuel revenues primarily due to lower fuel cost recovery;

• a $45 million decrease in retail sales, net of fuel revenues, due to unfavorable weather in the current year; and

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MD&A SEGMENT RESULTS — ELECTRIC UTILITIES AND INFRASTRUCTURE

• a $17 million decrease in wholesale revenues, net of fuel, primarily due to coal ash cost recovery in the prior year at Duke Energy Progress.

Partially offset by:

• a $19 million increase due to higher pricing from South Carolina retail rate case, net of a return of EDIT to customers;

• a $17 million increase in retail pricing due to Duke Energy Florida's base rate adjustments related to annual increases from the 2017 Settlement Agreement and the Solar Base Rate Adjustment; and

• a $17 million increase in weather-normal retail sales volumes.

Operating Expenses. The variance was driven primarily by:

• a $163 million decrease in fuel used in electric generation and purchased power primarily due to lower demand and changes in generation mix at Duke Energy Progress and lower coal and natural gas costs and lower amortization of deferred fuel costs at Duke Energy Indiana.

Partially offset by:

• a $43 million increase in operation, maintenance and other expense primarily due to higher employee benefit costs and increased vegetation management costs; and

• a $30 million increase in depreciation and amortization expense primarily due to additional plant in service and new depreciation rates associated with the South Carolina retail rate case.

Income Tax Expense. The decrease in tax expense was primarily due to a decrease in pretax income. The ETRs for the three months ended March 31, 2020, and 2019, were 17.6% and 18.4%, respectively.

Matters Impacting Future Electric Utilities and Infrastructure Results

The COVID-19 pandemic has not had a material impact on Electric Utilities and Infrastructure as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Electric Utilities and Infrastructure results of operations, financial position and cash flows in the future. Electric Utilities and Infrastructure will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Electric Utilities and Infrastructure customers, suppliers and partners and could cause Electric Utilities and Infrastructure to experience an increase in certain costs, such as bad debt, and a reduction in the demand for energy. Electric Utilities and Infrastructure also has various pending rate case proceedings that have been delayed. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

On December 31, 2019, Duke Energy Carolinas and Duke Energy Progress entered into a settlement agreement with NCDEQ and certain community groups under which Duke Energy Carolinas and Duke Energy Progress agreed to excavate seven of the nine remaining coal ash basins in North Carolina with ash moved to on-site lined landfills. At the two remaining basins, uncapped basin ash will be excavated and moved to lined landfills. An order from regulatory authorities disallowing recovery of costs related to closure of these ash basins could have an adverse impact on Electric Utilities and Infrastructure's results of operations, financial position and cash flows.

On May 21, 2019, Duke Energy Carolinas and Duke Energy Progress received orders from the PSCSC granting the companies’ requests for retail rate increases but denying recovery of certain coal ash costs. Duke Energy Carolinas and Duke Energy Progress have appealed these decisions to the South Carolina Supreme Court and those appeals are pending. Electric Utilities and Infrastructure's results of operations, financial position and cash flows could be adversely impacted if coal ash costs are not ultimately approved for recovery. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

In 2019, Duke Energy Indiana filed a general rate case with the IURC, and Duke Energy Carolinas and Duke Energy Progress filed general rate cases with the NCUC. The outcome of these rate cases 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 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 and Duke Energy Progress have petitioned for deferral of future grid improvement costs in their 2019 rate cases. Electric Utilities and Infrastructure's results of operations, financial position and cash flows could be adversely impacted if grid improvement costs are not ultimately approved for recovery and/or deferral treatment.

Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida’s service territories were impacted by several named storms in 2018. Hurricane Florence, Hurricane Michael and Winter Storm Diego caused flooding, extensive damage and widespread power outages to the service territories of Duke Energy Carolinas and Duke Energy Progress. Duke Energy Florida’s service territory was also impacted by Hurricane Michael, a Category 5 hurricane and the most powerful storm to hit the Florida Panhandle in recorded history. In September 2019, Hurricane Dorian impacted Duke Energy Progress and Duke Energy Florida's service territories. A significant portion of the incremental operation and maintenance expenses related to these storms has been deferred. 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. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

94

MD&A SEGMENT RESULTS — ELECTRIC UTILITIES AND INFRASTRUCTURE

On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. Duke Energy Indiana has interpreted the rule to identify the coal ash basin sites impacted and has assessed the amounts of coal ash subject to the rule and a method of compliance. Duke Energy Indiana's interpretation of the requirements of the CCR rule is subject to potential legal challenges and further regulatory approvals, which could result in additional ash basin closure requirements, higher costs of compliance and greater AROs. 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 "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 for the year ended December 31, 2019, for discussion of risks associated with the Tax Act.

Gas Utilities and Infrastructure

	Three Months Ended March 31,
(in millions)	2020		2019		Variance
Operating Revenues	$	664	$	756	$	(92	)
Operating Expenses
Cost of natural gas	199		327		(128		)
Operation, maintenance and other	110		110		—
Depreciation and amortization	66		65		1
Property and other taxes	30		33		(3		)
Total operating expenses	405		535		(130		)
Operating Income	259		221		38
Other Income and Expenses, net	49		40		9
Interest Expense	31		30		1
Income Before Income Taxes	277		231		46
Income Tax Expense	28		5		23
Segment Income	$	249	$	226	$	23
Piedmont LDC throughput (dekatherms)	148,503,995		151,662,741		(3,158,746		)
Duke Energy Midwest LDC throughput (Mcf)	33,785,834		38,538,272		(4,752,438		)

Three Months Ended March 31, 2020, as compared to March 31, 2019

Gas Utilities and Infrastructure’s results were impacted by an increase in operating income primarily due to the North Carolina base rate case and IMR, partially offset by prior year tax benefits related to AFUDC equity from ACP. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• a $134 million decrease due to lower natural gas costs passed through to customers and lower volumes due to warmer weather;

• a $20 million decrease due to return of EDIT to customers; and

• a $7 million decrease due to NCUC approval related to tax reform accounting from fixed-rate contracts in the prior year.

Partially offset by:

• a $53 million increase due to North Carolina base rate case increases; and

• a $12 million increase due to North Carolina IMR increases.

Operating Expenses. The variance was driven primarily by:

• a $128 million decrease in cost of natural gas due to lower natural gas prices, lower volumes and decreased off-system sales natural gas costs.

Other Income and Expenses, net. The variance was driven primarily by higher equity earnings from ACP in the current year.

Income Tax Expense. The increase in tax expense was primarily due to an adjustment, recorded in the first quarter of 2019, related to the income tax recognition for equity method investments and an increase in pretax income, partially offset by an increase in the amortization of excess deferred taxes. The ETRs for the three months ended March 31, 2020, and 2019, were 10.1% and 2.2%, respectively. The increase in the ETR was primarily due to an adjustment related to the income tax recognition for equity method investments recorded in the first quarter of 2019, partially offset by an increase in the amortization of excess deferred taxes. The equity method investment adjustment was immaterial and relates to prior years.

95

MD&A SEGMENT RESULTS — GAS UTILITIES AND INFRASTRUCTURE

Matters Impacting Future Gas Utilities and Infrastructure Results

The COVID-19 pandemic has not had a material impact on Gas Utilities and Infrastructure as of March 31, 2020; however we cannot predict the extent to which the COVID-19 pandemic will impact Gas Utilities and Infrastructure results of operations, financial position and cash flows in the future. Gas Utilities and Infrastructure will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Gas Utilities and Infrastructure customers, suppliers and partners and could cause Gas Utilities and Infrastructure to experience an increase in certain costs, such as bad debt, or cause constructions delays with ACP. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

Gas Utilities and Infrastructure has a 47% ownership interest in 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. Given the legal challenges and ongoing discussions with customers, ACP expects the project to enter full in-service in the first half of 2022.The delays resulting from legal challenges have impacted the cost for the project. Project cost is approximately $8 billion, excluding financing costs. This estimate is based on the current facts available around construction costs and timelines, and is subject to future changes as those facts develop. Abnormal weather, work delays (including delays due to judicial or regulatory action or COVID-19 social distancing) and other conditions may result in cost or schedule modifications, a suspension of AFUDC for ACP and/or impairment charges potentially material to Duke Energy's cash flows, financial position and results of operations. ACP and Duke Energy will continue to consider their options with respect to the foregoing given their existing contractual and legal obligations. See Notes 3 and 11 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and "Variable Interest Entities," respectively, for additional information.

On November 13, 2013, the PUCO issued an order authorizing recovery of MGP costs at certain sites in Ohio with a deadline to complete the MGP environmental investigation and remediation work prior to December 31, 2016. This deadline was subsequently extended to December 31, 2019. Duke Energy Ohio has filed for a request for extension of the deadline. A hearing on that request has not been scheduled. Disallowance of costs incurred, failure to complete the work by the deadline or failure to obtain an extension from the PUCO could result in an adverse impact on Gas 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.

Commercial Renewables

	Three Months Ended March 31,
(in millions)	2020			2019			Variance
Operating Revenues	$	129		$	106		$	23
Operating Expenses
Operation, maintenance and other	69			66			3
Depreciation and amortization	48			40			8
Property and other taxes	8			6			2
Total operating expenses	125			112			13
Operating Income (Loss)	4			(6		)	10
Other Income and Expenses, net	(1		)	(2		)	1
Interest Expense	18			21			(3		)
Loss Before Income Taxes	(15		)	(29		)	14
Income Tax Benefit	(24		)	(35		)	11
Less: Loss Attributable to Noncontrolling Interests	(48		)	(7		)	(41		)
Segment Income	$	57		$	13		$	44
Renewable plant production, GWh	2,437			2,068			369
Net proportional MW capacity in operation(a)	3,502			2,996			506

(a) Certain projects are included in tax equity structures where investors have differing interests in the project's economic attributes. One hundred percent of the tax equity project's capacity is included in the table above.

Three Months Ended March 31, 2020, as compared to March 31, 2019

Commercial Renewables' results were favorable primarily due to new tax equity structures and favorable wind revenue. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The increase was primarily due to favorable wind portfolio revenue as a result of favorable market pricing, favorable wind resource and new solar projects placed in service.

Operating Expenses. The increase was primarily due to higher depreciation expense as a result of new projects placed in service.

Income Tax Benefit. The decrease in the tax benefit was primarily driven by an increase in taxes associated with Duke Energy's interest in tax equity projects and a decrease in pretax losses.

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MD&A SEGMENT RESULTS — COMMERCIAL RENEWABLES

Loss Attributable to Noncontrolling Interests The increase was primarily due to new tax equity structures.

Matters Impacting Future Commercial Renewables Results

The COVID-19 pandemic has not had a material impact on Commercial Renewables as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Commercial Renewables results of operations, financial position and cash flows in the future. Commercial Renewables will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Commercial Renewables customers, suppliers and partners and could cause Commercial Renewables to experience delays in project construction and availability of financing. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

Commercial Renewables continues to experience growth with tax equity structures; however, the future expiration of federal tax incentives could result in adverse impacts to future results of operations, financial position and cash flows.

Duke Energy continues to monitor recoverability of its renewable merchant plants principally in the Electric Reliability Council of Texas West market, due to declining market pricing and declining long-term forecasted energy prices, primarily driven by lower forecasted natural gas prices. Although these assets were not impaired, a continued decline in energy market pricing would likely result in a future impairment. Impairment of these assets could result in adverse impacts to the future results of operations, financial position and cash flows of Commercial Renewables.

Other

	Three Months Ended March 31,
(in millions)	2020			2019			Variance
Operating Revenues	$	23		$	21		$	2
Operating Expenses	(89		)	28			(117		)
Operating Income (Loss)	112			(7		)	119
Other Income and Expenses, net	(33		)	44			(77		)
Interest Expense	171			171			—
Loss Before Income Taxes	(92		)	(134		)	42
Income Tax Benefit	(19		)	(45		)	26
Less: Preferred Dividends	39			—			39
Net Loss	$	(112	)	$	(89	)	$	(23	)

Three Months Ended March 31, 2020, as compared to March 31, 2019

The variance was driven by lower returns on investments and the declaration of preferred stock dividends, partially offset by a reversal of corporate allocated severance costs. The following is a detailed discussion of the variance drivers by line item.

Operating Expenses. The decrease was primarily driven by the deferral of 2018 corporate allocated severance costs due to the partial settlement between Duke Energy Carolinas and the Public Staff of the NCUC related to the 2019 North Carolina retail rate case.

Other Income and Expenses, net. The variance was primarily due to lower returns on investments that fund certain employee benefit obligations as well as lower Bison investment income.

Income Tax Benefit. The decrease in the tax benefit was primarily driven by a decrease in pretax losses.

Preferred Dividends. The variance was driven by the declaration of preferred stock dividends on preferred stock issued in 2019.

Matters Impacting Future Other Results

The COVID-19 pandemic has not had a material impact on Other as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Other results of operations, financial position and cash flows in the future. Other will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

97

MD&A DUKE ENERGY CAROLINAS

DUKE ENERGY CAROLINAS

Results of Operations

	Three Months Ended March 31,
(in millions)	2020		2019		Variance
Operating Revenues	$	1,748	$	1,744	$	4
Operating Expenses
Fuel used in electric generation and purchased power	453		472		(19		)
Operation, maintenance and other	386		440		(54		)
Depreciation and amortization	343		317		26
Property and other taxes	81		80		1
Impairment charges	2		—		2
Total operating expenses	1,265		1,309		(44		)
Gains on Sales of Other Assets and Other, net	1		—		1
Operating Income	484		435		49
Other Income and Expenses, net	43		31		12
Interest Expense	123		110		13
Income Before Income Taxes	404		356		48
Income Tax Expense	65		63		2
Net Income	$	339	$	293	$	46

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	2020
Residential sales	(5.1	)%
General service sales	(0.1	)%
Industrial sales	(1.2	)%
Wholesale power sales	(3.0	)%
Joint dispatch sales	(54.0	)%
Total sales	(2.7	)%
Average number of customers	1.8	%

Three Months Ended March 31, 2020, as compared to March 31, 2019

Operating Revenues. The variance was driven primarily by:

• a $23 million increase in weather-normal retail sales volumes; and

• an $11 million increase due to higher pricing from the South Carolina retail rate case, net of a return of EDIT to customers.

Partially offset by:

• a $26 million decrease in retail sales due to unfavorable weather in the current year.

Operating Expenses. The variance was driven primarily by:

• a $54 million decrease in operation, maintenance and other expense primarily driven by the deferral of 2018 severance costs due to the partial settlement agreement between Duke Energy Carolinas and the Public Staff of the NCUC related to the 2019 North Carolina retail rate case, partially offset by higher storm restoration costs; and

• a $19 million decrease in fuel used in electric generation and purchased power primarily due to changes in the generation mix.

Partially offset by:

• a $26 million increase in depreciation and amortization expense primarily due to additional plant in service and new depreciation rates associated with the South Carolina rate case.

Other Income and Expenses, net. The variance was primarily due to higher AFUDC equity in the current year.

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

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MD&A DUKE ENERGY CAROLINAS

Matters Impacting Future Results

The COVID-19 pandemic has not had a material impact on Duke Energy Carolinas as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Duke Energy Carolinas results of operations, financial position and cash flows in the future. Duke Energy Carolinas will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Duke Energy Carolinas customers, suppliers and partners and could cause Duke Energy Carolinas to experience an increase in certain costs, such as bad debt, and a reduction in the demand for energy. Duke Energy Carolinas also has pending rate case proceedings that have been delayed. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

On December 31, 2019, Duke Energy Carolinas entered into a settlement agreement with NCDEQ and certain community groups under which Duke Energy Carolinas agreed to excavate five of the six remaining coal ash basins in North Carolina with ash moved to on-site lined landfills. At the one remaining basin, uncapped basin ash will be excavated and moved to lined landfills. An order from regulatory authorities disallowing recovery of costs related to closure of these ash basins could have an adverse impact on Duke Energy Carolinas’ results of operations, financial position and cash flows.

Duke Energy Carolinas filed a general rate case with the NCUC on September 30, 2019. The outcome of this rate case could materially impact Duke Energy Carolina's results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," 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 has petitioned for deferral of future grid improvement costs in its 2019 rate case. Duke Energy Carolinas' results of operations, financial position and cash flows could be adversely impacted if grid improvement costs are not ultimately approved for recovery and/or deferral treatment.

Duke Energy Carolinas’ service territory was impacted by several named storms in 2018. Hurricane Florence, Hurricane Michael and Winter Storm Diego caused flooding, extensive damage and widespread power outages in the service territory. A significant portion of the incremental operation and maintenance expenses related to these storms has been deferred. An order from regulatory authorities disallowing the future recovery of storm restoration costs could have an adverse impact on Duke Energy Carolinas' results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

On May 21, 2019, the PSCSC issued an order granting Duke Energy Carolinas request for a retail rate increase but denying recovery of certain coal ash costs. Duke Energy Carolinas has appealed this decision to the South Carolina Supreme Court and that appeal is pending. Duke Energy Carolinas' results of operations, financial position and cash flows could be adversely impacted if coal ash costs are not ultimately approved for recovery. 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 for the year ended December 31, 2019, for discussion of risks associated with the Tax Act.

PROGRESS ENERGY

Results of Operations

	Three Months Ended March 31,
(in millions)	2020			2019			Variance
Operating Revenues	$	2,422		$	2,572		$	(150	)
Operating Expenses
Fuel used in electric generation and purchased power	763			925			(162		)
Operation, maintenance and other	554			567			(13		)
Depreciation and amortization	452			455			(3		)
Property and other taxes	135			137			(2		)
Total operating expenses	1,904			2,084			(180		)
Losses on Sales of Other Assets and Other, net	(1		)	—			(1		)
Operating Income	517			488			29
Other Income and Expenses, net	32			31			1
Interest Expense	206			219			(13		)
Income Before Income Taxes	343			300			43
Income Tax Expense	60			52			8
Net Income	283			248			35
Less: Net Loss Attributable to Noncontrolling Interests	—			(1		)	1
Net Income Attributable to Parent	$	283		$	249		$	34

99

MD&A PROGRESS ENERGY

Three Months Ended March 31, 2020, as compared to March 31, 2019

Operating Revenues. The variance was driven primarily by:

• a $160 million decrease in fuel cost recovery driven by lower fuel prices and volumes as well as less Duke Energy Progress native load transfer sales in the current year;

• a $16 million decrease in wholesale power revenues, net of fuel, primarily due to coal ash cost recovery in the prior year at Duke Energy Progress, partially offset by increased demand at Duke Energy Florida;

• a $15 million decrease in rider revenues primarily due to the Crystal River 3 Uprate regulatory asset being fully recovered in 2019 at Duke Energy Florida; and

• a $7 million decrease in retail sales, net of fuel revenues, due to unfavorable weather in the current year at Duke Energy Progress, partially offset by favorable weather in the current year at Duke Energy Florida.

Partially offset by:

• a $17 million increase in retail pricing due to base rate adjustments related to annual increases from the 2017 Settlement Agreement and the Solar Base Rate Adjustment at Duke Energy Florida;

• a $12 million increase in storm revenues due to Hurricane Dorian collections at Duke Energy Florida;

• a $10 million increase in other revenues primarily due to increased transmission revenues at Duke Energy Florida; and

• an $8 million increase due to higher pricing from the South Carolina retail rate case, net of a return of EDIT to customers at Duke Energy Progress.

Operating Expenses. The variance was driven primarily by:

• a $162 million decrease in fuel used in electric generation and purchased power primarily due to lower demand and changes in generation mix at Duke Energy Progress and lower fuel costs, net of deferrals at Duke Energy Florida; and

• a $13 million decrease in operation, maintenance and other expense at Duke Energy Progress primarily driven by the deferral of 2018 severance costs due to the partial settlement agreement between Duke Energy Carolinas and the Public Staff of the NCUC related to the 2019 North Carolina retail rate case, partially offset by storm cost amortizations and employee benefits at Duke Energy Florida.

Interest Expense. The variance was driven primarily by lower interest rates on outstanding debt at Duke Energy Progress.

Income Tax Expense. The increase in tax expense was primarily due to an increase in pretax income.

Matters Impacting Future Results

The COVID-19 pandemic has not had a material impact on Progress Energy as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Progress Energy results of operations, financial position and cash flows in the future. Progress Energy will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Progress Energy customers, suppliers and partners and could cause Progress Energy to experience an increase in certain costs, such as bad debt, and a reduction in the demand for energy. Progress Energy also has various pending rate case proceedings that have been delayed. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

On December 31, 2019, Duke Energy Progress entered into a settlement agreement with NCDEQ and certain community groups under which Duke Energy Progress agreed to excavate two of the three remaining coal ash basins in North Carolina with ash moved to on-site lined landfills. At the one remaining basin, uncapped basin ash will be excavated and moved to lined landfills. An order from regulatory authorities disallowing recovery of costs related to closure of these ash basins could have an adverse impact on Duke Energy Progress’ results of operations, financial position and cash flows.

Duke Energy Progress filed a general rate case with the NCUC on October 30, 2019. The outcome of this rate case 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.

Duke Energy Progress has petitioned for deferral of future grid improvement costs in its 2019 rate case. Progress Energy's results of operations, financial position and cash flows could be adversely impacted if grid improvement costs are not ultimately approved for recovery and/or deferral treatment.

Duke Energy Progress and Duke Energy Florida’s service territories were impacted by several named storms in 2018. Hurricane Florence, Hurricane Michael and Winter Storm Diego caused flooding, extensive damage and widespread power outages to the service territory of Duke Energy Progress. Duke Energy Florida’s service territory was also impacted by Hurricane Michael, a Category 5 hurricane and the most powerful storm to hit the Florida Panhandle in recorded history. In September 2019, Hurricane Dorian impacted Duke Energy Progress' and Duke Energy Florida's service territories. A significant portion of the incremental operation and maintenance expenses related to these storms has been deferred. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration 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.

100

MD&A PROGRESS ENERGY

On May 21, 2019, the PSCSC issued an order granting Duke Energy Progress' request for a retail rate increase but denying recovery of certain coal ash costs. Duke Energy Progress has appealed this decision to the South Carolina Supreme Court and that appeal is pending. Progress Energy's results of operations, financial position and cash flows could be adversely impacted if coal ash costs are not ultimately approved for recovery. 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 for the year ended December 31, 2019, for discussion of risks associated with the Tax Act.

DUKE ENERGY PROGRESS

Results of Operations

	Three Months Ended March 31,
(in millions)	2020			2019		Variance
Operating Revenues	$	1,338		$	1,484	$	(146	)
Operating Expenses
Fuel used in electric generation and purchased power	405			515		(110		)
Operation, maintenance and other	305			335		(30		)
Depreciation and amortization	287			290		(3		)
Property and other taxes	47			44		3
Total operating expenses	1,044			1,184		(140		)
Losses on Sales of Other Assets and Other, net	(1		)	—		(1		)
Operating Income	293			300		(7		)
Other Income and Expenses, net	22			24		(2		)
Interest Expense	69			77		(8		)
Income Before Income Taxes	246			247		(1		)
Income Tax Expense	42			44		(2		)
Net Income	$	204		$	203	$	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 period	2020
Residential sales	(5.7	)%
General service sales	(1.9	)%
Industrial sales	(0.2	)%
Wholesale power sales	(7.4	)%
Joint dispatch sales	(0.5	)%
Total sales	(4.1	)%
Average number of customers	1.4	%

Three Months Ended March 31, 2020, as compared to March 31, 2019

Operating Revenues. The variance was driven primarily by:

• a $109 million decrease in fuel cost recovery driven by lower fuel prices and volumes as well as less native load transfer sales in the current year;

• a $24 million decrease in retail sales due to unfavorable weather in the current year; and

• a $23 million decrease in wholesale power revenues, net of fuel, primarily due to coal ash cost recovery in the prior year.

Partially Offset by:

• an $8 million increase due to higher pricing from the South Carolina retail rate case, net of a return of EDIT to customers.

Operating Expenses. The variance was driven primarily by:

• a $110 million decrease in fuel used in electric generation and purchased power primarily due to lower demand and changes in generation mix; and

• a $30 million decrease in operation, maintenance and other expense primarily driven by the deferral of 2018 severance costs due to the partial settlement agreement between Duke Energy Carolinas and the Public Staff of the NCUC related to the 2019 North Carolina retail rate case.

Interest Expense. The variance was driven primarily by lower interest rates on outstanding debt.

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MD&A DUKE ENERGY PROGRESS

Matters Impacting Future Results

The COVID-19 pandemic has not had a material impact on Duke Energy Progress as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Duke Energy Progress results of operations, financial position and cash flows in the future. Duke Energy Progress will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Duke Energy Progress customers, suppliers and partners and could cause Duke Energy Progress to experience an increase in certain costs, such as bad debt, and a reduction in the demand for energy. Duke Energy Progress also has pending rate case proceedings that have been delayed. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

On December 31, 2019, Duke Energy Progress entered into a settlement agreement with NCDEQ and certain community groups under which Duke Energy Progress agreed to excavate two of the three remaining coal ash basins in North Carolina with ash moved to on-site lined landfills. At the one remaining basin, uncapped basin ash will be excavated and moved to lined landfills. An order from regulatory authorities disallowing recovery of costs related to closure of these ash basins could have an adverse impact on Duke Energy Progress’ results of operations, financial position and cash flows.

Duke Energy Progress filed a general rate case with the NCUC on October 30, 2019. The outcome of this rate case could materially impact Duke Energy Progress' results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

On May 21, 2019, the PSCSC issued an order granting Duke Energy Progress' request for a retail rate increase but denying recovery of certain coal ash costs. Duke Energy Progress has appealed this decision to the South Carolina Supreme Court and that appeal is pending. Duke Energy Progress' results of operations, financial position and cash flows could be adversely impacted if coal ash costs are not ultimately approved for recovery. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

Duke Energy Progress has petitioned for deferral of future grid improvement costs in its 2019 rate case. Duke Energy Progress' results of operations, financial position and cash flows could be adversely impacted if grid improvement costs are not ultimately approved for recovery and/or deferral treatment.

Duke Energy Progress' service territory was impacted by several named storms in 2018. Hurricane Florence, Hurricane Michael and Winter Storm Diego caused flooding, extensive damage and widespread power outages in the service territory. In September 2019, Hurricane Dorian reached the Carolinas bringing high winds, tornadoes and heavy rain, impacting about 300,000 customers within the service territory. A significant portion of the incremental operation and maintenance expenses related to these storms has been deferred. An order from regulatory authorities disallowing the deferral and future recovery of storm restoration costs could have an adverse impact on Duke Energy Progress' 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 for the year ended December 31, 2019, for discussion of risks associated with the Tax Act.

DUKE ENERGY FLORIDA

Results of Operations

	Three Months Ended March 31,
(in millions)	2020		2019		Variance
Operating Revenues	$	1,080	$	1,086	$	(6	)
Operating Expenses
Fuel used in electric generation and purchased power	358		410		(52		)
Operation, maintenance and other	245		230		15
Depreciation and amortization	165		165		—
Property and other taxes	88		93		(5		)
Total operating expenses	856		898		(42		)
Operating Income	224		188		36
Other Income and Expenses, net	10		13		(3		)
Interest Expense	84		82		2
Income Before Income Taxes	150		119		31
Income Tax Expense	30		23		7
Net Income	$	120	$	96	$	24

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MD&A DUKE ENERGY FLORIDA

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	2020
Residential sales	(3.7	)%
General service sales	0.4	%
Industrial sales	13.6	%
Wholesale and other	(18.0	)%
Total sales	3.6	%
Average number of customers	1.5	%

Three Months Ended March 31, 2020, as compared to March 31, 2019

Operating Revenues. The variance was driven primarily by:

• a $51 million decrease in fuel revenues primarily due to a decrease in fuel rates billed to retail customers; and

• a $15 million decrease in rider revenue requirements primarily due to the Crystal River 3 Uprate regulatory asset being fully recovered in 2019.

Partially offset by:

• a $17 million increase in retail pricing due to base rate adjustments related to annual increases from the 2017 Settlement Agreement and the Solar Base Rate Adjustment;

• a $17 million increase in retail sales, net of fuel revenues, due to favorable weather in the current year;

• a $12 million increase in storm revenues due to Hurricane Dorian collections;

• a $10 million increase in other revenues primarily due to increased transmission revenues; and

• a $7 million increase in wholesale power revenues, net of fuel, primarily due to increased demand.

Operating Expenses. The variance was driven primarily by:

• a $52 million decrease in fuel used in electric generation and purchased power primarily due to lower fuel costs, net of deferrals.

Partially offset by:

• a $15 million increase in operation, maintenance and other expense primarily due to storm cost amortizations and employee benefits.

Income Tax Expense. The increase in tax expense was primarily due to an increase in pretax income.

Matters Impacting Future Results

The COVID-19 pandemic has not had a material impact on Duke Energy Florida as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Duke Energy Florida results of operations, financial position and cash flows in the future. Duke Energy Florida will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Duke Energy Florida customers, suppliers and partners and could cause Duke Energy Florida to experience an increase in certain costs, such as bad debt, and a reduction in the demand for energy. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

On October 10, 2018, Hurricane Michael made landfall on Florida's Panhandle as a Category 5 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, particularly from Panama City Beach to Mexico Beach. In September 2019, Duke Energy Florida’s service territory was threatened by Hurricane Dorian with landfall as a possible Category 5 hurricane and therefore Duke Energy Florida incurred costs to secure necessary resources to be prepared for that potential impact. A significant portion of the incremental operation and maintenance expenses related to these storms has been deferred. 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 Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

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MD&A DUKE ENERGY OHIO

DUKE ENERGY OHIO

Results of Operations

	Three Months Ended March 31,
(in millions)	2020		2019		Variance
Operating Revenues
Regulated electric	$	346	$	355	$	(9	)
Regulated natural gas	152		176		(24		)
Total operating revenues	498		531		(33		)
Operating Expenses
Fuel used in electric generation and purchased power	87		93		(6		)
Cost of natural gas	37		54		(17		)
Operation, maintenance and other	123		132		(9		)
Depreciation and amortization	68		64		4
Property and other taxes	83		84		(1		)
Total operating expenses	398		427		(29		)
Operating Income	100		104		(4		)
Other Income and Expenses, net	3		9		(6		)
Interest Expense	24		30		(6		)
Income Before Income Taxes	79		83		(4		)
Income Tax Expense	14		14		—
Net Income	$	65	$	69	$	(4	)

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	2020		2020
Residential sales	(9.2	)%	(16.1	)%
General service sales	(3.4	)%	(13.9	)%
Industrial sales	(2.1	)%	(2.5	)%
Wholesale electric power sales	(33.1	)%	n/a
Other natural gas sales	n/a		(1.9	)%
Total sales	(5.5	)%	(12.3	)%
Average number of customers	0.8	%	0.6	%

Three Months Ended March 31, 2020, as compared to March 31, 2019

Operating Revenues. The variance was driven primarily by:

• a $28 million decrease in fuel related revenues primarily due to lower natural gas prices as well as decreased volumes;

• a $10 million decrease due to unfavorable weather in the current year; and

• a $5 million decrease in other revenues due to lower OVEC sales into PJM.

Partially offset by:

• a $5 million increase in retail pricing primarily due to gas rate case impacts in Kentucky; and

• a $4 million increase in rider revenues primarily related to the Distribution Capital Investment rider as a result of additional investments and the new Legacy Generation Riders arising from Ohio HB6, which provide an alternative method of recovering OVEC losses, partially offset by decreased Energy Efficiency Rider Revenue.

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MD&A DUKE ENERGY OHIO

Operating Expenses. The variance was driven primarily by:

• a $23 million decrease in fuel expense, primarily driven by lower natural gas prices; and

• a $9 million decrease in operations, maintenance and other expense primarily due to the timing of training and inspection programs for Customer Delivery and Customer Solutions as well as lower storm costs.

Partially offset by:

• a $4 million increase in depreciation and amortization primarily driven by an increase in distribution plant.

Other Income and Expenses, net. The variance was primarily due to lower intercompany interest income due to decreased borrowing and lower AFUDC equity.

Interest Expense. The variance was primarily driven by lower debt outstanding in the current year and lower post in-service carrying costs, partially offset by higher intercompany interest expense due to increased borrowing.

Matters Impacting Future Results

The COVID-19 pandemic has not had a material impact on Duke Energy Ohio as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Duke Energy Ohio results of operations, financial position and cash flows in the future. Duke Energy Ohio will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Duke Energy Ohio customers, suppliers and partners and could cause Duke Energy Ohio to experience an increase in certain costs, such as bad debt, and a reduction in the demand for energy. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

On November 13, 2013, the PUCO issued an order authorizing recovery of MGP costs at certain sites in Ohio with a deadline to complete the MGP environmental investigation and remediation work prior to December 31, 2016. This deadline was subsequently extended to December 31, 2019. Duke Energy Ohio has filed a request for extension of the deadline. A hearing on that request has not been scheduled. Disallowance of costs incurred, failure to complete the work by the deadline or failure to obtain an extension from the PUCO could result in an adverse impact on Duke Energy Ohio’s results of operations, financial position and cash flows. See Note 3 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

DUKE ENERGY INDIANA

Results of Operations

	Three Months Ended March 31,
(in millions)	2020		2019			Variance
Operating Revenues	$	692	$	768		$	(76	)
Operating Expenses
Fuel used in electric generation and purchased power	194		257			(63		)
Operation, maintenance and other	186		189			(3		)
Depreciation and amortization	132		131			1
Property and other taxes	22		19			3
Total operating expenses	534		596			(62		)
Losses on Sales of Other Assets and Other, net	—		(3		)	3
Operating Income	158		169			(11		)
Other Income and Expenses, net	10		19			(9		)
Interest Expense	43		43			—
Income Before Income Taxes	125		145			(20		)
Income Tax Expense	26		35			(9		)
Net Income	$	99	$	110		$	(11	)

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	2020
Residential sales	(10.0	)%
General service sales	(4.8	)%
Industrial sales	(2.6	)%
Wholesale power sales	1.8	%
Total sales	(5.3	)%
Average number of customers	1.1	%

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MD&A DUKE ENERGY INDIANA

Three Months Ended March 31, 2020, as compared to March 31, 2019

Operating Revenues. The variance was driven primarily by:

• a $58 million decrease in fuel revenues primarily due to lower cost of fuel and unseasonably milder weather;

• a $9 million decrease in retail sales due to unfavorable weather in the current year; and

• an $8 million decrease in rider revenues primarily related to lower Edwardsport IGCC sales volumes.

Operating Expenses. The variance was driven primarily by:

• a $63 million decrease in fuel used in electric generation and purchased power expense primarily due to lower coal and natural gas costs and lower amortization of deferred fuel costs, partially offset by higher purchased power expense.

Other Income and Expenses, net. The decrease was primarily due to life insurance proceeds received in the prior year.

Income Tax Expense. The decrease in income tax expense was primarily due to a decrease in pretax income and an increase in the amortization of excess deferred taxes.

Matters Impacting Future Results

The COVID-19 pandemic has not had a material impact on Duke Energy Indiana as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Duke Energy Indiana results of operations, financial position and cash flows in the future. Duke Energy Indiana will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Duke Energy Indiana customers, suppliers and partners and could cause Duke Energy Indiana to experience an increase in certain costs, such as bad debt, and a reduction in the demand for energy. Duke Energy Indiana also has a pending rate case proceeding that could be delayed. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

Duke Energy Indiana filed a general rate case with the IURC on July 2, 2019, its first general rate case in 16 years. The outcome of this rate case could materially impact 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.

On April 17, 2015, the EPA published in the Federal Register a rule to regulate the disposal of CCR from electric utilities as solid waste. Duke Energy Indiana has interpreted the rule to identify the coal ash basin sites impacted and has assessed the amounts of coal ash subject to the rule and a method of compliance. Duke Energy Indiana's interpretation of the requirements of the CCR rule is subject to potential legal challenges and further regulatory approvals, which could result in additional ash basin closure requirements, higher costs of compliance and greater AROs. 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.

PIEDMONT

Results of Operations

	Three Months Ended March 31,
(in millions)	2020		2019		Variance
Operating Revenues	$	512	$	579	$	(67	)
Operating Expenses
Cost of natural gas	162		273		(111		)
Operation, maintenance and other	80		80		—
Depreciation and amortization	45		42		3
Property and other taxes	12		12		—
Total operating expenses	299		407		(108		)
Operating Income	213		172		41
Other Income and Expenses, net	12		6		6
Interest Expense	27		22		5
Income Before Income Taxes	198		156		42
Income Tax Expense	20		34		(14		)
Net Income	$	178	$	122	$	56

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MD&A PIEDMONT

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	2020
Residential deliveries	(13.1	)%
Commercial deliveries	(12.4	)%
Industrial deliveries	(2.1	)%
Power generation deliveries	5.8	%
For resale	(23.7	)%
Total throughput deliveries	(2.1	)%
Secondary market volumes	(26.3	)%
Average number of customers	1.4	%

Due to the margin decoupling mechanism in North Carolina and the weather normalization adjustment (WNA) mechanisms in South Carolina and Tennessee and fixed-price contracts with most power generation customers, changes in throughput deliveries do not have a material impact on Piedmont's revenues or earnings. The margin decoupling mechanism adjusts for variations in residential and commercial use per customer, including those due to weather and conservation. The WNA mechanisms mostly offset the impact of weather on bills rendered, but do not ensure full recovery of approved margin during periods when winter weather is significantly warmer or colder than normal.

Three Months Ended March 31, 2020, as compared to March 31, 2019

Operating Revenues. The variance was driven primarily by:

• a $111 million decrease due to lower natural gas costs passed through to customers;

• a $20 million decrease due to return of EDIT to customers; and

• a $7 million decrease due to NCUC approval related to tax reform accounting from fixed-rate contracts in the prior year.

Partially offset by:

• a $53 million increase due to North Carolina base rate case increases; and

• a $12 million increase due to North Carolina IMR increases.

Operating Expenses. The variance was driven primarily by:

• a $111 million decrease in cost of natural gas due to lower natural gas prices.

Income Tax Expense. The decrease in income tax expense was primarily due to an increase in the amortization of excess deferred taxes, partially offset by an increase in pretax income.

Matters Impacting Future Results

The COVID-19 pandemic has not had a material impact on Piedmont as of March 31, 2020; however, we cannot predict the extent to which the COVID-19 pandemic will impact Piedmont results of operations, financial position and cash flows in the future. Piedmont will continue to actively monitor the impacts of COVID-19 including the potential economic slowdown caused by business closures or by reduced operations of businesses and governmental agencies. The pandemic and resultant economic slowdown could adversely affect Piedmont customers, suppliers and partners and could cause Piedmont to experience an increase in certain costs, such as bad debt. Furthermore, the actions of federal, state or local authorities may impact our business operations in ways that we currently cannot anticipate. See Item 1A. Risk Factors for discussion of risks associated with COVID-19 and Liquidity and Capital Resources within this section for a discussion of liquidity impacts of COVID-19.

LIQUIDITY AND CAPITAL RESOURCES

Sources and Uses of Cash

Duke Energy relies primarily upon cash flows from operations, debt and equity 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. Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2019, included a summary and detailed discussion of projected primary sources and uses of cash for 2020 to 2022.

In March 2020, capital markets experienced significant liquidity challenges as a result of the ongoing uncertainty around the economic impacts from COVID-19. Investor demand for liquidity and cash holdings created substantial volatility, particularly in the short-term commercial paper market. As such, issuers of commercial paper experienced difficulties issuing commercial paper for longer duration at competitive interest rates. During March 2020 and in response to market volatility and the ongoing economic uncertainty related to COVID-19, Duke Energy took several actions to enhance the Company's liquidity position including:

• Duke Energy drew down the remaining $500 million of availability under the existing $1 billion Three-Year Revolving Credit Facility; and

• Duke Energy entered into and borrowed the full amount under a $1.5 billion, 364-day Term Loan Credit Agreement. The Term Loan Credit Agreement contains a provision for additional borrowing capacity of $500 million. Duke Energy exercised the provision and borrowed an additional $188 million, for a total borrowing of approximately $1.7 billion.

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MD&A LIQUIDITY AND CAPITAL RESOURCES

As of March 31, 2020, Duke Energy had approximately $1.5 billion of cash on hand and $4.8 billion available under its $8 billion Master Credit Facility. Duke Energy has additional liquidity available totaling approximately $2.6 billion under outstanding equity forward agreements. Duke Energy expects to have sufficient liquidity in the form of cash on hand, cash from operations and available credit capacity to support its funding needs. Duke Energy continues to monitor access to credit and equity markets.

In addition to the $500 million draw under the Three-Year Revolving Credit Facility and $1.7 billion of incremental borrowings under the new 364-day Term Loan Credit Agreement, Duke Energy also issued approximately $1.5 billion of debt and raised $67 million of common equity through its dividend reinvestment program during the three months ended March 31, 2020. Refer to Notes 5 and 13 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities" and "Stockholders' Equity," respectively, for information regarding Duke Energy's debt and equity issuances, debt maturities and available credit facilities including the Master Credit Facility.

In light of the COVID-19 pandemic, Duke Energy currently does not expect significant changes to the projected capital and investment expenditures provided in the Form 10-K for the year ended December 31, 2019. However, Duke Energy will continue to reassess capital projects depending on the duration and severity of economic impacts caused by the pandemic.

Cash Flow Information

The following table summarizes Duke Energy’s cash flows.

	Three Months Ended
	March 31,
(in millions)	2020			2019
Cash flows provided by (used in):
Operating activities	$	1,554		$	1,239
Investing activities	(3,022		)	(2,713		)
Financing activities	2,593			1,433
Net increase (decrease) in cash, cash equivalents and restricted cash	1,125			(41		)
Cash, cash equivalents and restricted cash at beginning of period	573			591
Cash, cash equivalents and restricted cash at end of period	$	1,698		$	550

OPERATING CASH FLOWS

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

	Three Months Ended
	March 31,
(in millions)	2020			2019			Variance
Net income	$	890		$	893		$	(3	)
Non-cash adjustments to net income	1,627			1,299			328
Payments for asset retirement obligations	(132		)	(152		)	20
Working capital	(831		)	(801		)	(30		)
Net cash provided by operating activities	$	1,554		$	1,239		$	315

The variance was primarily due to timing of payments of property taxes, higher Nuclear Electric Insurance Limited (NEIL) refunds in the current year and lower storm costs in the current year.

INVESTING CASH FLOWS

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

	Three Months Ended
	March 31,
(in millions)	2020			2019			Variance
Capital, investment and acquisition expenditures	$	(2,909	)	$	(2,630	)	$	(279	)
Other investing items	(113		)	(83		)	(30		)
Net cash used in investing activities	$	(3,022	)	$	(2,713	)	$	(309	)

The variance relates to an increase in capital expenditures due to higher overall investments primarily in the Commercial Renewables segment.

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MD&A LIQUIDITY AND CAPITAL RESOURCES

FINANCING CASH FLOWS

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

	Three Months Ended
	March 31,
(in millions)	2020			2019			Variance
Issuances of long-term debt, net	$	1,662		$	1,536		$	126
Issuances of common stock	40			13			27
Issuances of preferred stock	—			974			(974		)
Notes payable, commercial paper and other short-term borrowings	1,569			(408		)	1,977
Dividends paid	(707		)	(649		)	(58		)
Contributions from noncontrolling interests	103			6			97
Other financing items	(74		)	(39		)	(35		)
Net cash provided by financing activities	$	2,593		$	1,433		$	1,160

The variance was primarily due to:

• a $1,977 million increase in net proceeds from issuances of notes payable and commercial paper primarily due to borrowings of $1.7 billion under the 364-day Term Loan Credit Agreement.

Partially offset by:

• a $974 million decrease in proceeds from the issuance of preferred stock.

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, coal ash and other environmental matters. These regulations can be changed from time to time and result in new obligations of 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.

Off-Balance Sheet Arrangements

During the three months ended March 31, 2020, there were no material changes to Duke Energy’s off-balance sheet arrangements. See Note 11 – Variable Interest Entities and Note 13 – Stockholders' Equity to the Condensed Consolidated Financial Statements for information regarding ACP and equity forward sales agreements. 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 for the year ended December 31, 2019.

Contractual Obligations

Duke Energy enters into contracts that require payment of cash at certain specified periods, based on certain specified minimum quantities and prices. During the three months ended March 31, 2020, there were no material changes in Duke Energy's contractual obligations. For an in-depth discussion of Duke Energy’s contractual obligations, see “Contractual Obligations” and “Quantitative and Qualitative Disclosures about Market Risk” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2019.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

For an in-depth discussion of the Duke Energy Registrants' market risks, see “Quantitative and Qualitative Disclosures about Market Risk” in Item 7 of the Annual Report on Form 10-K for the Duke Energy Registrants. During the three months ended March 31, 2020, there were no material changes to the Duke Energy Registrants' disclosures about market risk, other than as described below.

Credit Risk

In response to the COVID-19 pandemic, in March 2020, the Duke Energy Subsidiary Registrants announced a suspension of disconnections for nonpayment to be effective throughout the national emergency. This is expected to result in an increase in charge-offs over historical levels. In addition, the Registrants are monitoring the effects of the resultant economic slowdown on counterparties’ abilities to perform under their contractual obligations.

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 Exchange Act is recorded, processed, summarized and reported, within the time periods specified by the SEC rules and forms.

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MD&A OTHER MATTERS

Disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Duke Energy Registrants in the reports they file or submit under the Exchange Act is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, the Duke Energy Registrants have evaluated the effectiveness of their disclosure controls and procedures (as such term is defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act) as of March 31, 2020, and, based upon this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these controls and procedures are effective in providing reasonable assurance of compliance.

Changes in Internal Control over Financial Reporting

Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, the Duke Energy Registrants have evaluated changes in internal control over financial reporting (as such term is defined in Rules 13a-15 and 15d-15 under the Exchange Act) that occurred during the fiscal quarter ended March 31, 2020, and have concluded no change has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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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. For additional information, see Item 3, "Legal Proceedings," in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2019.

ITEM 1A. RISK FACTORS

In addition to the other information set forth in this report, careful consideration should be given to the factors discussed in Part I, “Item 1A. Risk Factors” in the Duke Energy Registrants' Annual Report on Form 10-K for the year ended December 31, 2019, which could materially affect the Duke Energy Registrants’ financial condition or future results. As described in the Duke Energy Form 8-K Filing on May 8, 2020, the information presented below updates, and should be read in conjunction with, the risk factors and information disclosed in the Annual Report on Form 10-K for the year ended December 31, 2019.

The Duke Energy Registrants’ operations have been and may be affected by COVID-19 in ways listed below and in ways the registrants cannot predict at this time.

The COVID-19 pandemic has begun to impact the Duke Energy Registrants' business strategy, results of operations, financial position and cash flows, albeit not materially as of this filing date, from specific activities listed below:

• Decreased demand for electricity and natural gas;

• Delays in rate cases and other legal proceedings; and

• The health and availability of our critical personnel and their ability to perform business functions.

Furthermore, due to the unpredictability of the COVID-19 pandemic’s ongoing impact on global health and economic stability as of this filing date, the Duke Energy Registrants expect that the activities listed below could negatively impact their business strategy, results of operations, financial position and cash flows:

• An inability to procure satisfactory levels of fuels or other necessary equipment to continue production of electricity and delivery of natural gas;

• An inability to obtain labor or equipment necessary for the construction of generation projects or pipeline expansion;

• An inability to maintain information technology systems and protections from cyberattack;

• An inability to obtain financing in volatile financial markets;

• Additional federal regulation tied to stimulus and other aid packages;

• Impairment charges to certain assets, including goodwill; and

• Actions of state utility commissions or federal or state governments to allow customers to suspend or delay payment of bills related to the provision of electric or gas services.

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

None.

111

EXHIBITS

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	One-Hundred and Second Supplemental Indenture, dated as of August 14, 2019 (incorporated by reference to Exhibit 4.1 to Registrant’s Current Report on Form 8-K filed on January 8, 2020, File No. 1-4928).		X
4.2	One-Hundred and Third Supplemental Indenture, dated as of January 8, 2020 (incorporated by reference to Exhibit 4.2 to Registrant’s Current Report on Form 8-K filed on January 8, 2020, File No. 1-4928).		X
4.3	One-Hundred and Fourth Supplemental Indenture, dated as of January 8, 2020 (incorporated by reference to Exhibit 4.3 to Registrant’s Current Report on Form 8-K filed on January 8, 2020, File No. 1-4928).		X
4.4	Seventieth Supplemental Indenture, dated as of March 12, 2020 (incorporated by reference to Exhibit 4.1 to Registrant’s Current Report on Form 8-K filed on March 12, 2020, File No. 1-3543).							X
10.1	Amendment No. 5 and Consent, dated as of March 16, 2020, among Registrants, the Lenders party thereto, the Issuing Lenders party thereto, and Wells Fargo Bank, N.A., as Administrative Agent, and Swingline Lender (incorporated by reference to Exhibit 10.1 to Registrants' Current Report on Form 8-K, filed on March 17, 2020, File Nos. 1-32853, 1-4928, 1-3382, 1-3274, 1-1232, 1-3543, 1-6196).	X	X		X	X	X	X	X
10.2	$1.5 billion 364-Day Term Loan Credit Agreement, dated as of March 19, 2020, among the Registrant, as Borrower, certain Lenders from time to time parties thereto, and PNC Bank, N.A., as Administrative Agent, and Registrant's borrowing of the remaining $500 million under Registrant's existing $1 billion revolving credit facility on March 17, 2020 (incorporated by reference to Exhibit 10.1 to Registrant's Current Report on Form 8-K filed on March 19, 2020, File No. 1-32853).	X
*10.2.1	Joinder Agreement, dated as of March 27, 2020, by and among the Registrant, each of the Incremental Lenders listed therein, and PNC BANK, N.A., as Administrative Agent.	X
10.3	Duke Energy Carolinas Summary of Partial Settlement in North Carolina Rate Case (incorporated by reference to Exhibit 99.1 to Registrants’ Current Report on Form 8-K filed on March 26, 2020, File Nos. 1-32853, 1-4928, 1-3382).	X	X		X
*10.4**	Performance Award Agreement	X

112

EXHIBITS

*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
*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

113

EXHIBITS

*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 (this does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document).	X	X	X	X	X	X	X	X
*101.SCH	XBRL Taxonomy Extension Schema Document.	X	X	X	X	X	X	X	X
*101.CAL	XBRL Taxonomy Calculation Linkbase Document.	X	X	X	X	X	X	X	X
*101.LAB	XBRL Taxonomy Label Linkbase Document.	X	X	X	X	X	X	X	X
*101.PRE	XBRL Taxonomy Presentation Linkbase Document.	X	X	X	X	X	X	X	X
*101.DEF	XBRL Taxonomy Definition Linkbase Document.	X	X	X	X	X	X	X	X

The total amount of securities of the registrant or its subsidiaries authorized under any instrument with respect to long-term debt not filed as an exhibit does not exceed 10% 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.

114

SIGNATURES

SIGNATURES

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

		DUKE ENERGY CORPORATION DUKE ENERGY CAROLINAS, LLC PROGRESS ENERGY, INC. DUKE ENERGY PROGRESS, LLC DUKE ENERGY FLORIDA, LLC DUKE ENERGY OHIO, INC. DUKE ENERGY INDIANA, LLC PIEDMONT NATURAL GAS COMPANY, INC.
Date:	May 12, 2020	/s/ STEVEN K. YOUNG
		Steven K. Young Executive Vice President and Chief Financial Officer (Principal Financial Officer)
Date:	May 12, 2020	/s/ DWIGHT L. JACOBS
		Dwight L. Jacobs Senior Vice President, Chief Accounting Officer, Tax and Controller (Principal Accounting Officer)

115

EX-10.4

Exhibit 10.4

PERFORMANCE AWARD AGREEMENT

Duke Energy Corporation (the "Corporation") grants to the individual named below ("Grantee"), in accordance with the terms of the Duke Energy Corporation 2015 Long-Term Incentive Plan, as it may be amended from time to time (the "Plan") and this Performance Award Agreement (the "Agreement"), the following number of Performance Shares (the "Award"), on the Date of Grant set forth below:

Name of Grantee:     ________________________________

Target # of Performance Shares:      ________________________________

Date of Grant:     ________________________________

Performance Period: The three-year period commencing on January 1 of the year in which the Date of Grant occurs

Section 1.Nature of Performance Shares. Each Performance Share, upon becoming vested, represents a right to receive payment in the form of one (1) share of Common Stock (a "Share"). Performance Shares are used solely as units of measurement and are not Shares, and Grantee is not, and has no rights as, a shareholder of the Corporation by virtue of this Award.

Section 2.Vesting of Performance Shares. Subject to Section 3 and 6 below, the Performance Shares shall vest as follows:

(a)The Performance Shares shall vest only if and to the extent the Committee determines that the Performance Goals (as defined in Exhibit A) have been met for the Performance Period set forth above.  

(b)     In general, Grantee must be employed by the Corporation or a Subsidiary on the last day of the Performance Period to be entitled to payment of any Performance Shares earned under Section 2(a) above. However, Grantee shall be entitled to a pro-rated portion of the Performance Shares earned under Section 2(a) above in the event that, during the Performance Period (i) Grantee ceases to be employed with the Corporation and its Subsidiaries by reason of death or Disability (defined by reference Section 22(e)(3) of the Code), (ii) the Corporation and its Subsidiaries terminate Grantee's employment other than for cause (as determined by the Corporation in its sole discretion), or (iii) Grantee voluntarily terminates employment with the Corporation and its Subsidiaries after having attained age 55 and completed 10 years of consecutive service from Grantee’s most recent date of hire or re-hire, as applicable (as determined under such rules as may be established by the Corporation from time-to-time). The pro-rated portion of the Performance Shares that becomes payable under this Section 2(b), if any, shall be determined by the Committee or its delegate, in its sole discretion, based

1

upon Grantee's continuous employment with the Corporation and its Subsidiaries during the Performance Period (including additional service credit provided to Grantee, if any, under an employment or change in control agreement with the Corporation or a Subsidiary, or a severance plan maintained by the Corporation or a Subsidiary, as applicable).Notwithstanding the foregoing provisions, Grantee shall be entitled to all (rather than a pro-rated portion) of the Performance Shares earned under Section 2(a) above in the event that, during the Performance Period, Grantee voluntarily terminates employment with the Corporation and its Subsidiaries after having attained age 60 and completed five years of consecutive service from Grantee’s most recent date of hire or re-hire, as applicable (as determined under such rules as may be established by the Corporation from time-to-time), but only if such voluntary termination occurs following the completion of the first year of the Performance Period.

(c)     For purposes of Section 2 of this Agreement, the continuous employment of Grantee with the Corporation and its Subsidiaries shall not be deemed to have been interrupted, and Grantee shall not be deemed to have ceased to be an employee, by reason of the transfer of his or her employment among the Corporation and its Subsidiaries or a leave of absence approved by the Corporation or a Subsidiary; provided that,to the extent permitted under applicable law, the Corporation shall pro-rate the payout of any Performance Shares earned in the event Grantee is on an approved but unpaid leave of absence during the Performance Period, based upon the portion of the Performance Period during which Grantee received payment of salary (as determined under such rules as may be established by the Corporation from time-to-time).

Section 3.     Forfeiture. The Performance Shares (including without limitation any right to accumulated Dividend Equivalents described in Section 5 hereof) shall be forfeited automatically without further action or notice if (a) Grantee ceases to be employed by the Corporation or a Subsidiary prior to the last day of the Performance Period other than as provided in Section 2(b), or (b) the Committee or its delegate, in its sole discretion, determines that Grantee is in violation of any obligation identified in Section 6. Grantee acknowledges and agrees that payments made under this Agreement are subject to the Corporation's requirement that the Grantee reimburse the portion of any payment where such portion of the payment was (i) inadvertently paid based on an incorrect calculation, or (ii) predicated upon the achievement of financial results that are subsequently the subject of a restatement caused or partially caused by Grantee's fraud or misconduct.

Section 4.     Payment of Performance Shares. Payment of the Performance Shares earned under Section 2 above shall be made to Grantee by March 15 of the calendar year immediately following the end of the Performance Period, except to the extent deferred by Grantee in accordance with procedures as the Committee, or its delegate, may prescribe from time to time.Payment of vested Performance Shares shall be in the form of one (1) Share for each full Performance Share earned; provided that if payment would be less than ten (10) Shares, or if payment would result in fractional shares, then, if so determined by the Committee or its delegate, in its sole discretion, payment may be made in cash in lieu of Shares.

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Section 5.     Dividend Equivalents. Upon payment of a Performance Share, Grantee shall be entitled to a cash payment (without interest) equal to the aggregate cash dividends declared and payable with respect to one (1) Share for each record date that occurs during the period beginning on the Date of Grant and ending on the date the Performance Share is paid (the "Dividend Equivalent"). The Dividend Equivalents shall be forfeited to the extent that the underlying Performance Share is forfeited and shall be paid to Grantee, if at all, at the same time that the related Performance Share is paid in accordance with Section 4 above. Dividend Equivalents will be subject to any required withholding for federal, state, local, foreign or other taxes.

Section 6.    Restrictive Covenants. 

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

(b) The noncompetition obligations of clause (i) of the preceding sentence shall be effective only with respect to a "competitor" of the Corporation or any Subsidiary which is understood to mean any person or entity in competition with the Corporation or any Subsidiary, and more particularly those persons and entities engaged in any business in which the Corporation, including Subsidiaries, is engaged at the termination of Grantee's continuous employment by the Corporation, including Subsidiaries; and within the following geographical areas: (i) any country in the world (other than the United States) where the Corporation, including Subsidiaries, has at least $25 million in capital deployed as of the termination of Grantee's employment; (ii) the states of Florida, Indiana, Kentucky, North Carolina, Ohio, South Carolina and Tennessee, and (iii) any other state in the United States where the Corporation, including the Subsidiaries, has at least $25 million in capital deployed as of the termination of Grantee's employment. The Corporation and Grantee intend the above restrictions on competition in geographical areas to be entirely severable and independent, and any invalidity or unenforceability of this provision with respect to any one or more of such restrictions, including geographical areas, shall not render this provision unenforceable as applied to any one or more of the other restrictions, including geographical areas.

3

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

(d) Nothing contained in this Agreement shall prohibit, restrict or otherwise discourage Grantee from reporting possible violations of federal, state or local laws or regulations to any federal, state or local governmental agency or commission (a "Government Agency"), from making other disclosures that are protected under the whistleblower provisions of federal, state or local laws or regulations, or from participating in "protected activity" as defined in 10 CFR 50.7 and Section 211 of the Energy Reorganization Act of 1974, including, without limitation, reporting any suspected instance of illegal activity of any nature, any nuclear safety concern, any workplace safety concern, any public safety concern, or any other matter within the United States Nuclear Regulatory Commission's ("NRC") regulatory responsibilities to the NRC or any other Government Agency. Grantee does not need prior authorization of any kind to engage in such activity or make any such reports or disclosures to any Government Agency and Grantee is not required to notify the Corporation that Grantee has made such reports or disclosures. Nothing in this Agreement limits any right Grantee may have to receive a whistleblower award or bounty for information provided to any Government Agency.

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

(f) Nothing in Section 6 shall be construed to prohibit Grantee from being retained during the Restricted Period in a capacity as an attorney licensed to practice law, or to restrict Grantee from providing advice and counsel in such capacity, in any jurisdiction where such prohibition or restriction is contrary to law. Notwithstanding any provisions of this Award to the contrary, Grantee may be entitled to immunity and protection from retaliation under the Defend Trade Secrets Act of 2016 for disclosing a trade secret under limited circumstances, as set forth in the Corporation's Innovations - Inventions, Patents and Intellectual Properties Policy.

(g) Grantee's agreement to the restrictions provided for in this Agreement and the Corporation's agreement to provide the Award are mutually

4

dependent consideration. Therefore, notwithstanding any other provision to the contrary in this Agreement, if Grantee materially breaches any provision of this Section 6 or if the enforceability of any material restriction on Grantee provided for in this Agreement is challenged and found unenforceable by a court of law, then the Corporation shall, at its election, have the right to (i) cancel the Award, (ii) recover from Grantee any Shares or Dividend Equivalents or other cash paid under Award, or (iii) with respect to any Shares paid under the Award that have been disposed of, require Grantee to repay to the Corporation the fair market value of such Shares on the date such shares were sold, transferred, or otherwise disposed of by Grantee. This provision shall be construed as a return of consideration or ill-gotten gains due to the failure of Grantee's promises under the Agreement, and not as a liquidated damages clause. Nothing herein shall (x) reduce or eliminate the Corporation's right to assert that the restrictions provided for in this agreement are fully enforceable as written, or as modified by a court pursuant to Section 6, or (y) eliminate, reduce, or compromise the application of temporary or permanent injunctive relief as a fully appropriate and applicable remedy to enforce the restrictions provided for in Section 6 (inclusive of its subparts), in addition to recovery of damages or other remedies otherwise allowed by law.

(h)      Notwithstanding any other provision of this Agreement to the contrary, if the Corporation determines at any time that the Grantee engaged in Detrimental Activity while employed by the Corporation or a Subsidiary, then, to the extent permitted by applicable law, such Grantee: (a) shall not be entitled to any further Shares, Dividend Equivalents or other amounts hereunder (and, if it is determined that a participant may have engaged in Detrimental Activity, payment of any Shares, Dividend Equivalents or other amounts otherwise due to the Grantee shall be suspended pending resolution to the Corporation’s satisfaction of any investigation of the matter), and (b) shall be required to promptly return to the Corporation, upon notice from the Corporation, any Shares, Dividend Equivalents or other amounts received under this Agreement by the Grantee during the three-year period preceding the date of the determination by the Corporation. To the extent that Shares, Dividend Equivalents or other amounts are not immediately returned or paid to the Corporation as provided in this paragraph, the Corporation may, to the extent permitted by applicable law, seek other remedies, including a set off of the Shares, Dividend Equivalents or other amounts so payable to it against any amounts that may be owing from time to time by the Corporation or an affiliate to the Grantee.  For purposes of this paragraph, “Detrimental Activity” means: (i) the engaging by the Grantee in misconduct that is detrimental to the financial condition or business reputation of the Corporation or its affiliates, including due to any adverse publicity, or (ii) the Grantee’s breach or violation of any material written policy of the Corporation, including without limitation the Corporation’s Code of Business Ethics or any written policy or regulation dealing with workplace harassment, including sexual harassment and other forms of harassment prohibited by the Corporation’s Harassment-Free Workplace Policy.

Section 7.     Change in Control.  Vesting of the Performance Shares shall not accelerate solely as a result of a Change in Control. In the event of a Change in Control, the surviving, continuing, successor, or purchasing entity, as the case may be, may, without Grantee's consent, either assume or continue the

5

Corporation's rights and obligations under this Agreement or provide a substantially equivalent award or other consideration in substitution for the Performance Shares subject to this Agreement.

Section 8. Withholding. To the extent the Corporation or any Subsidiary is required to withhold any federal, state, local, foreign or other taxes in connection with the delivery of Shares under this Agreement, then the Corporation or Subsidiary (as applicable) shall retain a number of Shares otherwise deliverable hereunder with a value equal to the required withholding (based on the Fair Market Value of the Shares on the date of delivery); provided that in no event shall the value of the Shares retained exceed the minimum amount of taxes required to be withheld or such other amount permitted under the Plan. If the Corporation or any Subsidiary is required to withhold any federal, state, local or other taxes at any time other than upon delivery of the Shares under this Agreement (for example, if Grantee elects to defer payment of the Performance Shares), then the Corporation or Subsidiary (as applicable) shall have the right in its sole discretion to (a) require Grantee to pay or provide for payment of the required tax withholding, or (b) deduct the required tax withholding from any amount of salary, bonus, incentive compensation or other amounts otherwise payable in cash to Grantee (other than deferred compensation subject to Section 409A of the Code).    

Section 9.     Conflicts with Plan, Correction of Errors, Section 409A and Grantee's Consent. In the event that any provision of this Agreement conflicts in any way with a provision of the Plan, such Plan provision shall be controlling and the applicable provision of this Agreement shall be without force and effect to the extent necessary to cause such Plan provision to be controlling. Capitalized terms used herein without definition shall have the meanings assigned to them in the Plan. In the event that, due to administrative error, this Agreement does not accurately reflect an Award properly granted to Grantee pursuant to the Plan, the Corporation, acting through its Executive Compensation and Benefits Department, reserves the right to cancel any erroneous document and, if appropriate, to replace the cancelled document with a corrected document.

To the extent applicable, it is intended that this Agreement comply with the provisions of Section 409A of the Code and that this Award not result in unfavorable tax consequences to Grantee under Section 409A of the Code. This Agreement will be administered and interpreted in a manner consistent with this intent, and any provision that would cause this Agreement to fail to satisfy Section 409A of the Code will have no force and effect until amended to comply therewith (which amendment may be retroactive to the extent permitted by Section 409A of the Code and made without the consent of Grantee). For purposes of this Agreement, each amount to be paid to Grantee pursuant to this Agreement shall be construed as a separate identified payment for purposes of Section 409A of the Code.

Notwithstanding the foregoing, this Award is subject to cancellation by the Corporation in its sole discretion unless Grantee has signed a duplicate of this Agreement, in the space provided below, and returned the signed duplicate to the Executive Compensation and Benefits Department – Performance Shares__________________________________________________________,

6

which, if, and to the extent, permitted by the Executive Compensation and Benefits Department, may be accomplished by electronic means.

IN WITNESS WHEREOF, the Corporation has caused this Agreement to be executed effective as of the Date of Grant.

DUKE ENERGY CORPORATION

By:

    Its:

Acceptance of Performance Award

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

____________________________    Grantee's Signature

____________________________    (print name)

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EXHIBIT APERFORMANCE GOALS

Cumulative Adjusted Basic EPS (__%)

_____% of the Target Number of Performance Shares subject to this Award shall become vested based upon the extent to which the Corporation achieves the "Cumulative Adjusted Basic EPS Performance Goal," which is based on the Corporation's cumulative adjusted basic earnings per share ("EPS"), for the Performance Period, in accordance with the applicable vesting percentage specified for Cumulative Adjusted Basic EPS in the following schedule:

Cumulative Adjusted Basic EPS Percent Payout of
Target Performance Shares*

*When such determination is at a level between those specified, the Committee, or its delegatee, in its sole discretion, shall interpolate to determine the applicable vesting percentage. The Committee shall have the authority to calculate and adjust the Cumulative Adjusted Basic EPS and the Cumulative Adjusted Basic EPS Performance Goal in the same manner as adjusted basic EPS is calculated and adjusted pursuant to the _____ Short-Term Incentive Program Guidelines, provided, however, that the Committee specifically reserves discretion to make adjustments to the EPS performance levels or results in the event that a major project is not placed in-service at the time assumed by the Corporation as of the Date of Grant for purposes of its business plan.

8

Total Shareholder Return (__%)

___% of the Target Number of Performance Shares subject to this Award shall become vested based upon the extent to which the Corporation achieves the "TSR Performance Goal," which is the Corporation's Total Shareholder Return ("TSR") percentile ranking among the companies that are in the Philadelphia Utility Index as of the beginning of the Performance Period, with higher percentile ranking for more positive/less negative TSR, for the Performance Period, in accordance with the applicable vesting percentage specified for such percentile ranking in the following schedule:

Relative TSR Performance Percentile Percent Payout of
Target Performance Shares**

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

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

9

purposes of this Agreement. If a member of the Philadelphia Utility Index on __________ becomes bankrupt or insolvent during the Performance Period and ceases to be publicly-traded, for purposes of this Agreement its TSR shall be -100%.

Total Incident Case Rate For Employees (___%)

____% of the Target Number of Performance Shares subject to this Award shall become vested based upon the extent to which the Corporation achieves the "TICR Performance Goal," which is the Corporation's total incident case rate for employees, including staff augmentation workers ("TICR") as compared to the applicable vesting percentage specified in the following schedule:

Duke Energy TICR vs. __________*** Percent Payout of
Target Performance Shares****

***The __________ shall consist of the results of the ______________, excluding companies without gas or nuclear operations, that report TICR results for at least one year during the _________ period.

****When such determination is at a level between those specified, the Committee, or its delegatee, in its sole discretion, shall interpolate to determine the applicable vesting percentage. The Committee retains discretion to make equitable adjustments to the TICR Performance Goal and the related payout levels to prevent dilution or enlargement of the Grantee’s right to payment in the event there are changes in the composition of the ___________ during the _________ period and/or there are fewer than ___ companies in the ___________________ (excluding companies without gas or nuclear operations) that report TICR results for at least one year during the __________ period.  The employees of any company acquired during the Performance Period shall not be taken into account when measuring the Corporation's TICR for the Performance Period.

Adjustments

If the Committee determines that a merger, consolidation, liquidation, issuance of rights or warrants to purchase securities, recapitalization, reclassification, stock dividend, spin-off, split-off, stock split, reverse stock split or other distribution with respect to the Shares, or any similar corporate transaction or event in respect of the Shares, the manner in which the Corporation conducts its business, changes in the law or regulations or regulatory structure, changes in accounting practices, other unusual or nonrecurring items or occurrences, or other events or circumstances, render the Performance Goals to be unsuitable, the Committee may, in its sole discretion, and without the consent of the Grantee or any other persons, modify the calculation of the Performance Goals, or any of the related minimum, target or maximum levels of achievement, or the performance results, in whole or in part, as the Committee deems equitable and appropriate to reflect such event.

10

In addition, the Committee reserves the right to reduce any vesting to the extent the Committee determines that such reduction is equitable and appropriate for any reason, including reductions based on overall financial performance, such as adjusted and reported earnings, capital deployment and credit position during the Performance Period.

11

EX-10.2.1

Exhibit 10.2.1

JOINDER AGREEMENT, dated as of March 27, 2020 (this “Joinder”), is made and entered into by and among DUKE ENERGY CORPORATION, a Delaware corporation (the “Borrower”), each of the entities listed under the caption “Incremental Lenders” on the signature pages hereto (each, an “Incremental Lender” and, collectively, the “Incremental Lenders”), and PNC BANK, N.A., as Administrative Agent (in such capacity, the “Administrative Agent”).

RECITALS:

WHEREAS, reference is made to the Credit Agreement dated as of March 19, 2020 (as amended, supplemented or otherwise modified prior to the date hereof, the “Credit Agreement”), by and among the Borrower, the lenders from time to time party thereto and the Administrative Agent;

WHEREAS, it is intended that (a) the Borrower will obtain the Incremental Commitments (as defined below) (as defined in the Credit Agreement) and (b) the proceeds of the borrowings under the Incremental Commitments will be used for general corporate purposes of the Borrower;

WHEREAS, subject to the terms and conditions of the Credit Agreement, and pursuant to Section 2.17 of the Credit Agreement, the Borrower has requested that the Incremental Lenders provide Incremental Commitments in an aggregate principal amount of $187,500,000; and

WHEREAS, the Incremental Lenders are willing to provide the Incremental Commitments to the Borrower on the Incremental Commitment Effective Date (as defined below).

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

SECTION 1. Defined Terms; Interpretation; Etc. Capitalized terms used and not defined herein shall have the meanings assigned to such terms in the Credit Agreement.

SECTION 2. Incremental Commitments. (a) Each Incremental Lender hereby agrees, severally and not jointly, to make an Incremental Loan to the Borrower on the Incremental Commitment Effective Date in Dollars in an aggregate principal amount equal to the amount set forth opposite such Incremental Lender’s name on Schedule I attached hereto (each, an “Incremental Commitment” and, collectively, the “Incremental Commitments”), on the terms set forth herein and in the Credit Agreement (as amended hereby), and subject to the conditions set forth herein. The Incremental Loans shall be deemed to be “Loans” as defined in the Credit Agreement (as amended hereby) for all purposes of the Credit Agreement having terms and provisions identical to those applicable to the Loans outstanding immediately prior to the Incremental Commitment Effective Date (the “Existing Loans”).

(b) The Incremental Loans shall be made as a single borrowing, with an initial Interest Period that commences on the Incremental Commitment Effective Date and ends on the last day of the Interest Period applicable to the Existing Loans on the Incremental Commitment Effective Date. During such initial Interest Period, the London Interbank Offered Rate applicable to the Incremental Loans shall be the same London Interbank Offered Rate applicable for the Existing Loans as of the Incremental Commitment Effective Date. Notwithstanding anything to the contrary contained herein or in the Credit Agreement, from and after the Incremental Commitment Effective Date, the Existing Loans and the Incremental Loans shall constitute a single Borrowing of Term Loans for all purposes under the Credit Agreement.

(c) Unless previously terminated, the Incremental Commitments of the Incremental Lenders pursuant to Section 2(a) shall terminate upon the making of the Incremental Loans on the Incremental Commitment Effective Date.

(d) Each Incremental Lender (i) confirms that a copy of the Credit Agreement, together with copies of the financial statements referred to therein and such other documents and information as it has deemed appropriate to make its own credit analysis and decision to enter into this Joinder and make its Incremental Loan, have been made available to such Incremental Lender; (ii) agrees that it will, independently and without reliance upon the Administrative Agent, any joint lead arranger or joint bookrunner, or any other Lender or agent 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 action under the Credit Agreement, including this Joinder; (iii) appoints and authorizes the Administrative Agent to take such action as agent on its behalf and to exercise such powers under the Credit Agreement as are delegated to the Administrative Agent by the terms thereof, together with such powers as are reasonably incidental thereto; and (iv) acknowledges and agrees that upon the Incremental Commitment Effective Date such Incremental Lender shall be a “Lender” and an “Incremental Lender” under, and for all purposes of, the Credit Agreement, and shall be subject to and bound by the terms thereof, and shall perform all the obligations of and shall have all rights of a Lender and an Incremental Lender thereunder.

SECTION 3. Conditions Precedent to Incremental Loans. This Joinder and each Incremental Lender’s obligation to provide the Incremental Loans pursuant to this Joinder, shall become effective as of the date on which the following conditions precedent are satisfied (such date, the “Incremental Commitment Effective Date”):

(a) The Administrative Agent shall have received from the Borrower and each Incremental Lender either (i) a counterpart of this Joinder duly executed and delivered on behalf of such party or (ii) written evidence satisfactory to the Administrative Agent (which may include facsimile or other electronic transmission of a signed counterpart of this Joinder) that such party has duly executed and delivered a counterpart of this Joinder.

(b) Each of the conditions set forth in Section 3.03 of the Credit Agreement shall have been satisfied or waived.

(c) The Administrative Agent and each Incremental Lender shall have received all documentation and other information about the Borrower as shall have been reasonably requested prior to the Incremental Commitment Effective Date by the Administrative Agent or such Incremental Lender that they shall have reasonably determined is required by regulatory authorities under applicable “know your customer” and anti-money laundering rules and regulations, including without limitation the USA PATRIOT Act.

(d) The Administrative Agent shall have received a Notice of Borrowing with respect to the Incremental Term Loans as required by Section 2.02 of the Credit Agreement.

The Administrative Agent shall notify the Borrower and the Lenders of the Incremental Commitment Effective Date, and such notice shall be conclusive and binding.

SECTION 4. Representations and Warranties. In order to induce the Incremental Lenders and the Administrative Agent to enter into this Joinder and to induce the Incremental Lenders to make the Incremental Loans hereunder, the Borrower hereby represents and warrants to the Incremental Lenders and the Administrative Agent on and as of the Incremental Commitment Effective Date that the

2

representations and warranties of the Borrower set forth in the Credit Agreement are true on and as of the Incremental Commitment Effective Date (or, in the case of any such representation or warranty expressly stated to have been made as of a specific date, as of such specific date).

SECTION 5. Expenses; Indemnity; Damage Waiver. Section 9.03 of the Credit Agreement is hereby incorporated by reference, mutatis mutandis, as if such Section was set forth in full herein.

SECTION 6. Waiver of Integral Multiple Requirement. Each party hereby waives the requirement in Section 2.17 of the Credit Agreement requiring that the Incremental Commitment be in an integral multiple of $10,000,000.

SECTION 7. Miscellaneous.

(a) Non-U.S. Lenders. Each Incremental Lender shall have delivered to the Administrative Agent and the Borrower such forms, certificates or other evidence with respect to United States federal income tax withholding matters as such Incremental Lender may be required to deliver to the Administrative Agent and the Borrower pursuant to Section 8.04(d) of the Credit Agreement.

(b) Recordation of the Incremental Loans. Upon execution and delivery hereof, and the funding of the Incremental Loans, the Administrative Agent will record in the Register the Incremental Loans made by the Incremental Lenders.

(c) Amendment, Modification and Waiver. This Joinder may not be amended and no provision hereof may be waived except pursuant to a writing signed by each of the parties hereto.

(d) Entire Agreement.This Joinder and the Credit Agreement constitute the entire agreement among the parties with respect to the subject matter hereof and thereof and supersede all other prior agreements and understandings, both written and verbal, among the parties or any of them with respect to the subject matter hereof.

(e) Governing Law.This Joinder and any claims controversy, dispute or cause of action (whether in contract or tort or otherwise) based upon, arising out of or relating to this Joinder and the transactions contemplated hereby shall be governed by, and construed in accordance with, the laws of the State of New York.

(f) Jurisdiction; Waiver of Venue; Service of Process.Section 9.09 of the Credit Agreement is hereby incorporated by reference, mutatis mutandis, as if such Section was set forth in full herein.

(g) WAIVER OF JURY TRIAL. SECTION 9.11 OF THE CREDIT AGREEMENT IS HEREBY INCORPORATED BY REFERENCE, MUTATIS MUTANDIS, AS IF SUCH SECTION WAS SET FORTH IN FULL HEREIN.

(h) Severability. Any term or provision of this Joinder that is invalid or unenforceable in any jurisdiction shall, as to that jurisdiction, be ineffective to the extent of such invalidity or unenforceability without rendering invalid or unenforceable the remaining terms and provisions of this Joinder or affecting the validity or enforceability of any of the terms or provisions

3

of this Joinder in any other jurisdiction. If any provision of this Joinder is so broad as to be unenforceable, the provision shall be interpreted to be only so broad as would be enforceable.

(i) Counterparts; Integration. Section 9.10 of the Credit Agreement is hereby incorporated by reference, mutatis mutandis, as if such Section was set forth in full herein.

(j) Headings. The headings of this Joinder are for purposes of reference only and shall not limit or otherwise affect the meaning hereof.

(k) Reference to and Effect on the Credit Agreement. On and after the Incremental Commitment Effective Date, each reference in the Credit Agreement to “this Agreement”, “hereunder”, “herein” or words of like import referring to the Credit Agreement, shall mean and be a reference to the Credit Agreement as modified by this Joinder. Except as specifically modified by this Joinder, the Credit Agreement shall remain in full force and effect and is hereby ratified and confirmed. The execution, delivery and performance of this Joinder shall not constitute a waiver of any provision of, or operate as a waiver of any right, power or remedy of the Administrative Agent or Lender under the Credit Agreement.

[Remainder of this page intentionally left blank]

IN WITNESS WHEREOF, the parties hereto have caused this Joinder to be duly executed by their respective authorized officers as of the day and year first above written.

DUKE ENERGY CORPORATION, as the Borrower
By:	/s/ Michael S. Hendershott
	Name: Michael S. Hendershott
	Title: Assistant Treasurer

PNC BANK, N.A., as Administrative Agent
By:	/s/ Alex Rolfe
	Name: Alex Rolfe
	Title: Vice President

TD BANK, N.A., as an Incremental Lender
By:	/s/ Shannon Batchman
	Name: Shannon Batchman
	Title: Sr. Vice President

Schedule I

As of the Incremental Commitment Effective Date:

Incremental Lender	Incremental Commitment
TD Bank, N.A.	$187,500,000
Total:	$187,500,000

4

EX-31.1.1

EXHIBIT 31.1.1

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Corporation;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ LYNN J. GOOD

Lynn J. Good

Chair, President and

Chief Executive Officer

EX-31.1.2

EXHIBIT 31.1.2

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Carolinas, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.3

EXHIBIT 31.1.3

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Progress Energy, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.4

EXHIBIT 31.1.4

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Progress, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.5

EXHIBIT 31.1.5

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Florida, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.6

EXHIBIT 31.1.6

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Ohio, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.7

EXHIBIT 31.1.7

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Indiana, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.1.8

EXHIBIT 31.1.8

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Lynn J. Good, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Piedmont Natural Gas Company, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

EX-31.2.1

EXHIBIT 31.2.1

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Corporation;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.2

EXHIBIT 31.2.2

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Carolinas, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.3

EXHIBIT 31.2.3

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Progress Energy, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer 

EX-31.2.4

EXHIBIT 31.2.4

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Progress, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.5

EXHIBIT 31.2.5

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Florida, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.6

EXHIBIT 31.2.6

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Ohio, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.7

EXHIBIT 31.2.7

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Duke Energy Indiana, LLC;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

EX-31.2.8

EXHIBIT 31.2.8

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Steven K. Young, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Piedmont Natural Gas Company, Inc.;

2) Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3) Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4) The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Acts Rules 13a–15(f) and 15d–15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5) The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 12, 2020

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer 

EX-32.1.1

EXHIBIT 32.1.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Corporation (“Duke Energy”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chair, 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

Chair, President and

Chief Executive Officer

May 12, 2020

EX-32.1.2

EXHIBIT 32.1.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Carolinas, LLC (“Duke Energy Carolinas”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Carolinas, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Carolinas.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

May 12, 2020

EX-32.1.3

EXHIBIT 32.1.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Progress Energy, Inc. (“Progress Energy”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Progress Energy, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Progress Energy.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

May 12, 2020

EX-32.1.4

EXHIBIT 32.1.4

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Progress, LLC (“Duke Energy Progress”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Progress, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Progress.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

May 12, 2020

EX-32.1.5

EXHIBIT 32.1.5

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Florida, LLC (“Duke Energy Florida”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Florida, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Florida.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

May 12, 2020

EX-32.1.6

EXHIBIT 32.1.6

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Ohio, Inc. (“Duke Energy Ohio”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Ohio, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Ohio.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

May 12, 2020

EX-32.1.7

EXHIBIT 32.1.7

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Indiana, LLC (“Duke Energy Indiana”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Duke Energy Indiana, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Indiana.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

May 12, 2020

EX-32.1.8

EXHIBIT 32.1.8

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Piedmont Natural Gas Company, Inc. (“Piedmont”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lynn J. Good, Chief Executive Officer of Piedmont, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Piedmont.

/s/ LYNN J. GOOD

Lynn J. Good

Chief Executive Officer

May 12, 2020

EX-32.2.1

EXHIBIT 32.2.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Corporation (“Duke Energy”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 12, 2020

EX-32.2.2

EXHIBIT 32.2.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Carolinas, LLC (“Duke Energy Carolinas”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Carolinas, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Carolinas.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 12, 2020

EX-32.2.3

EXHIBIT 32.2.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Progress Energy, Inc. (“Progress Energy”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Progress Energy, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Progress Energy.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 12, 2020

EX-32.2.4

EXHIBIT 32.2.4

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Progress, LLC (“Duke Energy Progress”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Progress, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Progress.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 12, 2020

EX-32.2.5

EXHIBIT 32.2.5

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Florida, LLC (“Duke Energy Florida”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Florida, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Florida.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 12, 2020

EX-32.2.6

EXHIBIT 32.2.6

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Ohio, Inc. (“Duke Energy Ohio”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Ohio, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Ohio.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 12, 2020

EX-32.2.7

EXHIBIT 32.2.7

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Duke Energy Indiana, LLC (“Duke Energy Indiana”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Duke Energy Indiana, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Duke Energy Indiana.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 12, 2020

EX-32.2.8

EXHIBIT 32.2.8

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Piedmont Natural Gas Company, Inc. (“Piedmont”) on Form 10-Q for the period ending March 31, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven K. Young, Executive Vice President and Chief Financial Officer of Piedmont, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Piedmont.

/s/ STEVEN K. YOUNG

Steven K. Young

Executive Vice President and Chief Financial Officer

May 12, 2020

XML

Investments in Debt and Equity Securities (Tables)

3 Months Ended

Mar. 31, 2020

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	119	$	—	$	—	$	101
Equity securities	2,499		170		4,488		3,523		55		5,661
Corporate debt securities	26		16		642		37		1		603
Municipal bonds	10		2		404		13		—		368
U.S. government bonds	70		—		1,212		33		1		1,256
NDTF equity security contracts	20		—		20		—		—		—
Other debt securities	4		3		163		3		—		141
Total NDTF Investments	$	2,629	$	191	$	7,048	$	3,609	$	57	$	8,130
Other Investments
Cash and cash equivalents	$	—	$	—	$	78	$	—	$	—	$	52
Equity securities	31		1		95		57		—		122
Corporate debt securities	—		—		89		3		—		67
Municipal bonds	6		1		98		4		—		94
U.S. government bonds	5		—		51		2		—		41
Other debt securities	—		—		52		—		—		56
Total Other Investments	$	42	$	2	$	463	$	66	$	—	$	432
Total Investments	$	2,671	$	193	$	7,511	$	3,675	$	57	$	8,562

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	119	$	—	$	—	$	101
Equity securities	2,499		170		4,488		3,523		55		5,661
Corporate debt securities	26		16		642		37		1		603
Municipal bonds	10		2		404		13		—		368
U.S. government bonds	70		—		1,212		33		1		1,256
NDTF equity security contracts	20		—		20		—		—		—
Other debt securities	4		3		163		3		—		141
Total NDTF Investments	$	2,629	$	191	$	7,048	$	3,609	$	57	$	8,130
Other Investments
Cash and cash equivalents	$	—	$	—	$	78	$	—	$	—	$	52
Equity securities	31		1		95		57		—		122
Corporate debt securities	—		—		89		3		—		67
Municipal bonds	6		1		98		4		—		94
U.S. government bonds	5		—		51		2		—		41
Other debt securities	—		—		52		—		—		56
Total Other Investments	$	42	$	2	$	463	$	66	$	—	$	432
Total Investments	$	2,671	$	193	$	7,511	$	3,675	$	57	$	8,562

Investments Classified by Contractual Maturity Date

The table below summarizes the maturity date for debt securities.

	March 31, 2020
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana
Due in one year or less	$	333	$	25	$	302	$	26	$	276	$	3
Due after one through five years	538		234		236		227		9		17
Due after five through 10 years	465		188		214		207		7		7
Due after 10 years	1,375		734		541		506		35		16
Total	$	2,711	$	1,181	$	1,293	$	966	$	327	$	43

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 months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	23	$	35
Realized losses	65		30
AFS:
Realized gains	20		10
Realized losses	6		11

Duke Energy Carolinas

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	33	$	—	$	—	$	21
Equity securities	1,355		81		2,498		1,914		8		3,154
Corporate debt securities	15		12		392		21		1		361
Municipal bonds	3		1		128		3		—		96
U.S. government bonds	35		—		502		16		1		578
Other debt securities	3		3		159		3		—		137
Total NDTF Investments	$	1,411	$	97	$	3,712	$	1,957	$	10	$	4,347

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	33	$	—	$	—	$	21
Equity securities	1,355		81		2,498		1,914		8		3,154
Corporate debt securities	15		12		392		21		1		361
Municipal bonds	3		1		128		3		—		96
U.S. government bonds	35		—		502		16		1		578
Other debt securities	3		3		159		3		—		137
Total NDTF Investments	$	1,411	$	97	$	3,712	$	1,957	$	10	$	4,347

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 months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	9	$	23
Realized losses	45		21
AFS:
Realized gains	12		9
Realized losses	5		10

Progress Energy

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	86	$	—	$	—	$	80
Equity securities	1,144		89		1,990		1,609		47		2,507
Corporate debt securities	11		4		250		16		—		242
Municipal bonds	7		1		276		10		—		272
U.S. government bonds	35		—		710		17		—		678
NDTF equity security contracts	20		—		20		—		—		—
Other debt securities	1		—		4		—		—		4
Total NDTF Investments	$	1,218	$	94	$	3,336	$	1,652	$	47	$	3,783
Other Investments
Cash and cash equivalents	$	—	$	—	$	69	$	—	$	—	$	49
Municipal bonds	5		—		53		3		—		51
Total Other Investments	$	5	$	—	$	122	$	3	$	—	$	100
Total Investments	$	1,223	$	94	$	3,458	$	1,655	$	47	$	3,883

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	86	$	—	$	—	$	80
Equity securities	1,144		89		1,990		1,609		47		2,507
Corporate debt securities	11		4		250		16		—		242
Municipal bonds	7		1		276		10		—		272
U.S. government bonds	35		—		710		17		—		678
NDTF equity security contracts	20		—		20		—		—		—
Other debt securities	1		—		4		—		—		4
Total NDTF Investments	$	1,218	$	94	$	3,336	$	1,652	$	47	$	3,783
Other Investments
Cash and cash equivalents	$	—	$	—	$	69	$	—	$	—	$	49
Municipal bonds	5		—		53		3		—		51
Total Other Investments	$	5	$	—	$	122	$	3	$	—	$	100
Total Investments	$	1,223	$	94	$	3,458	$	1,655	$	47	$	3,883

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 months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	14	$	12
Realized losses	20		9
AFS:
Realized gains	5		1
Realized losses	1		1

Duke Energy Progress

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	51	$	—	$	—	$	53
Equity securities	881		79		1,631		1,258		21		2,077
Corporate debt securities	11		4		250		16		—		242
Municipal bonds	7		1		276		10		—		272
U.S. government bonds	34		—		436		16		—		403
Other debt securities	1		—		4		—		—		4
Total NDTF Investments	$	934	$	84	$	2,648	$	1,300	$	21	$	3,051
Other Investments
Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	2
Total Other Investments	$	—	$	—	$	2	$	—	$	—	$	2
Total Investments	$	934	$	84	$	2,650	$	1,300	$	21	$	3,053

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	51	$	—	$	—	$	53
Equity securities	881		79		1,631		1,258		21		2,077
Corporate debt securities	11		4		250		16		—		242
Municipal bonds	7		1		276		10		—		272
U.S. government bonds	34		—		436		16		—		403
Other debt securities	1		—		4		—		—		4
Total NDTF Investments	$	934	$	84	$	2,648	$	1,300	$	21	$	3,051
Other Investments
Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	2
Total Other Investments	$	—	$	—	$	2	$	—	$	—	$	2
Total Investments	$	934	$	84	$	2,650	$	1,300	$	21	$	3,053

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 months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	14	$	10
Realized losses	20		8
AFS:
Realized gains	5		1
Realized losses	1		1

Duke Energy Florida

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	35	$	—	$	—	$	27
Equity securities	263		10		359		351		26		430
U.S. government bonds	1		—		274		1		—		275
NDTF equity security contracts	20		—		20		—		—		—
Total NDTF Investments(a)	$	284	$	10	$	688	$	352	$	26	$	732
Other Investments
Cash and cash equivalents	$	—	$	—	$	3	$	—	$	—	$	4
Municipal bonds	5		—		53		3		—		51
Total Other Investments	$	5	$	—	$	56	$	3	$	—	$	55
Total Investments	$	289	$	10	$	744	$	355	$	26	$	787

(a)

During the three months ended March 31, 2020, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of Crystal River Unit 3.

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	35	$	—	$	—	$	27
Equity securities	263		10		359		351		26		430
U.S. government bonds	1		—		274		1		—		275
NDTF equity security contracts	20		—		20		—		—		—
Total NDTF Investments(a)	$	284	$	10	$	688	$	352	$	26	$	732
Other Investments
Cash and cash equivalents	$	—	$	—	$	3	$	—	$	—	$	4
Municipal bonds	5		—		53		3		—		51
Total Other Investments	$	5	$	—	$	56	$	3	$	—	$	55
Total Investments	$	289	$	10	$	744	$	355	$	26	$	787

(a)

During the three months ended March 31, 2020, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of Crystal River Unit 3.

Duke Energy Indiana

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.

	March 31, 2020						December 31, 2019
	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	$	26	$	1	$	63	$	43	$	—	$	81
Corporate debt securities	—		—		4		—		—		6
Municipal bonds	1		1		36		1		—		36
U.S. government bonds	—		—		3		—		—		2
Total Investments	$	27	$	2	$	106	$	44	$	—	$	125

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.

	March 31, 2020						December 31, 2019
	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	$	26	$	1	$	63	$	43	$	—	$	81
Corporate debt securities	—		—		4		—		—		6
Municipal bonds	1		1		36		1		—		36
U.S. government bonds	—		—		3		—		—		2
Total Investments	$	27	$	2	$	106	$	44	$	—	$	125

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Debt and Credit Facilities (Tables)

3 Months Ended

Mar. 31, 2020

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments

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

					Three Months Ended March 31, 2020
							Duke		Duke		Duke
	Maturity	Interest			Duke		Energy		Energy		Energy
Issuance Date	Date	Rate			Energy		(Parent)		Carolinas		Indiana
Unsecured Debt
March 2020(a)	March 2021	1.400	%	(b)	$	1,688	$	1,688	$	—	$	—
First Mortgage Bonds
January 2020(c)	February 2030	2.450	%		500		—		500		—
January 2020(c)	August 2049	3.200	%		400		—		400		—
March 2020(d)	April 2050	2.750	%		550		—		—		550
Total issuances					$	3,138	$	1,688	$	900	$	550

(a) Debt issued in response to market volatility concerns related to the COVID-19 pandemic. Refer to Note 1 for additional information on the COVID-19 pandemic. Proceeds will be used to reduce outstanding commercial paper and for general corporate purposes.

(b) Debt issuance has a floating interest rate.

(c) Debt issued to repay at maturity $450 million first mortgage bonds due June 2020 and for general corporate purposes.

(d) Debt issued to repay at maturity $500 million first mortgage bonds due July 2020 and to pay down short-term debt.

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

(in millions)	Maturity Date	Interest Rate			March 31, 2020
Unsecured Debt
Duke Energy (Parent)	June 2020	2.100	%		$	330
Duke Energy Progress	December 2020	2.292	%	(a)	700
Progress Energy, Inc	January 2021	4.400	%		500
Duke Energy (Parent)	March 2021	1.400	%	(a)	1,688
First Mortgage Bonds
Duke Energy Florida	April 2020	4.550	%		250
Duke Energy Carolinas	June 2020	4.300	%		450
Duke Energy Indiana	July 2020	3.750	%		500
Duke Energy Progress	September 2020	1.076	%	(a)	300
Other(b)					359
Current maturities of long-term debt					$	5,077

(a)    Debt issuance has a floating interest rate.

(b)    Includes finance lease obligations, amortizing debt and small bullet maturities.

Schedule Of Line Of Credit Facilities

The table below includes the current borrowing sublimits and available capacity under these credit facilities.

	March 31, 2020
				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		$	1,500		$	1,250		$	800		$	600		$	600		$	600
Reduction to backstop issuances
Commercial paper(b)	(2,540		)	(1,140		)	(300		)	(275		)	(167		)	(243		)	(150		)	(265		)
Outstanding letters of credit	(49		)	(42		)	(4		)	(2		)	—			—			—			(1		)
Tax-exempt bonds	(81		)	—			—			—			—			—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—			—
Available capacity under the Master Credit Facility	$	4,830		$	1,468		$	946		$	723		$	633		$	357		$	369		$	334

(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.

Other Credit Facilities

	March 31, 2020
(in millions)	Facility size		Amount drawn
Duke Energy (Parent) Three-Year Revolving Credit Facility(a)	$	1,000	$	1,000
Duke Energy Progress Term Loan Facility	700		700

(a)

In March 2020, Duke Energy (Parent) drew down the remaining $500 million.

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Stockholders' Equity (Tables)

3 Months Ended

Mar. 31, 2020

Equity [Abstract]

Schedule Of Earnings Per Share

The following table presents Duke Energy’s basic and diluted EPS calculations, the weighted average number of common shares outstanding and common and preferred share dividends declared.

	Three Months Ended March 31,
(in millions, except per share amounts)	2020		2019
Income from continuing operations available to Duke Energy common stockholders excluding impact of participating securities and including accumulated preferred stock dividends adjustment	$	911	$	898
Weighted average common shares outstanding – basic	734		727
Equity forwards	2		—
Weighted average common shares outstanding – diluted	736		727
EPS from continuing operations available to Duke Energy common stockholders
Basic and diluted	$	1.24	$	1.24
Potentially dilutive items excluded from the calculation(a)	2		2
Dividends declared per common share	$	0.945	$	0.9275
Dividends declared on Series A preferred stock per depositary share(b)	$	0.359	$	—
Dividends declared on Series B preferred stock per share(c)	$	24.917	$	—

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

(b) 5.75% Series A Cumulative Redeemable Perpetual Preferred Stock dividends are payable quarterly in arrears on the 16th day of March, June, September and December. The preferred stock has a $25 liquidation preference per depositary share.

(c)

4.875% Series B Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock dividends are payable semiannually in arrears on the 16th day of March and September. The preferred stock has a $1,000 liquidation preference per share.

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Regulatory Matters

3 Months Ended

Mar. 31, 2020

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

COVID-19 Filings

North Carolina

On March 10, 2020, Governor Roy Cooper issued Executive Order No. 116 declaring a state of emergency due to the COVID-19 pandemic. In an effort to help mitigate the financial impacts of the COVID-19 pandemic on their customers, on March 19, 2020, Duke Energy Carolinas and Duke Energy Progress filed a request with the NCUC seeking authorization to waive: (1) any late payment charges incurred by a residential or nonresidential customer, effective March 21, 2020; (2) the application of fees for checks returned for insufficient funds for residential and nonresidential customers; (3) the reconnection charge when a residential or nonresidential customer seeks to have service restored for those customers whose service was recently disconnected for nonpayment and to work with customers regarding the other requirements to restore service, including re-establishment of credit; and (4) the fees and charges associated with the use of credit cards or debit cards to pay residential electric utility bills, effective March 21, 2020. The NCUC granted the companies’ request on March 20, 2020.

On March 31, 2020, the governor issued Executive Order No. 124, which, in addition to requiring the steps in the NCUC order noted above, stated that nothing in Executive Order No. 124 shall relieve a customer of its obligation to pay bills for receipt of utility services provided. Executive Order No. 124 remains in effect for 60 days unless otherwise rescinded or replaced with a superseding Executive Order.

On March 31, 2020, the Carolina Utility Customers Association (CUCA) filed a petition with the NCUC to temporarily suspend minimum demand charges for commercial and industrial customers. On April 2, 2020, the NCUC issued an order requiring the North Carolina Public Staff (Public Staff) and Duke Energy Carolinas, Duke Energy Progress and other utilities to file responses. On April 9, 2020, Duke Energy Carolinas and Duke Energy Progress filed responses to CUCA’s petition opposing CUCA’s request. The companies assert that voiding commission-approved tariffs and allowing all commercial and industrial customers on the requested rate schedules to avoid paying a portion of their bills is not legally permissible and would result in these costs unfairly being shifted to other customers that are already paying their respective fair share of similar fixed components. Pursuant to the NCUC’s April 2 order, reply comments were filed by CUCA, the Public Staff and Duke Energy Carolinas and Duke Energy Progress on April 15, 2020. A final order from the NCUC deciding CUCA's request is pending. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

South Carolina

On March 13, 2020, Governor Henry McMaster issued Executive Order No. 2020-08 declaring a state of emergency due to the COVID-19 pandemic. The governor also issued a letter on March 14, 2020, to the ORS Executive Director regarding the suspension of disconnection of essential utility services for nonpayment. On March 16, 2020, citing the governor’s letter, the ORS filed a request asking the PSCSC to grant waivers so that utilities could suspend disconnections of utility services for nonpayment. Duke Energy Carolinas and Duke Energy Progress supported such motion. On March 18, 2020, the PSCSC issued an order approving such waivers, and also approved waivers for regulations related to late fees and reconnect fees. The PSCSC's order also required utilities to track the financial impacts of actions taken pursuant to such waivers for possible reporting to the PSCSC.

On April 30, 2020, the ORS requested the PSCSC grant a waiver of the applicable regulations to allow customers the flexibility to obtain deferred payment plans longer than 6 months for past-due amounts. On May 5, 2020, Duke Energy Carolinas and Duke Energy Progress filed responsive comments stating that while utility bills will remain due, Duke Energy Carolinas and Duke Energy Progress do not plan to immediately reinstitute disconnection upon the expiration of the state of emergency and intend to work through a potential grace period as economic recovery begins. Duke Energy Carolinas and Duke Energy Progress also concurred with the observation of the ORS that reduced usage is impacting the fixed cost recovery and revenue assumptions included in rates. Those costs include not only ongoing operational and financing costs necessary to serve customers, but also the borrowings necessary to support extended payment arrangements that will be an important part of emerging from the COVID-19 pandemic. Duke Energy Carolinas and Duke Energy Progress will continue to track such costs, lost revenues and potential cost savings for future evaluation by the PSCSC.

Additionally, on May 8, 2020, the ORS filed a motion for the PSCSC to solicit comments from utilities and interested stakeholders regarding measures to be taken to mitigate impacts of COVID-19 on utility customers and require recordkeeping. In a detailed motion, the ORS specifically asked the PSCSC to: (1) solicit input from utilities regarding the temporary mitigation measures to address COVID-19; (2) request utilities to inform the PSCSC of the plans utilities have to return to normalized operations; (3) require utilities to track revenue impacts, incremental costs and savings related to COVID-19 and file the findings with the PSCSC on a quarterly basis; and (4) include any other matters that the PSCSC believes should be addressed. The ORS requests that such comments be filed within 30 days of a PSCSC order approving the motion. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

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% increase in annual base revenues. The request for rate increase was driven by capital investments subsequent to the previous base rate case, including the William States Lee Combined Cycle Facility, grid improvement projects, AMI, investments in customer service technologies, costs of complying with CCR regulations and the Coal Ash Act and recovery of costs related to licensing and development of the William States Lee III Nuclear Station.

On February 28, 2018, Duke Energy Carolinas 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% and a capital structure of 52% equity and 48% debt.

On June 22, 2018, the NCUC issued an order approving the Stipulation of Partial Settlement and requiring a revenue reduction.

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 also filed Notices of Appeal to the North Carolina Supreme Court. On August 8, 2018, the Public Staff filed a Notice of Cross Appeal to the North Carolina Supreme Court, which contends the commission’s June 22, 2018, 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. On November 29, 2018, the North Carolina Attorney General's Office filed a motion with the North Carolina Supreme Court requesting the court consolidate the Duke Energy Carolinas and Duke Energy Progress appeals and enter an order adopting the parties’ proposed briefing schedule as set out in the filing. On November 29, 2018, the North Carolina Supreme Court adopted a schedule for briefing set forth in the motion to consolidate the Duke Energy Carolinas and Duke Energy Progress appeals. Appellant briefs were filed on April 26, 2019. The Appellee response briefs were filed on September 25, 2019. Oral arguments before the North Carolina Supreme Court were held on March 11, 2020. Duke Energy Carolinas cannot predict the outcome of this matter.

2019 North Carolina Rate Case

On September 30, 2019, Duke Energy Carolinas filed an application with the NCUC for a net rate increase for retail customers of approximately $291 million, which represented an approximate 6% increase in annual base revenues. The gross rate case revenue increase request was $445 million, which was offset by an EDIT rider of $154 million to return to customers North Carolina and federal EDIT resulting from recent reductions in corporate tax rates. The request for rate increase was driven by major capital investments subsequent to the previous base rate case, coal ash pond closure costs, accelerated coal plant depreciation and deferred 2018 storm costs. Duke Energy Carolinas requested rates be effective no later than August 1, 2020. The NCUC established a procedural schedule with an evidentiary hearing to begin on March 23, 2020. On March 16, 2020, in consideration of public health and safety as a result of the COVID-19 pandemic, Duke Energy Carolinas filed a motion with the NCUC seeking a suspension of the procedural schedule in the rate case, including issuing discovery requests, and postponement of the evidentiary hearing for 60 days. Also on March 16, 2020, the NCUC issued an Order Postponing Hearing and Addressing Procedural Matters, which postponed the evidentiary hearing until further order by the commission.

On March 25, 2020, Duke Energy Carolinas and the Public Staff filed an Agreement and Stipulation of Partial Settlement, which is subject to review and approval of the NCUC, resolving certain issues in the base rate proceeding. Major components of the settlement included:

• Removal of deferred storm costs from the rate case;

• Filing a petition seeking to securitize the deferred storm costs within 120 days of a commission order in this rate case regarding the reasonableness and prudency of the storm costs;

• Agreement of certain assumptions to demonstrate the quantifiable benefits to customers of a securitization financing; and

• Agreement on certain accounting matters, including recovery of employee incentives, severance, aviation costs and executive compensation.

On May 6, 2020, Duke Energy Carolinas, Duke Energy Progress and the Public Staff filed a joint motion requesting that the NCUC issue an order scheduling one consolidated evidentiary hearing to consider the companies’ applications for net rate increases. The joint motion suggests, health and safety permitting, that the commission consider the possibility of holding the consolidated hearing in July. If the NCUC grants the joint motion, Duke Energy Carolinas expects the NCUC to issue an order on its net rate increase by the end of the year. Duke Energy Carolinas cannot predict the outcome of this matter.

2018 South Carolina Rate Case

On November 8, 2018, Duke Energy Carolinas filed an application with the PSCSC for a rate increase for retail customers of approximately $168 million, which represented an approximate 10% increase in retail revenues. The request for rate increase was driven by capital investments and environmental compliance progress made by Duke Energy Carolinas since its previous rate case, including the further implementation of Duke Energy Carolinas’ generation modernization program, which consists of retiring, replacing and upgrading generation plants, investments in customer service technologies and continued investments in base work to maintain its transmission and distribution systems. The request included net tax benefits resulting from the Tax Act of $66 million to reflect the change in ongoing tax expense, primarily from the reduction in the federal income tax rate from 35% to 21%. The request also included $46 million to return EDIT resulting from the federal tax rate change and deferred revenues since January 2018 related to the change and benefits of $17 million from a reduction in North Carolina state income taxes allocable to South Carolina (EDIT Rider).

Duke Energy Carolinas also requested approval of its proposed Grid Improvement Plan (GIP), adjustments to its Prepaid Advantage Program and a variety of accounting orders related to ongoing costs for environmental compliance, including recovery over a five-year period of $242 million of deferred coal ash related compliance costs, grid investments between rate changes, incremental depreciation expense, a result of new depreciation rates from the depreciation study approved in the 2017 North Carolina Rate Case above, and the balance of development costs associated with the cancellation of the Lee Nuclear Project. Finally, Duke Energy Carolinas sought approval to establish a reserve and accrual for end-of-life nuclear costs for nuclear fuel and materials and supplies. On March 8, 2019, the ORS moved to establish a new and separate hearing docket to review and consider the GIP proposed by Duke Energy Carolinas. Subsequently, on March 12, 2019, the ORS and Duke Energy Carolinas executed a Stipulation resolving the ORS’s motion. The Stipulation provided that costs incurred for the GIP after January 1, 2019, would be deferred with a return, subject to evaluation in a future rate proceeding. The Stipulation was approved by the PSCSC on June 19, 2019. On December 16, 2019, Duke Energy Carolinas and Duke Energy Progress filed a Joint Petition to Establish an Informational Docket for Review and Consideration of Grid Improvement Plans through which Duke Energy Carolinas and Duke Energy Progress would provide interested stakeholders information on the companies' grid activities. The PSCSC requested parties comment on procedural matters by January 31, 2020; accordingly, various groups filed comments, none of which opposed an informational docket. Duke Energy Carolinas cannot predict the outcome of this matter.

After hearings in March 2019, the PSCSC issued an order on May 21, 2019, which included a return on equity of 9.5% and a capital structure of 53% equity and 47% debt. The order also included the following material components:

• Approval of cancellation of the Lee Nuclear Project, with Duke Energy Carolinas maintaining the Combined Operating License;

• Approval of recovery of $125 million (South Carolina retail portion) of Lee Nuclear Project development costs (including AFUDC through December 2017) over a 12-year period, but denial of a return on the deferred balance of costs;

• Approval of recovery of $96 million of coal ash costs over a five-year period with a return at Duke Energy Carolinas' WACC;

• Denial of recovery of $115 million of certain coal ash costs deemed to be related to the Coal Ash Act and incremental to the federal CCR rule;

• Approval of a $66 million decrease to base rates to reflect the change in ongoing tax expense, primarily the reduction in the federal income tax rate from 35% to 21%;

• Approval of a $45 million decrease through the EDIT Rider to return EDIT resulting from the federal tax rate change and deferred revenues since January 2018 related to the change, to be returned in accordance with the Average Rate Assumption Method (ARAM) for protected EDIT, over a 20-year period for unprotected EDIT associated with Property, Plant and Equipment, over a five-year period for unprotected EDIT not associated with Property, Plant and Equipment and over a five-year period for the deferred revenues; and

• Approval of a $17 million decrease through the EDIT Rider related to reductions in the North Carolina state income tax rate from 6.9% to 2.5% to be returned over a five-year period.

As a result of the order, revised customer rates were effective June 1, 2019. On May 31, 2019, Duke Energy Carolinas filed a Petition for Rehearing or Reconsideration of that order contending substantial rights of Duke Energy Carolinas were prejudiced by unlawful, arbitrary and capricious rulings by the commission on certain issues presented in the proceeding. On June 19, 2019, the PSCSC issued a Directive denying Duke Energy Carolinas' request to rehear or reconsider the commission's rulings on certain issues presented in the proceeding including coal ash remediation and disposal costs, return on equity and the recovery of a return on deferred operation and maintenance expenses. An order detailing the commission's decision in the Directive was issued on October 18, 2019. Duke Energy Carolinas filed a notice of appeal on November 15, 2019, with the Supreme Court of South Carolina. On November 20, 2019, the South Carolina Energy Users Committee filed a Notice of Appeal and the ORS filed a Notice of Cross Appeal with the Supreme Court of South Carolina. On February 12, 2020, Duke Energy Carolinas and the ORS filed a joint motion to extend briefing schedule deadlines, which was approved by the Supreme Court of South Carolina on February 20, 2020. On March 10, 2020, the ORS filed a consent motion requesting withdrawal of their appeal. Initial briefs were filed on April 21, 2020. Response briefs and reply briefs are due July 6, 2020, and August 11, 2020, respectively. Also on April 21, 2020, the South Carolina Energy User's Committee filed a brief arguing that the PSCSC erred in allowing Duke Energy Carolinas' recovery of costs related to the Lee Nuclear Station. Based on legal analysis and the filing of the appeal, Duke Energy Carolinas has not recorded an adjustment for its deferred coal ash costs. 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% increase in annual base revenues. Subsequent to the filing, Duke Energy Progress adjusted the requested amount to $420 million, representing an approximate 13% increase. The request for rate increase was 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 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% and a capital structure of 52% equity and 48% debt. On February 23, 2018, the NCUC issued an order approving the stipulation.

On May 15, 2018, the Public Staff filed a Notice of Cross Appeal to the North Carolina Supreme Court from the NCUC's February 23, 2018, order. The Public Staff contends the NCUC’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 also filed Notices of Appeal to the North Carolina Supreme Court from the February 23, 2018, order. On November 29, 2018, the North Carolina Attorney General's Office filed a motion with the North Carolina Supreme Court requesting the court consolidate the Duke Energy Progress and Duke Energy Carolinas appeals and enter an order adopting the parties’ proposed briefing schedule as set out in the filing. Appellant briefs were filed on April 26, 2019. The Appellee response briefs were filed on September 25, 2019. Oral arguments before the North Carolina Supreme Court were held on March 11, 2020. Duke Energy Progress cannot predict the outcome of this matter.

2019 North Carolina Rate Case

On October 30, 2019, Duke Energy Progress filed an application with the NCUC for a net rate increase for retail customers of approximately $464 million, which represented an approximate 12.3% increase in annual base revenues. The gross rate case revenue increase request was $586 million, which was offset by riders of $122 million, primarily an EDIT rider of $120 million to return to customers North Carolina and federal EDIT resulting from recent reductions in corporate tax rates. The request for rate increase was driven by major capital investments subsequent to the previous base rate case, coal ash pond closure costs, accelerated coal plant depreciation and deferred 2018 storm costs. Duke Energy Progress seeks to defer and recover incremental Hurricane Dorian storm costs in this proceeding and requests rates be effective no later than September 1, 2020. As a result of the COVID-19 pandemic, on March 24, 2020, the NCUC suspended the procedural schedule and postponed the previously scheduled evidentiary hearing on this matter indefinitely. On April 7, 2020, the NCUC issued an order partially resuming the procedural schedule requiring intervenors to file direct testimony on April 13, 2020. Public Staff filed supplemental direct testimony on April 23, 2020. Duke Energy Progress filed rebuttal testimony on May 4, 2020. On May 6, 2020, Duke Energy Progress, Duke Energy Carolinas and the Public Staff filed a joint motion requesting that the NCUC issue an order scheduling one consolidated evidentiary hearing to consider the companies’ applications for net rate increases. The joint motion suggests, health and safety permitting, that the commission consider the possibility of holding the consolidated hearing in July. If the NCUC grants the joint motion, Duke Energy Progress expects the NCUC to issue an order on its net rate increase by the end of the year. Duke Energy Progress cannot predict the outcome of this matter.

Hurricane Dorian

Hurricane Dorian reached the Carolinas in September 2019 as a Category 2 hurricane making landfall within Duke Energy Progress’ service territory. Approximately 270,000 North Carolina customers and 30,000 South Carolina customers were impacted by the slow-moving storm that brought high winds, tornadoes and heavy rain. With storm-response mobilization occurring in preparation for the storm and the assistance of mutual aid partners, full restoration was accomplished within four days for all customers able to receive service. Total estimated incremental operation and maintenance expenses incurred to repair and restore the system are approximately $177 million with an additional $4 million in capital investments made for restoration efforts. Approximately $151 million and $179 million of the operation and maintenance expenses are deferred in Regulatory assets within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of March 31, 2020, and December 31, 2019, respectively. A request for an accounting order to defer incremental storm costs associated with Hurricane Dorian was included in Duke Energy Progress' October 30, 2019, general rate case filing with the NCUC. Duke Energy Progress cannot predict the outcome of this matter.

On February 7, 2020, a petition was filed with the PSCSC in the 2019 storm deferrals docket requesting deferral of approximately $22 million in operation and maintenance expenses to an existing storm deferral balance previously approved by the PSCSC. The PSCSC voted to approve the request on March 4, 2020, and issued a final order on April 7, 2020.

2018 South Carolina Rate Case

On November 8, 2018, Duke Energy Progress filed an application with the PSCSC for a rate increase for retail customers of approximately $59 million, which represented an approximate 10.3% increase in annual base revenues. The request for rate increase was driven by capital investments and environmental compliance progress made by Duke Energy Progress since its previous rate case, including the further implementation of Duke Energy Progress’ generation modernization program, which consists of retiring, replacing and upgrading generation plants, investments in customer service technologies and continued investments in base work to maintain its transmission and distribution systems. The request included a decrease resulting from the Tax Act of $17 million to reflect the change in ongoing tax expense, primarily the reduction in the federal income tax rate from 35% to 21%. The request also included $10 million to return EDIT resulting from the federal tax rate change and deferred revenues since January 2018 related to the change (EDIT Rider) and a $12 million increase due to the expiration of EDITs related to reductions in North Carolina state income taxes allocable to South Carolina.

Duke Energy Progress also requested approval of its proposed GIP, approval of a Prepaid Advantage Program and a variety of accounting orders related to ongoing costs for environmental compliance, including recovery over a five-year period of $51 million of deferred coal ash related compliance costs, AMI deployment, grid investments between rate changes and regulatory asset treatment related to the retirement of a generating plant located in Asheville, North Carolina. Finally, Duke Energy Progress sought approval to establish a reserve and accrual for end-of-life nuclear costs for materials and supplies and nuclear fuel. On March 8, 2019, the ORS moved to establish a new and separate hearing docket to review and consider the GIP proposed by Duke Energy Progress. Subsequently, on March 12, 2019, the ORS and Duke Energy Carolinas executed a Stipulation resolving the ORS’s motion, and Duke Energy Progress agreed to the Stipulation, as did other parties in the rate case. The Stipulation provided that costs incurred for the GIP after January 1, 2019, would be deferred with a return, with all costs subject to evaluation in a future rate proceeding, and that Duke Energy Progress would refile for consideration of the GIP in a new docket for resolution by January 1, 2020. The Stipulation was approved by the PSCSC on June 19, 2019. On December 16, 2019, Duke Energy Progress and Duke Energy Carolinas filed a Joint Petition to Establish an Informational Docket for Review and Consideration of Grid Improvement Plans through which Duke Energy Progress and Duke Energy Carolinas would provide interested stakeholders information on the companies' grid activities. The PSCSC requested parties comment on procedural matters by January 31, 2020; accordingly, various groups filed comments, none of which opposed an informational docket. Duke Energy Progress cannot predict the outcome of this matter.

After hearings in April 2019, the PSCSC issued an order on May 21, 2019, which included a return on equity of 9.5% and a capital structure of 53% equity and 47% debt. The order also included the following material components:

• Approval of recovery of $4 million of coal ash costs over a five-year period with a return at Duke Energy Progress' WACC;

• Denial of recovery of $65 million of certain coal ash costs deemed to be related to the Coal Ash Act and incremental to the federal CCR rule;

• Approval of a $17 million decrease to base rates to reflect the change in ongoing tax expense, primarily the reduction in the federal income tax rate from 35% to 21%;

• Approval of a $12 million decrease through the EDIT Tax Savings Rider resulting from the federal tax rate change and deferred revenues since January 2018 related to the change, to be returned in accordance with ARAM for protected EDIT, over a 20-year period for unprotected EDIT associated with Property, Plant and Equipment, over a five-year period for unprotected EDIT not associated with Property, Plant and Equipment and over a three-year period for the deferred revenues; and

• Approval of a $12 million increase due to the expiration of EDIT related to reductions in the North Carolina state income tax rate from 6.9% to 2.5%.

As a result of the order, revised customer rates were effective June 1, 2019. On May 31, 2019, Duke Energy Progress filed a Petition for Rehearing or Reconsideration of that order contending substantial rights of Duke Energy Progress were prejudiced by unlawful, arbitrary and capricious rulings by the commission on certain issues presented in the proceeding. On June 19, 2019, the PSCSC issued a Directive denying Duke Energy Progress' request to rehear or reconsider the commission's rulings on certain issues presented in the proceeding including coal ash remediation and disposal costs, return on equity and the recovery of a return on deferred operation and maintenance expenses, but allowing additional litigation-related costs. As a result of the Directive allowing litigation-related costs, customer rates were revised effective July 1, 2019. An order detailing the commission's decision in the Directive was issued on October 18, 2019. Duke Energy Progress filed a notice of appeal on November 15, 2019, with the Supreme Court of South Carolina. The ORS filed a Notice of Cross Appeal on November 20, 2019. On February 12, 2020, Duke Energy Progress and the ORS filed a joint motion to extend briefing schedule deadlines, which was approved by the Supreme Court of South Carolina on February 20, 2020. On March 10, 2020, the ORS filed a consent motion requesting withdrawal of their appeal. Initial briefs were filed on April 21, 2020. Response briefs and reply briefs are due July 6, 2020, and August 11, 2020, respectively. Based on legal analysis and the filing of the appeal, Duke Energy Progress has not recorded an adjustment for its deferred coal ash costs. Duke Energy Progress cannot predict the outcome of this matter.

Western Carolinas Modernization Plan

On November 4, 2015, Duke Energy Progress announced a Western Carolinas Modernization Plan, which included retirement of the existing Asheville coal-fired plant, the construction of two 280‑MW combined-cycle natural gas plants having dual-fuel capability, with the option to build a third natural gas simple cycle unit in 2023 based upon the outcome of initiatives to reduce the region's power demand. The plan also included upgrades to existing transmission lines and substations, installation of solar generation and a pilot battery storage project.

Duke Energy Progress retired the 376-MW Asheville coal-fired plant on January 29, 2020, at which time the net book value, including associated ash basin closure costs, of $214 million was transferred from Generation facilities to be retired, net to Regulatory assets within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

On March 28, 2016, the NCUC issued an order approving a Certificate of Public Convenience and Necessity (CPCN) for the new combined-cycle natural gas plants with an estimated cost of $893 million, but required Duke Energy Progress to refile for CPCN approval for the contingent simple cycle unit.

On December 27, 2019, Asheville Combined Cycle Power Block 1 and the common systems that serve both combined cycle units went into commercial operation. Power Block 1 consists of the Unit 5 Combustion Turbine and Unit 6 Steam Turbine Generator (which together form the first combined cycle unit approved in the CPCN Order). Power Block 2 consists of the Unit 7 Combustion Turbine and Unit 8 Steam Turbine Generator (which together form the second combined cycle unit approved in the CPCN Order). Duke Energy Progress placed the Unit 7 Combustion Turbine portion of Power Block 2 into commercial operation in simple-cycle mode on January 15, 2020. The Unit 8 Steam Turbine Generator went into commercial operation on April 5, 2020.

On October 8, 2018, Duke Energy Progress filed an application with the NCUC for a CPCN to construct the Hot Springs Microgrid Solar and Battery Storage Facility. On March 22, 2019, Duke Energy Progress and the Public Staff filed a Joint Proposed Order. On May 10, 2019, the NCUC issued an Order Granting Certificate of Public Convenience and Necessity with Conditions. On November 19, 2019, Duke Energy Progress filed a semiannual progress report for its Hot Springs Microgrid Solar and Battery Storage Facility. As required by an NCUC order issued December 6, 2019, an updated progress report was filed on January 15, 2020. An evidentiary hearing was held on March 5, 2020. Construction is expected to begin in the second quarter of 2020 with commercial operation expected to begin in December 2020.

Duke Energy Florida

COVID-19 Filings

On March 1, 2020, Governor Ron DeSantis issued Executive Order No. 20-51 directing the State Health Officer of Florida to declare a public health emergency in Florida related to the COVID-19 pandemic. The governor then issued a second Executive Order No. 20-52 on March 9, 2020, in which he declared a state of emergency in Florida and directed the Director of the Division of Emergency Management to implement the state’s Comprehensive Emergency Management Plan. The governor issued additional Executive Orders – Nos. 2020-68, 2020-69, 2020-71, 2020-72 and 2020-83 – in response to the ongoing health care emergency that, among other things, suspended the in-person public meeting requirements for state agencies and local governments and directed the state surgeon general to issue public health advisories to limit potential exposure to COVID-19, advising against gatherings of 10 or more persons. On March 19, 2020, Duke Energy Florida filed a request to modify its tariff to allow it to waive late fees for customers, and on April 6, 2020, the FPSC issued an order approving the request. Duke Energy Florida had already voluntarily waived reconnect fees and credit card fees, and is not disconnecting customers for nonpayment. On April 2, 2020, Duke Energy Florida filed a petition with the FPSC to accelerate a $78 million fuel cost refund to customers in the month of May 2020. Typically, the refund would be made over the course of 2021. The FPSC approved the petition on April 28, 2020.

Storm Restoration Cost Recovery

In October 2018, Duke Energy Florida’s service territory suffered damage when Hurricane Michael made landfall as a Category 5 hurricane with maximum sustained winds of 160 mph. The storm caused catastrophic damage from wind and storm surge, particularly from Panama City Beach to Mexico Beach, resulting in widespread outages and significant damage to transmission and distribution facilities across the central Florida Panhandle. In response to Hurricane Michael, Duke Energy Florida restored service to approximately 72,000 customers. Total estimated incremental operation and maintenance and capital costs are $311 million. Approximately $106 million and $107 million of the costs are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2020, and December 31, 2019, respectively. Approximately $205 million and $204 million of costs are included in Regulatory assets within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of March 31, 2020, and December 31, 2019, respectively, representing recoverable costs under the FPSC’s storm rule and Duke Energy Florida's OATT formula rates.

Duke Energy Florida filed a petition with the FPSC on April 30, 2019, to recover the retail portion of estimated incremental storm restoration costs for Hurricane Michael. On June 11, 2019, the FPSC approved the petition for recovery of estimated incremental storm restoration costs related to Hurricane Michael. The FPSC also approved the stipulation Duke Energy Florida filed, which will allow Duke Energy Florida to use the tax savings resulting from the Tax Act to recover these storm costs in lieu of implementing a storm surcharge. Approved storm costs are currently expected to be fully recovered by approximately year-end 2021. On November 22, 2019, Duke Energy Florida filed a petition for approval of actual retail recoverable storm restoration costs related to Hurricane Michael in the amount of $191 million plus interest. An Order Establishing Procedure was issued on January 30, 2020, and hearings are scheduled to begin September 15, 2020. Duke Energy Florida cannot predict the outcome of this matter.

Hurricane Dorian

In September 2019, Duke Energy Florida’s service territory was threatened by Hurricane Dorian with landfall as a possible Category 5 hurricane. For several days, various forecasts and models predicted significant impact to Duke Energy Florida’s service territory; accordingly, Duke Energy Florida incurred costs to secure necessary resources to be prepared for that potential impact. Although Hurricane Dorian never made landfall in Florida, its effects were still felt, and outages did occur. Preparations were required so that, if Hurricane Dorian had made landfall and impacts had been more severe, Duke Energy Florida would have been prepared to restore its customers’ power in a timely fashion.

On December 19, 2019, Duke Energy Florida filed a petition with the FPSC to recover $169 million, the estimated retail portion of these costs, consistent with the provisions in the 2017 Settlement. On February 24, 2020, the commission approved the request for recovery over a 12-month period with rates effective in March 2020 and subject to true up. The final actual amount will be filed later in 2020 and the FPSC will hold a hearing to determine the final amount of incremental costs. Duke Energy Florida cannot predict the outcome of this matter. Approximately $147 million and $167 million of these costs are included in Regulatory assets within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of March 31, 2020, and December 31, 2019, respectively, representing recoverable costs under the FPSC’s storm rule and Duke Energy Florida's OATT formula rates.

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 Settlement. The Hamilton Project, which was placed into service on December 22, 2018, had an annual retail revenue requirement of $15 million. 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, and revised customer rates became effective in January 2019. On April 2, 2019, the commission approved both solar projects as filed. The Columbia Project, which has a projected annual revenue requirement of $14 million, was placed in service in March 2020 and revised customer rates became effective in April 2020.

On March 25, 2019, Duke Energy Florida petitioned the FPSC to include in base rates the revenue requirements for its next wave of solar generation projects, the Trenton, Lake Placid and DeBary Solar Projects, as authorized by the 2017 Settlement. The annual retail revenue requirement for the Trenton and Lake Placid Projects was $13 million and $8 million, respectively, and they were placed into service in December 2019 with rates taking effect in January 2020. The DeBary Project has a projected annual revenue requirement of $11 million and a projected in-service date in the second quarter of 2020. The associated rate increase would take place with the first month’s billing cycle after each solar generation project goes into service. On July 22, 2019, the FPSC issued an order approving Duke Energy Florida's request.

Crystal River Unit 3 Accelerated Decommissioning Filing

On May 29, 2019, Duke Energy Florida entered into a Decommissioning Services Agreement for the accelerated decommissioning of the Crystal River Unit 3 nuclear power station located in Citrus County, Florida, with ADP CR3, LLC and ADP SF1, LLC, each of which is a wholly owned subsidiary of Accelerated Decommissioning Partners, LLC, a joint venture between NorthStar Group Services, Inc. and Orano USA LLC. Closing of this agreement is contingent upon the approval of the U.S. Nuclear Regulatory Commission (NRC) and FPSC. If approved, the decommissioning will be accelerated starting in 2020 and continuing through 2027, rather than the expected time frame under SAFSTOR of starting in 2067 and ending in 2074. Duke Energy Florida expects that the assets of the Nuclear Decommissioning Trust Fund will be sufficient to cover the contract price. On July 10, 2019, Duke Energy Florida petitioned the FPSC for approval of the agreement. On April 1, 2020, the NRC issued an order approving the license transfer application. Following the NRC order, on April 15, 2020, the FPSC issued its Second Order Modifying Order Establishing Procedure in which hearings are scheduled to begin July 7, 2020. Duke Energy Florida cannot predict the outcome of this matter.

Duke Energy Ohio

Duke Energy Ohio COVID-19 Filing

In response to the COVID-19 pandemic, on March 9, 2020, Governor Mike DeWine issued Executive Order No. 2020-01D declaring a state of emergency in the State of Ohio. The PUCO issued an order directing utilities to cease disconnections for nonpayment and waive late payment and reconnection fees and to minimize direct customer contact. The PUCO also directed utilities to maintain flexible payment plans and tariff interpretations to assist customers during this crisis and to seek any regulatory waivers, if necessary. In response, Duke Energy Ohio has ceased all disconnections except for safety-related concerns and is waiving late payment and reconnection fees. On March 19, 2020, Duke Energy Ohio filed its compliance plan with the PUCO and sought waiver of several regulations to minimize direct customer contact.

On April 16, 2020, Duke Energy Ohio filed an application for a Reasonable Arrangement to temporarily lower the minimum bill for demand-metered commercial and industrial customers. The proposal is conditioned on full recovery via Duke Energy Ohio's existing Economic Competitiveness Fund Rider (Rider ECF), which has been used by Duke Energy Ohio in the past for other reasonable arrangements with customers. On April 24, 2020, the Staff of the PUCO filed its recommendation finding Duke Energy Ohio’s application is reasonable and that the PUCO should approve it. Duke Energy Ohio cannot predict the outcome of this matter.

On May 11, 2020, Duke Energy Ohio filed with the PUCO a request seeking deferral of incremental costs incurred, as well as specific miscellaneous lost revenues. The request seeks to use existing bad debts and uncollectible riders already in place for both electric and natural gas operations. Duke Energy Ohio would subsequently file for rider recovery at a later date. Duke Energy Ohio cannot predict the outcome of this matter.

Duke Energy Kentucky COVID-19

In response to the COVID-19 pandemic, on March 6, 2020, Governor Andy Beshear issued Executive Order No. 2020-215 declaring a state of emergency in the Commonwealth of Kentucky. The KPSC issued an order directing utilities to cease disconnections for nonpayment and waive late payment and reconnection fees. The KPSC also directed utilities to maintain flexible payment plans and tariff interpretations to assist customers during this crisis and to seek any regulatory waivers if necessary. Duke Energy Kentucky had already voluntarily ceased all disconnections except for safety-related concerns and was waiving late payment and reconnection fees.

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 ESP. 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 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 term of the ESP would be from June 1, 2018, to May 31, 2025, and included 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. The Stipulation established a regulatory model for the next seven years via the approval of the ESP and continued the current model for procuring supply for non-shopping customers, including recovery mechanisms. On December 19, 2018, the PUCO approved the Stipulation without material modification. Several parties, including the Office of the Ohio Consumers' Counsel (OCC), filed applications for rehearing. On February 6, 2019, the PUCO granted the parties rehearing. The PUCO issued its Second Entry on Rehearing on July 17, 2019, upholding its December 19, 2018 order and denying all assignments of error raised by the non-stipulating parties. On October 11, 2019, the OCC filed its Third Application for Rehearing arguing the PUCO erred in finding OCC’s Second Application for Rehearing as improper. Duke Energy Ohio filed its Memorandum Contra on October 21, 2019. The PUCO denied OCC's Third Application for Rehearing as a matter of law. On September 13, 2019, Interstate Gas Supply/Retail Supply Association filed appeals to the Supreme Court of Ohio claiming the PUCO’s order was in error because it approved unsupported charges to competitive suppliers and cost subsidies shopping customers pay for non-shopping customers. On September 16, 2019, the OCC filed an appeal challenging the PUCO’s approval of OVEC recovery through Duke Energy Ohio's Price Stability Rider (Rider PSR) alleging the FPA pre-empts the commission’s jurisdiction and that the record does not support finding that Rider PSR results in a limitation on shopping. Appellant briefs were filed on January 6, 2020. Appellee briefs were scheduled to be filed on March 16, 2020. On March 13, 2020, the Supreme Court of Ohio granted OCC's motion to withdraw its appeal related to OVEC recovery. On April 22, 2020, the Supreme Court of Ohio dismissed all remaining appeals of PUCO's December 19, 2018 order approving the stipulation. The case has been resolved.

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 requested an estimated annual increase of approximately $15 million and a return on equity of 10.4%. The application also included 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% and 10.24%. On April 13, 2018, Duke Energy Ohio filed a Motion to consolidate this proceeding with several other cases 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 included a $19 million decrease in annual base distribution revenue with a return on equity unchanged from the current rate of 9.84% based upon a capital structure of 50.75% equity and 49.25% debt. Upon approval of new rates, Duke Energy Ohio's rider for recovering its initial SmartGrid implementation ended as these costs would be recovered through base rates. The Stipulation also renewed 14 existing riders, some of which were included in the company's ESP, and added 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). 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 reduced electric revenue by approximately $20 million on an annualized basis. On December 19, 2018, the PUCO approved the Stipulation without material modification. New base rates were implemented effective January 2, 2019. Several parties, including the OCC, filed applications for rehearing. On February 6, 2019, the PUCO granted the parties rehearing. The PUCO issued its Second Entry on Rehearing on July 17, 2019, upholding its December 19, 2018 order and denying all assignments of error raised by the non-stipulating parties. On October 11, 2019, the OCC filed its Third Application for Rehearing arguing the PUCO erred in finding OCC’s Second Application for Rehearing as improper. Duke Energy Ohio filed its Memorandum Contra on October 21, 2019. The PUCO denied OCC's Third Application for Rehearing as a matter of law. On September 13, 2019, Interstate Gas Supply/Retail Supply Association filed appeals to the Supreme Court of Ohio claiming the PUCO’s order was in error because it approved unsupported charges to competitive suppliers and cost subsidies shopping customers pay for non-shopping customers. On September 16, 2019, the OCC filed an appeal challenging the PUCO’s approval of OVEC recovery through Rider PSR alleging the FPA pre-empts the commission’s jurisdiction and that the record does not support finding that Rider PSR results in a limitation on shopping. Appellant briefs were filed on January 6, 2020. Appellee briefs were scheduled to be filed on March 16, 2020. On March 13, 2020, the Supreme Court of Ohio granted OCC's motion to withdraw its appeal related to OVEC recovery. On April 22, 2020, the Supreme Court of Ohio dismissed all remaining appeals of PUCO's December 19, 2018 order approving the stipulation. The case has been resolved.

Ohio Valley Electric Corporation

On March 31, 2017, Duke Energy Ohio filed for approval to adjust its existing Rider PSR to pass through net costs related to its contractual entitlement to capacity and energy from the generating assets owned by OVEC. Duke Energy Ohio sought deferral authority for net costs incurred from April 1, 2017, until the new rates under Rider PSR were put into effect. 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 activated Rider PSR for recovery of net costs incurred from January 1, 2018, through May 2025. On December 19, 2018, the PUCO approved the Stipulation without material modification. The PSR rider became effective April 1, 2019. Several parties, including the OCC, filed applications for rehearing. On February 6, 2019, the PUCO granted the parties rehearing. The PUCO issued its Second Entry on Rehearing on July 17, 2019, upholding its December 19, 2018 order and denying all assignments of error raised by the non-stipulating parties. On October 11, 2019, the OCC filed its Third Application for Rehearing arguing the PUCO erred in finding OCC’s Second Application for Rehearing as improper. Duke Energy Ohio filed its Memorandum Contra on October 21, 2019. The PUCO denied OCC's Third Application for Rehearing as a matter of law. On September 13, 2019, Interstate Gas Supply/Retail Supply Association filed appeals to the Supreme Court of Ohio claiming the PUCO’s order was in error because it approved unsupported charges to competitive suppliers and cost subsidies shopping customers pay for non-shopping customers. On September 16, 2019, the OCC filed an appeal challenging the PUCO’s approval of OVEC recovery through Rider PSR alleging the FPA pre-empts the commission’s jurisdiction and that the record does not support finding that Rider PSR results in a limitation on shopping. Appellant briefs were filed on January 6, 2020. Appellee briefs were scheduled to be filed on March 16, 2020. On March 13, 2020, the Supreme Court of Ohio granted OCC's motion to withdraw its appeal related to OVEC recovery. On April 22, 2020, the Supreme Court of Ohio dismissed all remaining appeals of PUCO's December 19, 2018 order approving the stipulation. The case has been resolved.

On July 23, 2019, an Ohio bill was signed into law that became effective January 1, 2020. Among other things, the bill allows for recovery of prudently incurred costs, net of any revenues, for Ohio investor-owned utilities that are participants under the OVEC power agreement. The recovery shall be through a non-bypassable rider that is to replace any existing recovery mechanism approved by the PUCO and will remain in place through 2030. The amounts recoverable from customers will be subject to an annual cap, with incremental costs that exceed such cap eligible for deferral and recovery subject to review. See Note 13 for additional discussion of Duke Energy Ohio's ownership interest in OVEC.

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. On April 10, 2019, the PUCO issued an Entry on Rehearing denying the rehearing applications. On February 26, 2020, the PUCO issued an order directing utilities to wind down their demand-side management programs by September 30, 2020, and to terminate the programs by December 31, 2020, in response to changes in Ohio law that eliminated Ohio's energy efficiency mandates. On March 27, 2020, Duke Energy Ohio filed an Application for Rehearing seeking clarification on the final true-up and reconciliation process after 2020. On April 22, 2020, the PUCO granted rehearing for further consideration.

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 for 2017 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 OCC'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.

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 currently estimates the pipeline development costs and construction activities will range from $163 million to $245 million in direct costs (excluding overheads and AFUDC). 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. In April 2018, Duke Energy Ohio filed a motion with OPSB to establish a procedural schedule and filed supplemental information supporting its application. On December 18, 2018, the OPSB established a procedural schedule that included a local public hearing on March 21, 2019. An evidentiary hearing began on April 9, 2019, and concluded on April 11, 2019. Briefs were filed on May 13, 2019, and reply briefs were filed on June 10, 2019. On November 21, 2019, the OPSB approved Duke Energy Ohio's application subject to 41 conditions on construction. Applications for rehearing were filed by several stakeholders on December 23, 2019, arguing that the OPSB approval was incorrect. Duke Energy Ohio filed a memorandum contra on January 2, 2020. On February 20, 2020, the OPSB denied the rehearing requests. Construction of the pipeline extension is expected to be completed before the 2021/2022 winter season. On April 15, 2020, Joint Appellants filed a notice of appeal at the Supreme Court of Ohio of the OPSB’s decision approving Duke Energy Ohio’s Central Corridor application. On April 16, 2020, several of the Joint Appellants filed a motion for a Stay asking the court to suspend the OPSB’s order. On April 27, 2020, Duke Energy Ohio and the OPSB each filed a motion in opposition to the Stay. If the Stay is granted, Duke Energy Ohio cannot continue working during the appeal process. Duke Energy Ohio cannot predict the outcome of this matter.

2012 Natural Gas Rate Case/MGP Cost Recovery

As part of its 2012 natural gas base rate case, Duke Energy Ohio has approval to defer and recover costs related to environmental remediation at two sites (East End and West End) that housed former MGP operations. Duke Energy Ohio has made annual applications for recovery of these deferred costs. Duke Energy Ohio has collected approximately $55 million in environmental remediation costs between 2009 through 2012 through a separate rider, Rider MGP, which is currently suspended. Duke Energy Ohio has made annual applications with the PUCO to recover its incremental remediation costs consistent with the PUCO’s directive in Duke Energy Ohio’s 2012 natural gas rate case. To date, the PUCO has not ruled on Duke Energy Ohio’s annual applications for the calendar years 2013 through 2017. On September 28, 2018, the staff of the PUCO issued a report recommending a disallowance of approximately $12 million of the $26 million in MGP remediation costs incurred between 2013 through 2017 that staff believes are not eligible for recovery. Staff interprets the PUCO’s 2012 Order granting Duke Energy Ohio recovery of MGP remediation as limiting the recovery to work directly on the East End and West End sites. On October 30, 2018, Duke Energy Ohio filed reply comments objecting to the staff’s recommendations and explaining, among other things, the obligation Duke Energy Ohio has under Ohio law to remediate all areas impacted by the former MGPs and not just physical property that housed the former plants and equipment. To date, the PUCO has not ruled on Duke Energy Ohio’s applications. On March 29, 2019, Duke Energy Ohio filed its annual application to recover incremental remediation expense for the calendar year 2018 seeking recovery of approximately $20 million in remediation costs. On July 12, 2019, the staff recommended a disallowance of approximately $11 million for work that staff believes occurred in areas not authorized for recovery. Additionally, staff recommended that any discussion pertaining to Duke Energy Ohio's recovery of ongoing MGP costs should be directly tied to or netted against insurance proceeds collected by Duke Energy Ohio. An evidentiary hearing began on November 18, 2019, and concluded on November 21, 2019. Initial briefs were filed on January 17, 2020, and reply briefs were filed on February 14, 2020. Duke Energy Ohio cannot predict the outcome of this matter.

On March 31, 2020, Duke Energy Ohio filed its annual application to recover incremental remediation expense for the calendar year 2019 seeking recovery of approximately $39 million in remediation costs incurred during 2019. Duke Energy Ohio cannot predict the outcome of this matter.

The 2012 PUCO order also contained conditional deadlines for completing the MGP environmental investigation and remediation costs at the MGP sites. Subsequent to the order, the deadline was extended to December 31, 2019. On May 10, 2019, Duke Energy Ohio filed an application requesting a continuation of its existing deferral authority for MGP remediation and investigation that must occur after December 31, 2019. On September 13, 2019, intervenor comments were filed opposing Duke Energy Ohio's request for continuation of existing deferral authority and on October 2, 2019, Duke Energy Ohio filed reply comments. Duke Energy Ohio cannot predict the outcome of this matter.

Duke Energy Kentucky Electric Base Rate Case

On September 3, 2019, Duke Energy Kentucky filed a rate case with the KPSC requesting an increase in electric base rates of approximately $46 million, which represents an approximate 12.5% increase across all customer classes. The request for rate increase is driven by increased investment in utility plant since the last electric base rate case in 2017. Duke Energy Kentucky seeks to implement a Storm Deferral Mechanism that will enable Duke Energy Kentucky to defer actual costs incurred for major storms that are over or under amounts in base rates. In response to large customers’ desire to have access to renewable resources, Duke Energy Kentucky is proposing a Green Source Advantage tariff designed for those large customers that wish to invest in renewable energy resources to meet sustainability goals. Duke Energy Kentucky is proposing an electric vehicle (EV) infrastructure pilot and modest incentives to assist customers in investing in EV technologies. Additionally, Duke Energy Kentucky is proposing to build an approximate 3.4-MW distribution battery energy storage system to be attached to Duke Energy Kentucky’s distribution system providing frequency regulation and enhanced reliability to Kentucky customers. The commission issued a procedural schedule with two rounds of discovery and opportunities for intervenor and rebuttal testimony. The Kentucky Attorney General filed its testimony recommending an increase of approximately $26 million. On January 31, 2020, Duke Energy Kentucky filed rebuttal testimony updating its rate increase calculations to approximately $44 million. Hearings were held on February 19-20, 2020, with briefing completed March 20, 2020. On April 27, 2020, the KPSC issued its decision approving a $24 million increase for Duke Energy Kentucky with a 9.25% return on equity. The KPSC denied Duke Energy Kentucky’s major storm deferral mechanism and EV and battery storage pilots. The KPSC approved Duke Energy Kentucky’s Green Source Advantage tariff. New customer rates were effective on May 1, 2020. Duke Energy Kentucky is evaluating the order and whether to seek rehearing. Duke Energy Kentucky cannot predict the outcome of this matter.

Duke Energy Indiana

COVID-19

In response to the COVID-19 pandemic, on March 6, 2020, Governor Eric Holcomb issued Executive Order No. 20-02, which by law expired in 30 days unless extended, declaring a public health disaster emergency in the state of Indiana. On April 3, 2020, the governor then issued Executive Order No. 20-17 which renewed the public health disaster emergency declaration for an additional 30 days to May 5, 2020. On May 1, 2020, Executive Order No, 20-25 further renewed the public health disaster emergency an additional 30 days to June 4, 2020. All other Executive Orders issued since March 6, 2020, (Nos. 20-04 – 20-16) were renewed for the same 30-day period, provided they were supplements to Executive Order No. 20-02. Executive Order No. 20-05 was issued on March 19, 2020, requiring utilities in the state to suspend disconnections of utility service. Duke Energy Indiana had already voluntarily suspended all disconnections and is waiving late payment fees and check return fees. The utility is also waiving credit card fees for residential customers.

On May 8, 2020, Duke Energy Indiana, along with other Indiana utilities, filed a request with the IURC for approval of deferral treatment for costs and revenue reductions associated with the COVID-19 pandemic. The utilities requested initial deferral approval in July 2020, with individual subdockets for each utility to be established for consideration of utility-specific cost and revenue impacts, cost recovery timing and customer payment plans. The same day, the Indiana Office of Utility Consumer Counselor filed a petition asking the IURC to continue to suspend disconnections, allow the utilities accounting deferrals and require tacking of cost savings. Duke Energy Indiana cannot predict the outcome of thIs matter.

2019 Indiana Rate Case

On July 2, 2019, Duke Energy Indiana filed a general rate case with the IURC, its first general rate case in 16 years, for a rate increase for retail customers of approximately $395 million. The request for rate increase is driven by strategic investments to generate cleaner electricity, improve reliability and serve a growing customer base. The request is premised upon a Duke Energy Indiana rate base of $10.2 billion as of December 31, 2018, and adjusted for projected changes through December 31, 2020. On September 9, 2019, Duke Energy Indiana revised its revenue request from $395 million to $393 million and filed updated testimony for the Retail Rate Case. The updated filing reflects a clarification in the presentation of Utility Receipts Tax, a $2 million reduction in the revenue requirement for revenues that will remain in riders and changes to allocation of revenue requirements within rate classes. The Utility Receipts Tax is currently embedded in base rates and rider rates. The proposed treatment is to include the Utility Receipts Tax as a line item on the customer bill rather than included in rates. The request is an approximate 15% increase in retail revenues and approximately 17% when including estimated Utility Receipts Tax. The rebuttal case, filed on December 4, 2019, updated the requested revenue requirement to result in a 15.6% or $396 million average retail rate increase, including the impacts of the Utility Receipts Tax. Hearings concluded on February 7, 2020, and rates are expected to be effective mid-2020. Duke Energy Indiana cannot predict the outcome of these matters.

The IURC determined to take two issues out of the rate case and place them in separate subdocket proceedings due to the complexity of the rate case. The commission moved the request for approval of an electric transportation pilot and future coal ash recovery issues to separate subdockets. Coal ash expenditures prior to 2019 are still included in the rate case. Duke Energy Indiana filed testimony on April 15, 2020, in the coal ash subdocket requesting recovery for the post-2018 coal ash basin closure costs for plans that have been approved by the Indiana Department of Environmental Management as well as continuing deferral, with carrying costs, on the balance. An evidentiary hearing is scheduled to begin on September 14, 2020, and an order is expected in the first quarter of 2021. Duke Energy Indiana cannot predict the outcome of this matter.

Piedmont

COVID-19 Filings

North Carolina

On March 10, 2020, Governor Roy Cooper issued Executive Order No. 116 declaring a state of emergency due to the COVID-19 pandemic. In an effort to help mitigate the financial impacts of the COVID-19 pandemic on their customers, on March 19, 2020, Piedmont filed a request with the NCUC seeking authorization to waive: (1) any late payment charges incurred by a residential or nonresidential customer, effective March 21, 2020; (2) the application of fees for checks returned for insufficient funds for residential and nonresidential customers; (3) the reconnection charge when a residential or nonresidential customer seeks to have service restored for those customers whose service was recently disconnected for nonpayment and to work with customers regarding the other requirements to restore service, including re-establishment of credit; and (4) the fees and charges associated with the use of credit cards or debit cards to pay residential electric utility bills, effective March 21, 2020. The NCUC granted Piedmont’s request on March 20, 2020.

On March 31, 2020, the governor issued Executive Order No. 124, which, in addition to requiring the steps in the NCUC order noted above, stated that nothing in Executive Order No. 124 shall relieve a customer of its obligation to pay bills for receipt of utility services provided. Executive Order No. 124 remains in effect for 60 days unless otherwise rescinded or replaced with a superseding Executive Order.

South Carolina

On March 13, 2020, Governor Henry McMaster issued Executive Order No. 2020-08 declaring a state of emergency due to the COVID-19 pandemic. The governor also issued a letter on March 14, 2020, to the ORS Executive Director regarding the suspension of disconnection of essential utility services for nonpayment. On March 16, 2020, citing the governor’s letter, the ORS filed a request asking the PSCSC to grant waivers so that utilities could suspend disconnections of utility services for nonpayment. Piedmont supported such motion. On March 18, 2020, the PSCSC issued an order approving such waivers, and also approved waivers for regulations related to late fees and reconnect fees. The PSCSC's order also required utilities to track the financial impacts of actions taken pursuant to such waivers for possible reporting to the PSCSC.

On April 30, 2020, the ORS requested the PSCSC grant a waiver of the applicable regulations to allow customers the flexibility to obtain deferred payment plans longer than 6 months for past-due amounts. On May 5, 2020, Piedmont filed responsive comments stating that while utility bills will remain due, Piedmont does not plan to immediately reinstitute disconnection upon the expiration of the state of emergency and intends to work through a potential grace period as economic recovery begins. Piedmont also concurred with the observation of the ORS that reduced usage is impacting the fixed cost recovery and revenue assumptions included in rates. Those costs include not only ongoing operational and financing costs necessary to serve customers, but also the borrowings necessary to support extended payment arrangements that will be an important part of emerging from the COVID-19 pandemic. Piedmont will continue to track such costs, lost revenues and potential cost savings for future evaluation by the PSCSC.

Additionally, on May 8, 2020, the ORS filed a motion for the PSCSC to solicit comments from utilities and interested stakeholders regarding measures to be taken to mitigate impacts of COVID-19 on utility customers and require recordkeeping. In a detailed motion, the ORS specifically asked the PSCSC to: (1) solicit input from utilities regarding the temporary mitigation measures to address COVID-19; (2) request utilities to inform the PSCSC of the plans utilities have to return to normalized operations; (3) require utilities to track revenue impacts, incremental costs and savings related to COVID-19 and file the findings with the PSCSC on a quarterly basis; and (4) include any other matters that the PSCSC believes should be addressed. The ORS requests that such comments be filed within 30 days of a PSCSC order approving the motion. Piedmont cannot predict the outcome of this matter.

Tennessee

On March 12, 2020, Governor Bill Lee issued Executive Order No. 14 declaring a state of emergency due to the COVID-19 pandemic. In an effort to help mitigate the financial impacts of the COVID-19 pandemic on their customers, on March 20, 2020, Piedmont filed a request with the TPUC seeking authorization to waive, effective March 21, 2020: (1) any late payment charges incurred by a residential or nonresidential customer; (2) the application of fees for checks returned for insufficient funds for residential and nonresidential customers; and (3) the reconnection charge when a residential or nonresidential customer seeks to have service restored for those customers whose service was recently disconnected for nonpayment and to work with customers regarding the other requirements to restore service, including re-establishment of credit. The TPUC granted Piedmont’s request by Order issued March 31,2020. The Order also stated that customers were not relieved of their obligation to pay for utility services received.

North Carolina Integrity Management Rider Filing

In April 2020, Piedmont filed a petition with the NCUC under the IMR mechanism to collect an additional $15 million in annual revenues, effective June 2020, based on the eligible capital investments closed to integrity and safety projects over the six-month period ending March 31, 2020. Piedmont cannot predict the outcome of this matter.

Tennessee Integrity Management Rider Filing

In November 2019, Piedmont filed a petition with the TPUC under the IMR mechanism to collect an additional $2 million in annual revenues, effective January 2020, based on the eligible capital investments closed to integrity and safety projects over the 12-month period ending October 31, 2019. An evidentiary hearing occurred on May 11, 2020. Upon approval from the TPUC, the revenue adjustment will be implemented, retroactive to January 2020. Piedmont cannot predict the outcome of this matter.

OTHER REGULATORY MATTERS

Atlantic Coast Pipeline, LLC

On September 2, 2014, Duke Energy, Dominion Energy, Inc. (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 be responsible for building and operating the ACP pipeline and holds a leading ownership percentage in ACP of 53%, following the purchase in March 2020 of Southern Company Gas' 5% ownership interest. Duke Energy owns a 47% interest, which is accounted for as an equity method investment through its Gas Utilities and Infrastructure segment. See Note 11 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 and, 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. Due to legal challenges not directly related to the request for a Notice to Proceed in Virginia, this request is still pending.

ACP is the subject of challenges in state and federal courts and agencies, including, among others, challenges of the project’s biological opinion (BiOp) and 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 project's air permit for a compressor station at Buckingham, Virginia, 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. Since December 2018, notable developments in these challenges include a stay in December 2018 issued by the U.S. Court of Appeals for the Fourth Circuit (Fourth Circuit) and the same court's July 26, 2019, vacatur of the project's BiOp and ITS (which stay and subsequent vacatur halted most project construction activity), a Fourth Circuit decision vacating the project's permits to cross the Monongahela and George Washington National Forests and the Appalachian Trail, the Fourth Circuit's remand to USACE of ACP's Huntington District 404 verification, the Fourth Circuit’s remand to the National Park Service of ACP’s Blue Ridge Parkway right-of-way and the most recent vacatur of the air permit for a compressor station at Buckingham, Virginia. ACP is vigorously defending these challenges and coordinating with the federal and state authorities which are the direct parties to the challenges. The Solicitor General of the United States and ACP filed petitions for certiorari to the Supreme Court of the United States on June 25, 2019, regarding the Appalachian Trail crossing and certiorari was granted on October 4, 2019. The Supreme Court hearing took place on February 24, 2020, and a ruling is expected in the second quarter of 2020.

In anticipation of the Fourth Circuit's vacatur of the BiOp and ITS, ACP and the FWS commenced work in mid-May of 2019 to set the basis for a reissued BiOp and ITS. On February 10, 2020, the FERC issued a letter to FWS requesting the re-initiation of formal consultation in support of reissuing the BiOp and ITS, and on April 14, 2020, ACP submitted the Biological Assessment, which may form the foundation for FWS' BiOp. ACP continues coordinating and working with FWS and other parties in preparation for a reissuance of the BiOp and ITS.

ACP triggered the Adverse Government Actions (AGA) clause of its agreements with its customers in December 2019. Formal negotiations have resulted in agreement on material terms, such as updated pricing and construction milestones. The modified customer agreements are expected to be executed by the third quarter of 2020.

On April 15, 2020, the United States District Court for the District of Montana granted partial summary judgment in favor of the plaintiffs in Northern Plains Resource Council v. U.S. Army Corps of Engineers (Northern Plains), vacating USACE’s Nationwide Permit 12 (NWP 12) and remanding it to USACE for consultation under the Endangered Species Act (ESA) of 1973. In Northern Plains, the court ruled that NWP 12 was unlawful because USACE did not consult under the ESA with the FWS and/or National Marine Fisheries Service prior to NWP 12’s reissuance in 2017. Because NWP 12 has been vacated and its application enjoined, USACE currently has suspended verification of any new or pending applications under NWP 12 until further court action clarifies the situation. ACP is reviewing the potential impact of this ruling to its own reliance on NWP 12 for small water body crossings along the pipeline route, as well as potential mitigation measures.

Given the legal challenges and ongoing discussions with customers, ACP expects the project to enter full in-service in the first half of 2022.

The delays resulting from the legal challenges described above have also impacted the cost for the project. Project cost is approximately $8 billion, excluding financing costs. This estimate is based on the current facts available around construction costs and timelines, and is subject to future changes as those facts develop. Abnormal weather, work delays (including delays due to judicial or regulatory action or COVID-19 social distancing) and other conditions may result in cost or schedule modifications, a suspension of AFUDC for ACP and/or impairment charges potentially material to Duke Energy's cash flows, financial position and results of operations.

Duke Energy’s investment in ACP was $1.2 billion at March 31, 2020. Duke Energy evaluated this investment for impairment at March 31, 2020, and December 31, 2019, and determined that fair value approximated carrying value and therefore no impairment was necessary. Duke Energy also has a guarantee agreement supporting its share of the ACP revolving credit facility. Duke Energy’s maximum exposure to loss under the terms of the guarantee is $845 million, which represents 47% of the outstanding borrowings under the credit facility as of March 31, 2020. See Note 13 for additional information.

Constitution Pipeline Company, LLC

Duke Energy owned a 24% ownership interest in Constitution, which was accounted for as an equity method investment. Constitution was 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 was to be constructed and operated by Williams Partners L.P., which had a 41% ownership share. The remaining interest was held by Cabot Oil and Gas Corporation and WGL Holdings, Inc. In December 2014, Constitution received approval from the FERC to construct and operate the proposed pipeline. However, since April 2016, Constitution had stopped construction and discontinued capitalization of future development costs due to permitting delays and adverse rulings by regulatory agencies and courts.

In late 2019, Constitution determined that its principal shipper would not agree to an amended precedent agreement. Without such an amendment, the project would no longer be viable and, as of February 5, 2020, the Constitution partners formally resolved to initiate the dissolution of Constitution, and to terminate the Constitution Pipeline project. See Note 11 for additional information related to ownership interest and carrying value of the investment. Williams Partners L.P., as project Operator, is currently working to liquidate the project's assets.

Potential Coal Plant Retirements

The Subsidiary Registrants periodically file IRPs 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 and Indiana earlier than their current estimated useful lives. Duke Energy continues to evaluate the potential need to retire these coal-fired generating facilities earlier than the current estimated useful lives and plans to seek regulatory recovery for amounts that would not be otherwise recovered when any of these assets are retired.

The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2020, 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	$	149
Duke Energy Indiana
Gallagher Units 2 and 4(b)	280	118
Gibson Units 1-5(c)	3,132	1,708
Cayuga Units 1-2(c)	1,005	964
Total Duke Energy	5,002	$	2,939

(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 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.

(c) On July 1, 2019, Duke Energy Indiana filed its 2018 IRP with the IURC. The 2018 IRP included scenarios evaluating the potential retirement of coal-fired generating units at Gibson and Cayuga. The rate case filed July 2, 2019, includes proposed depreciation rates reflecting retirement dates from 2026 to 2038.

Duke Energy continues to evaluate the potential need to retire generating facilities earlier than the current estimated useful lives, and plans to seek regulatory recovery, as necessary, for amounts that would not be otherwise recovered when any of these assets are retired. However, such recovery, including recovery of carrying costs on remaining book values, could be subject to future approvals and therefore cannot be assured.

Duke Energy Carolinas and Duke Energy Progress are evaluating the potential for coal-fired generating unit retirements with a net carrying value of approximately $707 million and $1.2 billion, respectively, included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2020.

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Related Party Transactions

3 Months Ended

Mar. 31, 2020

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 March 31,
(in millions)	2020		2019
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	134	$	212
Indemnification coverages(b)	5		5
Joint Dispatch Agreement (JDA) revenue(c)	7		23
JDA expense(c)	24		93
Intercompany natural gas purchases(d)	6		4
Progress Energy
Corporate governance and shared service expenses(a)	$	146	$	176
Indemnification coverages(b)	9		9
JDA revenue(c)	24		93
JDA expense(c)	7		23
Intercompany natural gas purchases(d)	19		19
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	75	$	106
Indemnification coverages(b)	4		4
JDA revenue(c)	24		93
JDA expense(c)	7		23
Intercompany natural gas purchases(d)	19		19
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	70
Indemnification coverages(b)	5		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	84	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	106	$	97
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	34	$	32
Indemnification coverages(b)	1		1
Intercompany natural gas sales(d)	25		23
Natural gas storage and transportation costs(e)	6		5

(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 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.

(e) Piedmont has related party transactions as a customer of its equity method investments in Pine Needle LNG Company, LLC, Hardy Storage Company, LLC and Cardinal Pipeline Company, LLC natural gas storage and transportation facilities. These expenses are included in Cost of natural gas on Piedmont's Condensed Consolidated Statements of Operations and Comprehensive Income.

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, such as pipeline lease arrangements, and their proportionate share of certain charged expenses. These transactions of the Subsidiary Registrants are incurred in the ordinary course of business and are eliminated in consolidation.

As discussed in Note 11, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to CRC, an affiliate formed by a subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but do include a subordinated note from CRC for a portion of the purchase price.

Intercompany Income Taxes

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

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
March 31, 2020
Intercompany income tax receivable	$	—	$	114	$	1	$	4	$	—	$	—	$	—
Intercompany income tax payable	44		—		—		—		—		6		10
December 31, 2019
Intercompany income tax receivable	$	—	$	125	$	28	$	—	$	9	$	28	$	13
Intercompany income tax payable	5		—		—		2		—		—		—

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Fair Value Measurements (Fair Value Measurement Amounts for Assets and Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	$ 2,711
Derivative assets	34	$ 25
Total assets	7,545	8,610
Derivative liabilities	(390)	(277)
Net assets (liabilities)	7,155	8,310
Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	3	3
Total assets	5,431	6,675
Derivative liabilities	(49)	(15)
Net assets (liabilities)	5,382	6,660
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	28	7
Total assets	2,063	1,869
Derivative liabilities	(250)	(145)
Net assets (liabilities)	1,813	1,701
Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	3	15
Total assets	3	15
Derivative liabilities	(91)	(117)
Net assets (liabilities)	(88)	(102)
Not Categorized
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	48	51
Net assets (liabilities)	48	51
NDTF equity securities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	4,488	5,684
NDTF equity securities | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	4,440	5,633
NDTF equity securities | Not Categorized
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	48	51
NDTF
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	4,488	5,661
Debt securities, available-for-sale	2,540	2,469
NDTF | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	767	826
NDTF | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	1,773	1,643
Other Investments
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	95	122
Debt securities, available-for-sale	368	310
Other Investments | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	95	122
Debt securities, available-for-sale	126	91
Other Investments | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	242	219
NDTF equity security contracts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	20
Derivative liabilities		(23)
NDTF equity security contracts | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	20
Derivative liabilities		(23)
Duke Energy Carolinas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	1,181
Derivative assets	2
Total assets	3,714	4,347
Derivative liabilities	(74)	(49)
Net assets (liabilities)	3,640	4,298
Duke Energy Carolinas | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	2,632	3,330
Net assets (liabilities)	2,632	3,330
Duke Energy Carolinas | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	2
Total assets	1,034	966
Derivative liabilities	(74)	(49)
Net assets (liabilities)	960	917
Duke Energy Carolinas | Not Categorized
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	48	51
Net assets (liabilities)	48	51
Duke Energy Carolinas | NDTF equity securities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	2,498	3,154
Duke Energy Carolinas | NDTF equity securities | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	2,450	3,103
Duke Energy Carolinas | NDTF equity securities | Not Categorized
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	48	51
Duke Energy Carolinas | NDTF
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	2,498	3,154
Debt securities, available-for-sale	1,214	1,193
Duke Energy Carolinas | NDTF | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	182	227
Duke Energy Carolinas | NDTF | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	1,032	966
Progress Energy
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	1,293
Derivative assets	25	7
Total assets	3,483	3,913
Derivative liabilities	(95)	(65)
Net assets (liabilities)	3,388	3,825
Progress Energy | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	2,644	3,178
Net assets (liabilities)	2,644	3,178
Progress Energy | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	25	7
Total assets	839	735
Derivative liabilities	(95)	(65)
Net assets (liabilities)	744	647
Progress Energy | NDTF equity securities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	1,990	2,530
Progress Energy | NDTF equity securities | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	1,990	2,530
Progress Energy | NDTF
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	1,990	2,507
Debt securities, available-for-sale	1,326	1,276
Progress Energy | NDTF | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	585	599
Progress Energy | NDTF | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	741	677
Progress Energy | Other Investments
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	122	100
Progress Energy | Other Investments | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	69	49
Progress Energy | Other Investments | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	53	51
Progress Energy | NDTF equity security contracts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	20
Derivative liabilities		(23)
Progress Energy | NDTF equity security contracts | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	20
Derivative liabilities		(23)
Duke Energy Progress
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	966
Derivative assets	5
Total assets	2,655	3,053
Derivative liabilities	(51)	(49)
Net assets (liabilities)	2,604	3,004
Duke Energy Progress | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	1,909	2,376
Net assets (liabilities)	1,909	2,376
Duke Energy Progress | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	5
Total assets	746	677
Derivative liabilities	(51)	(49)
Net assets (liabilities)	695	628
Duke Energy Progress | NDTF equity securities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	1,631	2,077
Duke Energy Progress | NDTF equity securities | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	1,631	2,077
Duke Energy Progress | NDTF
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	1,631	2,077
Debt securities, available-for-sale	1,017	974
Duke Energy Progress | NDTF | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	276	297
Duke Energy Progress | NDTF | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	741	677
Duke Energy Progress | Other Investments
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	2	2
Duke Energy Progress | Other Investments | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	2	2
Duke Energy Florida
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	327
Derivative assets		7
Total assets	744	817
Derivative liabilities	(29)	(1)
Net assets (liabilities)	715	793
Duke Energy Florida | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	671	759
Net assets (liabilities)	671	759
Duke Energy Florida | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets		7
Total assets	73	58
Derivative liabilities	(29)	(1)
Net assets (liabilities)	44	34
Duke Energy Florida | NDTF equity securities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	359	453
Duke Energy Florida | NDTF equity securities | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	359	453
Duke Energy Florida | NDTF
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	359	430
Debt securities, available-for-sale	309	302
Duke Energy Florida | NDTF | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	309	302
Duke Energy Florida | Other Investments
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	56	55
Duke Energy Florida | Other Investments | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	3	4
Duke Energy Florida | Other Investments | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	53	51
Duke Energy Florida | NDTF equity security contracts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	20
Derivative liabilities		(23)
Duke Energy Florida | NDTF equity security contracts | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	20
Derivative liabilities		(23)
Duke Energy Indiana
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	63	81
Debt securities, available-for-sale	43
Derivative assets	2	13
Total assets	108	138
Derivative liabilities		(1)
Net assets (liabilities)	108	137
Duke Energy Indiana | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets		2
Total assets	63	83
Derivative liabilities	0	(1)
Net assets (liabilities)	63	82
Duke Energy Indiana | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total assets	43	44
Net assets (liabilities)	43	44
Duke Energy Indiana | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	2	11
Total assets	2	11
Net assets (liabilities)	2	11
Duke Energy Indiana | Other Investments
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	63	81
Duke Energy Indiana | Other Investments | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities, FV-NI	63	81
Piedmont Natural Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	3	1
Derivative liabilities	(91)	(117)
Net assets (liabilities)	(88)	(116)
Piedmont Natural Gas | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative assets	3	1
Net assets (liabilities)	3	1
Piedmont Natural Gas | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative liabilities	(91)	(117)
Net assets (liabilities)	(91)	(117)
Debt Securities | Duke Energy Indiana | Other Investments
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	43	44
Debt Securities | Duke Energy Indiana | Other Investments | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt securities, available-for-sale	$ 43	$ 44

XML

Variable Interest Entities (Sales and Cash Flows) (Details) - VIE not primary beneficiary - CRC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Duke Energy Ohio
Variable Interest Entities [Line Items]
Receivables sold	$ 537	$ 575
Loss recognized on sale	4	4
Cash proceeds from receivables sold	559	597
Return received on retained interests	2	2
Duke Energy Indiana
Variable Interest Entities [Line Items]
Receivables sold	647	734
Loss recognized on sale	4	5
Cash proceeds from receivables sold	672	758
Return received on retained interests	$ 2	$ 3

XML

Variable Interest Entities (Schedule of Consolidated VIEs) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory Assets: Current	$ 1,770	$ 1,796
Current Assets: Other	1,000	764
Other Noncurrent Assets: Regulatory assets	13,413	13,222
Property, Plant and Equipment: Cost	149,676	147,654
Accumulated depreciation and amortization	(46,599)	(45,773)
Other Noncurrent Assets: Other	3,315	3,289
Current Liabilities: Other	2,004	2,367
Current maturities of long-term debt	5,077	3,141
Long-Term Debt	56,311	54,985
Other Noncurrent Liabilities: AROs	12,497	12,437
Other Noncurrent Liabilities: Other	1,669	1,581
Duke Energy Carolinas
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory Assets: Current	524	550
Current Assets: Other	31	21
Other Noncurrent Assets: Regulatory assets	3,427	3,360
Property, Plant and Equipment: Cost	49,534	48,922
Accumulated depreciation and amortization	(16,884)	(16,525)
Other Noncurrent Assets: Other	1,136	1,149
Current Liabilities: Other	479	611
Current maturities of long-term debt	457	458
Long-Term Debt	12,050	11,142
Other Noncurrent Liabilities: AROs	5,552	5,528
Other Noncurrent Liabilities: Other	640	627
Duke Energy Progress
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory Assets: Current	503	526
Current Assets: Other	48	60
Other Noncurrent Assets: Regulatory assets	4,392	4,152
Property, Plant and Equipment: Cost	34,898	34,603
Accumulated depreciation and amortization	(12,114)	(11,915)
Other Noncurrent Assets: Other	682	651
Current Liabilities: Other	429	478
Current maturities of long-term debt	1,006	1,006
Long-Term Debt	7,903	7,902
Other Noncurrent Liabilities: AROs	5,442	5,408
Other Noncurrent Liabilities: Other	83	92
Duke Energy Florida
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Regulatory Assets: Current	451	419
Current Assets: Other	37	58
Other Noncurrent Assets: Regulatory assets	2,097	2,194
Property, Plant and Equipment: Cost	20,880	20,457
Accumulated depreciation and amortization	(5,339)	(5,236)
Other Noncurrent Assets: Other	329	311
Current Liabilities: Other	383	415
Current maturities of long-term debt	322	571
Long-Term Debt	7,384	7,416
Other Noncurrent Liabilities: AROs	578	578
Other Noncurrent Liabilities: Other	169	136
DEFPF | Duke Energy Florida | VIE primary beneficiary
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Receivables of VIEs	4	5
Regulatory Assets: Current	53	52
Current Assets: Other	13	39
Other Noncurrent Assets: Regulatory assets	980	989
Current Liabilities: Other	2	10
Current maturities of long-term debt	54	54
Long-Term Debt	1,028	1,057
DERF | Duke Energy Carolinas | VIE primary beneficiary
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Receivables of VIEs	616	642
Long-Term Debt	475	474
DEPR | Duke Energy Progress | VIE primary beneficiary
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Receivables of VIEs	410	489
Long-Term Debt	325	325
DEFR | Duke Energy Florida | VIE primary beneficiary
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Receivables of VIEs	331	336
Long-Term Debt	250	250
CRC | VIE primary beneficiary
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Receivables of VIEs	467	522
Long-Term Debt	350	350
Commercial Renewables | VIE primary beneficiary
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Current Assets: Other	287	203
Property, Plant and Equipment: Cost	6,106	5,747
Accumulated depreciation and amortization	(1,094)	(1,041)
Other Noncurrent Assets: Other	82	106
Current maturities of long-term debt	162	162
Long-Term Debt	1,538	1,541
Other Noncurrent Liabilities: AROs	129	127
Other Noncurrent Liabilities: Other	$ 258	$ 228

XML

Derivatives and Hedging (Derivative Instruments with Credit-Risk Related Contingent Features and Cash Collateral) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value of derivatives in a net liability position	$ 96	$ 79
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	96	79
Duke Energy Carolinas
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value of derivatives in a net liability position	45	35
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	45	35
Progress Energy
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value of derivatives in a net liability position	51	44
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	51	44
Duke Energy Progress
Schedule of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features
Aggregate fair value of derivatives in a net liability position	51	44
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	$ 51	$ 44

XML

Cover Page - shares	3 Months Ended
	Mar. 31, 2020	Apr. 30, 2020
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2020
Document Transition Report	false
Entity File Number	1-32853
Entity Registrant Name	DUKE ENERGY CORPORATION
Entity Tax Identification Number	20-2777218
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	550 South Tryon Street
Entity Address, City or Town	Charlotte
Entity Address, State or Province	NC
Entity Address, Postal Zip Code	28202-1803
City Area Code	704
Local Phone Number	382-3853
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		734,852,539
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Amendment Flag	false
Entity Central Index Key	0001326160
Duke Energy Carolinas
Document Information [Line Items]
Entity File Number	1-4928
Entity Registrant Name	DUKE ENERGY CAROLINAS, LLC
Entity Tax Identification Number	56-0205520
Entity Incorporation, State or Country Code	NC
Entity Address, Address Line One	526 South Church Street
Entity Address, City or Town	Charlotte
Entity Address, State or Province	NC
Entity Address, Postal Zip Code	28202-1803
City Area Code	704
Local Phone Number	382-3853
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0000030371
Progress Energy
Document Information [Line Items]
Entity File Number	1-15929
Entity Registrant Name	PROGRESS ENERGY, INC.
Entity Tax Identification Number	56-2155481
Entity Incorporation, State or Country Code	NC
Entity Address, Address Line One	410 South Wilmington Street
Entity Address, City or Town	Raleigh
Entity Address, State or Province	NC
Entity Address, Postal Zip Code	27601-1748
City Area Code	704
Local Phone Number	382-3853
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001094093
Duke Energy Progress
Document Information [Line Items]
Entity File Number	1-3382
Entity Registrant Name	DUKE ENERGY PROGRESS, LLC
Entity Tax Identification Number	56-0165465
Entity Incorporation, State or Country Code	NC
Entity Address, Address Line One	410 South Wilmington Street
Entity Address, City or Town	Raleigh
Entity Address, State or Province	NC
Entity Address, Postal Zip Code	27601-1748
City Area Code	704
Local Phone Number	382-3853
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0000017797
Duke Energy Florida
Document Information [Line Items]
Entity File Number	1-3274
Entity Registrant Name	DUKE ENERGY FLORIDA, LLC
Entity Tax Identification Number	59-0247770
Entity Incorporation, State or Country Code	FL
Entity Address, Address Line One	299 First Avenue North
Entity Address, City or Town	St. Petersburg
Entity Address, State or Province	FL
Entity Address, Postal Zip Code	33701
City Area Code	704
Local Phone Number	382-3853
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Shell Company	false
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0000037637
Duke Energy Ohio
Document Information [Line Items]
Entity File Number	1-1232
Entity Registrant Name	DUKE ENERGY OHIO, INC.
Entity Tax Identification Number	31-0240030
Entity Incorporation, State or Country Code	OH
Entity Address, Address Line One	139 East Fourth Street
Entity Address, City or Town	Cincinnati
Entity Address, State or Province	OH
Entity Address, Postal Zip Code	45202
City Area Code	704
Local Phone Number	382-3853
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Shell Company	false
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0000020290
Duke Energy Indiana
Document Information [Line Items]
Entity File Number	1-3543
Entity Registrant Name	DUKE ENERGY INDIANA, LLC
Entity Tax Identification Number	35-0594457
Entity Incorporation, State or Country Code	IN
Entity Address, Address Line One	1000 East Main Street
Entity Address, City or Town	Plainfield
Entity Address, State or Province	IN
Entity Address, Postal Zip Code	46168
City Area Code	704
Local Phone Number	382-3853
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Shell Company	false
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0000081020
Piedmont Natural Gas
Document Information [Line Items]
Entity File Number	1-6196
Entity Registrant Name	PIEDMONT NATURAL GAS COMPANY, INC.
Entity Tax Identification Number	56-0556998
Entity Incorporation, State or Country Code	NC
Entity Address, Address Line One	4720 Piedmont Row Drive
Entity Address, City or Town	Charlotte
Entity Address, State or Province	NC
Entity Address, Postal Zip Code	28210
City Area Code	704
Local Phone Number	364-3120
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Shell Company	false
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0000078460
Common Stock
Document Information [Line Items]
Title of 12(b) Security	Common Stock, $0.001 par value
Trading Symbol	DUK
Security Exchange Name	NYSE
Junior Subordinated Debentures 5.125% Coupon Due January 2073 [Member]
Document Information [Line Items]
Title of 12(b) Security	5.125% Junior Subordinated Debentures
Trading Symbol	DUKH
Security Exchange Name	NYSE
Junior Subordinated Debentures 5.625% Coupon Due September 2078 [Member]
Document Information [Line Items]
Title of 12(b) Security	5.625% Junior Subordinated Debentures
Trading Symbol	DUKB
Security Exchange Name	NYSE
Depositary Share [Member]
Document Information [Line Items]
Title of 12(b) Security	Depositary Shares
Trading Symbol	DUK PR A
Security Exchange Name	NYSE

XML

Commitments and Contingencies (Schedule of Legal Reserves) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
Reserves for legal matters	$ 61	$ 62
Duke Energy Carolinas
Loss Contingencies [Line Items]
Reserves for legal matters	3	2
Progress Energy
Loss Contingencies [Line Items]
Reserves for legal matters	52	55
Duke Energy Progress
Loss Contingencies [Line Items]
Reserves for legal matters	9	12
Duke Energy Florida
Loss Contingencies [Line Items]
Reserves for legal matters	23	22
Piedmont Natural Gas
Loss Contingencies [Line Items]
Reserves for legal matters	$ 1	$ 1

XML

Condensed Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Current Assets
Cash and cash equivalents	$ 1,450	$ 311
Receivables (net of allowance for doubtful accounts)	809	1,066
Receivables of VIEs (net of allowance for doubtful accounts)	1,828	1,994
Inventory	3,324	3,232
Regulatory assets (includes amounts related to VIEs)	1,770	1,796
Other (includes amounts related to VIEs)	1,000	764
Total current assets	10,181	9,163
Property, Plant and Equipment
Cost	149,676	147,654
Accumulated depreciation and amortization	(46,599)	(45,773)
Generation facilities to be retired, net	31	246
Net property, plant and equipment	103,108	102,127
Other Noncurrent Assets
Goodwill	19,303	19,303
Regulatory assets (includes amounts related to VIEs)	13,413	13,222
Nuclear decommissioning trust funds	7,052	8,140
Operating lease right-of-use assets, net	1,633	1,658
Investments in equity method unconsolidated affiliates	2,067	1,936
Other (includes amounts related to VIEs)	3,315	3,289
Total other noncurrent assets	46,783	47,548
Total Assets	160,072	158,838
Current Liabilities
Accounts payable	2,364	3,487
Notes payable and commercial paper	3,033	3,135
Taxes accrued	493	392
Interest accrued	571	565
Current maturities of long-term debt (includes amounts related to VIEs)	5,077	3,141
Asset retirement obligations	802	881
Regulatory liabilities	826	784
Other	2,004	2,367
Total current liabilities	15,170	14,752
Long-Term Debt (includes amounts related to VIEs)	56,311	54,985
Other Noncurrent Liabilities
Deferred income taxes	9,321	8,878
Asset retirement obligations	12,497	12,437
Regulatory liabilities	14,029	15,264
Operating lease liabilities	1,414	1,432
Accrued pension and other post-retirement benefit costs	919	934
Investment tax credits	659	624
Other (includes amounts related to VIEs)	1,669	1,581
Total other noncurrent liabilities	40,508	41,150
Commitments and Contingencies
Equity
Common stock	1	1
Additional paid-in capital	40,930	40,881
Retained earnings	4,221	4,108
Accumulated other comprehensive loss	(193)	(130)
Total Duke Energy Corporation stockholders' equity	46,921	46,822
Noncontrolling interests	1,162	1,129
Total equity	48,083	47,951
Total Liabilities and Equity	160,072	158,838
Duke Energy Carolinas
Current Assets
Cash and cash equivalents	16	18
Receivables (net of allowance for doubtful accounts)	212	324
Receivables of VIEs (net of allowance for doubtful accounts)	616	642
Receivables from affiliated companies	87	114
Notes receivable from affiliated companies	436
Inventory	1,067	996
Regulatory assets (includes amounts related to VIEs)	524	550
Other (includes amounts related to VIEs)	31	21
Total current assets	2,989	2,665
Property, Plant and Equipment
Cost	49,534	48,922
Accumulated depreciation and amortization	(16,884)	(16,525)
Net property, plant and equipment	32,650	32,397
Other Noncurrent Assets
Regulatory assets (includes amounts related to VIEs)	3,427	3,360
Nuclear decommissioning trust funds	3,717	4,359
Operating lease right-of-use assets, net	132	123
Other (includes amounts related to VIEs)	1,136	1,149
Total other noncurrent assets	8,412	8,991
Total Assets	44,051	44,053
Current Liabilities
Accounts payable	605	954
Accounts payable to affiliated companies	225	210
Notes payable to affiliated companies		29
Taxes accrued	132	46
Interest accrued	144	115
Current maturities of long-term debt (includes amounts related to VIEs)	457	458
Asset retirement obligations	197	206
Regulatory liabilities	275	255
Other	479	611
Total current liabilities	2,514	2,884
Long-Term Debt (includes amounts related to VIEs)	12,050	11,142
Long-Term Debt Payable to Affiliated Companies	300	300
Other Noncurrent Liabilities
Deferred income taxes	3,968	3,921
Asset retirement obligations	5,552	5,528
Regulatory liabilities	5,766	6,423
Operating lease liabilities	112	102
Accrued pension and other post-retirement benefit costs	82	84
Investment tax credits	230	231
Other (includes amounts related to VIEs)	640	627
Total other noncurrent liabilities	16,350	16,916
Equity
Member's equity	12,844	12,818
Accumulated other comprehensive loss	(7)	(7)
Total member's equity	12,837	12,811
Total Liabilities and Equity	44,051	44,053
Progress Energy
Current Assets
Cash and cash equivalents	52	48
Receivables (net of allowance for doubtful accounts)	159	220
Receivables of VIEs (net of allowance for doubtful accounts)	745	830
Receivables from affiliated companies	49	76
Notes receivable from affiliated companies		164
Inventory	1,463	1,423
Regulatory assets (includes amounts related to VIEs)	954	946
Other (includes amounts related to VIEs)	196	210
Total current assets	3,618	3,917
Property, Plant and Equipment
Cost	55,788	55,070
Accumulated depreciation and amortization	(17,461)	(17,159)
Generation facilities to be retired, net	31	246
Net property, plant and equipment	38,358	38,157
Other Noncurrent Assets
Goodwill	3,655	3,655
Regulatory assets (includes amounts related to VIEs)	6,489	6,346
Nuclear decommissioning trust funds	3,335	3,782
Operating lease right-of-use assets, net	762	788
Other (includes amounts related to VIEs)	1,121	1,049
Total other noncurrent assets	15,362	15,620
Total Assets	57,338	57,694
Current Liabilities
Accounts payable	730	1,104
Accounts payable to affiliated companies	329	310
Notes payable to affiliated companies	2,300	1,821
Taxes accrued	117	46
Interest accrued	214	228
Current maturities of long-term debt (includes amounts related to VIEs)	1,828	1,577
Asset retirement obligations	421	485
Regulatory liabilities	347	330
Other	821	902
Total current liabilities	7,107	6,803
Long-Term Debt (includes amounts related to VIEs)	17,377	17,907
Long-Term Debt Payable to Affiliated Companies	150	150
Other Noncurrent Liabilities
Deferred income taxes	4,537	4,462
Asset retirement obligations	6,020	5,986
Regulatory liabilities	4,708	5,225
Operating lease liabilities	678	697
Accrued pension and other post-retirement benefit costs	480	488
Other (includes amounts related to VIEs)	404	383
Total other noncurrent liabilities	16,827	17,241
Equity
Additional paid-in capital	9,143	9,143
Retained earnings	6,747	6,465
Accumulated other comprehensive loss	(16)	(18)
Total Duke Energy Corporation stockholders' equity	15,874	15,590
Noncontrolling interests	3	3
Total equity	15,877	15,593
Total Liabilities and Equity	57,338	57,694
Duke Energy Progress
Current Assets
Cash and cash equivalents	32	22
Receivables (net of allowance for doubtful accounts)	77	123
Receivables of VIEs (net of allowance for doubtful accounts)	410	489
Receivables from affiliated companies	50	52
Inventory	956	934
Regulatory assets (includes amounts related to VIEs)	503	526
Other (includes amounts related to VIEs)	48	60
Total current assets	2,076	2,206
Property, Plant and Equipment
Cost	34,898	34,603
Accumulated depreciation and amortization	(12,114)	(11,915)
Generation facilities to be retired, net	31	246
Net property, plant and equipment	22,815	22,934
Other Noncurrent Assets
Regulatory assets (includes amounts related to VIEs)	4,392	4,152
Nuclear decommissioning trust funds	2,644	3,047
Operating lease right-of-use assets, net	377	387
Other (includes amounts related to VIEs)	682	651
Total other noncurrent assets	8,095	8,237
Total Assets	32,986	33,377
Current Liabilities
Accounts payable	319	629
Accounts payable to affiliated companies	208	203
Notes payable to affiliated companies	229	66
Taxes accrued	43	17
Interest accrued	90	110
Current maturities of long-term debt (includes amounts related to VIEs)	1,006	1,006
Asset retirement obligations	421	485
Regulatory liabilities	263	236
Other	429	478
Total current liabilities	3,008	3,230
Long-Term Debt (includes amounts related to VIEs)	7,903	7,902
Long-Term Debt Payable to Affiliated Companies	150	150
Other Noncurrent Liabilities
Deferred income taxes	2,446	2,388
Asset retirement obligations	5,442	5,408
Regulatory liabilities	3,790	4,232
Operating lease liabilities	344	354
Accrued pension and other post-retirement benefit costs	235	238
Investment tax credits	135	137
Other (includes amounts related to VIEs)	83	92
Total other noncurrent liabilities	12,475	12,849
Equity
Total member's equity	9,450	9,246
Total Liabilities and Equity	32,986	33,377
Duke Energy Florida
Current Assets
Cash and cash equivalents	12	17
Receivables (net of allowance for doubtful accounts)	80	96
Receivables of VIEs (net of allowance for doubtful accounts)	335	341
Notes receivable from affiliated companies		173
Inventory	508	489
Regulatory assets (includes amounts related to VIEs)	451	419
Other (includes amounts related to VIEs)	37	58
Total current assets	1,423	1,593
Property, Plant and Equipment
Cost	20,880	20,457
Accumulated depreciation and amortization	(5,339)	(5,236)
Net property, plant and equipment	15,541	15,221
Other Noncurrent Assets
Regulatory assets (includes amounts related to VIEs)	2,097	2,194
Nuclear decommissioning trust funds	691	734
Operating lease right-of-use assets, net	386	401
Other (includes amounts related to VIEs)	329	311
Total other noncurrent assets	3,503	3,640
Total Assets	20,467	20,454
Current Liabilities
Accounts payable	411	474
Accounts payable to affiliated companies	111	131
Notes payable to affiliated companies	305
Taxes accrued	74	43
Interest accrued	79	75
Current maturities of long-term debt (includes amounts related to VIEs)	322	571
Regulatory liabilities	84	94
Other	383	415
Total current liabilities	1,769	1,803
Long-Term Debt (includes amounts related to VIEs)	7,384	7,416
Other Noncurrent Liabilities
Deferred income taxes	2,192	2,179
Asset retirement obligations	578	578
Regulatory liabilities	918	993
Operating lease liabilities	334	343
Accrued pension and other post-retirement benefit costs	214	218
Other (includes amounts related to VIEs)	169	136
Total other noncurrent liabilities	4,405	4,447
Equity
Member's equity	6,909	6,789
Accumulated other comprehensive loss		(1)
Total member's equity	6,909	6,788
Total Liabilities and Equity	20,467	20,454
Duke Energy Ohio
Current Assets
Cash and cash equivalents	14	17
Receivables (net of allowance for doubtful accounts)	84	84
Receivables from affiliated companies	52	92
Inventory	121	135
Regulatory assets (includes amounts related to VIEs)	33	49
Other (includes amounts related to VIEs)	11	21
Total current assets	315	398
Property, Plant and Equipment
Cost	10,401	10,241
Accumulated depreciation and amortization	(2,883)	(2,843)
Net property, plant and equipment	7,518	7,398
Other Noncurrent Assets
Goodwill	920	920
Regulatory assets (includes amounts related to VIEs)	567	549
Operating lease right-of-use assets, net	21	21
Other (includes amounts related to VIEs)	56	52
Total other noncurrent assets	1,564	1,542
Total Assets	9,397	9,338
Current Liabilities
Accounts payable	227	288
Accounts payable to affiliated companies	68	68
Notes payable to affiliated companies	399	312
Taxes accrued	170	219
Interest accrued	30	30
Asset retirement obligations	3	1
Regulatory liabilities	66	64
Other	68	75
Total current liabilities	1,031	1,057
Long-Term Debt (includes amounts related to VIEs)	2,595	2,594
Long-Term Debt Payable to Affiliated Companies	25	25
Other Noncurrent Liabilities
Deferred income taxes	942	922
Asset retirement obligations	78	79
Regulatory liabilities	760	763
Operating lease liabilities	20	21
Accrued pension and other post-retirement benefit costs	101	100
Other (includes amounts related to VIEs)	97	94
Total other noncurrent liabilities	1,998	1,979
Equity
Common stock	762	762
Additional paid-in capital	2,776	2,776
Retained earnings	210	145
Total Duke Energy Corporation stockholders' equity	3,748	3,683
Total Liabilities and Equity	9,397	9,338
Duke Energy Indiana
Current Assets
Cash and cash equivalents	15	25
Receivables (net of allowance for doubtful accounts)	50	60
Receivables from affiliated companies	76	79
Notes receivable from affiliated companies	543
Inventory	538	517
Regulatory assets (includes amounts related to VIEs)	78	90
Other (includes amounts related to VIEs)	36	60
Total current assets	1,336	831
Property, Plant and Equipment
Cost	16,481	16,305
Accumulated depreciation and amortization	(5,349)	(5,233)
Net property, plant and equipment	11,132	11,072
Other Noncurrent Assets
Regulatory assets (includes amounts related to VIEs)	1,098	1,082
Operating lease right-of-use assets, net	57	57
Other (includes amounts related to VIEs)	214	234
Total other noncurrent assets	1,369	1,373
Total Assets	13,837	13,276
Current Liabilities
Accounts payable	157	201
Accounts payable to affiliated companies	66	87
Notes payable to affiliated companies		30
Taxes accrued	81	49
Interest accrued	60	58
Current maturities of long-term debt (includes amounts related to VIEs)	503	503
Asset retirement obligations	181	189
Regulatory liabilities	46	55
Other	92	112
Total current liabilities	1,186	1,284
Long-Term Debt (includes amounts related to VIEs)	3,950	3,404
Long-Term Debt Payable to Affiliated Companies	150	150
Other Noncurrent Liabilities
Deferred income taxes	1,158	1,150
Asset retirement obligations	645	643
Regulatory liabilities	1,672	1,685
Operating lease liabilities	54	55
Accrued pension and other post-retirement benefit costs	148	148
Investment tax credits	170	164
Other (includes amounts related to VIEs)	30	18
Total other noncurrent liabilities	3,877	3,863
Equity
Total member's equity	4,674	4,575
Total Liabilities and Equity	13,837	13,276
Piedmont Natural Gas
Current Assets
Cash and cash equivalents	4
Receivables (net of allowance for doubtful accounts)	191	241
Receivables from affiliated companies	13	10
Inventory	39	72
Regulatory assets (includes amounts related to VIEs)	96	73
Other (includes amounts related to VIEs)	13	28
Total current assets	356	424
Property, Plant and Equipment
Cost	8,653	8,446
Accumulated depreciation and amortization	(1,703)	(1,681)
Net property, plant and equipment	6,950	6,765
Other Noncurrent Assets
Goodwill	49	49
Regulatory assets (includes amounts related to VIEs)	263	290
Operating lease right-of-use assets, net	23	24
Investments in equity method unconsolidated affiliates	84	83
Other (includes amounts related to VIEs)	132	121
Total other noncurrent assets	551	567
Total Assets	7,857	7,756
Current Liabilities
Accounts payable	145	215
Accounts payable to affiliated companies	12	3
Notes payable to affiliated companies	486	476
Taxes accrued	36	24
Interest accrued	32	33
Regulatory liabilities	91	81
Other	54	67
Total current liabilities	856	899
Long-Term Debt (includes amounts related to VIEs)	2,385	2,384
Other Noncurrent Liabilities
Deferred income taxes	742	708
Asset retirement obligations	17	17
Regulatory liabilities	1,087	1,131
Operating lease liabilities	22	23
Accrued pension and other post-retirement benefit costs	7	3
Other (includes amounts related to VIEs)	121	148
Total other noncurrent liabilities	1,996	2,030
Equity
Common stock	1,310	1,310
Retained earnings	1,310	1,133
Total Duke Energy Corporation stockholders' equity	2,620	2,443
Total Liabilities and Equity	7,857	7,756
Preferred stock, Series A
Equity
Preferred stock	973	973
Preferred stock, Series B
Equity
Preferred stock	$ 989	$ 989

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Regulatory Matters (Regulatory Matters Narrative - Duke Energy Florida) (Details) $ in Millions		1 Months Ended
	Mar. 25, 2019 USD ($)	Apr. 30, 2020 USD ($)	Jan. 31, 2019 USD ($)	Apr. 02, 2020 USD ($)	Mar. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 19, 2019 USD ($)	Nov. 22, 2019 USD ($)	Oct. 31, 2018 customer
Hurricane Michael storm damage | Duke Energy Florida
Public Utilities, General Disclosures [Line Items]
Customers experiencing outages | customer									72,000
Estimated storm costs - capital and operation maintenance					$ 311
Amount of recovery costs sought								$ 191
Property, plant and equipment, net					106	$ 107
Hurricane Dorian storm damage | Duke Energy Florida
Public Utilities, General Disclosures [Line Items]
Estimated storm costs - capital and operation maintenance					147	167	$ 169
Noncurrent assets | Hurricane Michael storm damage | Duke Energy Florida
Public Utilities, General Disclosures [Line Items]
Estimated storm costs - capital and operation maintenance					$ 205	$ 204
Hamilton Project | 2017 Second Revised and Restated Stipulation and Settlement Agreement | FPSC | Duke Energy Florida
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount			$ 15
Trenton Generation Project | 2017 Second Revised and Restated Stipulation and Settlement Agreement | FPSC | Duke Energy Florida
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount	$ 13
Lake Placid Generation Project | 2017 Second Revised and Restated Stipulation and Settlement Agreement | FPSC | Duke Energy Florida
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount	8
DeBary Solar Project | 2017 Second Revised and Restated Stipulation and Settlement Agreement | FPSC | Duke Energy Florida
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 11
Subsequent event | FPSC
Public Utilities, General Disclosures [Line Items]
Accelerated fuel cost refund				$ 78
Subsequent event | Columbia Project | 2017 Second Revised and Restated Stipulation and Settlement Agreement | FPSC | Duke Energy Florida
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount		$ 14

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Condensed Consolidated Statements of Changes in Equity (Parenthetical)	3 Months Ended
	Mar. 31, 2019 shares
Preferred stock, Series A | Preferred Stock
Stock issuances, in shares	40,000,000

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Regulatory Matters (Other Regulatory Matters) (Details) - USD ($) $ in Millions	Sep. 02, 2014	Mar. 31, 2020	Dec. 31, 2019
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net		$ 103,108	$ 102,127
Duke Energy Carolinas
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net		32,650	32,397
Duke Energy Progress
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net		22,815	$ 22,934
ACP
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage	47.00%
Long-term purchase commitment, period	20 years
Estimated capital cost		8,000
Investment amount		$ 1,200
Constitution
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage		24.00%
Dominion resources | ACP
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage		53.00%
Southern Company Gas | ACP
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage	5.00%
Williams Partners L.P. | Constitution
Public Utilities, General Disclosures [Line Items]
Joint owner ownership percentage		41.00%
Financial guarantee | ACP
Public Utilities, General Disclosures [Line Items]
Maximum potential amount of future payments associated with guarantees		$ 845
Credit Facility | ACP
Public Utilities, General Disclosures [Line Items]
Percentage of outstanding borrowings		47.00%
Generation facilities evaluated for retirement | Duke Energy Carolinas
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net		$ 707
Generation facilities evaluated for retirement | Duke Energy Progress
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net		$ 1,200

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Debt and Credit Facilities (Schedule of Line of Credit Facilities) (Details) - Master Credit Facility	Mar. 31, 2020 USD ($)
Line of Credit Facility [Line Items]
Facility size	$ 8,000,000,000
Commercial paper	(2,540,000,000)
Outstanding letters of credit	(49,000,000)
Tax-exempt bonds	(81,000,000)
Coal ash set-aside	(500,000,000)
Available capacity under the Master Credit Facility	4,830,000,000
Duke Energy Carolinas
Line of Credit Facility [Line Items]
Facility size	1,500,000,000
Commercial paper	(300,000,000)
Outstanding letters of credit	(4,000,000)
Coal ash set-aside	(250,000,000)
Available capacity under the Master Credit Facility	946,000,000
Duke Energy Progress
Line of Credit Facility [Line Items]
Facility size	1,250,000,000
Commercial paper	(275,000,000)
Outstanding letters of credit	(2,000,000)
Coal ash set-aside	(250,000,000)
Available capacity under the Master Credit Facility	723,000,000
Duke Energy Florida
Line of Credit Facility [Line Items]
Facility size	800,000,000
Commercial paper	(167,000,000)
Available capacity under the Master Credit Facility	633,000,000
Duke Energy Ohio
Line of Credit Facility [Line Items]
Facility size	600,000,000
Commercial paper	(243,000,000)
Available capacity under the Master Credit Facility	357,000,000
Duke Energy Indiana
Line of Credit Facility [Line Items]
Facility size	600,000,000
Commercial paper	(150,000,000)
Tax-exempt bonds	(81,000,000)
Available capacity under the Master Credit Facility	369,000,000
Piedmont Natural Gas
Line of Credit Facility [Line Items]
Facility size	600,000,000
Commercial paper	(265,000,000)
Outstanding letters of credit	(1,000,000)
Available capacity under the Master Credit Facility	334,000,000
Duke Energy (Parent)
Line of Credit Facility [Line Items]
Facility size	2,650,000,000
Commercial paper	(1,140,000,000)
Outstanding letters of credit	(42,000,000)
Available capacity under the Master Credit Facility	1,468,000,000
Duke Energy (Parent) | Proceeds loaned to subsidiary registrants
Line of Credit Facility [Line Items]
Commercial paper	$ (625,000,000)

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Revenue (Aging of Trade Receivables) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Financing Receivable, Past Due [Line Items]
Unbilled Receivables	$ 716	$ 843
Trade and Other Receivables, not past due	1,584
Trade and Other Receivables	2,726
30-60 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	216
60-90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	65
90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	145
Duke Energy Carolinas
Financing Receivable, Past Due [Line Items]
Unbilled Receivables	285	298
Trade and Other Receivables, not past due	448
Trade and Other Receivables	839
Duke Energy Carolinas | 30-60 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	69
Duke Energy Carolinas | 60-90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	18
Duke Energy Carolinas | 90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	19
Progress Energy
Financing Receivable, Past Due [Line Items]
Unbilled Receivables	195	217
Trade and Other Receivables, not past due	585
Trade and Other Receivables	924
Progress Energy | 30-60 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	67
Progress Energy | 60-90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	20
Progress Energy | 90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	57
Duke Energy Progress
Financing Receivable, Past Due [Line Items]
Unbilled Receivables	85	122
Trade and Other Receivables, not past due	321
Trade and Other Receivables	496
Duke Energy Progress | 30-60 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	44
Duke Energy Progress | 60-90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	14
Duke Energy Progress | 90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	32
Duke Energy Florida
Financing Receivable, Past Due [Line Items]
Unbilled Receivables	110	95
Trade and Other Receivables, not past due	262
Trade and Other Receivables	426
Duke Energy Florida | 30-60 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	23
Duke Energy Florida | 60-90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	6
Duke Energy Florida | 90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	25
Duke Energy Ohio
Financing Receivable, Past Due [Line Items]
Unbilled Receivables	1	1
Trade and Other Receivables, not past due	45
Trade and Other Receivables	89
Duke Energy Ohio | 30-60 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	9
Duke Energy Ohio | 60-90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	2
Duke Energy Ohio | 90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	32
Duke Energy Indiana
Financing Receivable, Past Due [Line Items]
Unbilled Receivables	16	16
Trade and Other Receivables, not past due	24
Trade and Other Receivables	53
Duke Energy Indiana | 30-60 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	1
Duke Energy Indiana | 60-90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	1
Duke Energy Indiana | 90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	11
Piedmont Natural Gas
Financing Receivable, Past Due [Line Items]
Unbilled Receivables	32	$ 78
Trade and Other Receivables, not past due	134
Trade and Other Receivables	200
Piedmont Natural Gas | 30-60 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	18
Piedmont Natural Gas | 60-90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	5
Piedmont Natural Gas | 90 days
Financing Receivable, Past Due [Line Items]
Trade and Other Receivables	$ 11

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Employee Benefit Plans (Components of Net Periodic Pension Costs) (Details) - Qualified Pension Plans - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	$ 41	$ 37
Interest cost on projected benefit obligation	67	83
Expected return on plan assets	(143)	(143)
Amortization of actuarial loss	34	24
Amortization of prior service credit	(8)	(8)
Amortization of settlement charges	2
Net periodic pension costs	(7)	(7)
Duke Energy Carolinas
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	12	12
Interest cost on projected benefit obligation	16	20
Expected return on plan assets	(36)	(38)
Amortization of actuarial loss	7	6
Amortization of prior service credit	(2)	(2)
Amortization of settlement charges	1
Net periodic pension costs	(2)	(2)
Progress Energy
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	12	11
Interest cost on projected benefit obligation	21	26
Expected return on plan assets	(48)	(44)
Amortization of actuarial loss	11	9
Amortization of prior service credit	(1)	(1)
Amortization of settlement charges	1
Net periodic pension costs	(4)	1
Duke Energy Progress
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	6	6
Interest cost on projected benefit obligation	10	12
Expected return on plan assets	(22)	(23)
Amortization of actuarial loss	5	3
Net periodic pension costs	(1)	(2)
Duke Energy Florida
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	5	4
Interest cost on projected benefit obligation	12	14
Expected return on plan assets	(25)	(22)
Amortization of actuarial loss	6	6
Net periodic pension costs	(2)	2
Duke Energy Ohio
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	1	1
Interest cost on projected benefit obligation	4	5
Expected return on plan assets	(7)	(8)
Amortization of actuarial loss	2	1
Net periodic pension costs		(1)
Duke Energy Indiana
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	2	2
Interest cost on projected benefit obligation	6	6
Expected return on plan assets	(11)	(11)
Amortization of actuarial loss	3	2
Net periodic pension costs		(1)
Piedmont Natural Gas
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	1	1
Interest cost on projected benefit obligation	2	3
Expected return on plan assets	(5)	(5)
Amortization of actuarial loss	2	2
Amortization of prior service credit	(2)	(3)
Net periodic pension costs	$ (2)	$ (2)

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Related Party Transactions (Other Revenue and Expense) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Duke Energy Carolinas | Corporate governance and shared service expenses | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 134	$ 212
Duke Energy Carolinas | Indemnification coverages | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	5	5
Duke Energy Carolinas | JDA | Duke Energy Progress
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	24	93
Related party transaction, other revenues from transactions with related party	7	23
Duke Energy Carolinas | Intercompany natural gas purchases and sales | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	6	4
Progress Energy | Corporate governance and shared service expenses | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	146	176
Progress Energy | Indemnification coverages | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	9	9
Progress Energy | JDA | Duke Energy Carolinas
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	7	23
Related party transaction, other revenues from transactions with related party	24	93
Progress Energy | Intercompany natural gas purchases and sales | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	19	19
Duke Energy Progress | Corporate governance and shared service expenses | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	75	106
Duke Energy Progress | Indemnification coverages | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	4	4
Duke Energy Progress | JDA | Duke Energy Carolinas
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	7	23
Related party transaction, other revenues from transactions with related party	24	93
Duke Energy Progress | Intercompany natural gas purchases and sales | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	19	19
Duke Energy Florida | Corporate governance and shared service expenses | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	71	70
Duke Energy Florida | Indemnification coverages | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	5	5
Duke Energy Ohio | Corporate governance and shared service expenses | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	84	85
Duke Energy Ohio | Indemnification coverages | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	1	1
Duke Energy Indiana | Corporate governance and shared service expenses | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	106	97
Duke Energy Indiana | Indemnification coverages | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	2	2
Piedmont Natural Gas | Corporate governance and shared service expenses | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	34	32
Piedmont Natural Gas | Indemnification coverages | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	1	1
Piedmont Natural Gas | Intercompany natural gas purchases and sales | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, other revenues from transactions with related party	25	23
Piedmont Natural Gas | Natural gas storage and transportation costs | Affiliated Entity
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 6	$ 5

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Organization and Basis of Presentation (Schedule of New Accounting Pronouncements) (Details) - ASU 2016-13 $ in Millions	Jan. 01, 2020 USD ($)
Retained Earnings Adjustments [Line Items]
Total pretax impact to Retained Earnings	$ 120
Duke Energy Carolinas
Retained Earnings Adjustments [Line Items]
Total pretax impact to Retained Earnings	16
Progress Energy
Retained Earnings Adjustments [Line Items]
Total pretax impact to Retained Earnings	2
Duke Energy Progress
Retained Earnings Adjustments [Line Items]
Total pretax impact to Retained Earnings	1
Duke Energy Florida
Retained Earnings Adjustments [Line Items]
Total pretax impact to Retained Earnings	1
Piedmont Natural Gas
Retained Earnings Adjustments [Line Items]
Total pretax impact to Retained Earnings	$ 1

XML

Income Taxes (Tables)

3 Months Ended

Mar. 31, 2020

Income Tax Disclosure [Abstract]

Summary of Effective Tax Rates

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

	Three Months Ended
	March 31,
	2020		2019
Duke Energy	13.3	%	9.6	%
Duke Energy Carolinas	16.1	%	17.7	%
Progress Energy	17.5	%	17.3	%
Duke Energy Progress	17.1	%	17.8	%
Duke Energy Florida	20.0	%	19.3	%
Duke Energy Ohio	17.7	%	16.9	%
Duke Energy Indiana	20.8	%	24.1	%
Piedmont	10.1	%	21.8	%

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Regulatory Matters (Regulatory Matters Narrative - Duke Energy Progress) (Details) - Duke Energy Progress customer in Thousands, $ in Millions							3 Months Ended
	Jan. 29, 2020 USD ($) MW	Oct. 30, 2019 USD ($)	May 21, 2019 USD ($)	Nov. 08, 2018 USD ($)	Nov. 22, 2017	Jun. 01, 2017 USD ($)	Mar. 31, 2020 USD ($)	Feb. 07, 2020 USD ($)	Dec. 31, 2019 USD ($)	Sep. 30, 2019 USD ($) customer	Mar. 28, 2016 USD ($)
2017 North Carolina Rate Case | NCUC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount						$ 477
Requested rate increase, percentage						14.90%
Requested rate increase (decrease), amended amount						$ 420
Requested rate increase (decrease) amended, percentage						13.00%
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%
2019 North Carolina Rate Case | NCUC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ 464
Requested rate increase, percentage		12.30%
Requested rate increase (decrease), gross amount		$ 586
Rider reduction		122
Requested rate increase (decrease), rider reduction		$ 120
Hurricane Dorian storm damage
Public Utilities, General Disclosures [Line Items]
Estimated storm costs - O&M										$ 177
Estimated storm costs - capital investments										$ 4
Storm deferral - O&M								$ 22
South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount				$ 59
Requested rate increase, percentage				10.30%
Change in tax rate, deferred tax liability, income tax benefit			$ 17	$ 17
Measurement period adjustment, income tax expense (benefit)			$ 12	10
Approved return on equity percentage			9.50%
Public utilities, approved equity capital structure, percentage			53.00%
Public utilities, approved debt capital structure, percentage			47.00%
Western Carolinas Modernization Plan | NCUC
Public Utilities, General Disclosures [Line Items]
Regulatory asset, amortization period							10 years
Estimated capital cost											$ 893
NORTH CAROLINA | Hurricane Dorian storm damage
Public Utilities, General Disclosures [Line Items]
Customers experiencing outages | customer										270
SOUTH CAROLINA | Hurricane Dorian storm damage
Public Utilities, General Disclosures [Line Items]
Customers experiencing outages | customer										30
Storm Costs [Member] | Hurricane Dorian storm damage
Public Utilities, General Disclosures [Line Items]
Regulatory assets							$ 151		$ 179
Asset retirement obligations - coal ash | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory assets			$ 4	$ 51
Recovery costs denied			$ 65
Regulatory asset, amortization period			5 years	5 years
Asset retirement obligations - unprotected EDIT, Property, Plant and Equipment | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory asset, amortization period			20 years
Asset retirement obligations - unprotected EDIT | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory asset, amortization period			5 years
Asset retirement obligations - deferred revenue | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory asset, amortization period			3 years
State and local jurisdiction | North Carolina Department of Revenue | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
State and local taxes reduction amount			$ (12)	$ (12)
Asheville Plant
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	376
Generation facilities retired, net	$ 214

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Business Segments (Tables)

3 Months Ended

Mar. 31, 2020

Segment Reporting Information [Line Items]

Business Segment Data

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

	Three Months Ended March 31, 2020
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Total
Unaffiliated revenues	$	5,174	$	640	$	129	$	5,943	$	6		$	—		$	5,949
Intersegment revenues	9		24		—		33		17			(50		)	—
Total revenues	$	5,183	$	664	$	129	$	5,976	$	23		$	(50	)	$	5,949
Segment income (loss)(a)	$	705	$	249	$	57	$	1,011	$	(112	)	$	—		$	899
Add: Noncontrolling interests(b)															(48		)
Add: Preferred stock dividend															39
Net income															$	890
Segment assets	$	134,838	$	14,098	$	6,184	$	155,120	$	4,964		$	(12	)	$	160,072

	Three Months Ended March 31, 2019
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Total
Unaffiliated revenues	$	5,321	$	732	$	106	$	6,159	$	4		$	—		$	6,163
Intersegment revenues	8		24		—		32		17			(49		)	—
Total revenues	$	5,329	$	756	$	106	$	6,191	$	21		$	(49	)	$	6,163
Segment income (loss)	$	750	$	226	$	13	$	989	$	(89	)	$	—		$	900
Add: Noncontrolling interests(b)															(7		)
Net income															$	893

(a) Other includes a $98 million reversal, included in Operations, maintenance and other on the Condensed Consolidated Statements of Operations, of 2018 severance costs due to the partial settlement of the Duke Energy Carolina's 2019 North Carolina rate case. See Note 3 for additional information.

(b)

Includes the allocation of losses to noncontrolling tax equity members. See Note 1 for additional information.

Duke Energy Ohio

Segment Reporting Information [Line Items]

Business Segment Data

	Three Months Ended March 31, 2020
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Total
Total revenues	$	346	$	152	$	498	$	—		$	—		$	498
Segment income/Net (loss) income	$	30	$	36	$	66	$	(1	)	$	—		$	65
Segment assets	$	6,238	$	3,135	$	9,373	$	26		$	(2	)	$	9,397

	Three Months Ended March 31, 2019
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Total
Total revenues	$	355	$	176	$	531	$	—		$	531
Segment income/Net (loss) income	$	36	$	35	$	71	$	(2	)	$	69

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Variable Interest Entities

3 Months Ended

Mar. 31, 2020

Variable Interest Entities [Abstract]

Variable Interest Entities

VARIABLE INTEREST ENTITIES

CONSOLIDATED VIEs

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

No financial support was provided to any of the consolidated VIEs during the three months ended March 31, 2020, and the year ended December 31, 2019, or is expected to be provided in the future that was not previously contractually required.

Receivables Financing – DERF/DEPR/DEFR

DERF, DEPR and 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 LLCs 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 are considered the primary beneficiaries and consolidate DERF, DEPR and DEFR, respectively, as they make those decisions. Due to the COVID-19 pandemic, as described in Note 1, the Duke Energy Registrants suspended customer disconnections for nonpayment. The impact of COVID-19 and the Duke Energy Registrant’s related response on customers’ ability to pay for service is uncertain, and it is reasonably possible eventual write-offs of customer receivables may increase over current estimates. See Note 3 for information about COVID-19 filings with state utility commissions.

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 approximately 75% cash and 25% 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 is not held 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 is considered the primary beneficiary and consolidates CRC as it makes these decisions. Neither Duke Energy Ohio nor Duke Energy Indiana consolidate CRC. Due to the COVID-19 pandemic, as described in Note 1, the Duke Energy Registrants suspended customer disconnections for nonpayment. The impact of COVID-19 and the Duke Energy Registrant’s related response on customers’ ability to pay for service is uncertain, and it is reasonably possible eventual write-offs of customer receivables may increase over current estimates. See Note 3 for information about COVID-19 filings with state utility commissions.

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	February 2023		December 2022		April 2023		April 2021
Credit facility amount	$	350	$	475	$	375	$	250
Amounts borrowed at March 31, 2020	350		475		325		250
Amounts borrowed at December 31, 2019	350		474		325		250
Restricted Receivables at March 31, 2020	467		616		410		331
Restricted Receivables at December 31, 2019	522		642		489		336

Nuclear Asset-Recovery Bonds – DEFPF

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

In 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)	March 31, 2020		December 31, 2019
Receivables of VIEs	$	4	$	5
Regulatory Assets: Current	53		52
Current Assets: Other	13		39
Other Noncurrent Assets: Regulatory assets	980		989
Current Liabilities: Other	2		10
Current maturities of long-term debt	54		54
Long-Term Debt	1,028		1,057

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. Additionally, Duke Energy has VIEs associated with tax equity arrangements entered into with third-party investors in order to finance the cost of renewable assets eligible for tax credits. The activities that most significantly impacted the economic performance of these renewable energy facilities were decisions associated with siting, negotiating PPAs and Engineering, Procurement and Construction agreements, and decisions associated with ongoing operations and maintenance-related activities. Duke Energy is considered the primary beneficiary and 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 Commercial Renewables VIEs.

(in millions)	March 31, 2020			December 31, 2019
Current Assets: Other	$	287		$	203
Property, Plant and Equipment: Cost	6,106			5,747
Accumulated depreciation and amortization	(1,094		)	(1,041		)
Other Noncurrent Assets: Other	82			106
Current maturities of long-term debt	162			162
Long-Term Debt	1,538			1,541
Other Noncurrent Liabilities: AROs	129			127
Other Noncurrent Liabilities: Other	258			228

NON-CONSOLIDATED VIEs

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

	March 31, 2020
	Duke Energy												Duke		Duke
	Pipeline			Commercial			Other						Energy		Energy
(in millions)	Investments			Renewables			VIEs			Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	(1	)	$	—		$	(1	)	$	39	$	48
Investments in equity method unconsolidated affiliates	1,243			371			—			1,614			—		—
Total assets	$	1,243		$	370		$	—		$	1,613		$	39	$	48
Taxes accrued	(1		)	—			—			(1		)	—		—
Other current liabilities	—			—			3			3			—		—
Deferred income taxes	69			—			—			69			—		—
Other noncurrent liabilities	105			—			11			116			—		—
Total liabilities	$	173		$	—		$	14		$	187		$	—	$	—
Net assets (liabilities)	$	1,070		$	370		$	(14	)	$	1,426		$	39	$	48

	December 31, 2019
	Duke Energy												Duke		Duke
	Pipeline			Commercial			Other						Energy		Energy
(in millions)	Investments			Renewables			VIEs			Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	(1	)	$	—		$	(1	)	$	64	$	77
Investments in equity method unconsolidated affiliates	1,179			300			—			1,479			—		—
Total assets	$	1,179		$	299		$	—		$	1,478		$	64	$	77
Taxes accrued	(1		)	—			—			(1		)	—		—
Other current liabilities	—			—			4			4			—		—
Deferred income taxes	59			—			—			59			—		—
Other noncurrent liabilities	—			—			11			11			—		—
Total liabilities	$	58		$	—		$	15		$	73		$	—	$	—
Net assets (liabilities)	$	1,121		$	299		$	(15	)	$	1,405		$	64	$	77

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 PPA with OVEC, which is discussed below, and various guarantees, including Duke Energy's 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 $845 million, which represents 47% of the outstanding borrowings under the credit facility as of March 31, 2020. 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		March 31,		December 31,
Entity Name	Interest		2020		2019
ACP(a)	47	%	$	1,243	$	1,179
Constitution(b)	24	%	—		—
Total			$	1,243	$	1,179

(a) Duke Energy evaluated this investment for impairment as of March 31, 2020, and December 31, 2019, and determined that fair value approximated carrying value and therefore no impairment was necessary.

(b) During the year ended December 31, 2019, Duke Energy recorded an OTTI related to Constitution. This charge resulted in the full write-down of Duke Energy's investment in Constitution.

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. In 2019, Duke Energy acquired a majority ownership in a portfolio of distributed fuel cell projects from Bloom Energy Corporation. Duke Energy is not the primary beneficiary of the assets within the portfolio and does not consolidate the assets in the portfolio.

OVEC

Duke Energy Ohio’s 9% ownership interest in OVEC is considered a non-consolidated VIE due to OVEC having insufficient equity to finance its activities without subordinated financial support. The activities that most significantly impact OVEC's economic performance include fuel strategy and supply activities and decisions associated with ongoing operations and maintenance-related activities. Duke Energy Ohio does not have the unilateral power to direct these activities, and therefore, does not consolidate OVEC.

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 Corp (FES), a subsidiary of FirstEnergy Corp. and an ICPA counterparty with a power participation ratio of 4.85%, 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. In addition, certain proposed environmental rulemaking could result in future increased OVEC cost allocations. See Note 3 for additional information.

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.

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019
Receivables sold	$	234	$	253	$	274	$	307
Less: Retained interests	39		64		48		77
Net receivables sold	$	195	$	189	$	226	$	230

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

	Duke Energy Ohio				Duke Energy Indiana
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(in millions)	2020		2019		2020		2019
Sales
Receivables sold	$	537	$	575	$	647	$	734
Loss recognized on sale	4		4		4		5
Cash flows
Cash proceeds from receivables sold	$	559	$	597	$	672	$	758
Return received on retained interests	2		2		2		3

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

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Income Taxes

3 Months Ended

Mar. 31, 2020

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

EFFECTIVE TAX RATES

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

	Three Months Ended
	March 31,
	2020		2019
Duke Energy	13.3	%	9.6	%
Duke Energy Carolinas	16.1	%	17.7	%
Progress Energy	17.5	%	17.3	%
Duke Energy Progress	17.1	%	17.8	%
Duke Energy Florida	20.0	%	19.3	%
Duke Energy Ohio	17.7	%	16.9	%
Duke Energy Indiana	20.8	%	24.1	%
Piedmont	10.1	%	21.8	%

The increase in the ETR for Duke Energy for the three months ended March 31, 2020, was primarily due to an adjustment related to the income tax recognition for equity method investments recorded in the first quarter of 2019, partially offset by an increase in the amortization of excess deferred taxes. The equity method investment adjustment was immaterial and relates to prior years.

The decrease in the ETR for Duke Energy Carolinas for the three months ended March 31, 2020, was primarily due to an increase in the amortization of excess deferred taxes.

The decrease in the ETR for Duke Energy Indiana for the three months ended March 31, 2020, was primarily due to an increase in the amortization of excess deferred taxes.

The decrease in the ETR for Piedmont for the three months ended March 31, 2020, was primarily due to an increase in the amortization of excess deferred taxes.

OTHER TAX MATTERS

On March 27, 2020, the CARES Act was enacted. The CARES Act is an emergency economic stimulus package in response to the COVID-19 pandemic. Among other provisions, the CARES Act accelerates the remaining AMT credit refund allowances resulting in taxpayers being able to immediately claim a refund in full for any AMT credit carryforwards. As a result, the remaining AMT credit carryforwards have been reclassified to a current receivable included in Other within Current Assets on the Condensed Consolidated Balance Sheets as of March 31, 2020. The total income tax receivable related to AMT credit carryforwards is approximately $572 million. The other provisions within the CARES Act do not materially impact Duke Energy's income tax accounting. See Note 1 for information on COVID-19.

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Debt and Credit Facilities (Schedule of Other Credit Facilities) (Details)	1 Months Ended	3 Months Ended
	Mar. 31, 2020 USD ($)	Mar. 31, 2020 USD ($)
Master Credit Facility
Line of Credit Facility [Line Items]
Facility size	$ 8,000,000,000	$ 8,000,000,000
Duke Energy Progress | Master Credit Facility
Line of Credit Facility [Line Items]
Facility size	1,250,000,000	1,250,000,000
Duke Energy Progress | Term Loan Facility
Line of Credit Facility [Line Items]
Facility size	700,000,000	700,000,000
Amount drawn	700,000,000	$ 700,000,000
Duke Energy (Parent) Three-Year Revolving Credit Facility | Master Credit Facility
Line of Credit Facility [Line Items]
Facility Term		3 years
Facility size	1,000,000,000	$ 1,000,000,000
Amount drawn	1,000,000,000	$ 1,000,000,000
Additional amount drawn	$ 500,000,000

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Revenue (Unbilled Revenues) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	$ 716	$ 843
Duke Energy Carolinas
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	285	298
Progress Energy
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	195	217
Duke Energy Progress
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	85	122
Duke Energy Florida
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	110	95
Duke Energy Ohio
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	1	1
Duke Energy Indiana
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	16	16
Piedmont Natural Gas
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	32	78
CRC | Duke Energy Ohio
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	61	82
CRC | Duke Energy Indiana
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled Receivables	$ 94	$ 115

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Income Taxes (Effective Tax Rates) (Details)	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
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	13.30%	9.60%
Duke Energy Carolinas
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	16.10%	17.70%
Progress Energy
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	17.50%	17.30%
Duke Energy Progress
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	17.10%	17.80%
Duke Energy Florida
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	20.00%	19.30%
Duke Energy Ohio
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	17.70%	16.90%
Duke Energy Indiana
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	20.80%	24.10%
Piedmont Natural Gas
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	10.10%	21.80%

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Related Party Transactions (Intercompany Income Taxes) (Details) - Affiliated Entity - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Duke Energy Carolinas
Related Party Transaction [Line Items]
Income tax payable	$ 44	$ 5
Progress Energy
Related Party Transaction [Line Items]
Income taxes receivable	114	125
Duke Energy Progress
Related Party Transaction [Line Items]
Income taxes receivable	1	28
Duke Energy Florida
Related Party Transaction [Line Items]
Income taxes receivable	4
Income tax payable		2
Duke Energy Ohio
Related Party Transaction [Line Items]
Income taxes receivable		9
Duke Energy Indiana
Related Party Transaction [Line Items]
Income taxes receivable		28
Income tax payable	6
Piedmont Natural Gas
Related Party Transaction [Line Items]
Income taxes receivable		$ 13
Income tax payable	$ 10

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Regulatory Matters (Regulatory Matters Narrative - Duke Energy Carolinas) (Details) - Duke Energy Carolinas - USD ($) $ in Millions	Sep. 30, 2019	May 21, 2019	Nov. 08, 2018	Feb. 28, 2018	Aug. 25, 2017
2017 North Carolina Rate Case | NCUC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount					$ 647
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%
2019 North Carolina Rate Case | NCUC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 291
Requested rate increase, percentage	6.00%
Requested rate increase (decrease), gross amount	$ 445
Requested rate increase (decrease), rider reduction	$ 154
South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount			$ 168
Requested rate increase, percentage			10.00%
Change in tax rate, deferred tax liability, income tax benefit		$ 66	$ 66
Measurement period adjustment, income tax expense (benefit)		$ 45	46
Approved return on equity percentage		9.50%
Public utilities, approved equity capital structure, percentage		53.00%
Public utilities, approved debt capital structure, percentage		47.00%
State and local jurisdiction | North Carolina Department of Revenue | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
State and local taxes reduction amount		$ 17	17
Regulatory asset, amortization period		5 years
Asset retirement obligations - coal ash | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory assets		$ 96	$ 242
Regulatory asset, amortization period		5 years	5 years
Recovery costs denied		$ 115
Asset retirement obligations - unprotected EDIT, Property, Plant and Equipment | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory asset, amortization period		20 years
Asset retirement obligations - unprotected EDIT | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory asset, amortization period		5 years
Asset retirement obligations - deferred revenue | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory asset, amortization period		5 years
Deferred project costs | South Carolina Rate Case 2018 | PSCSC
Public Utilities, General Disclosures [Line Items]
Regulatory assets		$ 125
Regulatory asset, amortization period		12 years

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Organization and Basis of Presentation (Schedule of Inventory) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Public Utilities, Inventory [Line Items]
Inventory	$ 3,324	$ 3,232
Materials and supplies
Public Utilities, Inventory [Line Items]
Inventory	2,280	2,297
Coal
Public Utilities, Inventory [Line Items]
Inventory	742	586
Natural gas, oil and other fuel
Public Utilities, Inventory [Line Items]
Inventory	302	349
Duke Energy Carolinas
Public Utilities, Inventory [Line Items]
Inventory	1,067	996
Duke Energy Carolinas | Materials and supplies
Public Utilities, Inventory [Line Items]
Inventory	759	768
Duke Energy Carolinas | Coal
Public Utilities, Inventory [Line Items]
Inventory	268	187
Duke Energy Carolinas | Natural gas, oil and other fuel
Public Utilities, Inventory [Line Items]
Inventory	40	41
Progress Energy
Public Utilities, Inventory [Line Items]
Inventory	1,463	1,423
Progress Energy | Materials and supplies
Public Utilities, Inventory [Line Items]
Inventory	1,018	1,038
Progress Energy | Coal
Public Utilities, Inventory [Line Items]
Inventory	246	186
Progress Energy | Natural gas, oil and other fuel
Public Utilities, Inventory [Line Items]
Inventory	199	199
Duke Energy Progress
Public Utilities, Inventory [Line Items]
Inventory	956	934
Duke Energy Progress | Materials and supplies
Public Utilities, Inventory [Line Items]
Inventory	678	686
Duke Energy Progress | Coal
Public Utilities, Inventory [Line Items]
Inventory	167	138
Duke Energy Progress | Natural gas, oil and other fuel
Public Utilities, Inventory [Line Items]
Inventory	111	110
Duke Energy Florida
Public Utilities, Inventory [Line Items]
Inventory	508	489
Duke Energy Florida | Materials and supplies
Public Utilities, Inventory [Line Items]
Inventory	340	351
Duke Energy Florida | Coal
Public Utilities, Inventory [Line Items]
Inventory	79	48
Duke Energy Florida | Natural gas, oil and other fuel
Public Utilities, Inventory [Line Items]
Inventory	89	90
Duke Energy Ohio
Public Utilities, Inventory [Line Items]
Inventory	121	135
Duke Energy Ohio | Materials and supplies
Public Utilities, Inventory [Line Items]
Inventory	83	79
Duke Energy Ohio | Coal
Public Utilities, Inventory [Line Items]
Inventory	10	15
Duke Energy Ohio | Natural gas, oil and other fuel
Public Utilities, Inventory [Line Items]
Inventory	28	41
Duke Energy Indiana
Public Utilities, Inventory [Line Items]
Inventory	538	517
Duke Energy Indiana | Materials and supplies
Public Utilities, Inventory [Line Items]
Inventory	319	318
Duke Energy Indiana | Coal
Public Utilities, Inventory [Line Items]
Inventory	218	198
Duke Energy Indiana | Natural gas, oil and other fuel
Public Utilities, Inventory [Line Items]
Inventory	1	1
Piedmont Natural Gas
Public Utilities, Inventory [Line Items]
Inventory	39	72
Piedmont Natural Gas | Materials and supplies
Public Utilities, Inventory [Line Items]
Inventory	5	5
Piedmont Natural Gas | Natural gas, oil and other fuel
Public Utilities, Inventory [Line Items]
Inventory	$ 34	$ 67

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Employee Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2020

Qualified Pension Plans

Defined Benefit Plan Disclosure [Line Items]

Components of Net Periodic Pension Costs

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

	Three Months Ended March 31, 2020
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	41		$	12		$	12		$	6		$	5		$	1		$	2		$	1
Interest cost on projected benefit obligation	67			16			21			10			12			4			6			2
Expected return on plan assets	(143		)	(36		)	(48		)	(22		)	(25		)	(7		)	(11		)	(5		)
Amortization of actuarial loss	34			7			11			5			6			2			3			2
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(2		)
Amortization of settlement charges	2			1			1			—			—			—			—			—
Net periodic pension costs	$	(7	)	$	(2	)	$	(4	)	$	(1	)	$	(2	)	$	—		$	—		$	(2	)

	Three Months Ended March 31, 2019
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	37		$	12		$	11		$	6		$	4		$	1		$	2		$	1
Interest cost on projected benefit obligation	83			20			26			12			14			5			6			3
Expected return on plan assets	(143		)	(38		)	(44		)	(23		)	(22		)	(8		)	(11		)	(5		)
Amortization of actuarial loss	24			6			9			3			6			1			2			2
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(3		)
Net periodic pension costs	$	(7	)	$	(2	)	$	1		$	(2	)	$	2		$	(1	)	$	(1	)	$	(2	)

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Revenue

3 Months Ended

Mar. 31, 2020

Revenue from Contract with Customer [Abstract]

Revenue

REVENUE

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.

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)	2020		2021		2022		2023		2024		Thereafter		Total
Progress Energy	$	84	$	92	$	87	$	44	$	45	$	58	$	410
Duke Energy Progress	6		8		8		8		8		—		38
Duke Energy Florida	78		84		79		36		37		58		372
Duke Energy Indiana	8		5		—		—		—		—		13

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 revenues 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.

Fixed-capacity payments under long-term contracts for the Gas Utilities and Infrastructure 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)	2020		2021		2022		2023		2024		Thereafter		Total
Piedmont	$	51	$	65	$	64	$	61	$	58	$	376	$	675

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 Certificates (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.

Other

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

Disaggregated Revenues

Disaggregated revenues are presented as follows:

	Three Months Ended March 31, 2020
			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	$	2,261	$	756	$	1,064	$	502	$	562	$	176		$	265	$	—
General	1,492		549		648		319		329		114			181		—
Industrial	693		269		216		154		62		35			175		—
Wholesale	497		114		321		279		42		7			55		—
Other revenues	191		60		118		63		55		20			16		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,134	$	1,748	$	2,367	$	1,317	$	1,050	$	352		$	692	$	—
Gas Utilities and Infrastructure
Residential	$	362	$	—	$	—	$	—	$	—	$	97		$	—	$	264
Commercial	169		—		—		—		—		43			—		126
Industrial	41		—		—		—		—		6			—		36
Power Generation	—		—		—		—		—		—			—		11
Other revenues	30		—		—		—		—		6			—		24
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	602	$	—	$	—	$	—	$	—	$	152		$	—	$	461
Commercial Renewables
Revenue from contracts with customers	$	58	$	—	$	—	$	—	$	—	$	—		$	—	$	—
Other
Revenue from contracts with customers	$	6	$	—	$	—	$	—	$	—	$	—		$	—	$	—
Total revenue from contracts with customers	$	5,800	$	1,748	$	2,367	$	1,317	$	1,050	$	504		$	692	$	461
Other revenue sources(a)	$	149	$	—	$	55	$	21	$	30	$	(6	)	$	—	$	51
Total revenues	$	5,949	$	1,748	$	2,422	$	1,338	$	1,080	$	498		$	692	$	512

(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.

	Three Months Ended March 31, 2019
			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	$	2,370	$	760	$	1,114	$	536	$	578	$	189	$	306	$	—
General	1,427		496		632		306		326		103		197		—
Industrial	711		266		222		161		61		33		190		—
Wholesale	541		119		353		315		38		14		54		—
Other revenues	172		78		172		125		47		16		17		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,221	$	1,719	$	2,493	$	1,443	$	1,050	$	355	$	764	$	—
Gas Utilities and Infrastructure
Residential	$	414	$	—	$	—	$	—	$	—	$	112	$	—	$	302
Commercial	206		—		—		—		—		49		—		157
Industrial	48		—		—		—		—		7		—		42
Power Generation	—		—		—		—		—		—		—		13
Other revenues	63		—		—		—		—		8		—		56
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	731	$	—	$	—	$	—	$	—	$	176	$	—	$	570
Commercial Renewables
Revenue from contracts with customers	$	42	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	4	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total revenue from contracts with customers	$	5,998	$	1,719	$	2,493	$	1,443	$	1,050	$	531	$	764	$	570
Other revenue sources(a)	$	165	$	25	$	79	$	41	$	36	$	—	$	4	$	9
Total revenues	$	6,163	$	1,744	$	2,572	$	1,484	$	1,086	$	531	$	768	$	579

(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.

As described in Note 1, Duke Energy adopted the new guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. The following table presents the reserve for credit losses for trade and other receivables based on adoption of the new standard.

	March 31, 2020
				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, 2019	$	76		$	10		$	16		$	8		$	7		$	4	$	3	$	6
Cumulative Change in Accounting Principle	5			1			2			1			1			—		—		1
Write-Offs	(10		)	(3		)	(4		)	(2		)	(2		)	—		—		(1		)
Credit Loss Expense	18			3			6			2			5			1		—		3
Balance at March 31, 2020	$	89		$	11		$	20		$	9		$	11		$	5	$	3	$	9

Trade and other receivables are evaluated based on an estimate of the risk of loss over the life of the receivable and current and historical conditions using supportable assumptions. Management evaluates the risk of loss for trade and other receivables by comparing the historical write-off amounts to total revenue over a specified period. Historical loss rates are adjusted due to the impact of current conditions as well as forecasted conditions over a reasonable time period. The calculated write-off rate can be applied to the receivable balance for which an established reserve does not already exist. Management reviews the assumptions and risk of loss annually for trade and other receivables. Due to the COVID-19 pandemic, as described in Note 1, the Duke Energy Registrants suspended customer disconnections for nonpayment. The specific actions taken by each Duke Energy Registrant are described in Note 3. The impact of COVID-19 and Duke Energy’s related response on customers’ ability to pay for service is uncertain, and it is reasonably possible eventual write-offs of customer receivables may increase over current estimates.

The aging of trade receivables is presented in the table below. Duke Energy considers receivables greater than 30 days outstanding past due.

	March 31, 2020
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Unbilled Receivables	$	716	$	285	$	195	$	85	$	110	$	1	$	16	$	32
0-30 days	1,584		448		585		321		262		45		24		134
30-60 days	216		69		67		44		23		9		1		18
60-90 days	65		18		20		14		6		2		1		5
90+ days	145		19		57		32		25		32		11		11
Trade and Other Receivables	$	2,726	$	839	$	924	$	496	$	426	$	89	$	53	$	200

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)	March 31, 2020		December 31, 2019
Duke Energy	$	716	$	843
Duke Energy Carolinas	285		298
Progress Energy	195		217
Duke Energy Progress	85		122
Duke Energy Florida	110		95
Duke Energy Ohio	1		1
Duke Energy Indiana	16		16
Piedmont	32		78

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 account for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 11 for further information. These receivables for unbilled revenues are shown in the table below.

(in millions)	March 31, 2020		December 31, 2019
Duke Energy Ohio	$	61	$	82
Duke Energy Indiana	94		115

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Subsequent Events

3 Months Ended

Mar. 31, 2020

Subsequent Events [Abstract]

Subsequent Events

SUBSEQUENT EVENTS

For information on subsequent events related to regulatory matters, commitments and contingencies and derivatives and hedging, see Notes 3, 4 and 8.

XML

Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2020

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. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of March 31, 2020, 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	$	149
Duke Energy Indiana
Gallagher Units 2 and 4(b)	280	118
Gibson Units 1-5(c)	3,132	1,708
Cayuga Units 1-2(c)	1,005	964
Total Duke Energy	5,002	$	2,939

(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 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.

(c)

On July 1, 2019, Duke Energy Indiana filed its 2018 IRP with the IURC. The 2018 IRP included scenarios evaluating the potential retirement of coal-fired generating units at Gibson and Cayuga. The rate case filed July 2, 2019, includes proposed depreciation rates reflecting retirement dates from 2026 to 2038.

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Revenue (Tables)

3 Months Ended

Mar. 31, 2020

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)	2020		2021		2022		2023		2024		Thereafter		Total
Piedmont	$	51	$	65	$	64	$	61	$	58	$	376	$	675

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)	2020		2021		2022		2023		2024		Thereafter		Total
Progress Energy	$	84	$	92	$	87	$	44	$	45	$	58	$	410
Duke Energy Progress	6		8		8		8		8		—		38
Duke Energy Florida	78		84		79		36		37		58		372
Duke Energy Indiana	8		5		—		—		—		—		13

Disaggregation of Revenue

Disaggregated revenues are presented as follows:

	Three Months Ended March 31, 2020
			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	$	2,261	$	756	$	1,064	$	502	$	562	$	176		$	265	$	—
General	1,492		549		648		319		329		114			181		—
Industrial	693		269		216		154		62		35			175		—
Wholesale	497		114		321		279		42		7			55		—
Other revenues	191		60		118		63		55		20			16		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,134	$	1,748	$	2,367	$	1,317	$	1,050	$	352		$	692	$	—
Gas Utilities and Infrastructure
Residential	$	362	$	—	$	—	$	—	$	—	$	97		$	—	$	264
Commercial	169		—		—		—		—		43			—		126
Industrial	41		—		—		—		—		6			—		36
Power Generation	—		—		—		—		—		—			—		11
Other revenues	30		—		—		—		—		6			—		24
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	602	$	—	$	—	$	—	$	—	$	152		$	—	$	461
Commercial Renewables
Revenue from contracts with customers	$	58	$	—	$	—	$	—	$	—	$	—		$	—	$	—
Other
Revenue from contracts with customers	$	6	$	—	$	—	$	—	$	—	$	—		$	—	$	—
Total revenue from contracts with customers	$	5,800	$	1,748	$	2,367	$	1,317	$	1,050	$	504		$	692	$	461
Other revenue sources(a)	$	149	$	—	$	55	$	21	$	30	$	(6	)	$	—	$	51
Total revenues	$	5,949	$	1,748	$	2,422	$	1,338	$	1,080	$	498		$	692	$	512

(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.

	Three Months Ended March 31, 2019
			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	$	2,370	$	760	$	1,114	$	536	$	578	$	189	$	306	$	—
General	1,427		496		632		306		326		103		197		—
Industrial	711		266		222		161		61		33		190		—
Wholesale	541		119		353		315		38		14		54		—
Other revenues	172		78		172		125		47		16		17		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,221	$	1,719	$	2,493	$	1,443	$	1,050	$	355	$	764	$	—
Gas Utilities and Infrastructure
Residential	$	414	$	—	$	—	$	—	$	—	$	112	$	—	$	302
Commercial	206		—		—		—		—		49		—		157
Industrial	48		—		—		—		—		7		—		42
Power Generation	—		—		—		—		—		—		—		13
Other revenues	63		—		—		—		—		8		—		56
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	731	$	—	$	—	$	—	$	—	$	176	$	—	$	570
Commercial Renewables
Revenue from contracts with customers	$	42	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Other
Revenue from contracts with customers	$	4	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total revenue from contracts with customers	$	5,998	$	1,719	$	2,493	$	1,443	$	1,050	$	531	$	764	$	570
Other revenue sources(a)	$	165	$	25	$	79	$	41	$	36	$	—	$	4	$	9
Total revenues	$	6,163	$	1,744	$	2,572	$	1,484	$	1,086	$	531	$	768	$	579

(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.

Reserve for Credit Losses for Trade and Other Receivables

As described in Note 1, Duke Energy adopted the new guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. The following table presents the reserve for credit losses for trade and other receivables based on adoption of the new standard.

	March 31, 2020
				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, 2019	$	76		$	10		$	16		$	8		$	7		$	4	$	3	$	6
Cumulative Change in Accounting Principle	5			1			2			1			1			—		—		1
Write-Offs	(10		)	(3		)	(4		)	(2		)	(2		)	—		—		(1		)
Credit Loss Expense	18			3			6			2			5			1		—		3
Balance at March 31, 2020	$	89		$	11		$	20		$	9		$	11		$	5	$	3	$	9

Aging of Trade Receivables

The aging of trade receivables is presented in the table below. Duke Energy considers receivables greater than 30 days outstanding past due.

	March 31, 2020
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Unbilled Receivables	$	716	$	285	$	195	$	85	$	110	$	1	$	16	$	32
0-30 days	1,584		448		585		321		262		45		24		134
30-60 days	216		69		67		44		23		9		1		18
60-90 days	65		18		20		14		6		2		1		5
90+ days	145		19		57		32		25		32		11		11
Trade and Other Receivables	$	2,726	$	839	$	924	$	496	$	426	$	89	$	53	$	200

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

(in millions)	March 31, 2020		December 31, 2019
Duke Energy	$	716	$	843
Duke Energy Carolinas	285		298
Progress Energy	195		217
Duke Energy Progress	85		122
Duke Energy Florida	110		95
Duke Energy Ohio	1		1
Duke Energy Indiana	16		16
Piedmont	32		78

These receivables for unbilled revenues are shown in the table below.

(in millions)	March 31, 2020		December 31, 2019
Duke Energy Ohio	$	61	$	82
Duke Energy Indiana	94		115

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Derivatives and Hedging (Tables)

3 Months Ended

Mar. 31, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Notional Amounts of Outstanding Derivative Positions

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

	March 31, 2020
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	991	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	2,027		400		1,600		1,050		550		27
Total notional amount(a)	$	3,018	$	400	$	1,600	$	1,050	$	550	$	27

	December 31, 2019
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	993	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,277		450		800		250		550		27
Total notional amount(a)	$	2,270	$	450	$	800	$	250	$	550	$	27

(a)

Duke Energy includes amounts related to consolidated VIEs of $691 million in cash flow hedges as of March 31, 2020, and $693 million in cash flow hedges as of December 31, 2019.

The tables below include volumes of outstanding commodity derivatives. Amounts disclosed represent the absolute value of notional volumes of commodity contracts excluding NPNS. The Duke Energy Registrants have netted contractual amounts where offsetting purchase and sale contracts exist with identical delivery locations and times of delivery. Where all commodity positions are perfectly offset, no quantities are shown.

	March 31, 2020
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana	Piedmont
Electricity (GWh)	6,737	—	—	—	—	977	5,760	—
Natural gas (millions of dekatherms)	709	145	158	158	—	—	4	402

	December 31, 2019
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana	Piedmont
Electricity (GWh)	15,858	—	—	—	—	1,887	13,971	—
Natural gas (millions of dekatherms)	704	130	160	160	—	—	3	411

Location And Fair Value Of Derivatives Recognized in the Condensed Consolidated Balance Sheets

The following tables show the fair value and balance sheet location of derivative instruments. Although derivatives subject to master netting arrangements are netted on the Condensed Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.

Derivative Assets	March 31, 2020
			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	$	6	$	—	$	—	$	—	$	—	$	—	$	2	$	3
Noncurrent	4		2		1		1		—		1		—		—
Total Derivative Assets – Commodity Contracts	$	10	$	2	$	1	$	1	$	—	$	1	$	2	$	3
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	$	3	$	—	$	3	$	3	$	—	$	—	$	—	$	—
Noncurrent	1		—		1		1		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	4	$	—	$	4	$	4	$	—	$	—	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Noncurrent(a)	20		—		20		—		20		—		—		—
Total Derivative Assets – Equity Securities Contracts	$	20	$	—	$	20	$	—	$	20	$	—	$	—	$	—
Total Derivative Assets	$	34	$	2	$	25	$	5	$	20	$	1	$	2	$	3

(a) Equity security contracts are current since they were set to expire in May 2020 but are classified as noncurrent assets on the Condensed Consolidated Balance Sheet because the amount is presented within the NDTF.

Derivative Liabilities	March 31, 2020
			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	$	79	$	40	$	31	$	31	$	—	$	—	$	—	$	8
Noncurrent	130		11		35		20		—		—		—		83
Total Derivative Liabilities – Commodity Contracts	$	209	$	51	$	66	$	51	$	—	$	—	$	—	$	91
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	69	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	54		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	30		—		29		—		29		1		—		—
Noncurrent	28		23		—		—		—		6		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	181	$	23	$	29	$	—	$	29	$	7	$	—	$	—
Total Derivative Liabilities	$	390	$	74	$	95	$	51	$	29	$	7	$	—	$	91

Derivative Assets	December 31, 2019
			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	$	17	$	—	$	—	$	—	$	—	$	3	$	13	$	1
Noncurrent	1		—		—		—		—		1		—		—
Total Derivative Assets – Commodity Contracts	$	18	$	—	$	—	$	—	$	—	$	4	$	13	$	1
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	6		—		6		—		6		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	6	$	—	$	6	$	—	$	6	$	—	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Current	1		—		1		—		1		—		—		—
Total Derivative Assets – Equity Securities Contracts	$	1	$	—	$	1	$	—	$	1	$	—	$	—	$	—
Total Derivative Assets	$	25	$	—	$	7	$	—	$	7	$	4	$	13	$	1

Derivative Liabilities	December 31, 2019
			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	$	67	$	33	$	26	$	26	$	—	$	—	$	1	$	7
Noncurrent	156		10		37		22		—		—		—		110
Total Derivative Liabilities – Commodity Contracts	$	223	$	43	$	63	$	48	$	—	$	—	$	1	$	117
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	19	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	21		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	8		6		1		1		—		1		—		—
Noncurrent	5		—		—		—		—		5		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	53	$	6	$	1	$	1	$	—	$	6	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Current	24		—		24		—		24		—		—		—
Total Derivative Liabilities – Equity Securities Contracts	$	24	$	—	$	24	$	—	$	24	$	—	$	—	$	—
Total Derivative Liabilities	$	300	$	49	$	88	$	49	$	24	$	6	$	1	$	117

Offsetting Assets

The following tables present the line items on the Condensed Consolidated Balance Sheets where derivatives are reported. Substantially all of Duke Energy's outstanding derivative contracts are subject to enforceable master netting arrangements. The gross amounts offset in the tables below show the effect of these netting arrangements on financial position, and include collateral posted to offset the net position. The amounts shown are calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

Derivative Assets	March 31, 2020
				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	$	9		$	—		$	3		$	3		$	—	$	—	$	2	$	3
Gross amounts offset	—			—			—			—			—		—		—		—
Net amounts presented in Current Assets: Other	$	9		$	—		$	3		$	3		$	—	$	—	$	2	$	3
Noncurrent
Gross amounts recognized	$	25		$	2		$	22		$	2		$	20	$	1	$	—	$	—
Gross amounts offset	(3		)	(2		)	(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	2		$	—		$	1		$	1		$	—	$	1	$	—	$	—
Net amounts presented in NDTF	$	20		$	—		$	20		$	—		$	20	$	—	$	—	$	—

Derivative Liabilities	March 31, 2020
				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	$	178		$	40		$	60		$	31		$	29	$	1	$	—	$	8
Gross amounts offset	—			—			—			—			—		—		—		—
Net amounts presented in Current Liabilities: Other	$	178		$	40		$	60		$	31		$	29	$	1	$	—	$	8
Noncurrent
Gross amounts recognized	$	212		$	34		$	35		$	20		$	—	$	6	$	—	$	83
Gross amounts offset	(3		)	(2		)	(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	209		$	32		$	34		$	19		$	—	$	6	$	—	$	83

Derivative Assets	December 31, 2019
				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	$	24		$	—	$	7		$	—	$	7		$	3	$	13	$	1
Gross amounts offset	(1		)	—		(1		)	—		(1		)	—		—		—
Net amounts presented in Current Assets: Other	$	23		$	—	$	6		$	—	$	6		$	3	$	13	$	1
Noncurrent
Gross amounts recognized	$	1		$	—	$	—		$	—	$	—		$	1	$	—	$	—
Gross amounts offset	—			—		—			—		—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	1		$	—	$	—		$	—	$	—		$	1	$	—	$	—

Derivative Liabilities	December 31, 2019
				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	$	118		$	39	$	51		$	27	$	24		$	1	$	1	$	7
Gross amounts offset	(24		)	—		(24		)	—		(24		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	94		$	39	$	27		$	27	$	—		$	1	$	1	$	7
Noncurrent
Gross amounts recognized	$	182		$	10	$	37		$	22	$	—		$	5	$	—	$	110
Gross amounts offset	—			—		—			—		—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	182		$	10	$	37		$	22	$	—		$	5	$	—	$	110

Offsetting Liabilities

Derivative Assets	March 31, 2020
				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	$	9		$	—		$	3		$	3		$	—	$	—	$	2	$	3
Gross amounts offset	—			—			—			—			—		—		—		—
Net amounts presented in Current Assets: Other	$	9		$	—		$	3		$	3		$	—	$	—	$	2	$	3
Noncurrent
Gross amounts recognized	$	25		$	2		$	22		$	2		$	20	$	1	$	—	$	—
Gross amounts offset	(3		)	(2		)	(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	2		$	—		$	1		$	1		$	—	$	1	$	—	$	—
Net amounts presented in NDTF	$	20		$	—		$	20		$	—		$	20	$	—	$	—	$	—

Derivative Liabilities	March 31, 2020
				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	$	178		$	40		$	60		$	31		$	29	$	1	$	—	$	8
Gross amounts offset	—			—			—			—			—		—		—		—
Net amounts presented in Current Liabilities: Other	$	178		$	40		$	60		$	31		$	29	$	1	$	—	$	8
Noncurrent
Gross amounts recognized	$	212		$	34		$	35		$	20		$	—	$	6	$	—	$	83
Gross amounts offset	(3		)	(2		)	(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	209		$	32		$	34		$	19		$	—	$	6	$	—	$	83

Derivative Assets	December 31, 2019
				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	$	24		$	—	$	7		$	—	$	7		$	3	$	13	$	1
Gross amounts offset	(1		)	—		(1		)	—		(1		)	—		—		—
Net amounts presented in Current Assets: Other	$	23		$	—	$	6		$	—	$	6		$	3	$	13	$	1
Noncurrent
Gross amounts recognized	$	1		$	—	$	—		$	—	$	—		$	1	$	—	$	—
Gross amounts offset	—			—		—			—		—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	1		$	—	$	—		$	—	$	—		$	1	$	—	$	—

Derivative Liabilities	December 31, 2019
				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	$	118		$	39	$	51		$	27	$	24		$	1	$	1	$	7
Gross amounts offset	(24		)	—		(24		)	—		(24		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	94		$	39	$	27		$	27	$	—		$	1	$	1	$	7
Noncurrent
Gross amounts recognized	$	182		$	10	$	37		$	22	$	—		$	5	$	—	$	110
Gross amounts offset	—			—		—			—		—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	182		$	10	$	37		$	22	$	—		$	5	$	—	$	110

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.

	March 31, 2020
			Duke				Duke
	Duke		Energy		Progress		Energy
(in millions)	Energy		Carolinas		Energy		Progress
Aggregate fair value of derivatives in a net liability position	$	96	$	45	$	51	$	51
Fair value of collateral already posted	—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	96		45		51		51

	December 31, 2019
			Duke				Duke
	Duke		Energy		Progress		Energy
(in millions)	Energy		Carolinas		Energy		Progress
Aggregate fair value of derivatives in a net liability position	$	79	$	35	$	44	$	44
Fair value of collateral already posted	—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	79		35		44		44

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Commitments and Contingencies (Table)

3 Months Ended

Mar. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Schedule of Reserves

The table below presents recorded reserves based on management’s best estimate of probable loss for legal matters, excluding asbestos-related reserves discussed above. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Other Noncurrent Liabilities and Other within Current Liabilities. The reasonably possible range of loss in excess of recorded reserves is not material, other than as described above.

(in millions)	March 31, 2020		December 31, 2019
Reserves for Legal Matters
Duke Energy	$	61	$	62
Duke Energy Carolinas	3		2
Progress Energy	52		55
Duke Energy Progress	9		12
Duke Energy Florida	23		22
Piedmont	1		1

The following table contains 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.

	Three Months Ended March 31, 2020
				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	$	58		$	11		$	16		$	4	$	9	$	19		$	4	$	8
Provisions/adjustments	3			—			—			1		—		1			1		—
Cash reductions	(3		)	(1		)	(1		)	—		—		(1		)	—		—
Balance at end of period	$	58		$	10		$	15		$	5	$	9	$	19		$	5	$	8

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	$	58
Duke Energy Carolinas	11
Duke Energy Ohio	41
Piedmont	2

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2020

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, coal ash 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 Duke Energy Registrants.

Remediation Activities

In addition to AROs recorded as a result of various environmental regulations, the Duke Energy Registrants are responsible for environmental remediation at various sites. These include certain properties that are part of ongoing operations and sites formerly owned or used by Duke Energy entities. These sites are in various stages of investigation, remediation and monitoring. Managed in conjunction with relevant federal, state and local agencies, remediation activities vary based upon site conditions and location, remediation requirements, complexity and sharing of responsibility. If remediation activities involve joint and several liability provisions, strict liability, or cost recovery or contribution actions, the Duke Energy Registrants could potentially be held responsible for environmental impacts caused by other potentially responsible parties and may also benefit from insurance policies or contractual indemnities that cover some or all cleanup costs. Liabilities are recorded when losses become probable and are reasonably estimable. The total costs that may be incurred cannot be estimated because the extent of environmental impact, allocation among potentially responsible parties, remediation alternatives and/or regulatory decisions have not yet been determined at all sites. Additional costs associated with remediation activities are likely to be incurred in the future and could be significant. Costs are typically expensed as Operation, maintenance and other on the Condensed Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.

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

	Three Months Ended March 31, 2020
				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	$	58		$	11		$	16		$	4	$	9	$	19		$	4	$	8
Provisions/adjustments	3			—			—			1		—		1			1		—
Cash reductions	(3		)	(1		)	(1		)	—		—		(1		)	—		—
Balance at end of period	$	58		$	10		$	15		$	5	$	9	$	19		$	5	$	8

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	$	58
Duke Energy Carolinas	11
Duke Energy Ohio	41
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. Despite a stay of the litigation from May 2019 through September 2019 to allow the parties to discuss potential resolution, no resolution was reached, and litigation resumed. In February and March 2020, the court heard arguments on numerous cross motions filed by the parties to seek legal determinations concerning several insurance related defenses raised by the insurance providers. Trial is scheduled for February 2021. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

Duke Energy Carolinas

Asbestos-related Injuries and Damages Claims

Duke Energy Carolinas has experienced numerous claims for indemnification and medical cost reimbursement related to asbestos exposure. These claims relate to damages for bodily injuries alleged to have arisen from exposure to or use of asbestos in connection with construction and maintenance activities conducted on its electric generation plants prior to 1985. As of March 31, 2020, there were 118 asserted claims for non-malignant cases with cumulative relief sought of up to $30 million, and 51 asserted claims for malignant cases with cumulative relief sought of up to $17 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 $596 million at March 31, 2020, and $604 million at December 31, 2019. 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 Duke Energy Carolinas' best estimate for current and future asbestos claims through 2039 and are recorded on an undiscounted basis. 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 2039 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-insured 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 $747 million in excess of the self-insured retention. Receivables for insurance recoveries were $742 million at March 31, 2020, and $742 million at December 31, 2019. 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 June 18, 2018, Duke Energy Progress and Duke Energy Florida sued the U.S. in the U.S. Court of Federal Claims for damages incurred for the period 2014 through 2018. 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 in the amount of $100 million and $203 million for Duke Energy Progress and Duke Energy Florida, respectively. Discovery is ongoing and a trial is expected to occur in early 2021.

Duke Energy Indiana

Coal Ash Basin Closure Plan Appeal

On January 27, 2020, Hoosier Environmental Council filed a Petition for Administrative Review with the Indiana Office of Environmental Adjudication (the court) challenging the Indiana Department of Environmental Management’s December 10, 2019, partial approval of Duke Energy Indiana’s ash pond closure plan. On March 11, 2020, Duke Energy Indiana filed a Motion to Dismiss. On May 5, 2020, the court entered an order denying that motion. The court will schedule a trial on the merits for a future date. Duke Energy Indiana cannot predict the outcome of this matter.

Other Litigation and Legal Proceedings

The Duke Energy Registrants are involved in other legal, tax and regulatory proceedings arising in the ordinary course of business, some of which involve significant amounts. The Duke Energy Registrants believe the final disposition of these proceedings will not have a material effect on their results of operations, cash flows or financial position.

The table below presents recorded reserves based on management’s best estimate of probable loss for legal matters, excluding asbestos-related reserves discussed above. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Other Noncurrent Liabilities and Other within Current Liabilities. The reasonably possible range of loss in excess of recorded reserves is not material, other than as described above.

(in millions)	March 31, 2020		December 31, 2019
Reserves for Legal Matters
Duke Energy	$	61	$	62
Duke Energy Carolinas	3		2
Progress Energy	52		55
Duke Energy Progress	9		12
Duke Energy Florida	23		22
Piedmont	1		1

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 uncapped 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 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.

As described in Note 1, Duke Energy adopted the new guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. The reserve for credit losses for insurance receivables based on adoption of the new standard is $15 million for Duke Energy and Duke Energy Carolinas. Insurance receivables are evaluated based on the risk of default and the historical losses, current conditions and expected conditions around collectability. Management evaluates the risk of default annually based on payment history, credit rating and changes in the risk of default from credit agencies.

The reserve for credit losses for financial guarantees based on adoption of the new standard is $99 million for Duke Energy. Management considers financial guarantees for evaluation under this standard based on the anticipated amount outstanding at the time of default. The reserve for credit losses is based on the evaluation of the contingent components of financial guarantees. Management evaluates the risk of default, exposure and length of time remaining in the period for each contract.

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Derivatives and Hedging

3 Months Ended

Mar. 31, 2020

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 derivatives 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 accumulated other comprehensive income (loss) for the three months ended March 31, 2020, and 2019, 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 and forward-starting interest rate swaps not accounted for under regulatory accounting.

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.

	March 31, 2020
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	991	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	2,027		400		1,600		1,050		550		27
Total notional amount(a)	$	3,018	$	400	$	1,600	$	1,050	$	550	$	27

	December 31, 2019
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio
Cash flow hedges	$	993	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	1,277		450		800		250		550		27
Total notional amount(a)	$	2,270	$	450	$	800	$	250	$	550	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $691 million in cash flow hedges as of March 31, 2020, and $693 million in cash flow hedges as of December 31, 2019.

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.

	March 31, 2020
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana	Piedmont
Electricity (GWh)	6,737	—	—	—	—	977	5,760	—
Natural gas (millions of dekatherms)	709	145	158	158	—	—	4	402

	December 31, 2019
		Duke		Duke	Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana	Piedmont
Electricity (GWh)	15,858	—	—	—	—	1,887	13,971	—
Natural gas (millions of dekatherms)	704	130	160	160	—	—	3	411

U.S. EQUITY SECURITIES RISK

In May 2019, Duke Energy Florida entered into a Decommissioning Services Agreement for the accelerated decommissioning of Crystal River Unit 3 with ADP CR3, LLC and ADP SF1, LLC. See Note 3 for additional information on the accelerated decommissioning. Duke Energy Florida executed U.S. equity option collars within the NDTF in May 2019 to preserve the U.S. equity portfolio value in the Duke Energy Florida NDTF in the event the accelerated decommissioning is approved. These option collars were executed as a purchase of a put option and the sale of a call option on certain U.S. equity index funds. The put and call options create a collar to guarantee a minimum and maximum investment value for the Duke Energy Florida NDTF U.S. equity portfolio. The put and call options were entered into at zero-cost, with the price to purchase the puts offset entirely by the funds received to sell the calls. As of March 31, 2020, the aggregate notional amount of both the put and call options was 305,000 units in U.S. equity security index funds. The options are not designated as hedging instruments. Substantially all of Duke Energy Florida’s NDTF qualifies for regulatory accounting. With regulatory accounting, the mark-to-market gains or losses on the options are deferred as regulatory liabilities or regulatory assets, respectively. The Duke Energy Florida NDTF liquidated the options in April 2020, and received proceeds of approximately $7 million.

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	March 31, 2020
			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	$	6	$	—	$	—	$	—	$	—	$	—	$	2	$	3
Noncurrent	4		2		1		1		—		1		—		—
Total Derivative Assets – Commodity Contracts	$	10	$	2	$	1	$	1	$	—	$	1	$	2	$	3
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	$	3	$	—	$	3	$	3	$	—	$	—	$	—	$	—
Noncurrent	1		—		1		1		—		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	4	$	—	$	4	$	4	$	—	$	—	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Noncurrent(a)	20		—		20		—		20		—		—		—
Total Derivative Assets – Equity Securities Contracts	$	20	$	—	$	20	$	—	$	20	$	—	$	—	$	—
Total Derivative Assets	$	34	$	2	$	25	$	5	$	20	$	1	$	2	$	3

(a) Equity security contracts are current since they were set to expire in May 2020 but are classified as noncurrent assets on the Condensed Consolidated Balance Sheet because the amount is presented within the NDTF.

Derivative Liabilities	March 31, 2020
			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	$	79	$	40	$	31	$	31	$	—	$	—	$	—	$	8
Noncurrent	130		11		35		20		—		—		—		83
Total Derivative Liabilities – Commodity Contracts	$	209	$	51	$	66	$	51	$	—	$	—	$	—	$	91
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	69	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	54		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	30		—		29		—		29		1		—		—
Noncurrent	28		23		—		—		—		6		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	181	$	23	$	29	$	—	$	29	$	7	$	—	$	—
Total Derivative Liabilities	$	390	$	74	$	95	$	51	$	29	$	7	$	—	$	91

Derivative Assets	December 31, 2019
			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	$	17	$	—	$	—	$	—	$	—	$	3	$	13	$	1
Noncurrent	1		—		—		—		—		1		—		—
Total Derivative Assets – Commodity Contracts	$	18	$	—	$	—	$	—	$	—	$	4	$	13	$	1
Interest Rate Contracts
Not Designated as Hedging Instruments
Current	6		—		6		—		6		—		—		—
Total Derivative Assets – Interest Rate Contracts	$	6	$	—	$	6	$	—	$	6	$	—	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Current	1		—		1		—		1		—		—		—
Total Derivative Assets – Equity Securities Contracts	$	1	$	—	$	1	$	—	$	1	$	—	$	—	$	—
Total Derivative Assets	$	25	$	—	$	7	$	—	$	7	$	4	$	13	$	1

Derivative Liabilities	December 31, 2019
			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	$	67	$	33	$	26	$	26	$	—	$	—	$	1	$	7
Noncurrent	156		10		37		22		—		—		—		110
Total Derivative Liabilities – Commodity Contracts	$	223	$	43	$	63	$	48	$	—	$	—	$	1	$	117
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	19	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	21		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	8		6		1		1		—		1		—		—
Noncurrent	5		—		—		—		—		5		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	53	$	6	$	1	$	1	$	—	$	6	$	—	$	—
Equity Securities Contracts
Not Designated as Hedging Instruments
Current	24		—		24		—		24		—		—		—
Total Derivative Liabilities – Equity Securities Contracts	$	24	$	—	$	24	$	—	$	24	$	—	$	—	$	—
Total Derivative Liabilities	$	300	$	49	$	88	$	49	$	24	$	6	$	1	$	117

OFFSETTING ASSETS AND LIABILITIES

The following tables present the line items on the Condensed Consolidated Balance Sheets where derivatives are reported. Substantially all of Duke Energy's outstanding derivative contracts are subject to enforceable master netting arrangements. The gross amounts offset in the tables below show the effect of these netting arrangements on financial position, and include collateral posted to offset the net position. The amounts shown are calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

Derivative Assets	March 31, 2020
				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	$	9		$	—		$	3		$	3		$	—	$	—	$	2	$	3
Gross amounts offset	—			—			—			—			—		—		—		—
Net amounts presented in Current Assets: Other	$	9		$	—		$	3		$	3		$	—	$	—	$	2	$	3
Noncurrent
Gross amounts recognized	$	25		$	2		$	22		$	2		$	20	$	1	$	—	$	—
Gross amounts offset	(3		)	(2		)	(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	2		$	—		$	1		$	1		$	—	$	1	$	—	$	—
Net amounts presented in NDTF	$	20		$	—		$	20		$	—		$	20	$	—	$	—	$	—

Derivative Liabilities	March 31, 2020
				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	$	178		$	40		$	60		$	31		$	29	$	1	$	—	$	8
Gross amounts offset	—			—			—			—			—		—		—		—
Net amounts presented in Current Liabilities: Other	$	178		$	40		$	60		$	31		$	29	$	1	$	—	$	8
Noncurrent
Gross amounts recognized	$	212		$	34		$	35		$	20		$	—	$	6	$	—	$	83
Gross amounts offset	(3		)	(2		)	(1		)	(1		)	—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	209		$	32		$	34		$	19		$	—	$	6	$	—	$	83

Derivative Assets	December 31, 2019
				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	$	24		$	—	$	7		$	—	$	7		$	3	$	13	$	1
Gross amounts offset	(1		)	—		(1		)	—		(1		)	—		—		—
Net amounts presented in Current Assets: Other	$	23		$	—	$	6		$	—	$	6		$	3	$	13	$	1
Noncurrent
Gross amounts recognized	$	1		$	—	$	—		$	—	$	—		$	1	$	—	$	—
Gross amounts offset	—			—		—			—		—			—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	1		$	—	$	—		$	—	$	—		$	1	$	—	$	—

Derivative Liabilities	December 31, 2019
				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	$	118		$	39	$	51		$	27	$	24		$	1	$	1	$	7
Gross amounts offset	(24		)	—		(24		)	—		(24		)	—		—		—
Net amounts presented in Current Liabilities: Other	$	94		$	39	$	27		$	27	$	—		$	1	$	1	$	7
Noncurrent
Gross amounts recognized	$	182		$	10	$	37		$	22	$	—		$	5	$	—	$	110
Gross amounts offset	—			—		—			—		—			—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	182		$	10	$	37		$	22	$	—		$	5	$	—	$	110

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.

	March 31, 2020
			Duke				Duke
	Duke		Energy		Progress		Energy
(in millions)	Energy		Carolinas		Energy		Progress
Aggregate fair value of derivatives in a net liability position	$	96	$	45	$	51	$	51
Fair value of collateral already posted	—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	96		45		51		51

	December 31, 2019
			Duke				Duke
	Duke		Energy		Progress		Energy
(in millions)	Energy		Carolinas		Energy		Progress
Aggregate fair value of derivatives in a net liability position	$	79	$	35	$	44	$	44
Fair value of collateral already posted	—		—		—		—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	79		35		44		44

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

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Investments in Debt and Equity Securities (Maturities) (Details) $ in Millions	Mar. 31, 2020 USD ($)
Debt Securities, Available-for-sale [Line Items]
Due in one year or less	$ 333
Due after one through five years	538
Due after five through 10 years	465
Due after 10 years	1,375
Total	2,711
Duke Energy Carolinas
Debt Securities, Available-for-sale [Line Items]
Due in one year or less	25
Due after one through five years	234
Due after five through 10 years	188
Due after 10 years	734
Total	1,181
Progress Energy
Debt Securities, Available-for-sale [Line Items]
Due in one year or less	302
Due after one through five years	236
Due after five through 10 years	214
Due after 10 years	541
Total	1,293
Duke Energy Progress
Debt Securities, Available-for-sale [Line Items]
Due in one year or less	26
Due after one through five years	227
Due after five through 10 years	207
Due after 10 years	506
Total	966
Duke Energy Florida
Debt Securities, Available-for-sale [Line Items]
Due in one year or less	276
Due after one through five years	9
Due after five through 10 years	7
Due after 10 years	35
Total	327
Duke Energy Indiana
Debt Securities, Available-for-sale [Line Items]
Due in one year or less	3
Due after one through five years	17
Due after five through 10 years	7
Due after 10 years	16
Total	$ 43

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Variable Interest Entities (Receivables Sold) (Details) - VIE not primary beneficiary - CRC - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Duke Energy Ohio
Variable Interest Entities [Line Items]
Receivables sold	$ 234	$ 253
Less: Retained interests	39	64
Net receivables sold	195	189
Duke Energy Indiana
Variable Interest Entities [Line Items]
Receivables sold	274	307
Less: Retained interests	48	77
Net receivables sold	$ 226	$ 230

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Variable Interest Entities (Schedule of Accounts Receivable Securitizations) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Variable Interest Entities [Line Items]
Long-Term Debt	$ 56,311	$ 54,985
Duke Energy Carolinas
Variable Interest Entities [Line Items]
Long-Term Debt	12,050	11,142
Duke Energy Progress
Variable Interest Entities [Line Items]
Long-Term Debt	7,903	7,902
Duke Energy Florida
Variable Interest Entities [Line Items]
Long-Term Debt	7,384	7,416
CRC | VIE primary beneficiary
Variable Interest Entities [Line Items]
Facility size	350
Long-Term Debt	350	350
Accounts receivable from securitization	467	522
DERF | Duke Energy Carolinas | VIE primary beneficiary
Variable Interest Entities [Line Items]
Facility size	475
Long-Term Debt	475	474
Accounts receivable from securitization	616	642
DEPR | Duke Energy Progress | VIE primary beneficiary
Variable Interest Entities [Line Items]
Facility size	375
Long-Term Debt	325	325
Accounts receivable from securitization	410	489
DEFR | Duke Energy Florida | VIE primary beneficiary
Variable Interest Entities [Line Items]
Facility size	250
Long-Term Debt	250	250
Accounts receivable from securitization	$ 331	$ 336

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Derivatives and Hedging (Schedule of Offsetting Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	$ 390	$ 300
Net amounts recognized on the Condensed Consolidated Balance Sheet	390	277
Current liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	178	118
Gross amounts offset		(24)
Net amounts recognized on the Condensed Consolidated Balance Sheet	178	94
Noncurrent liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	212	182
Gross amounts offset	(3)
Net amounts recognized on the Condensed Consolidated Balance Sheet	209	182
Duke Energy Carolinas
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	74	49
Net amounts recognized on the Condensed Consolidated Balance Sheet	74	49
Duke Energy Carolinas | Current liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	40	39
Net amounts recognized on the Condensed Consolidated Balance Sheet	40	39
Duke Energy Carolinas | Noncurrent liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	34	10
Gross amounts offset	(2)
Net amounts recognized on the Condensed Consolidated Balance Sheet	32	10
Progress Energy
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	95	88
Net amounts recognized on the Condensed Consolidated Balance Sheet	95	65
Progress Energy | Current liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	60	51
Gross amounts offset		(24)
Net amounts recognized on the Condensed Consolidated Balance Sheet	60	27
Progress Energy | Noncurrent liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	35	37
Gross amounts offset	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	34	37
Duke Energy Progress
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	51	49
Net amounts recognized on the Condensed Consolidated Balance Sheet	51	49
Duke Energy Progress | Current liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	31	27
Net amounts recognized on the Condensed Consolidated Balance Sheet	31	27
Duke Energy Progress | Noncurrent liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	20	22
Gross amounts offset	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	19	22
Duke Energy Florida
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	29	24
Net amounts recognized on the Condensed Consolidated Balance Sheet	29	1
Duke Energy Florida | Current liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	29	24
Gross amounts offset		(24)
Net amounts recognized on the Condensed Consolidated Balance Sheet	29
Duke Energy Ohio
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	7	6
Duke Energy Ohio | Current liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	1	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	1
Duke Energy Ohio | Noncurrent liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	6	5
Net amounts recognized on the Condensed Consolidated Balance Sheet	6	5
Duke Energy Indiana
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized		1
Net amounts recognized on the Condensed Consolidated Balance Sheet		1
Duke Energy Indiana | Current liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized		1
Net amounts recognized on the Condensed Consolidated Balance Sheet		1
Piedmont Natural Gas
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	91	117
Net amounts recognized on the Condensed Consolidated Balance Sheet	91	117
Piedmont Natural Gas | Current liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	8	7
Net amounts recognized on the Condensed Consolidated Balance Sheet	8	7
Piedmont Natural Gas | Noncurrent liabilities
Offsetting Derivative Liabilities [Abstract]
Gross amounts recognized	83	110
Net amounts recognized on the Condensed Consolidated Balance Sheet	$ 83	$ 110

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Regulatory Matters (Regulatory Matters Narrative - Duke Energy Ohio) (Details) $ in Millions							1 Months Ended		3 Months Ended		12 Months Ended
	Apr. 27, 2020 USD ($)	Jan. 31, 2020 USD ($)	Sep. 03, 2019 USD ($) MW	Apr. 13, 2018 USD ($)	Sep. 27, 2017 USD ($)	Sep. 26, 2017 USD ($)	Mar. 31, 2017 USD ($)	Dec. 31, 2015 USD ($)	Mar. 31, 2020 USD ($)	Mar. 31, 2019 USD ($)	Dec. 31, 2017 USD ($)	Jul. 12, 2019 USD ($)	Dec. 31, 2018 USD ($)	Sep. 28, 2018 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulated operating revenue, electric, non-nuclear									$ 5,124	$ 5,285
Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Regulated operating revenue, electric, non-nuclear									346	$ 355
Ohio Base Rate Case 2017 | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount							$ 15
Requested return on equity, percent							10.40%
Requested rate increase (decrease), amended amount				$ (19)
Requested rate increase (decrease) amended, percentage				9.84%
Public utilities, requested equity capital structure, percentage				50.75%
Public utilities, requested debt capital structure, percentage				49.25%
Approved rate increase (decrease), amount				$ (20)
Energy Efficiency Cost Recovery | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Regulated operating revenue, electric, non-nuclear								$ 20
MGP Cost Recovery - 2009 Through 2012 | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Regulatory assets									55
MGP Cost Recovery - 2013 Through 2017 | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Regulatory assets														$ 26
MGP Cost Recovery - 2018 | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Regulatory assets									39				$ 20
Duke Energy Kentucky Electric base rate case | KPSC | Duke Energy Kentucky
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount			$ 46
Requested rate increase (decrease), amended amount		$ 44
Requested rate increase, percentage			12.50%
Distribution battery energy storage system (in MW) | MW			3.4
Approved return on equity percentage	9.25%
Duke Energy Kentucky Electric base rate case, Kentucky Attorney General | KPSC | Duke Energy Kentucky
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount			$ 26
Minimum | Ohio Base Rate Case 2017 | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount						$ (18)
Requested return on equity, percent						9.22%
Minimum | Natural Gas Pipeline extension | OPSB | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Estimated capital cost excluding AFUDC									163
Maximum | Ohio Base Rate Case 2017 | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount						$ (29)
Requested return on equity, percent						10.24%
Requested Rider Revenue Increase				$ 10
Maximum | Energy Efficiency Cost Recovery | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount					$ 38
Approved rate increase (decrease), one-time waiver amount											$ 56
Maximum | Natural Gas Pipeline extension | OPSB | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Estimated capital cost excluding AFUDC									$ 245
MGP Costs - regulatory disallowance | MGP Cost Recovery - 2013 Through 2017 | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Regulatory assets														$ 12
MGP Costs - regulatory disallowance | MGP Cost Recovery - 2018 | PUCO | Duke Energy Ohio
Public Utilities, General Disclosures [Line Items]
Regulatory assets												$ 11
Subsequent event | Duke Energy Kentucky Electric base rate case | KPSC | Duke Energy Kentucky
Public Utilities, General Disclosures [Line Items]
Approved rate increase (decrease), amount	$ 24

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Condensed Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total		Preferred Stock	Common Stockholders' Equity		Common Stock	Additional Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive (Loss) Income, Net (Losses) Gains on Cash Flow Hedges		Accumulated Other Comprehensive (Loss) Income, Net Unrealized (Losses) Gains on Available-for-Sale-Securities		Accumulated Other Comprehensive (Loss) Income, Pension and OPEB Adjustments		Noncontrolling Interests		Duke Energy Carolinas		Duke Energy Carolinas Member's Equity		Duke Energy Carolinas Accumulated Other Comprehensive (Loss) Income, Net (Losses) Gains on Cash Flow Hedges		Progress Energy	Progress Energy Common Stockholders' Equity	Progress Energy Additional Paid-in Capital	Progress Energy Retained Earnings		Progress Energy Accumulated Other Comprehensive (Loss) Income, Net (Losses) Gains on Cash Flow Hedges		Progress Energy Accumulated Other Comprehensive (Loss) Income, Net Unrealized (Losses) Gains on Available-for-Sale-Securities	Progress Energy Accumulated Other Comprehensive (Loss) Income, Pension and OPEB Adjustments		Progress Energy Noncontrolling Interests	Duke Energy Progress	Duke Energy Progress Member's Equity	Duke Energy Florida	Duke Energy Florida Member's Equity	Duke Energy Florida Accumulated Other Comprehensive (Loss) Income, Net Unrealized (Losses) Gains on Available-for-Sale-Securities	Duke Energy Ohio	Duke Energy Ohio Common Stock	Duke Energy Ohio Additional Paid-in Capital	Duke Energy Ohio Retained Earnings	Duke Energy Indiana	Duke Energy Indiana Member's Equity	Piedmont Natural Gas	Piedmont Natural Gas Common Stock	Piedmont Natural Gas Retained Earnings	Preferred stock, Series A		Preferred stock, Series A Preferred Stock		Preferred stock, Series A Common Stockholders' Equity	[1]	Preferred stock, Series B	Common Stock	Common Stock Common Stockholders' Equity	Common Stock Common Stock	Common Stock Additional Paid-in Capital
Beginning Balance at Dec. 31, 2018	$ 43,834			$ 43,817		$ 1	$ 40,795		$ 3,113		$ (14)		$ (3)		$ (75)		$ 17								$ 14,257	$ 14,254	$ 9,143	$ 5,131		$ (12)		$ (1)	$ (7)		$ 3
Beginning Balance, in shares at Dec. 31, 2018						727,000,000
Beginning Balance (member's equity) at Dec. 31, 2018																			$ 11,683		$ 11,689		$ (6)														$ 8,441	$ 6,095	$ 6,097	$ (2)						$ 4,339
Beginning Balance (parent) at Dec. 31, 2018																																									$ 3,445	$ 762	$ 2,776	$ (93)			$ 2,091	$ 1,160	$ 931
Net income (attributable to parent)	900																		293		293				249											$ 203	203	96	96		69			69	$ 110	110	122		122
Net Income	893																								248	249		249							(1)
Net income	893			900					900								(7)
Other comprehensive income (loss)	(12)			(12)							(16)		4												3	3				2			1					1		1
Stock issuances																																																		$ 974	[1]	$ 974	[1]	$ 974			$ 28	$ 28		$ 28
Stock issuances, in shares																																																				40,000,000							1,000,000
Common stock dividends	(676)			(676)					(676)
Other	4	[2]		(1)	[2]				23	[2]	(6)	[2]	(1)	[2]	(17)	[2]	5	[2]	(1)				(1)					6	[3]	(4)	[3]		(2)	[3]
Ending Balance at Mar. 31, 2019	45,045		$ 974	45,030		$ 1	40,823		3,360		(36)				(92)		15								14,508	14,506	9,143	5,386		(14)		(1)	(8)		2
Ending Balance, in shares at Mar. 31, 2019						728,000,000
Ending Balance (member's equity) at Mar. 31, 2019																			11,975		11,982		(7)														8,644	6,192	6,193	(1)						4,449
Ending Balance (parent) at Mar. 31, 2019																																									$ 3,514	762	2,776	(24)			$ 2,213	1,160	1,053
Beginning Balance at Dec. 31, 2019	$ 47,951		1,962	46,822		$ 1	40,881		4,108		(51)		3		(82)		1,129								$ 15,593	15,590	9,143	6,465		(10)		(1)	(7)		3
Beginning Balance, in shares at Dec. 31, 2019	733,000,000					733,000,000																			100																90,000,000						100
Beginning Balance, in shares at Dec. 31, 2019																																																		40,000,000						1,000,000
Beginning Balance (member's equity) at Dec. 31, 2019																			12,811		12,818		(7)													9,246	9,246	6,788	6,789	(1)					4,575	4,575
Beginning Balance (parent) at Dec. 31, 2019	$ 46,822																								$ 15,590																$ 3,683	762	2,776	145			$ 2,443	1,310	1,133
Net income (attributable to parent)	938																		339		339				283											204	204	120	120		$ 65			65	99	99	178		178
Net Income	890																								283	283		283
Net income	851			899					899								(48)
Other comprehensive income (loss)	(77)	[4]		(63)							(65)		1		1		(14)								2	2				1		$ 1						1		$ 1
Stock issuances																																																									$ 50	$ 50		$ 50
Stock issuances, in shares																																																											2,000,000
Common stock dividends	(695)			(695)					(695)										(300)		(300)
Contribution from noncontrolling interest in subsidiaries	103																103
Distributions to noncontrolling interest in subsidiaries	(7)																(7)
Other	(93)	[5]		(92)	[5]		(1)	[5]	(91)	[5]							(1)	[5]	(13)	[6]	(13)	[6]	0	[6]	(1)	(1)		(1)																			$ (1)		(1)
Ending Balance at Mar. 31, 2020	$ 48,083		$ 1,962	$ 46,921		$ 1	$ 40,930		$ 4,221		$ (116)		$ 4		$ (81)		$ 1,162								$ 15,877	$ 15,874	$ 9,143	$ 6,747		$ (9)			$ (7)		$ 3
Ending Balance, in shares at Mar. 31, 2020																																																		40,000,000						1,000,000
Ending Balance, in shares at Mar. 31, 2020	735,000,000					735,000,000																			100																90,000,000						100
Ending Balance (member's equity) at Mar. 31, 2020																			$ 12,837		$ 12,844		$ (7)													$ 9,450	$ 9,450	$ 6,909	$ 6,909						$ 4,674	$ 4,674
Ending Balance (parent) at Mar. 31, 2020	$ 46,921																								$ 15,874																$ 3,748	$ 762	$ 2,776	$ 210			$ 2,620	$ 1,310	$ 1,310

[1] Duke Energy issued 40 million depositary shares of preferred stock, Series A.

[2] Amounts in Retained Earnings and Accumulated Other Comprehensive (Loss) Income primarily represent impacts to accumulated other comprehensive income due to implementation of a new accounting standard related to Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.

[3] Amounts in Retained Earnings and Accumulated Other Comprehensive Loss primarily represent impacts to accumulated other comprehensive income due to implementation of a new accounting standard related to Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.

[4] Net of income tax impact of approximately $23 million in the first quarter of 2020 and immaterial income tax impact in the first quarter of 2019.

[5] Amounts in Retained earnings primarily represent impacts due to implementation of a new accounting standard related to Current Estimated Credit Losses. See Note 1 for additional discussion.

[6] Amounts primarily represent impacts due to implementation of a new accounting standard related to Current Estimated Credit Losses. See Note 1 for additional discussion.

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Regulatory Matters (Schedule of Net Carrying Value Of Facilities and Megawatt Capacity) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($) MW	Dec. 31, 2019 USD ($)
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net	$ 103,108	$ 102,127
Duke Energy Carolinas
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net	32,650	32,397
Duke Energy Indiana
Public Utilities, General Disclosures [Line Items]
Public utilities, property, plant and equipment, net	$ 11,132	$ 11,072
Generation facilities to be retired
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	5,002
Public utilities, property, plant and equipment, net	$ 2,939
Allen Steam Station Units 1-3 | Generation facilities to be retired | Duke Energy Carolinas
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	585
Public utilities, property, plant and equipment, net	$ 149
Gallagher Units 2 and 4 | Generation facilities to be retired | Duke Energy Indiana
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	280
Public utilities, property, plant and equipment, net	$ 118
Gibson Units 1-5 | Generation facilities to be retired | Duke Energy Indiana
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	3,132
Public utilities, property, plant and equipment, net	$ 1,708
Cayuga Units 1-2 | Generation facilities to be retired | Duke Energy Indiana
Public Utilities, General Disclosures [Line Items]
Capacity (in MW) | MW	1,005
Public utilities, property, plant and equipment, net	$ 964

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Debt and Credit Facilities (Summary of Debt Issuances) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Debt Instrument [Line Items]
Debt issuances	$ 3,138,000,000
Repayments of long-term debt	292,000,000	$ 1,201,000,000
Duke Energy Carolinas
Debt Instrument [Line Items]
Debt issuances	900,000,000
Repayments of long-term debt	2,000,000	1,000,000
Duke Energy Carolinas | First Mortgage Bonds
Debt Instrument [Line Items]
Repayments of long-term debt	450,000,000
Duke Energy Indiana
Debt Instrument [Line Items]
Debt issuances	550,000,000
Repayments of long-term debt		$ 60,000,000
Duke Energy Indiana | First Mortgage Bonds
Debt Instrument [Line Items]
Repayments of long-term debt	$ 500,000,000
Unsecured Debt | March 2020 1.400% Due March 2021
Debt Instrument [Line Items]
Interest Rate	1.40%
Debt issuances	$ 1,688,000,000
First Mortgage Bonds | January 2020 2.450% Due 2030
Debt Instrument [Line Items]
Interest Rate	2.45%
Debt issuances	$ 500,000,000
First Mortgage Bonds | January 2020 3.20% Due 2049
Debt Instrument [Line Items]
Interest Rate	3.20%
Debt issuances	$ 400,000,000
First Mortgage Bonds | March 2020 2.750% Due 2050
Debt Instrument [Line Items]
Interest Rate	2.75%
Debt issuances	$ 550,000,000
First Mortgage Bonds | Duke Energy Carolinas | January 2020 2.450% Due 2030
Debt Instrument [Line Items]
Debt issuances	500,000,000
First Mortgage Bonds | Duke Energy Carolinas | January 2020 3.20% Due 2049
Debt Instrument [Line Items]
Debt issuances	400,000,000
First Mortgage Bonds | Duke Energy Indiana | March 2020 2.750% Due 2050
Debt Instrument [Line Items]
Debt issuances	550,000,000
Duke Energy (Parent) | Duke Energy (Parent)
Debt Instrument [Line Items]
Debt issuances	1,688,000,000
Duke Energy (Parent) | Unsecured Debt | Duke Energy (Parent) | March 2020 1.400% Due March 2021
Debt Instrument [Line Items]
Debt issuances	$ 1,688,000,000

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Condensed Consolidated Statements of Comprehensive Income (Parenthetical) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($)
Statement of Comprehensive Income [Abstract]
Other comprehensive income (loss), tax	$ 23

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Business Segments (Business Segment Data) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Segment Reporting Information [Line Items]
Operating revenues	$ 5,949	$ 6,163
Segment income (loss)	899	900
Add: Noncontrolling interests	(48)	(7)
Add: Preferred stock dividend	39
Net Income	890	893
Segment assets	160,072		$ 158,838
Electric Utilities and Infrastructure
Segment Reporting Information [Line Items]
Operating revenues	5,174	5,321
Gas Utilities and Infrastructure
Segment Reporting Information [Line Items]
Operating revenues	640	732
Commercial Renewables
Segment Reporting Information [Line Items]
Operating revenues	129	106
Total Reportable Segments
Segment Reporting Information [Line Items]
Operating revenues	5,943	6,159
Other
Segment Reporting Information [Line Items]
Operating revenues	6	4
Operating Segments | Electric Utilities and Infrastructure
Segment Reporting Information [Line Items]
Operating revenues	5,183	5,329
Segment income (loss)	705	750
Segment assets	134,838
Operating Segments | Gas Utilities and Infrastructure
Segment Reporting Information [Line Items]
Operating revenues	664	756
Segment income (loss)	249	226
Segment assets	14,098
Operating Segments | Commercial Renewables
Segment Reporting Information [Line Items]
Operating revenues	129	106
Segment income (loss)	57	13
Segment assets	6,184
Operating Segments | Total Reportable Segments
Segment Reporting Information [Line Items]
Operating revenues	5,976	6,191
Segment income (loss)	1,011	989
Segment assets	155,120
Other | Other
Segment Reporting Information [Line Items]
Operating revenues	23	21
Segment income (loss)	(112)	(89)
Segment assets	4,964
Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(50)	(49)
Segment assets	(12)
Eliminations | Electric Utilities and Infrastructure
Segment Reporting Information [Line Items]
Operating revenues	9	8
Eliminations | Gas Utilities and Infrastructure
Segment Reporting Information [Line Items]
Operating revenues	24	24
Eliminations | Total Reportable Segments
Segment Reporting Information [Line Items]
Operating revenues	33	32
Eliminations | Other
Segment Reporting Information [Line Items]
Operating revenues	17	17
Duke Energy Carolinas
Segment Reporting Information [Line Items]
Operating revenues	1,748	1,744
Segment assets	44,051		44,053
Duke Energy Carolinas | Other
Segment Reporting Information [Line Items]
Segment income (loss)	98
Duke Energy Ohio
Segment Reporting Information [Line Items]
Operating revenues	498	531
Segment income (loss)	65	69
Segment assets	9,397		$ 9,338
Duke Energy Ohio | Operating Segments
Segment Reporting Information [Line Items]
Operating revenues		531
Segment income (loss)		71
Duke Energy Ohio | Operating Segments | Electric Utilities and Infrastructure
Segment Reporting Information [Line Items]
Operating revenues	346	355
Segment income (loss)	30	36
Segment assets	6,238
Duke Energy Ohio | Operating Segments | Gas Utilities and Infrastructure
Segment Reporting Information [Line Items]
Operating revenues	152	176
Segment income (loss)	36	35
Segment assets	3,135
Duke Energy Ohio | Operating Segments | Total Reportable Segments
Segment Reporting Information [Line Items]
Operating revenues	498
Segment income (loss)	66
Segment assets	9,373
Duke Energy Ohio | Other
Segment Reporting Information [Line Items]
Segment income (loss)		$ (2)
Duke Energy Ohio | Other | Other
Segment Reporting Information [Line Items]
Segment income (loss)	(1)
Segment assets	26
Duke Energy Ohio | Eliminations
Segment Reporting Information [Line Items]
Segment assets	$ (2)

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Organization and Basis of Presentation (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Noncontrolling Interest [Line Items]
Sale of noncontrolling interests	$ 103	$ 6
Net Income (Loss) Allocation to Noncontrolling Tax Equity Members	$ 49	$ 7

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Derivatives and Hedging (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended
	Apr. 30, 2020	Mar. 31, 2020
Call option
Derivative [Line Items]
Aggregate notional amount		305,000
Put option
Derivative [Line Items]
Aggregate notional amount		305,000
Not Designated as Hedging Instruments | Duke Energy Florida | Equity Securities Contracts | Subsequent event
Derivative [Line Items]
Proceeds liquidation of options	$ 7

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Debt and Credit Facilities (Narrative) (Details) - Master Credit Facility	Mar. 31, 2020 USD ($)
Debt Instrument [Line Items]
Facility size	$ 8,000,000,000
Duke Energy Carolinas
Debt Instrument [Line Items]
Facility size	1,500,000,000
Duke Energy Carolinas | USDOJ | North Carolina ash basins
Debt Instrument [Line Items]
Minimum master credit facility balance required	$ 250,000,000

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Revenue (Reserve for Credit Losses for Trade and Other Receivables) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($)
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	$ 76
Cumulative Change in Accounting Principle	89
Write-Offs	(10)
Credit Loss Expense	18
Balance at March 31, 2020	89
Duke Energy Carolinas
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	10
Cumulative Change in Accounting Principle	11
Write-Offs	(3)
Credit Loss Expense	3
Balance at March 31, 2020	11
Progress Energy
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	16
Cumulative Change in Accounting Principle	20
Write-Offs	(4)
Credit Loss Expense	6
Balance at March 31, 2020	20
Duke Energy Progress
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	8
Cumulative Change in Accounting Principle	9
Write-Offs	(2)
Credit Loss Expense	2
Balance at March 31, 2020	9
Duke Energy Florida
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	7
Cumulative Change in Accounting Principle	11
Write-Offs	(2)
Credit Loss Expense	5
Balance at March 31, 2020	11
Duke Energy Ohio
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	4
Cumulative Change in Accounting Principle	5
Credit Loss Expense	1
Balance at March 31, 2020	5
Duke Energy Indiana
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	3
Cumulative Change in Accounting Principle	3
Balance at March 31, 2020	3
Piedmont Natural Gas
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	6
Cumulative Change in Accounting Principle	9
Write-Offs	(1)
Credit Loss Expense	3
Balance at March 31, 2020	9
Cumulative Change in Accounting Principle
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	5
Cumulative Change in Accounting Principle	5
Cumulative Change in Accounting Principle | Duke Energy Carolinas
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	1
Cumulative Change in Accounting Principle	1
Cumulative Change in Accounting Principle | Progress Energy
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	2
Cumulative Change in Accounting Principle	2
Cumulative Change in Accounting Principle | Duke Energy Progress
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	1
Cumulative Change in Accounting Principle	1
Cumulative Change in Accounting Principle | Duke Energy Florida
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	1
Cumulative Change in Accounting Principle	1
Cumulative Change in Accounting Principle | Piedmont Natural Gas
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance at December 31, 2019	1
Cumulative Change in Accounting Principle	$ 1

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Stockholders' Equity (Common Stock) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Billions	1 Months Ended
	Mar. 31, 2020	Nov. 30, 2019
Forward Contract Indexed to Issuer's Equity [Line Items]
Maximum value of shares to be issued under ATM program		$ 1.5
Equity forwards
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares offered	940	28,750
Forward contract indexed to issuer's equity, forward rate per share	$ 89.76	$ 85.99

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Goodwill (Narrative) (Details) - USD ($)	Mar. 31, 2020	Dec. 31, 2019
Goodwill [Line Items]
Goodwill	$ 19,303,000,000	$ 19,303,000,000
Accumulated impairment charges	122,000,000	122,000,000
Electric Utilities and Infrastructure
Goodwill [Line Items]
Goodwill	17,379,000,000	17,379,000,000
Gas Utilities and Infrastructure
Goodwill [Line Items]
Goodwill	1,924,000,000	1,924,000,000
Duke Energy Ohio
Goodwill [Line Items]
Goodwill	920,000,000	920,000,000
Accumulated impairment charges	216,000,000	216,000,000
Duke Energy Ohio | Electric Utilities and Infrastructure
Goodwill [Line Items]
Goodwill	596,000,000	596,000,000
Duke Energy Ohio | Gas Utilities and Infrastructure
Goodwill [Line Items]
Goodwill	324,000,000	324,000,000
Progress Energy
Goodwill [Line Items]
Goodwill	3,655,000,000	3,655,000,000
Accumulated impairment charges	0	0
Piedmont Natural Gas
Goodwill [Line Items]
Goodwill	49,000,000	49,000,000
Accumulated impairment charges	$ 0	$ 0

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Employee Benefit Plans

3 Months Ended

Mar. 31, 2020

Retirement Benefits [Abstract]

Employee Benefit Plans

EMPLOYEE BENEFIT PLANS

DEFINED BENEFIT RETIREMENT PLANS

Duke Energy and certain subsidiaries maintain, 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.

QUALIFIED PENSION PLANS

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

	Three Months Ended March 31, 2020
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	41		$	12		$	12		$	6		$	5		$	1		$	2		$	1
Interest cost on projected benefit obligation	67			16			21			10			12			4			6			2
Expected return on plan assets	(143		)	(36		)	(48		)	(22		)	(25		)	(7		)	(11		)	(5		)
Amortization of actuarial loss	34			7			11			5			6			2			3			2
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(2		)
Amortization of settlement charges	2			1			1			—			—			—			—			—
Net periodic pension costs	$	(7	)	$	(2	)	$	(4	)	$	(1	)	$	(2	)	$	—		$	—		$	(2	)

	Three Months Ended March 31, 2019
				Duke						Duke			Duke			Duke			Duke
	Duke			Energy			Progress			Energy			Energy			Energy			Energy
(in millions)	Energy			Carolinas			Energy			Progress			Florida			Ohio			Indiana			Piedmont
Service cost	$	37		$	12		$	11		$	6		$	4		$	1		$	2		$	1
Interest cost on projected benefit obligation	83			20			26			12			14			5			6			3
Expected return on plan assets	(143		)	(38		)	(44		)	(23		)	(22		)	(8		)	(11		)	(5		)
Amortization of actuarial loss	24			6			9			3			6			1			2			2
Amortization of prior service credit	(8		)	(2		)	(1		)	—			—			—			—			(3		)
Net periodic pension costs	$	(7	)	$	(2	)	$	1		$	(2	)	$	2		$	(1	)	$	(1	)	$	(2	)

NON-QUALIFIED PENSION PLANS

Net periodic pension costs for non-qualified pension plans were not material for the three months ended March 31, 2020, and 2019.

OTHER POST-RETIREMENT BENEFIT PLANS

Net periodic costs for other post-retirement benefit plans were not material for the three months ended March 31, 2020, and 2019.

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Organization and Basis of Presentation (Tables)

3 Months Ended

Mar. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

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.

	March 31, 2020						December 31, 2019
					Duke						Duke
	Duke		Progress		Energy		Duke		Progress		Energy
	Energy		Energy		Florida		Energy		Energy		Florida
Current Assets
Cash and cash equivalents	$	1,450	$	52	$	12	$	311	$	48	$	17
Other	185		13		13		222		39		39
Other Noncurrent Assets
Other	63		60		—		40		39		—
Total cash, cash equivalents and restricted cash	$	1,698	$	125	$	25	$	573	$	126	$	56

Schedule of Utility Inventory

The components of inventory are presented in the tables below.

	March 31, 2020
			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	$	2,280	$	759	$	1,018	$	678	$	340	$	83	$	319	$	5
Coal	742		268		246		167		79		10		218		—
Natural gas, oil and other fuel	302		40		199		111		89		28		1		34
Total inventory	$	3,324	$	1,067	$	1,463	$	956	$	508	$	121	$	538	$	39

	December 31, 2019
			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	$	2,297	$	768	$	1,038	$	686	$	351	$	79	$	318	$	5
Coal	586		187		186		138		48		15		198		—
Natural gas, oil and other fuel	349		41		199		110		90		41		1		67
Total inventory	$	3,232	$	996	$	1,423	$	934	$	489	$	135	$	517	$	72

Schedule of New Accounting Pronouncements

Duke Energy recorded an adjustment for the cumulative effect of a change in accounting principle due to the adoption of this standard on January 1, 2020, as shown in the table below:

	January 1, 2020
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Piedmont
Total pretax impact to Retained Earnings	$	120	$	16	$	2	$	1	$	1	$	1

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Fair Value Measurements

3 Months Ended

Mar. 31, 2020

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 as defined by GAAP. 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.

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 the 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. 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 12 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2019, 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 8. See Note 9 for additional information related to investments by major security type for the Duke Energy Registrants.

	March 31, 2020
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	4,488		$	4,440		$	—		$	—		$	48
NDTF debt securities	2,540			767			1,773			—			—
Other equity securities	95			95			—			—			—
Other debt securities	368			126			242			—			—
NDTF equity security contracts	20			—			20			—			—
Derivative assets	34			3			28			3			—
Total assets	7,545			5,431			2,063			3			48
Derivative liabilities	(390		)	(49		)	(250		)	(91		)	—
Net assets (liabilities)	$	7,155		$	5,382		$	1,813		$	(88	)	$	48

	December 31, 2019
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	5,684		$	5,633		$	—		$	—		$	51
NDTF debt securities	2,469			826			1,643			—			—
Other equity securities	122			122			—			—			—
Other debt securities	310			91			219			—			—
Derivative assets	25			3			7			15			—
Total assets	8,610			6,675			1,869			15			51
NDTF equity security contracts	(23		)	—			(23		)	—			—
Derivative liabilities	(277		)	(15		)	(145		)	(117		)	—
Net assets (liabilities)	$	8,310		$	6,660		$	1,701		$	(102	)	$	51

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

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	(102	)	$	(113	)
Purchases, sales, issuances and settlements:
Settlements		(9		)	(12		)
Total gains included on the Condensed Consolidated Balance Sheet		23			10
Balance at end of period		$	(88	)	$	(115	)

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.

	March 31, 2020
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	2,498		$	2,450	$	—		$	48
NDTF debt securities	1,214			182		1,032			—
Derivative assets	2			—		2			—
Total assets	3,714			2,632		1,034			48
Derivative liabilities	(74		)	—		(74		)	—
Net assets	$	3,640		$	2,632	$	960		$	48

	December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	3,154		$	3,103	$	—		$	51
NDTF debt securities	1,193			227		966			—
Total assets	4,347			3,330		966			51
Derivative liabilities	(49		)	—		(49		)	—
Net assets	$	4,298		$	3,330	$	917		$	51

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	1,990		$	1,990	$	—		$	2,530		$	2,530	$	—
NDTF debt securities	1,326			585		741			1,276			599		677
Other debt securities	122			69		53			100			49		51
NDTF equity security contracts	20			—		20			—			—		—
Derivative assets	25			—		25			7			—		7
Total assets	3,483			2,644		839			3,913			3,178		735
NDTF equity security contracts	—			—		—			(23		)	—		(23		)
Derivative liabilities	(95		)	—		(95		)	(65		)	—		(65		)
Net assets	$	3,388		$	2,644	$	744		$	3,825		$	3,178	$	647

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	1,631		$	1,631	$	—		$	2,077		$	2,077	$	—
NDTF debt securities	1,017			276		741			974			297		677
Other debt securities	2			2		—			2			2		—
Derivative assets	5			—		5			—			—		—
Total assets	2,655			1,909		746			3,053			2,376		677
Derivative liabilities	(51		)	—		(51		)	(49		)	—		(49		)
Net assets	$	2,604		$	1,909	$	695		$	3,004		$	2,376	$	628

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	359		$	359	$	—		$	453		$	453	$	—
NDTF debt securities	309			309		—			302			302		—
Other debt securities	56			3		53			55			4		51
NDTF equity security contracts	20			—		20			—			—		—
Derivative assets	—			—		—			7			—		7
Total assets	744			671		73			817			759		58
NDTF equity security contracts	—			—		—			(23		)	—		(23		)
Derivative liabilities	(29		)	—		(29		)	(1		)	—		(1		)
Net assets	$	715		$	671	$	44		$	793		$	759	$	34

DUKE ENERGY OHIO

The recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets were not material at March 31, 2020, and December 31, 2019.

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Total Fair Value			Level 1			Level 2		Level 3
Other equity securities	$	63	$	63	$	—	$	—	$	81		$	81		$	—	$	—
Other debt securities	43		—		43		—		44			—			44		—
Derivative assets	2		—		—		2		13			2			—		11
Total assets	$	108	$	63	$	43	$	2	$	138		$	83		$	44	$	11
Derivative liabilities	—		—		—		—		(1		)	(1		)	—		—
Net assets	$	108	$	63	$	43	$	2	$	137		$	82		$	44	$	11

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

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	11		$	22
Purchases, sales, issuances and settlements:
Settlements		(6		)	(10		)
Total losses included on the Condensed Consolidated Balance Sheet		(3		)	(7		)
Balance at end of period		$	2		$	5

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 3			Total Fair Value			Level 1		Level 3
Derivative assets	$	3		$	3	$	—		$	1		$	1	$	—
Derivative liabilities	(91		)	—		(91		)	(117		)	—		(117		)
Net (liabilities) assets	$	(88	)	$	3	$	(91	)	$	(116	)	$	1	$	(117	)

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

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	(117	)	$	(141	)
Total gains and settlements		26			20
Balance at end of period		$	(91	)	$	(121	)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

	March 31, 2020
												Weighted
	Fair Value											Average
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range						Range
Duke Energy Ohio
FTRs	$	1		RTO auction pricing	FTR price – per MWh	$	0.04		-	$	3.29	$	1.03
Duke Energy Indiana
FTRs	2			RTO auction pricing	FTR price – per MWh	(0.37		)	-	6.06		0.54
Piedmont
Natural gas contracts	(91		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	1.64			-	2.41		1.94
Duke Energy
Total Level 3 derivatives	$	(88	)

	December 31, 2019
												Weighted
	Fair Value											Average
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range						Range
Duke Energy Ohio
FTRs	$	4		RTO auction pricing	FTR price – per MWh	$	0.59		-	$	3.47	$	2.07
Duke Energy Indiana
FTRs	11			RTO auction pricing	FTR price – per MWh	(0.66		)	-	9.24		1.15
Piedmont
Natural gas contracts	(117		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	1.59			-	2.46		1.91
Duke Energy
Total Level 3 derivatives	$	(102	)

OTHER FAIR VALUE DISCLOSURES

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

	March 31, 2020				December 31, 2019
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy(a)	$	61,388	$	65,644	$	58,126	$	63,062
Duke Energy Carolinas	12,807		14,312		11,900		13,516
Progress Energy	19,355		21,802		19,634		22,291
Duke Energy Progress	9,059		9,798		9,058		9,934
Duke Energy Florida	7,706		8,831		7,987		9,131
Duke Energy Ohio	2,620		2,904		2,619		2,964
Duke Energy Indiana	4,603		5,433		4,057		4,800
Piedmont	2,385		2,551		2,384		2,642

(a) Book value of long-term debt includes $1.4 billion at March 31, 2020, and $1.5 billion at December 31, 2019, of unamortized debt discount and premium, net of purchase accounting adjustments related to the mergers with Progress Energy and Piedmont that are excluded from fair value of long-term debt.

At both March 31, 2020, and December 31, 2019, fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper and nonrecourse notes payable of VIEs are not materially different from their carrying amounts because of the short-term nature of these instruments and/or because the stated rates approximate market rates.

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Business Segments

3 Months Ended

Mar. 31, 2020

Segment Reporting [Abstract]

Business Segments

BUSINESS SEGMENTS

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 primarily includes Duke Energy's regulated electric utilities in the Carolinas, Florida and the Midwest. 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. The Commercial Renewables segment 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, Duke Energy’s wholly owned captive insurance company, Bison, and Duke Energy's interest in National Methanol Company.

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

	Three Months Ended March 31, 2020
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Total
Unaffiliated revenues	$	5,174	$	640	$	129	$	5,943	$	6		$	—		$	5,949
Intersegment revenues	9		24		—		33		17			(50		)	—
Total revenues	$	5,183	$	664	$	129	$	5,976	$	23		$	(50	)	$	5,949
Segment income (loss)(a)	$	705	$	249	$	57	$	1,011	$	(112	)	$	—		$	899
Add: Noncontrolling interests(b)															(48		)
Add: Preferred stock dividend															39
Net income															$	890
Segment assets	$	134,838	$	14,098	$	6,184	$	155,120	$	4,964		$	(12	)	$	160,072

	Three Months Ended March 31, 2019
	Electric		Gas				Total
	Utilities and		Utilities and		Commercial		Reportable
(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other			Eliminations			Total
Unaffiliated revenues	$	5,321	$	732	$	106	$	6,159	$	4		$	—		$	6,163
Intersegment revenues	8		24		—		32		17			(49		)	—
Total revenues	$	5,329	$	756	$	106	$	6,191	$	21		$	(49	)	$	6,163
Segment income (loss)	$	750	$	226	$	13	$	989	$	(89	)	$	—		$	900
Add: Noncontrolling interests(b)															(7		)
Net income															$	893

(a) Other includes a $98 million reversal, included in Operations, maintenance and other on the Condensed Consolidated Statements of Operations, of 2018 severance costs due to the partial settlement of the Duke Energy Carolina's 2019 North Carolina rate case. See Note 3 for additional information.

(b)

Includes the allocation of losses to noncontrolling tax equity members. See Note 1 for additional information.

Duke Energy Ohio

Duke Energy Ohio has two reportable segments, Electric Utilities and Infrastructure and Gas Utilities and Infrastructure. The remainder of Duke Energy Ohio's operations is presented as Other.

	Three Months Ended March 31, 2020
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Eliminations			Total
Total revenues	$	346	$	152	$	498	$	—		$	—		$	498
Segment income/Net (loss) income	$	30	$	36	$	66	$	(1	)	$	—		$	65
Segment assets	$	6,238	$	3,135	$	9,373	$	26		$	(2	)	$	9,397

	Three Months Ended March 31, 2019
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other			Total
Total revenues	$	355	$	176	$	531	$	—		$	531
Segment income/Net (loss) income	$	36	$	35	$	71	$	(2	)	$	69

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Goodwill

3 Months Ended

Mar. 31, 2020

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill

GOODWILL

Duke Energy

The following table presents the goodwill by reportable segment included on Duke Energy's Condensed Consolidated Balance Sheets at March 31, 2020, and December 31, 2019.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables			Total
Goodwill balance	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(122		)	(122		)
Goodwill, 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 March 31, 2020, and December 31, 2019.

Progress Energy

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

Piedmont

Piedmont's Goodwill is included in the Gas Utilities and Infrastructure segment and there are no accumulated impairment charges.

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2020

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 8. See Note 9 for additional information related to investments by major security type for the Duke Energy Registrants.

	March 31, 2020
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	4,488		$	4,440		$	—		$	—		$	48
NDTF debt securities	2,540			767			1,773			—			—
Other equity securities	95			95			—			—			—
Other debt securities	368			126			242			—			—
NDTF equity security contracts	20			—			20			—			—
Derivative assets	34			3			28			3			—
Total assets	7,545			5,431			2,063			3			48
Derivative liabilities	(390		)	(49		)	(250		)	(91		)	—
Net assets (liabilities)	$	7,155		$	5,382		$	1,813		$	(88	)	$	48

	December 31, 2019
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Not Categorized
NDTF equity securities	$	5,684		$	5,633		$	—		$	—		$	51
NDTF debt securities	2,469			826			1,643			—			—
Other equity securities	122			122			—			—			—
Other debt securities	310			91			219			—			—
Derivative assets	25			3			7			15			—
Total assets	8,610			6,675			1,869			15			51
NDTF equity security contracts	(23		)	—			(23		)	—			—
Derivative liabilities	(277		)	(15		)	(145		)	(117		)	—
Net assets (liabilities)	$	8,310		$	6,660		$	1,701		$	(102	)	$	51

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.

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	(102	)	$	(113	)
Purchases, sales, issuances and settlements:
Settlements		(9		)	(12		)
Total gains included on the Condensed Consolidated Balance Sheet		23			10
Balance at end of period		$	(88	)	$	(115	)

Quantitative Information Table - Level 3

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

	March 31, 2020
												Weighted
	Fair Value											Average
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range						Range
Duke Energy Ohio
FTRs	$	1		RTO auction pricing	FTR price – per MWh	$	0.04		-	$	3.29	$	1.03
Duke Energy Indiana
FTRs	2			RTO auction pricing	FTR price – per MWh	(0.37		)	-	6.06		0.54
Piedmont
Natural gas contracts	(91		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	1.64			-	2.41		1.94
Duke Energy
Total Level 3 derivatives	$	(88	)

	December 31, 2019
												Weighted
	Fair Value											Average
Investment Type	(in millions)			Valuation Technique	Unobservable Input	Range						Range
Duke Energy Ohio
FTRs	$	4		RTO auction pricing	FTR price – per MWh	$	0.59		-	$	3.47	$	2.07
Duke Energy Indiana
FTRs	11			RTO auction pricing	FTR price – per MWh	(0.66		)	-	9.24		1.15
Piedmont
Natural gas contracts	(117		)	Discounted cash flow	Forward natural gas curves – price per MMBtu	1.59			-	2.46		1.91
Duke Energy
Total Level 3 derivatives	$	(102	)

Schedule Of Long Term Debt Fair Value

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

	March 31, 2020				December 31, 2019
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy(a)	$	61,388	$	65,644	$	58,126	$	63,062
Duke Energy Carolinas	12,807		14,312		11,900		13,516
Progress Energy	19,355		21,802		19,634		22,291
Duke Energy Progress	9,059		9,798		9,058		9,934
Duke Energy Florida	7,706		8,831		7,987		9,131
Duke Energy Ohio	2,620		2,904		2,619		2,964
Duke Energy Indiana	4,603		5,433		4,057		4,800
Piedmont	2,385		2,551		2,384		2,642

(a)

Book value of long-term debt includes $1.4 billion at March 31, 2020, and $1.5 billion at December 31, 2019, of unamortized debt discount and premium, net of 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

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.

	March 31, 2020
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	2,498		$	2,450	$	—		$	48
NDTF debt securities	1,214			182		1,032			—
Derivative assets	2			—		2			—
Total assets	3,714			2,632		1,034			48
Derivative liabilities	(74		)	—		(74		)	—
Net assets	$	3,640		$	2,632	$	960		$	48

	December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Not Categorized
NDTF equity securities	$	3,154		$	3,103	$	—		$	51
NDTF debt securities	1,193			227		966			—
Total assets	4,347			3,330		966			51
Derivative liabilities	(49		)	—		(49		)	—
Net assets	$	4,298		$	3,330	$	917		$	51

Progress Energy

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	1,990		$	1,990	$	—		$	2,530		$	2,530	$	—
NDTF debt securities	1,326			585		741			1,276			599		677
Other debt securities	122			69		53			100			49		51
NDTF equity security contracts	20			—		20			—			—		—
Derivative assets	25			—		25			7			—		7
Total assets	3,483			2,644		839			3,913			3,178		735
NDTF equity security contracts	—			—		—			(23		)	—		(23		)
Derivative liabilities	(95		)	—		(95		)	(65		)	—		(65		)
Net assets	$	3,388		$	2,644	$	744		$	3,825		$	3,178	$	647

Duke Energy Progress

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	1,631		$	1,631	$	—		$	2,077		$	2,077	$	—
NDTF debt securities	1,017			276		741			974			297		677
Other debt securities	2			2		—			2			2		—
Derivative assets	5			—		5			—			—		—
Total assets	2,655			1,909		746			3,053			2,376		677
Derivative liabilities	(51		)	—		(51		)	(49		)	—		(49		)
Net assets	$	2,604		$	1,909	$	695		$	3,004		$	2,376	$	628

Duke Energy Florida

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 2			Total Fair Value			Level 1		Level 2
NDTF equity securities	$	359		$	359	$	—		$	453		$	453	$	—
NDTF debt securities	309			309		—			302			302		—
Other debt securities	56			3		53			55			4		51
NDTF equity security contracts	20			—		20			—			—		—
Derivative assets	—			—		—			7			—		7
Total assets	744			671		73			817			759		58
NDTF equity security contracts	—			—		—			(23		)	—		(23		)
Derivative liabilities	(29		)	—		(29		)	(1		)	—		(1		)
Net assets	$	715		$	671	$	44		$	793		$	759	$	34

Duke Energy Indiana

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Total Fair Value			Level 1			Level 2		Level 3
Other equity securities	$	63	$	63	$	—	$	—	$	81		$	81		$	—	$	—
Other debt securities	43		—		43		—		44			—			44		—
Derivative assets	2		—		—		2		13			2			—		11
Total assets	$	108	$	63	$	43	$	2	$	138		$	83		$	44	$	11
Derivative liabilities	—		—		—		—		(1		)	(1		)	—		—
Net assets	$	108	$	63	$	43	$	2	$	137		$	82		$	44	$	11

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs

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

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	11		$	22
Purchases, sales, issuances and settlements:
Settlements		(6		)	(10		)
Total losses included on the Condensed Consolidated Balance Sheet		(3		)	(7		)
Balance at end of period		$	2		$	5

Piedmont Natural Gas

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.

	March 31, 2020								December 31, 2019
(in millions)	Total Fair Value			Level 1		Level 3			Total Fair Value			Level 1		Level 3
Derivative assets	$	3		$	3	$	—		$	1		$	1	$	—
Derivative liabilities	(91		)	—		(91		)	(117		)	—		(117		)
Net (liabilities) assets	$	(88	)	$	3	$	(91	)	$	(116	)	$	1	$	(117	)

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs

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

	Derivatives (net)
		Three Months Ended March 31,
(in millions)		2020			2019
Balance at beginning of period		$	(117	)	$	(141	)
Total gains and settlements		26			20
Balance at end of period		$	(91	)	$	(121	)

XML

Goodwill (Tables)

3 Months Ended

Mar. 31, 2020

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill By Reportable Operating Segment

The following table presents the goodwill by reportable segment included on Duke Energy's Condensed Consolidated Balance Sheets at March 31, 2020, and December 31, 2019.

	Electric Utilities		Gas Utilities		Commercial
(in millions)	and Infrastructure		and Infrastructure		Renewables			Total
Goodwill balance	$	17,379	$	1,924	$	122		$	19,425
Accumulated impairment charges	—		—		(122		)	(122		)
Goodwill, adjusted for accumulated impairment charges	$	17,379	$	1,924	$	—		$	19,303

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Regulatory Matters (Regulatory Matters Narrative - Piedmont) (Details) - Piedmont Natural Gas - USD ($) $ in Millions	1 Months Ended
	Apr. 30, 2020	Nov. 30, 2019
Tennessee Integrity Management Rider Filing November 2018 | TPUC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ 2
Subsequent event | North Carolina Integrity Management Rider Filing | NCUC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 15

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Commitments and Contingencies (Narrative) (Details) $ in Millions		3 Months Ended
	Jun. 18, 2018 USD ($)	Mar. 31, 2020 USD ($) plant claim	Jan. 01, 2020 USD ($)	Dec. 31, 2019 USD ($)
ASU 2016-13
Loss Contingencies [Line Items]
Reserve for credit losses for financial guarantees			$ 99
Coal Ash Insurance Coverage Litigation
Loss Contingencies [Line Items]
Number of NC and SC Plants with Ash Basins | plant		15
Duke Energy Carolinas | Asbestos-related Injuries and Damages Claims
Loss Contingencies [Line Items]
Asbestos-related injuries and damages reserves		$ 596		$ 604
Reinsurance retention policy, excess retention, amount reinsured		747
Probable insurance recoveries		$ 742		$ 742
Duke Energy Carolinas | Asbestos-related Injuries and Damages Claims | Non-malignant cases
Loss Contingencies [Line Items]
Loss contingency, pending claims, number | claim		118
Asbestos-related injuries and damages reserves		$ 30
Duke Energy Carolinas | Asbestos-related Injuries and Damages Claims | Malignant cases
Loss Contingencies [Line Items]
Loss contingency, pending claims, number | claim		51
Asbestos-related injuries and damages reserves		$ 17
Duke Energy Progress | Spent Nuclear Fuel Matters
Loss Contingencies [Line Items]
Pending litigation, damages sought	$ 100
Duke Energy Florida | Spent Nuclear Fuel Matters
Loss Contingencies [Line Items]
Pending litigation, damages sought	$ 203
Duke Energy and Duke Energy Carolinas | ASU 2016-13
Loss Contingencies [Line Items]
Reserve for credit losses for insurance receivables			$ 15

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Condensed Consolidated Statements of Operations and Comprehensive Income - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2020		Mar. 31, 2019
Operating Revenues
Regulated electric	$ 5,124		$ 5,285
Regulated natural gas	638		728
Nonregulated electric and other	187		150
Total operating revenues	5,949		6,163
Operating Expenses
Operation, maintenance and other	1,339		1,419
Depreciation and amortization	1,130		1,089
Property and other taxes	345		343
Impairment charges	2
Total operating expenses	4,462		4,787
Gains (Losses) on Sales of Other Assets and Other, net	1		(3)
Operating Income	1,488		1,373
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	44		43
Other income and expenses, net	46		115
Total other income and expenses	90		158
Interest Expense	551		543
Income Before Income Taxes	1,027		988
Income Tax Expense	137		95
Net Income	890		893
Less: Net Loss Attributable to Noncontrolling Interests	(48)		(7)
Net Income Attributable to Parent	938		900
Less: Preferred Dividends	39
Net Income (Loss) Available to Common Stockholders, Basic	899		900
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments	1
Net unrealized (losses) gains on cash flow hedges	(81)		(17)
Unrealized gains on available-for-sale securities	1		4
Other Comprehensive Loss, net of tax	(77)	[1]	(12)
Comprehensive Income	813		881
Less: Comprehensive Loss Attributable to Noncontrolling Interests	(62)		(7)
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	$ 836		$ 888
Net income attributable to Duke Energy Corporation common stockholders
Basic and Diluted (in usd per share)	$ 1.24		$ 1.24
Weighted average shares outstanding
Weighted Average Number of Shares Outstanding, Basic	734		727
Weighted Average Number of Shares Outstanding, Diluted	736		727
Duke Energy Carolinas
Operating Revenues
Total operating revenues	$ 1,748		$ 1,744
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	453		472
Operation, maintenance and other	386		440
Depreciation and amortization	343		317
Property and other taxes	81		80
Impairment charges	2
Total operating expenses	1,265		1,309
Gains (Losses) on Sales of Other Assets and Other, net	1
Operating Income	484		435
Other Income and Expenses
Total other income and expenses	43		31
Interest Expense	123		110
Income Before Income Taxes	404		356
Income Tax Expense	65		63
Net Income Attributable to Parent	339		293
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	339		293
Progress Energy
Operating Revenues
Total operating revenues	2,422		2,572
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	763		925
Operation, maintenance and other	554		567
Depreciation and amortization	452		455
Property and other taxes	135		137
Total operating expenses	1,904		2,084
Gains (Losses) on Sales of Other Assets and Other, net	(1)
Operating Income	517		488
Other Income and Expenses
Total other income and expenses	32		31
Interest Expense	206		219
Income Before Income Taxes	343		300
Income Tax Expense	60		52
Net Income	283		248
Less: Net Loss Attributable to Noncontrolling Interests			(1)
Net Income Attributable to Parent	283		249
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments			1
Net unrealized (losses) gains on cash flow hedges	1		2
Unrealized gains on available-for-sale securities	1
Other Comprehensive Loss, net of tax	2		3
Comprehensive Income	285		251
Less: Comprehensive Loss Attributable to Noncontrolling Interests			(1)
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	285		252
Duke Energy Progress
Operating Revenues
Total operating revenues	1,338		1,484
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	405		515
Operation, maintenance and other	305		335
Depreciation and amortization	287		290
Property and other taxes	47		44
Total operating expenses	1,044		1,184
Gains (Losses) on Sales of Other Assets and Other, net	(1)
Operating Income	293		300
Other Income and Expenses
Total other income and expenses	22		24
Interest Expense	69		77
Income Before Income Taxes	246		247
Income Tax Expense	42		44
Net Income Attributable to Parent	204		203
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	204		203
Duke Energy Florida
Operating Revenues
Total operating revenues	1,080		1,086
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	358		410
Operation, maintenance and other	245		230
Depreciation and amortization	165		165
Property and other taxes	88		93
Total operating expenses	856		898
Operating Income	224		188
Other Income and Expenses
Total other income and expenses	10		13
Interest Expense	84		82
Income Before Income Taxes	150		119
Income Tax Expense	30		23
Net Income Attributable to Parent	120		96
Other Comprehensive Income (Loss), net of tax
Unrealized gains on available-for-sale securities	1		1
Other Comprehensive Loss, net of tax	1		1
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	121		97
Duke Energy Ohio
Operating Revenues
Regulated electric	346		355
Regulated natural gas	152		176
Total operating revenues	498		531
Operating Expenses
Operation, maintenance and other	123		132
Depreciation and amortization	68		64
Property and other taxes	83		84
Total operating expenses	398		427
Operating Income	100		104
Other Income and Expenses
Total other income and expenses	3		9
Interest Expense	24		30
Income Before Income Taxes	79		83
Income Tax Expense	14		14
Net Income Attributable to Parent	65		69
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	65		69
Duke Energy Indiana
Operating Revenues
Total operating revenues	692		768
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	194		257
Operation, maintenance and other	186		189
Depreciation and amortization	132		131
Property and other taxes	22		19
Total operating expenses	534		596
Gains (Losses) on Sales of Other Assets and Other, net			(3)
Operating Income	158		169
Other Income and Expenses
Total other income and expenses	10		19
Interest Expense	43		43
Income Before Income Taxes	125		145
Income Tax Expense	26		35
Net Income Attributable to Parent	99		110
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	99		110
Piedmont Natural Gas
Operating Revenues
Total operating revenues	512		579
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	162		273
Operation, maintenance and other	80		80
Depreciation and amortization	45		42
Property and other taxes	12		12
Total operating expenses	299		407
Operating Income	213		172
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	2		2
Other income and expenses, net	12		6
Interest Expense	27		22
Income Before Income Taxes	198		156
Income Tax Expense	20		34
Net Income Attributable to Parent	178		122
Other Comprehensive Income (Loss), net of tax
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	178		122
Fuel used in electric generation and purchased power | Duke Energy Ohio
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	87		93
Fuel used in electric generation and purchased power
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	1,447		1,609
Cost of natural gas
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	199		327
Cost of natural gas | Duke Energy Ohio
Operating Expenses
Fuel used in electric generation and purchased power/Cost of natural gas	$ 37		$ 54

[1] Net of income tax impact of approximately $23 million in the first quarter of 2020 and immaterial income tax impact in the first quarter of 2019.

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Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Allowance for doubtful accounts - receivables	$ 28	$ 22
Regulatory Assets: Current	1,770	1,796
Current Assets: Other	1,000	764
Other Noncurrent Assets: Regulatory assets	13,413	13,222
Other, noncurrent assets	3,315	3,289
Current maturities of long-term debt	5,077	3,141
Long-Term Debt	$ 56,311	$ 54,985
Common stock, par value (in usd per share)	$ 0.001	$ 0.001
Common stock, shares authorized	2,000,000,000	2,000,000,000
Common stock, shares outstanding	735,000,000	733,000,000
Other, noncurrent liabilities	$ 1,669	$ 1,581
Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	61	54
Regulatory Assets: Current	53	52
Current Assets: Other	300	242
Other Noncurrent Assets: Regulatory assets	980	989
Other, noncurrent assets	87	110
Current maturities of long-term debt	216	216
Long-Term Debt	3,966	3,997
Other, noncurrent liabilities	258	228
Duke Energy Carolinas
Allowance for doubtful accounts - receivables	3	3
Regulatory Assets: Current	524	550
Current Assets: Other	31	21
Other Noncurrent Assets: Regulatory assets	3,427	3,360
Other, noncurrent assets	1,136	1,149
Current maturities of long-term debt	457	458
Long-Term Debt	12,050	11,142
Other, noncurrent liabilities	640	627
Duke Energy Carolinas | Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	8	7
Progress Energy
Allowance for doubtful accounts - receivables	8	7
Regulatory Assets: Current	954	946
Current Assets: Other	196	210
Other Noncurrent Assets: Regulatory assets	6,489	6,346
Other, noncurrent assets	1,121	1,049
Current maturities of long-term debt	1,828	1,577
Long-Term Debt	$ 17,377	$ 17,907
Common stock, par value (in usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized	100	100
Common stock, shares outstanding	100	100
Other, noncurrent liabilities	$ 404	$ 383
Progress Energy | Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	12	9
Regulatory Assets: Current	53	52
Current Assets: Other	13	39
Other Noncurrent Assets: Regulatory assets	980	989
Current maturities of long-term debt	54	54
Long-Term Debt	1,603	1,632
Duke Energy Progress
Allowance for doubtful accounts - receivables	2	3
Regulatory Assets: Current	503	526
Current Assets: Other	48	60
Other Noncurrent Assets: Regulatory assets	4,392	4,152
Other, noncurrent assets	682	651
Current maturities of long-term debt	1,006	1,006
Long-Term Debt	7,903	7,902
Other, noncurrent liabilities	83	92
Duke Energy Progress | Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	7	5
Duke Energy Florida
Allowance for doubtful accounts - receivables	6	3
Regulatory Assets: Current	451	419
Current Assets: Other	37	58
Other Noncurrent Assets: Regulatory assets	2,097	2,194
Other, noncurrent assets	329	311
Current maturities of long-term debt	322	571
Long-Term Debt	7,384	7,416
Other, noncurrent liabilities	169	136
Duke Energy Florida | Variable Interest Entity [Member]
Allowance for doubtful accounts - receivables of VIEs	5	4
Regulatory Assets: Current	53	52
Current Assets: Other	13	39
Other Noncurrent Assets: Regulatory assets	980	989
Current maturities of long-term debt	54	54
Long-Term Debt	1,278	1,307
Duke Energy Ohio
Allowance for doubtful accounts - receivables	5	4
Regulatory Assets: Current	33	49
Current Assets: Other	11	21
Other Noncurrent Assets: Regulatory assets	567	549
Other, noncurrent assets	56	52
Long-Term Debt	$ 2,595	$ 2,594
Common stock, par value (in usd per share)	$ 8.50	$ 8.50
Common stock, shares authorized	120,000,000	120,000,000
Common stock, shares outstanding	90,000,000	90,000,000
Other, noncurrent liabilities	$ 97	$ 94
Duke Energy Indiana
Allowance for doubtful accounts - receivables	3	3
Regulatory Assets: Current	78	90
Current Assets: Other	36	60
Other Noncurrent Assets: Regulatory assets	1,098	1,082
Other, noncurrent assets	214	234
Current maturities of long-term debt	503	503
Long-Term Debt	3,950	3,404
Other, noncurrent liabilities	30	18
Piedmont Natural Gas
Allowance for doubtful accounts - receivables	5	2
Regulatory Assets: Current	96	73
Current Assets: Other	13	28
Other Noncurrent Assets: Regulatory assets	263	290
Other, noncurrent assets	132	121
Long-Term Debt	$ 2,385	$ 2,384
Common stock, shares authorized	100	100
Common stock, shares outstanding	100	100
Other, noncurrent liabilities	$ 121	$ 148
Preferred stock, Series A
Preferred stock, par value (in usd per share)	$ 0.001	$ 0.001
Preferred stock, depositary shares authorized	40,000,000	40,000,000
Preferred stock, depositary shares outstanding	40,000,000	40,000,000
Preferred stock, Series B
Preferred stock, par value (in usd per share)	$ 0.001	$ 0.001
Preferred stock, depositary shares authorized	1,000,000	1,000,000
Preferred stock, depositary shares outstanding	1,000,000	1,000,000

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Investments in Debt and Equity Securities (Estimated Fair Value of Investments in Debt and Equity Securities) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Debt Securities, Available-for-sale
Estimated Fair Value	$ 2,711
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	2,671	$ 3,675
Unrealized Holding Losses	193	57
Estimated Fair Value	7,511	8,562
NDTF
Available-for-sale Securities
Cash and cash equivalents	119	101
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	2,499	3,523
Equity Securities, FV-NI, Accumulated Unrealized Loss	170	55
Equity securities, FV-NI	4,488	5,661
Debt Securities, Available-for-sale
Estimated Fair Value	2,540	2,469
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	2,629	3,609
Unrealized Holding Losses	191	57
Estimated Fair Value	7,048	8,130
Other Investments
Available-for-sale Securities
Cash and cash equivalents	78	52
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	31	57
Equity Securities, FV-NI, Accumulated Unrealized Loss	1
Equity securities, FV-NI	95	122
Debt Securities, Available-for-sale
Estimated Fair Value	368	310
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	42	66
Unrealized Holding Losses	2
Estimated Fair Value	463	432
Duke Energy Carolinas
Debt Securities, Available-for-sale
Estimated Fair Value	1,181
Duke Energy Carolinas | NDTF
Available-for-sale Securities
Cash and cash equivalents	33	21
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	1,355	1,914
Equity Securities, FV-NI, Accumulated Unrealized Loss	81	8
Equity securities, FV-NI	2,498	3,154
Debt Securities, Available-for-sale
Estimated Fair Value	1,214	1,193
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	1,411	1,957
Unrealized Holding Losses	97	10
Estimated Fair Value	3,712	4,347
Progress Energy
Debt Securities, Available-for-sale
Estimated Fair Value	1,293
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	1,223	1,655
Unrealized Holding Losses	94	47
Estimated Fair Value	3,458	3,883
Progress Energy | NDTF
Available-for-sale Securities
Cash and cash equivalents	86	80
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	1,144	1,609
Equity Securities, FV-NI, Accumulated Unrealized Loss	89	47
Equity securities, FV-NI	1,990	2,507
Debt Securities, Available-for-sale
Estimated Fair Value	1,326	1,276
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	1,218	1,652
Unrealized Holding Losses	94	47
Estimated Fair Value	3,336	3,783
Progress Energy | Other Investments
Available-for-sale Securities
Cash and cash equivalents	69	49
Debt Securities, Available-for-sale
Estimated Fair Value	122	100
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	5	3
Estimated Fair Value	122	100
Duke Energy Progress
Debt Securities, Available-for-sale
Estimated Fair Value	966
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	934	1,300
Unrealized Holding Losses	84	21
Estimated Fair Value	2,650	3,053
Duke Energy Progress | NDTF
Available-for-sale Securities
Cash and cash equivalents	51	53
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	881	1,258
Equity Securities, FV-NI, Accumulated Unrealized Loss	79	21
Equity securities, FV-NI	1,631	2,077
Debt Securities, Available-for-sale
Estimated Fair Value	1,017	974
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	934	1,300
Unrealized Holding Losses	84	21
Estimated Fair Value	2,648	3,051
Duke Energy Progress | Other Investments
Available-for-sale Securities
Cash and cash equivalents	2	2
Debt Securities, Available-for-sale
Estimated Fair Value	2	2
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Estimated Fair Value	2	2
Duke Energy Florida
Debt Securities, Available-for-sale
Estimated Fair Value	327
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	289	355
Unrealized Holding Losses	10	26
Estimated Fair Value	744	787
Duke Energy Florida | NDTF
Available-for-sale Securities
Cash and cash equivalents	35	27
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	263	351
Equity Securities, FV-NI, Accumulated Unrealized Loss	10	26
Equity securities, FV-NI	359	430
Debt Securities, Available-for-sale
Estimated Fair Value	309	302
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	284	352
Unrealized Holding Losses	10	26
Estimated Fair Value	688	732
Duke Energy Florida | Other Investments
Available-for-sale Securities
Cash and cash equivalents	3	4
Debt Securities, Available-for-sale
Estimated Fair Value	56	55
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	5	3
Estimated Fair Value	56	55
Duke Energy Indiana
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	26	43
Equity Securities, FV-NI, Accumulated Unrealized Loss	1
Equity securities, FV-NI	63	81
Debt Securities, Available-for-sale
Estimated Fair Value	43
Investments, Accumulated Gross Unrealized Gains (Losses) [Abstract]
Unrealized Holding Gains	27	44
Unrealized Holding Losses	2
Estimated Fair Value	106	125
Duke Energy Indiana | Other Investments
Equity Securities, FV-NI
Equity securities, FV-NI	63	81
Corporate debt securities | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	26	37
Gross Unrealized Holding Losses	16	1
Estimated Fair Value	642	603
Corporate debt securities | Other Investments
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains		3
Estimated Fair Value	89	67
Corporate debt securities | Duke Energy Carolinas | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	15	21
Gross Unrealized Holding Losses	12	1
Estimated Fair Value	392	361
Corporate debt securities | Progress Energy | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	11	16
Gross Unrealized Holding Losses	4
Estimated Fair Value	250	242
Corporate debt securities | Duke Energy Progress | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	11	16
Gross Unrealized Holding Losses	4
Estimated Fair Value	250	242
Corporate debt securities | Duke Energy Indiana
Debt Securities, Available-for-sale
Estimated Fair Value	4	6
Municipal bonds | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	10	13
Gross Unrealized Holding Losses	2
Estimated Fair Value	404	368
Municipal bonds | Other Investments
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	6	4
Gross Unrealized Holding Losses	1
Estimated Fair Value	98	94
Municipal bonds | Duke Energy Carolinas | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	3	3
Gross Unrealized Holding Losses	1
Estimated Fair Value	128	96
Municipal bonds | Progress Energy | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	7	10
Gross Unrealized Holding Losses	1
Estimated Fair Value	276	272
Municipal bonds | Progress Energy | Other Investments
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	5	3
Estimated Fair Value	53	51
Municipal bonds | Duke Energy Progress | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	7	10
Gross Unrealized Holding Losses	1
Estimated Fair Value	276	272
Municipal bonds | Duke Energy Florida | Other Investments
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	5	3
Estimated Fair Value	53	51
Municipal bonds | Duke Energy Indiana
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	1	1
Gross Unrealized Holding Losses	1
Estimated Fair Value	36	36
U.S. government bonds | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	70	33
Gross Unrealized Holding Losses		1
Estimated Fair Value	1,212	1,256
U.S. government bonds | Other Investments
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	5	2
Estimated Fair Value	51	41
U.S. government bonds | Duke Energy Carolinas | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	35	16
Gross Unrealized Holding Losses		1
Estimated Fair Value	502	578
U.S. government bonds | Progress Energy | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	35	17
Estimated Fair Value	710	678
U.S. government bonds | Duke Energy Progress | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	34	16
Estimated Fair Value	436	403
U.S. government bonds | Duke Energy Florida | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	1	1
Estimated Fair Value	274	275
U.S. government bonds | Duke Energy Indiana
Debt Securities, Available-for-sale
Estimated Fair Value	3	2
NDTF equity security contracts | NDTF
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	20
Equity securities, FV-NI	20
NDTF equity security contracts | Progress Energy | NDTF
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	20
Equity securities, FV-NI	20
NDTF equity security contracts | Duke Energy Florida | NDTF
Equity Securities, FV-NI
Equity Securities, FV-NI, Accumulated Unrealized Gain	20
Equity securities, FV-NI	20
Other debt securities | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	4	3
Gross Unrealized Holding Losses	3
Estimated Fair Value	163	141
Other debt securities | Other Investments
Debt Securities, Available-for-sale
Estimated Fair Value	52	56
Other debt securities | Duke Energy Carolinas | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	3	3
Gross Unrealized Holding Losses	3
Estimated Fair Value	159	137
Other debt securities | Progress Energy | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	1
Estimated Fair Value	4	4
Other debt securities | Duke Energy Progress | NDTF
Debt Securities, Available-for-sale
Gross Unrealized Holding Gains	1
Estimated Fair Value	$ 4	$ 4

XML

Variable Interest Entities (Schedule of Non-Consolidated VIEs) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	$ 2,067	$ 1,936
Taxes accrued	493	392
Current Liabilities: Other	2,004	2,367
Deferred income taxes	9,321	8,878
Other Noncurrent Liabilities: Other	1,669	1,581
VIE not primary beneficiary
Variable Interest Entities [Line Items]
Receivables from affiliated companies	(1)	(1)
Investments in equity method unconsolidated affiliates	1,614	1,479
Total assets	1,613	1,478
Taxes accrued	(1)	(1)
Current Liabilities: Other	3	4
Deferred income taxes	69	59
Other Noncurrent Liabilities: Other	116	11
Total liabilities	187	73
Net assets	1,426	1,405
Pipeline Investments | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates	1,243	1,179
Total assets	1,243	1,179
Taxes accrued	(1)	(1)
Deferred income taxes	69	59
Other Noncurrent Liabilities: Other	105
Total liabilities	173	58
Net assets	1,070	1,121
Commercial Renewables | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Receivables from affiliated companies	(1)	(1)
Investments in equity method unconsolidated affiliates	371	300
Total assets	370	299
Net assets	370	299
Other VIEs | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Current Liabilities: Other	3	4
Other Noncurrent Liabilities: Other	11	11
Total liabilities	14	15
Net assets	(14)	(15)
Duke Energy Ohio
Variable Interest Entities [Line Items]
Receivables from affiliated companies	52	92
Taxes accrued	170	219
Current Liabilities: Other	68	75
Deferred income taxes	942	922
Other Noncurrent Liabilities: Other	97	94
Duke Energy Ohio | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Receivables from affiliated companies	39	64
Total assets	39	64
Net assets	39	64
Duke Energy Indiana
Variable Interest Entities [Line Items]
Receivables from affiliated companies	76	79
Taxes accrued	81	49
Current Liabilities: Other	92	112
Deferred income taxes	1,158	1,150
Other Noncurrent Liabilities: Other	30	18
Duke Energy Indiana | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Receivables from affiliated companies	48	77
Total assets	48	77
Net assets	$ 48	$ 77

XML

Fair Value Measurements (Other Fair Value Disclosure) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	$ 61,388	$ 58,126
Long-term debt, fair value	65,644	63,062
Piedmont Natural Gas and Progress Energy [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized debt discount (premium), net	1,400	1,500
Duke Energy Carolinas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	12,807	11,900
Long-term debt, fair value	14,312	13,516
Progress Energy
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	19,355	19,634
Long-term debt, fair value	21,802	22,291
Duke Energy Progress
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	9,059	9,058
Long-term debt, fair value	9,798	9,934
Duke Energy Florida
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	7,706	7,987
Long-term debt, fair value	8,831	9,131
Duke Energy Ohio
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	2,620	2,619
Long-term debt, fair value	2,904	2,964
Duke Energy Indiana
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	4,603	4,057
Long-term debt, fair value	5,433	4,800
Piedmont Natural Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, book value	2,385	2,384
Long-term debt, fair value	$ 2,551	$ 2,642

XML

Derivatives and Hedging (Location and Fair Value Amounts of Derivatives Reflected in the Condensed Consolidated Balance Sheets) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	$ 34	$ 25
Location and fair value amounts of derivatives (Liability)	390	300
Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	9	24
Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	25	1
Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	178	118
Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	212	182
Commodity Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	10	18
Location and fair value amounts of derivatives (Liability)	209	223
Interest Rate Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	4	6
Location and fair value amounts of derivatives (Liability)	181	53
Equity Securities Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	1
Location and fair value amounts of derivatives (Liability)		24
Not Designated as Hedging Instruments | Commodity Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	6	17
Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	4	1
Not Designated as Hedging Instruments | Commodity Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	79	67
Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	130	156
Not Designated as Hedging Instruments | Interest Rate Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	6
Not Designated as Hedging Instruments | Interest Rate Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1
Not Designated as Hedging Instruments | Interest Rate Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	30	8
Not Designated as Hedging Instruments | Interest Rate Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	28	5
Not Designated as Hedging Instruments | Equity Securities Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		1
Not Designated as Hedging Instruments | Equity Securities Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20
Not Designated as Hedging Instruments | Equity Securities Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		24
Designated as Hedging Instruments | Interest Rate Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	69	19
Designated as Hedging Instruments | Interest Rate Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	54	21
Duke Energy Carolinas
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2
Location and fair value amounts of derivatives (Liability)	74	49
Duke Energy Carolinas | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2
Duke Energy Carolinas | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	40	39
Duke Energy Carolinas | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	34	10
Duke Energy Carolinas | Commodity Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2
Location and fair value amounts of derivatives (Liability)	51	43
Duke Energy Carolinas | Interest Rate Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	23	6
Duke Energy Carolinas | Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2
Duke Energy Carolinas | Not Designated as Hedging Instruments | Commodity Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	40	33
Duke Energy Carolinas | Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	11	10
Duke Energy Carolinas | Not Designated as Hedging Instruments | Interest Rate Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		6
Duke Energy Carolinas | Not Designated as Hedging Instruments | Interest Rate Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	23
Progress Energy
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	25	7
Location and fair value amounts of derivatives (Liability)	95	88
Progress Energy | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	7
Progress Energy | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	22
Progress Energy | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	60	51
Progress Energy | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	35	37
Progress Energy | Commodity Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1
Location and fair value amounts of derivatives (Liability)	66	63
Progress Energy | Interest Rate Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	4	6
Location and fair value amounts of derivatives (Liability)	29	1
Progress Energy | Equity Securities Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	1
Location and fair value amounts of derivatives (Liability)		24
Progress Energy | Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1
Progress Energy | Not Designated as Hedging Instruments | Commodity Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	31	26
Progress Energy | Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	35	37
Progress Energy | Not Designated as Hedging Instruments | Interest Rate Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	6
Progress Energy | Not Designated as Hedging Instruments | Interest Rate Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1
Progress Energy | Not Designated as Hedging Instruments | Interest Rate Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	29	1
Progress Energy | Not Designated as Hedging Instruments | Equity Securities Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		1
Progress Energy | Not Designated as Hedging Instruments | Equity Securities Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20
Progress Energy | Not Designated as Hedging Instruments | Equity Securities Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		24
Duke Energy Progress
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	5
Location and fair value amounts of derivatives (Liability)	51	49
Duke Energy Progress | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3
Duke Energy Progress | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2
Duke Energy Progress | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	31	27
Duke Energy Progress | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	20	22
Duke Energy Progress | Commodity Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1
Location and fair value amounts of derivatives (Liability)	51	48
Duke Energy Progress | Interest Rate Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	4
Location and fair value amounts of derivatives (Liability)		1
Duke Energy Progress | Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1
Duke Energy Progress | Not Designated as Hedging Instruments | Commodity Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	31	26
Duke Energy Progress | Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	20	22
Duke Energy Progress | Not Designated as Hedging Instruments | Interest Rate Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3
Duke Energy Progress | Not Designated as Hedging Instruments | Interest Rate Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1
Duke Energy Progress | Not Designated as Hedging Instruments | Interest Rate Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		1
Duke Energy Florida
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	7
Location and fair value amounts of derivatives (Liability)	29	24
Duke Energy Florida | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		7
Duke Energy Florida | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20
Duke Energy Florida | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	29	24
Duke Energy Florida | Interest Rate Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		6
Location and fair value amounts of derivatives (Liability)	29
Duke Energy Florida | Equity Securities Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20	1
Location and fair value amounts of derivatives (Liability)		24
Duke Energy Florida | Not Designated as Hedging Instruments | Interest Rate Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		6
Duke Energy Florida | Not Designated as Hedging Instruments | Interest Rate Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	29
Duke Energy Florida | Not Designated as Hedging Instruments | Equity Securities Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		1
Duke Energy Florida | Not Designated as Hedging Instruments | Equity Securities Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	20
Duke Energy Florida | Not Designated as Hedging Instruments | Equity Securities Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		24
Duke Energy Ohio
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	4
Location and fair value amounts of derivatives (Liability)	7	6
Duke Energy Ohio | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		3
Duke Energy Ohio | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	1
Duke Energy Ohio | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1	1
Duke Energy Ohio | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	6	5
Duke Energy Ohio | Commodity Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	4
Duke Energy Ohio | Interest Rate Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	7	6
Duke Energy Ohio | Not Designated as Hedging Instruments | Commodity Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		3
Duke Energy Ohio | Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	1	1
Duke Energy Ohio | Not Designated as Hedging Instruments | Interest Rate Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	1	1
Duke Energy Ohio | Not Designated as Hedging Instruments | Interest Rate Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	6	5
Duke Energy Indiana
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	13
Location and fair value amounts of derivatives (Liability)		1
Duke Energy Indiana | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	13
Duke Energy Indiana | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		1
Duke Energy Indiana | Commodity Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	13
Location and fair value amounts of derivatives (Liability)		1
Duke Energy Indiana | Not Designated as Hedging Instruments | Commodity Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	2	13
Duke Energy Indiana | Not Designated as Hedging Instruments | Commodity Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)		1
Piedmont Natural Gas
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	1
Location and fair value amounts of derivatives (Liability)	91	117
Piedmont Natural Gas | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	1
Piedmont Natural Gas | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	8	7
Piedmont Natural Gas | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	83	110
Piedmont Natural Gas | Commodity Contracts
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	1
Location and fair value amounts of derivatives (Liability)	91	117
Piedmont Natural Gas | Not Designated as Hedging Instruments | Commodity Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	3	1
Piedmont Natural Gas | Not Designated as Hedging Instruments | Commodity Contracts | Current liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	8	7
Piedmont Natural Gas | Not Designated as Hedging Instruments | Commodity Contracts | Noncurrent liabilities
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Liability)	83	110
Piedmont Natural Gas | Not Designated as Hedging Instruments | Interest Rate Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	0
Piedmont Natural Gas | Not Designated as Hedging Instruments | Equity Securities Contracts | Current assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)		$ 0
Piedmont Natural Gas | Not Designated as Hedging Instruments | Equity Securities Contracts | Noncurrent assets
Derivatives, Fair Value [Line Items]
Location and fair value amounts of derivatives (Asset)	$ 0

XML

Revenue (Remaining Performance Obligations) (Details) $ in Millions	Mar. 31, 2020 USD ($)
Progress Energy
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 410
Progress Energy | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	9 months
Revenue, remaining performance obligation, amount	$ 84
Progress Energy | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 92
Progress Energy | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 87
Progress Energy | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 44
Progress Energy | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 45
Progress Energy | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period
Revenue, remaining performance obligation, amount	$ 58
Duke Energy Progress
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 38
Duke Energy Progress | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	9 months
Revenue, remaining performance obligation, amount	$ 6
Duke Energy Progress | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 8
Duke Energy Progress | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 8
Duke Energy Progress | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 8
Duke Energy Progress | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 8
Duke Energy Progress | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period
Duke Energy Florida
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 372
Duke Energy Florida | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	9 months
Revenue, remaining performance obligation, amount	$ 78
Duke Energy Florida | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 84
Duke Energy Florida | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 79
Duke Energy Florida | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 36
Duke Energy Florida | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 37
Duke Energy Florida | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period
Revenue, remaining performance obligation, amount	$ 58
Duke Energy Indiana
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 13
Duke Energy Indiana | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	9 months
Revenue, remaining performance obligation, amount	$ 8
Duke Energy Indiana | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 5
Duke Energy Indiana | 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, expected timing of satisfaction, period	1 year
Duke Energy Indiana | 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, expected timing of satisfaction, period	1 year
Duke Energy Indiana | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Duke Energy Indiana | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period
Piedmont Natural Gas
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 675
Piedmont Natural Gas | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	9 months
Revenue, remaining performance obligation, amount	$ 51
Piedmont Natural Gas | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 65
Piedmont Natural Gas | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 64
Piedmont Natural Gas | 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, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 61
Piedmont Natural Gas | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, remaining performance obligation, amount	$ 58
Piedmont Natural Gas | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, period
Revenue, remaining performance obligation, amount	$ 376

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Fair Value Measurements (Reconciliation of Assets and Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Derivatives (net)
Balance at beginning of period	$ (102)	$ (113)
Purchases, sales, issuances and settlements:
Settlements	(9)	(12)
Total gains included on the Condensed Consolidated Balance Sheet	23	10
Balance at end of period	(88)	(115)
Duke Energy Indiana
Derivatives (net)
Balance at beginning of period	11	22
Purchases, sales, issuances and settlements:
Settlements	(6)	(10)
Total gains included on the Condensed Consolidated Balance Sheet	(3)	(7)
Balance at end of period	2	5
Piedmont Natural Gas
Derivatives (net)
Balance at beginning of period	(117)	(141)
Purchases, sales, issuances and settlements:
Total gains and settlements	26	20
Balance at end of period	$ (91)	$ (121)

XML

Organization and Basis of Presentation

3 Months Ended

Mar. 31, 2020

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

Duke Energy

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Duke Energy Carolinas

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•

Progress Energy

•

•

•

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•

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•

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Duke Energy Progress

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Duke Energy Florida

•

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Duke Energy Ohio

•

•

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Duke Energy Indiana

•

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Piedmont

•

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•

•

•

•

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

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with 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 and should be read in conjunction with the Consolidated Financial Statements in the Duke Energy Registrants’ combined Annual Report on Form 10-K for the year ended December 31, 2019.

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.

BASIS OF CONSOLIDATION

These Condensed Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and subsidiaries or VIEs where the respective Duke Energy Registrants have control. See Note 11 for additional information on VIEs. These Condensed Consolidated Financial Statements also reflect the Duke Energy Registrants’ proportionate share of certain jointly owned generation and transmission facilities.

COVID-19

The COVID-19 pandemic is having a significant impact on global health and economic environments. In March 2020, the World Health Organization (WHO) declared COVID-19 a global pandemic, and President Trump proclaimed that the COVID-19 outbreak in the United States constitutes a national emergency. The COVID-19 pandemic has not had a material financial impact on the Duke Energy Registrants as of March 31, 2020; however, the extent to which the COVID-19 pandemic will impact the Duke Energy Registrants during 2020 and beyond is uncertain at this time. The Duke Energy Registrants are monitoring developments closely. See Notes 3, 5, 11, 12 and 15 for information on COVID-19 and steps taken to mitigate the impacts to our business and customers.

NONCONTROLLING INTEREST

Duke Energy maintains a controlling financial interest in certain less than wholly owned nonregulated subsidiaries. As a result, Duke Energy consolidates these subsidiaries and presents the third-party investors' portion of Duke Energy's net income (loss), net assets and comprehensive income (loss) as noncontrolling interest. Noncontrolling interest is included as a component of equity on the Condensed Consolidated Balance Sheet.

Several operating agreements of Duke Energy's subsidiaries with noncontrolling interest are subject to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements that vary throughout the lives of the subsidiaries. Therefore, Duke Energy and the other investors' (the owners) interests in the subsidiaries are not fixed, and the subsidiaries apply the Hypothetical Liquidation at Book Value (HLBV) method in allocating income or loss and other comprehensive income or loss (all measured on a pretax basis) to the owners. The HLBV method measures the amounts that each owner would hypothetically claim at each balance sheet reporting date, including tax benefits realized by the owners, upon a hypothetical liquidation of the subsidiary at the net book value of its underlying assets. The change in the amount that each owner would hypothetically receive at the reporting date compared to the amount it would have received on the previous reporting date represents the amount of income or loss allocated to each owner for the reporting period. Duke Energy has received $103 million for the sale of noncontrolling interests to tax equity members for the three months ended March 31, 2020. Duke Energy allocated approximately $49 million and $7 million of losses to noncontrolling tax equity members utilizing the HLBV method for the three months ended March 31, 2020, and March 31, 2019, respectively.

Other operating agreements of Duke Energy's subsidiaries with noncontrolling interest allocate profit and loss based on their pro rata shares of the ownership interest in the respective subsidiary. Therefore, Duke Energy allocates net income or loss and other comprehensive income or loss of these subsidiaries to the owners based on their pro rata shares.

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 VIEs. See Note 11 for additional information. Restricted cash amounts are included in Other within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets. The following table presents the components of cash, cash equivalents and restricted cash included in the Condensed Consolidated Balance Sheets.

	March 31, 2020						December 31, 2019
					Duke						Duke
	Duke		Progress		Energy		Duke		Progress		Energy
	Energy		Energy		Florida		Energy		Energy		Florida
Current Assets
Cash and cash equivalents	$	1,450	$	52	$	12	$	311	$	48	$	17
Other	185		13		13		222		39		39
Other Noncurrent Assets
Other	63		60		—		40		39		—
Total cash, cash equivalents and restricted cash	$	1,698	$	125	$	25	$	573	$	126	$	56

INVENTORY

Provisions for inventory write-offs were not material at March 31, 2020, and December 31, 2019. The components of inventory are presented in the tables below.

	March 31, 2020
			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	$	2,280	$	759	$	1,018	$	678	$	340	$	83	$	319	$	5
Coal	742		268		246		167		79		10		218		—
Natural gas, oil and other fuel	302		40		199		111		89		28		1		34
Total inventory	$	3,324	$	1,067	$	1,463	$	956	$	508	$	121	$	538	$	39

	December 31, 2019
			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	$	2,297	$	768	$	1,038	$	686	$	351	$	79	$	318	$	5
Coal	586		187		186		138		48		15		198		—
Natural gas, oil and other fuel	349		41		199		110		90		41		1		67
Total inventory	$	3,232	$	996	$	1,423	$	934	$	489	$	135	$	517	$	72

NEW ACCOUNTING STANDARDS

The following new accounting standard was adopted by the Duke Energy Registrants in 2020.

Current Expected Credit Losses. In June 2016, the FASB issued new accounting guidance for credit losses. Duke Energy adopted the new accounting guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year results. Duke Energy did not adopt any practical expedients.

Duke Energy recognizes allowances for credit losses based on management's estimate of losses expected to be incurred over the lives of certain assets or guarantees. Management monitors credit quality, changes in expected credit losses and the appropriateness of the allowance for credit losses on a forward-looking basis. Management reviews the risk of loss periodically as part of the existing assessment of collectability of receivables.

Duke Energy reviews the credit quality of its counterparties as part of its regular risk management process and requires credit enhancements, such as deposits or letters of credit, as appropriate and as allowed by regulators.

Duke Energy recorded cumulative effects of changes in accounting principles related to the adoption of new credit loss standard, for allowances for credit losses of trade and other receivables, insurance receivables and financial guarantees. These amounts are included in the Condensed Consolidated Balance Sheets in Receivables, Receivables of VIEs, Other Noncurrent Assets and Other Noncurrent Liabilities. See Notes 4 and 12 for more information.

Duke Energy recorded an adjustment for the cumulative effect of a change in accounting principle due to the adoption of this standard on January 1, 2020, as shown in the table below:

	January 1, 2020
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Piedmont
Total pretax impact to Retained Earnings	$	120	$	16	$	2	$	1	$	1	$	1

The following new accounting standard has been issued but not yet adopted by the Duke Energy Registrants as of March 31, 2020.

Reference Rate Reform. In March 2020, the FASB issued new accounting guidance for reference rate reform. This guidance is elective and provides expedients to facilitate financial reporting for the anticipated transition away from the London Inter-bank Offered Rate (LIBOR) and other interbank reference rates by the end of 2021. The optional expedients are effective for modification of existing contracts or new arrangements executed between March 12, 2020, through December 31, 2022.

Duke Energy has variable-rate debt and manages interest rate risk by entering into financial contracts including interest rate swaps that are generally indexed to LIBOR. Impacted financial arrangements extending beyond 2021 may require contractual amendment or termination to fully adapt to a post-LIBOR environment. Duke Energy is assessing these financial arrangements and is evaluating the use of optional expedients outlined in the new accounting guidance. Alternative index provisions are also being assessed and incorporated into new financial arrangements that extend beyond 2021.

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Debt and Credit Facilities

3 Months Ended

Mar. 31, 2020

Debt Disclosure [Abstract]

Debt And Credit Facilities

DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

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

					Three Months Ended March 31, 2020
							Duke		Duke		Duke
	Maturity	Interest			Duke		Energy		Energy		Energy
Issuance Date	Date	Rate			Energy		(Parent)		Carolinas		Indiana
Unsecured Debt
March 2020(a)	March 2021	1.400	%	(b)	$	1,688	$	1,688	$	—	$	—
First Mortgage Bonds
January 2020(c)	February 2030	2.450	%		500		—		500		—
January 2020(c)	August 2049	3.200	%		400		—		400		—
March 2020(d)	April 2050	2.750	%		550		—		—		550
Total issuances					$	3,138	$	1,688	$	900	$	550

(a) Debt issued in response to market volatility concerns related to the COVID-19 pandemic. Refer to Note 1 for additional information on the COVID-19 pandemic. Proceeds will be used to reduce outstanding commercial paper and for general corporate purposes.

(b) Debt issuance has a floating interest rate.

(c) Debt issued to repay at maturity $450 million first mortgage bonds due June 2020 and for general corporate purposes.

(d) Debt issued to repay at maturity $500 million first mortgage bonds due July 2020 and to pay down short-term debt.

CURRENT MATURITIES OF LONG-TERM DEBT

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

(in millions)	Maturity Date	Interest Rate			March 31, 2020
Unsecured Debt
Duke Energy (Parent)	June 2020	2.100	%		$	330
Duke Energy Progress	December 2020	2.292	%	(a)	700
Progress Energy, Inc	January 2021	4.400	%		500
Duke Energy (Parent)	March 2021	1.400	%	(a)	1,688
First Mortgage Bonds
Duke Energy Florida	April 2020	4.550	%		250
Duke Energy Carolinas	June 2020	4.300	%		450
Duke Energy Indiana	July 2020	3.750	%		500
Duke Energy Progress	September 2020	1.076	%	(a)	300
Other(b)					359
Current maturities of long-term debt					$	5,077

(a)    Debt issuance has a floating interest rate.

(b)    Includes finance lease obligations, amortizing debt and small bullet maturities.

AVAILABLE CREDIT FACILITIES

Master Credit Facility

In March 2020, Duke Energy amended its existing $8 billion Master Credit Facility to extend the termination date to March 2025. The Duke Energy Registrants, excluding Progress Energy, 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. This requirement expires on May 15, 2020.

The table below includes the current borrowing sublimits and available capacity under these credit facilities.

	March 31, 2020
				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		$	1,500		$	1,250		$	800		$	600		$	600		$	600
Reduction to backstop issuances
Commercial paper(b)	(2,540		)	(1,140		)	(300		)	(275		)	(167		)	(243		)	(150		)	(265		)
Outstanding letters of credit	(49		)	(42		)	(4		)	(2		)	—			—			—			(1		)
Tax-exempt bonds	(81		)	—			—			—			—			—			(81		)	—
Coal ash set-aside	(500		)	—			(250		)	(250		)	—			—			—			—
Available capacity under the Master Credit Facility	$	4,830		$	1,468		$	946		$	723		$	633		$	357		$	369		$	334

(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.

Other Credit Facilities

	March 31, 2020
(in millions)	Facility size		Amount drawn
Duke Energy (Parent) Three-Year Revolving Credit Facility(a)	$	1,000	$	1,000
Duke Energy Progress Term Loan Facility	700		700

(a)

In March 2020, Duke Energy (Parent) drew down the remaining $500 million.

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Investments in Debt and Equity Securities

3 Months Ended

Mar. 31, 2020

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 NDTF at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, (ii) the grantor trusts at Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana related to OPEB plans and (iii) Bison. The Duke Energy Registrants classify investments in debt securities as 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 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 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 has a credit loss. The Duke Energy Registrants analyze all investment holdings each reporting period to determine whether a decline in fair value is related to a credit loss. If an credit loss exists, the unrealized credit loss is included in earnings. There were no material credit losses as of March 31, 2020, and December 31, 2019.

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	119	$	—	$	—	$	101
Equity securities	2,499		170		4,488		3,523		55		5,661
Corporate debt securities	26		16		642		37		1		603
Municipal bonds	10		2		404		13		—		368
U.S. government bonds	70		—		1,212		33		1		1,256
NDTF equity security contracts	20		—		20		—		—		—
Other debt securities	4		3		163		3		—		141
Total NDTF Investments	$	2,629	$	191	$	7,048	$	3,609	$	57	$	8,130
Other Investments
Cash and cash equivalents	$	—	$	—	$	78	$	—	$	—	$	52
Equity securities	31		1		95		57		—		122
Corporate debt securities	—		—		89		3		—		67
Municipal bonds	6		1		98		4		—		94
U.S. government bonds	5		—		51		2		—		41
Other debt securities	—		—		52		—		—		56
Total Other Investments	$	42	$	2	$	463	$	66	$	—	$	432
Total Investments	$	2,671	$	193	$	7,511	$	3,675	$	57	$	8,562

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	23	$	35
Realized losses	65		30
AFS:
Realized gains	20		10
Realized losses	6		11

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	33	$	—	$	—	$	21
Equity securities	1,355		81		2,498		1,914		8		3,154
Corporate debt securities	15		12		392		21		1		361
Municipal bonds	3		1		128		3		—		96
U.S. government bonds	35		—		502		16		1		578
Other debt securities	3		3		159		3		—		137
Total NDTF Investments	$	1,411	$	97	$	3,712	$	1,957	$	10	$	4,347

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	9	$	23
Realized losses	45		21
AFS:
Realized gains	12		9
Realized losses	5		10

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	86	$	—	$	—	$	80
Equity securities	1,144		89		1,990		1,609		47		2,507
Corporate debt securities	11		4		250		16		—		242
Municipal bonds	7		1		276		10		—		272
U.S. government bonds	35		—		710		17		—		678
NDTF equity security contracts	20		—		20		—		—		—
Other debt securities	1		—		4		—		—		4
Total NDTF Investments	$	1,218	$	94	$	3,336	$	1,652	$	47	$	3,783
Other Investments
Cash and cash equivalents	$	—	$	—	$	69	$	—	$	—	$	49
Municipal bonds	5		—		53		3		—		51
Total Other Investments	$	5	$	—	$	122	$	3	$	—	$	100
Total Investments	$	1,223	$	94	$	3,458	$	1,655	$	47	$	3,883

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	14	$	12
Realized losses	20		9
AFS:
Realized gains	5		1
Realized losses	1		1

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	51	$	—	$	—	$	53
Equity securities	881		79		1,631		1,258		21		2,077
Corporate debt securities	11		4		250		16		—		242
Municipal bonds	7		1		276		10		—		272
U.S. government bonds	34		—		436		16		—		403
Other debt securities	1		—		4		—		—		4
Total NDTF Investments	$	934	$	84	$	2,648	$	1,300	$	21	$	3,051
Other Investments
Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	2
Total Other Investments	$	—	$	—	$	2	$	—	$	—	$	2
Total Investments	$	934	$	84	$	2,650	$	1,300	$	21	$	3,053

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were as follows.

	Three Months Ended
(in millions)	March 31, 2020		March 31, 2019
FV-NI:
Realized gains	$	14	$	10
Realized losses	20		8
AFS:
Realized gains	5		1
Realized losses	1		1

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.

	March 31, 2020						December 31, 2019
	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	$	—	$	—	$	35	$	—	$	—	$	27
Equity securities	263		10		359		351		26		430
U.S. government bonds	1		—		274		1		—		275
NDTF equity security contracts	20		—		20		—		—		—
Total NDTF Investments(a)	$	284	$	10	$	688	$	352	$	26	$	732
Other Investments
Cash and cash equivalents	$	—	$	—	$	3	$	—	$	—	$	4
Municipal bonds	5		—		53		3		—		51
Total Other Investments	$	5	$	—	$	56	$	3	$	—	$	55
Total Investments	$	289	$	10	$	744	$	355	$	26	$	787

(a) During the three months ended March 31, 2020, Duke Energy Florida continued to receive reimbursements from the NDTF for costs related to ongoing decommissioning activity of Crystal River Unit 3.

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were immaterial.

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.

	March 31, 2020						December 31, 2019
	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	$	26	$	1	$	63	$	43	$	—	$	81
Corporate debt securities	—		—		4		—		—		6
Municipal bonds	1		1		36		1		—		36
U.S. government bonds	—		—		3		—		—		2
Total Investments	$	27	$	2	$	106	$	44	$	—	$	125

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months ended March 31, 2020, and 2019, were immaterial.

DEBT SECURITY MATURITIES

The table below summarizes the maturity date for debt securities.

	March 31, 2020
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana
Due in one year or less	$	333	$	25	$	302	$	26	$	276	$	3
Due after one through five years	538		234		236		227		9		17
Due after five through 10 years	465		188		214		207		7		7
Due after 10 years	1,375		734		541		506		35		16
Total	$	2,711	$	1,181	$	1,293	$	966	$	327	$	43

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Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2020

VIE primary beneficiary

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	February 2023		December 2022		April 2023		April 2021
Credit facility amount	$	350	$	475	$	375	$	250
Amounts borrowed at March 31, 2020	350		475		325		250
Amounts borrowed at December 31, 2019	350		474		325		250
Restricted Receivables at March 31, 2020	467		616		410		331
Restricted Receivables at December 31, 2019	522		642		489		336

VIE not primary beneficiary

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

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

	March 31, 2020
	Duke Energy												Duke		Duke
	Pipeline			Commercial			Other						Energy		Energy
(in millions)	Investments			Renewables			VIEs			Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	(1	)	$	—		$	(1	)	$	39	$	48
Investments in equity method unconsolidated affiliates	1,243			371			—			1,614			—		—
Total assets	$	1,243		$	370		$	—		$	1,613		$	39	$	48
Taxes accrued	(1		)	—			—			(1		)	—		—
Other current liabilities	—			—			3			3			—		—
Deferred income taxes	69			—			—			69			—		—
Other noncurrent liabilities	105			—			11			116			—		—
Total liabilities	$	173		$	—		$	14		$	187		$	—	$	—
Net assets (liabilities)	$	1,070		$	370		$	(14	)	$	1,426		$	39	$	48

	December 31, 2019
	Duke Energy												Duke		Duke
	Pipeline			Commercial			Other						Energy		Energy
(in millions)	Investments			Renewables			VIEs			Total			Ohio		Indiana
Receivables from affiliated companies	$	—		$	(1	)	$	—		$	(1	)	$	64	$	77
Investments in equity method unconsolidated affiliates	1,179			300			—			1,479			—		—
Total assets	$	1,179		$	299		$	—		$	1,478		$	64	$	77
Taxes accrued	(1		)	—			—			(1		)	—		—
Other current liabilities	—			—			4			4			—		—
Deferred income taxes	59			—			—			59			—		—
Other noncurrent liabilities	—			—			11			11			—		—
Total liabilities	$	58		$	—		$	15		$	73		$	—	$	—
Net assets (liabilities)	$	1,121		$	299		$	(15	)	$	1,405		$	64	$	77

DEFPF | VIE primary beneficiary

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

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

(in millions)	March 31, 2020		December 31, 2019
Receivables of VIEs	$	4	$	5
Regulatory Assets: Current	53		52
Current Assets: Other	13		39
Other Noncurrent Assets: Regulatory assets	980		989
Current Liabilities: Other	2		10
Current maturities of long-term debt	54		54
Long-Term Debt	1,028		1,057

Commercial Renewables | VIE primary beneficiary

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 Commercial Renewables VIEs.

(in millions)	March 31, 2020			December 31, 2019
Current Assets: Other	$	287		$	203
Property, Plant and Equipment: Cost	6,106			5,747
Accumulated depreciation and amortization	(1,094		)	(1,041		)
Other Noncurrent Assets: Other	82			106
Current maturities of long-term debt	162			162
Long-Term Debt	1,538			1,541
Other Noncurrent Liabilities: AROs	129			127
Other Noncurrent Liabilities: Other	258			228

CRC | VIE not primary beneficiary

Variable Interest Entities [Line Items]

Schedule Of Variable Interest Entities

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019
Receivables sold	$	234	$	253	$	274	$	307
Less: Retained interests	39		64		48		77
Net receivables sold	$	195	$	189	$	226	$	230

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

	Duke Energy Ohio				Duke Energy Indiana
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(in millions)	2020		2019		2020		2019
Sales
Receivables sold	$	537	$	575	$	647	$	734
Loss recognized on sale	4		4		4		5
Cash flows
Cash proceeds from receivables sold	$	559	$	597	$	672	$	758
Return received on retained interests	2		2		2		3

Pipeline Investments | VIE not primary beneficiary

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		March 31,		December 31,
Entity Name	Interest		2020		2019
ACP(a)	47	%	$	1,243	$	1,179
Constitution(b)	24	%	—		—
Total			$	1,243	$	1,179

(a) Duke Energy evaluated this investment for impairment as of March 31, 2020, and December 31, 2019, and determined that fair value approximated carrying value and therefore no impairment was necessary.

(b)

During the year ended December 31, 2019, Duke Energy recorded an OTTI related to Constitution. This charge resulted in the full write-down of Duke Energy's investment in Constitution.

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Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2020

Related Party Transactions [Abstract]

Schedule of Related Party Transactions, Other Revenue and Expense

The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
March 31, 2020
Intercompany income tax receivable	$	—	$	114	$	1	$	4	$	—	$	—	$	—
Intercompany income tax payable	44		—		—		—		—		6		10
December 31, 2019
Intercompany income tax receivable	$	—	$	125	$	28	$	—	$	9	$	28	$	13
Intercompany income tax payable	5		—		—		2		—		—		—

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 March 31,
(in millions)	2020		2019
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	134	$	212
Indemnification coverages(b)	5		5
Joint Dispatch Agreement (JDA) revenue(c)	7		23
JDA expense(c)	24		93
Intercompany natural gas purchases(d)	6		4
Progress Energy
Corporate governance and shared service expenses(a)	$	146	$	176
Indemnification coverages(b)	9		9
JDA revenue(c)	24		93
JDA expense(c)	7		23
Intercompany natural gas purchases(d)	19		19
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	75	$	106
Indemnification coverages(b)	4		4
JDA revenue(c)	24		93
JDA expense(c)	7		23
Intercompany natural gas purchases(d)	19		19
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	71	$	70
Indemnification coverages(b)	5		5
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	84	$	85
Indemnification coverages(b)	1		1
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	106	$	97
Indemnification coverages(b)	2		2
Piedmont
Corporate governance and shared service expenses(a)	$	34	$	32
Indemnification coverages(b)	1		1
Intercompany natural gas sales(d)	25		23
Natural gas storage and transportation costs(e)	6		5

(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 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.

(e)

Piedmont has related party transactions as a customer of its equity method investments in Pine Needle LNG Company, LLC, Hardy Storage Company, LLC and Cardinal Pipeline Company, LLC natural gas storage and transportation facilities. These expenses are included in Cost of natural gas on Piedmont's Condensed Consolidated Statements of Operations and Comprehensive Income.

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Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020		Mar. 31, 2019
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income	$ 890		$ 893
Other Comprehensive Loss, net of tax(a)
Pension and OPEB adjustments	1
Net unrealized losses on cash flow hedges	(81)		(17)
Reclassification into earnings from cash flow hedges	2		1
Unrealized gains on available-for-sale securities	1		4
Other Comprehensive Loss, net of tax	(77)	[1]	(12)
Comprehensive Income	813		881
Less: Comprehensive Loss Attributable to Noncontrolling Interests	(62)		(7)
Comprehensive Income Attributable to Duke Energy	875		888
Less: Preferred Dividends	39
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	$ 836		$ 888

[1] Net of income tax impact of approximately $23 million in the first quarter of 2020 and immaterial income tax impact in the first quarter of 2019.

XML

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	$ 890	$ 893
Net income (attributable to parent)	938	900
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,301	1,238
Equity component of AFUDC	(40)	(31)
(Gains) Losses on sales of other assets	(1)	3
Impairment charges	2
Deferred income taxes	422	97
Equity in earnings of unconsolidated affiliates	(44)	(43)
Payments for asset retirement obligations	(132)	(152)
Provision for rate refunds	(13)	35
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions		10
Receivables	466	388
Inventory	(92)	(31)
Other current assets	(131)	98
Increase (decrease) in
Accounts payable	(657)	(636)
Taxes accrued	113	(107)
Other current liabilities	(455)	(407)
Other assets	(25)	(162)
Other liabilities	(50)	46
Net cash provided by operating activities	1,554	1,239
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,832)	(2,536)
Contributions to equity method investments	(77)	(94)
Purchases of debt and equity securities	(1,392)	(860)
Proceeds from sales and maturities of debt and equity securities	1,347	851
Other	(68)	(74)
Net cash used in investing activities	(3,022)	(2,713)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,954	2,737
Proceeds from the issuance of preferred stock		974
Proceeds from the issuance of common stock	40	13
Payments for the redemption of long-term debt	(292)	(1,201)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	1,784	135
Payments for the redemption of short-term debt with original maturities greater than 90 days	(17)	(239)
Notes payable and commercial paper	(198)	(304)
Contributions from noncontrolling interests	103	6
Dividends paid	(707)	(649)
Other	(74)	(39)
Net cash provided by financing activities	2,593	1,433
Net increase (decrease) in cash, cash equivalents and restricted cash	1,125	(41)
Cash, cash equivalents and restricted cash at beginning of period	573	591
Cash, cash equivalents and restricted cash at end of period	1,698	550
Significant non-cash transactions:
Accrued capital expenditures	934	811
Non-cash dividends	27	27
Duke Energy Carolinas
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	339	293
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	414	388
Equity component of AFUDC	(14)	(9)
(Gains) Losses on sales of other assets	(1)
Impairment charges	2
Deferred income taxes	22	64
Payments for asset retirement obligations	(41)	(65)
Provision for rate refunds		19
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions		1
Receivables	156	124
Receivable from affiliated companies	27	94
Inventory	(72)	(59)
Other current assets	96	(35)
Increase (decrease) in
Accounts payable	(253)	(266)
Accounts payable to affiliated companies	15	18
Taxes accrued	87	(91)
Other current liabilities	(108)	(70)
Other assets	(60)	(31)
Other liabilities	(11)	(7)
Net cash provided by operating activities	598	368
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(724)	(721)
Purchases of debt and equity securities	(607)	(405)
Proceeds from sales and maturities of debt and equity securities	607	405
Notes receivable from affiliated companies	(436)
Other	(18)	(9)
Net cash used in investing activities	(1,178)	(730)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	910	25
Payments for the redemption of long-term debt	(2)	(1)
Notes payable to affiliated companies	(29)	306
Distributions to parent	(300)
Other	(1)	(1)
Net cash provided by financing activities	578	329
Net increase (decrease) in cash, cash equivalents and restricted cash	(2)	(33)
Cash, cash equivalents and restricted cash at beginning of period	18	33
Cash, cash equivalents and restricted cash at end of period	16
Significant non-cash transactions:
Accrued capital expenditures	254	221
Progress Energy
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	283	248
Net income (attributable to parent)	283	249
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	552	546
Equity component of AFUDC	(14)	(15)
(Gains) Losses on sales of other assets	1
Deferred income taxes	80	82
Payments for asset retirement obligations	(79)	(75)
Provision for rate refunds	2	6
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	1	1
Receivables	149	187
Receivable from affiliated companies	27	122
Inventory	(40)	(18)
Other current assets	43	35
Increase (decrease) in
Accounts payable	(211)	(196)
Accounts payable to affiliated companies	19	(94)
Taxes accrued	71	26
Other current liabilities	(128)	(196)
Other assets	(41)	(111)
Other liabilities	(56)	(7)
Net cash provided by operating activities	659	541
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(972)	(1,012)
Purchases of debt and equity securities	(651)	(409)
Proceeds from sales and maturities of debt and equity securities	643	405
Notes receivable from affiliated companies	164	(31)
Other	(39)	(45)
Net cash used in investing activities	(855)	(1,092)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		1,295
Payments for the redemption of long-term debt	(283)	(1,132)
Notes payable to affiliated companies	479	370
Other	(1)	1
Net cash provided by financing activities	195	534
Net increase (decrease) in cash, cash equivalents and restricted cash	(1)	(17)
Cash, cash equivalents and restricted cash at beginning of period	126	112
Cash, cash equivalents and restricted cash at end of period	125	95
Significant non-cash transactions:
Accrued capital expenditures	310	310
Duke Energy Progress
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	204	203
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	331	336
Equity component of AFUDC	(10)	(14)
(Gains) Losses on sales of other assets	1
Deferred income taxes	43	33
Payments for asset retirement obligations	(75)	(68)
Provision for rate refunds	2	6
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(2)	(3)
Receivables	133	87
Receivable from affiliated companies	2	(5)
Inventory	(22)	(5)
Other current assets	54	96
Increase (decrease) in
Accounts payable	(220)	(196)
Accounts payable to affiliated companies	5	(57)
Taxes accrued	26	(4)
Other current liabilities	(73)	(109)
Other assets	(51)	(47)
Other liabilities	(8)	(7)
Net cash provided by operating activities	340	246
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(466)	(548)
Purchases of debt and equity securities	(550)	(315)
Proceeds from sales and maturities of debt and equity securities	540	308
Notes receivable from affiliated companies		(38)
Other	(16)	(20)
Net cash used in investing activities	(492)	(613)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		1,270
Payments for the redemption of long-term debt	(1)	(601)
Notes payable to affiliated companies	163	(294)
Other		(1)
Net cash provided by financing activities	162	374
Net increase (decrease) in cash, cash equivalents and restricted cash	10	7
Cash, cash equivalents and restricted cash at beginning of period	22	23
Cash, cash equivalents and restricted cash at end of period	32	30
Significant non-cash transactions:
Accrued capital expenditures	87	117
Duke Energy Florida
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	120	96
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	219	207
Equity component of AFUDC	(4)	(1)
Deferred income taxes	34	45
Payments for asset retirement obligations	(5)	(7)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3	2
Receivables	15	55
Receivable from affiliated companies		(6)
Inventory	(19)	(13)
Other current assets	7	(35)
Increase (decrease) in
Accounts payable	11
Accounts payable to affiliated companies	(20)	(62)
Taxes accrued	31	20
Other current liabilities	(58)	(84)
Other assets	13	(63)
Other liabilities	(46)	(1)
Net cash provided by operating activities	301	153
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(506)	(422)
Purchases of debt and equity securities	(101)	(95)
Proceeds from sales and maturities of debt and equity securities	103	97
Notes receivable from affiliated companies	173
Other	(23)	(25)
Net cash used in investing activities	(354)	(445)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		25
Payments for the redemption of long-term debt	(282)	(81)
Notes payable to affiliated companies	305	291
Other	(1)	2
Net cash provided by financing activities	22	237
Net increase (decrease) in cash, cash equivalents and restricted cash	(31)	(55)
Cash, cash equivalents and restricted cash at beginning of period	56	75
Cash, cash equivalents and restricted cash at end of period	25	20
Significant non-cash transactions:
Accrued capital expenditures	223	193
Duke Energy Ohio
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	65	69
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	69	65
Equity component of AFUDC	(1)	(3)
Deferred income taxes	14	20
Payments for asset retirement obligations		(1)
Provision for rate refunds	3	4
(Increase) decrease in
Receivables	1	5
Receivable from affiliated companies	40	35
Inventory	14	15
Other current assets	8	(6)
Increase (decrease) in
Accounts payable	(19)	(5)
Accounts payable to affiliated companies		(8)
Taxes accrued	(49)	(45)
Other current liabilities	2	14
Other assets	(2)	(10)
Other liabilities	(8)	(4)
Net cash provided by operating activities	137	145
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(217)	(233)
Notes receivable from affiliated companies		(463)
Other	(10)	(11)
Net cash used in investing activities	(227)	(707)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		794
Notes payable to affiliated companies	87	(236)
Net cash provided by financing activities	87	558
Net increase (decrease) in cash, cash equivalents and restricted cash	(3)	(4)
Cash, cash equivalents and restricted cash at beginning of period	17	21
Cash, cash equivalents and restricted cash at end of period	14	17
Significant non-cash transactions:
Accrued capital expenditures	66	68
Duke Energy Indiana
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	99	110
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	133	132
Equity component of AFUDC	(6)	(4)
(Gains) Losses on sales of other assets		3
Deferred income taxes	16	28
Payments for asset retirement obligations	(12)	(11)
(Increase) decrease in
Receivables	15	4
Receivable from affiliated companies	3	20
Inventory	(21)	(13)
Other current assets	25	19
Increase (decrease) in
Accounts payable	(13)	8
Accounts payable to affiliated companies	(21)	(11)
Taxes accrued	43	20
Other current liabilities	(27)	(15)
Other assets	(4)	12
Other liabilities	8	6
Net cash provided by operating activities	238	308
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(210)	(208)
Purchases of debt and equity securities	(5)	(6)
Proceeds from sales and maturities of debt and equity securities	2	4
Notes receivable from affiliated companies	(543)
Other	(6)	(11)
Net cash used in investing activities	(762)	(221)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	544
Payments for the redemption of long-term debt		(60)
Notes payable to affiliated companies	(30)	(31)
Net cash provided by financing activities	514	(91)
Net increase (decrease) in cash, cash equivalents and restricted cash	(10)	(4)
Cash, cash equivalents and restricted cash at beginning of period	25	24
Cash, cash equivalents and restricted cash at end of period	15	20
Significant non-cash transactions:
Accrued capital expenditures	70	76
Piedmont Natural Gas
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (attributable to parent)	178	122
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	46	42
Equity component of AFUDC	(5)
Deferred income taxes	12	23
Equity in earnings of unconsolidated affiliates	(2)	(2)
Provision for rate refunds	(18)	7
(Increase) decrease in
Receivables	65	27
Receivable from affiliated companies	(3)	12
Inventory	33	45
Other current assets	(9)	22
Increase (decrease) in
Accounts payable	(76)	(44)
Accounts payable to affiliated companies	9	(4)
Taxes accrued	12	(49)
Other current liabilities	(12)	15
Other assets	1	(3)
Other liabilities	(1)	(5)
Net cash provided by operating activities	230	208
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(231)	(209)
Other	(5)	(2)
Net cash used in investing activities	(236)	(211)
CASH FLOWS FROM FINANCING ACTIVITIES
Notes payable to affiliated companies	10	3
Net cash provided by financing activities	10	3
Net increase (decrease) in cash, cash equivalents and restricted cash	4
Cash, cash equivalents and restricted cash at end of period	4
Significant non-cash transactions:
Accrued capital expenditures	$ 114	$ 92

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Regulatory Matters (Regulatory Matters Narrative - Duke Energy Indiana) (Details) - Indiana rate case 2019 - IURC - Duke Energy Indiana - USD ($) $ in Millions	Dec. 04, 2019	Sep. 09, 2019	Jul. 02, 2019	Dec. 31, 2018
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ 395	$ 395
Rate base				$ 10,200
Requested rate increase (decrease), amended amount	$ 396	393
Amount reduced from initial request		$ 2
Requested rate increase, percentage			15.00%
Requested rate increase, percentage, net of tax	15.60%		17.00%

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Commitments and Contingencies (Schedule of Environmental Loss Contingencies) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($)
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	$ 58
Provisions/adjustments	3
Cash reductions	(3)
Balance at end of period	58
Environmental exit costs, reasonably possible additional loss	58
Duke Energy Carolinas
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	11
Cash reductions	(1)
Balance at end of period	10
Environmental exit costs, reasonably possible additional loss	11
Progress Energy
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	16
Cash reductions	(1)
Balance at end of period	15
Duke Energy Progress
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	4
Provisions/adjustments	1
Cash reductions	0
Balance at end of period	5
Duke Energy Florida
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	9
Cash reductions	0
Balance at end of period	9
Duke Energy Ohio
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	19
Provisions/adjustments	1
Cash reductions	(1)
Balance at end of period	19
Environmental exit costs, reasonably possible additional loss	41
Duke Energy Indiana
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	4
Provisions/adjustments	1
Cash reductions	0
Balance at end of period	5
Piedmont Natural Gas
Accrual for Environmental Loss Contingencies [Roll Forward]
Balance at beginning of period	8
Cash reductions	0
Balance at end of period	8
Environmental exit costs, reasonably possible additional loss	$ 2

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Revenue (Remaining Performance Obligations Total) (Details) (Details) $ in Millions	Mar. 31, 2020 USD ($)
Progress Energy
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 410
Duke Energy Progress
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	38
Duke Energy Florida [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	372
Duke Energy Indiana
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	13
Piedmont Natural Gas
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 675

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Fair Value Measurements (Quantitative Level 3 Fair Value Disclosures) (Details) $ in Millions	Mar. 31, 2020 USD ($) $ / MWh $ / MMBTU	Dec. 31, 2019 USD ($) $ / MWh $ / MMBTU	Mar. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability) | $	$ (88)	$ (102)	$ (115)	$ (113)
Duke Energy Ohio | FTRs | RTO auction pricing
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability) | $	$ 1	$ 4
Duke Energy Ohio | FTRs | Minimum | RTO auction pricing
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	0.04	0.59
Duke Energy Ohio | FTRs | Maximum | RTO auction pricing
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	3.29	3.47
Duke Energy Ohio | FTRs | Weighted Average | RTO auction pricing
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	1.03	2.07
Duke Energy Indiana
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability) | $	$ 2	$ 11	5	22
Duke Energy Indiana | FTRs | RTO auction pricing
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability) | $	$ 2	$ 11
Duke Energy Indiana | FTRs | Minimum | RTO auction pricing
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	(0.37)	(0.66)
Duke Energy Indiana | FTRs | Maximum | RTO auction pricing
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	6.06	9.24
Duke Energy Indiana | FTRs | Weighted Average | RTO auction pricing
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MWh	0.54	1.15
Piedmont Natural Gas
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability) | $	$ (91)	$ (117)	$ (121)	$ (141)
Piedmont Natural Gas | Natural gas contracts | Discounted cash flow
Fair Value Measurement Inputs and Valuation Techniques
Net derivative asset (liability) | $	$ (91)	$ (117)
Piedmont Natural Gas | Natural gas contracts | Minimum | Discounted cash flow
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MMBTU	1.64	1.59
Piedmont Natural Gas | Natural gas contracts | Maximum | Discounted cash flow
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MMBTU	2.41	2.46
Piedmont Natural Gas | Natural gas contracts | Weighted Average | Discounted cash flow
Fair Value Measurement Inputs and Valuation Techniques
Input measurements (in usd per MWh and usd per MMBtu) | $ / MMBTU	1.94	1.91

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Investments in Debt and Equity Securities (Realized Gains and Losses) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
FV-NI:
Realized gains	$ 23	$ 35
Realized losses	65	30
AFS:
Realized gains	20	10
Realized losses	6	11
Duke Energy Carolinas
FV-NI:
Realized gains	9	23
Realized losses	45	21
AFS:
Realized gains	12	9
Realized losses	5	10
Progress Energy
FV-NI:
Realized gains	14	12
Realized losses	20	9
AFS:
Realized gains	5	1
Realized losses	1	1
Duke Energy Progress
FV-NI:
Realized gains	14	10
Realized losses	20	8
AFS:
Realized gains	5	1
Realized losses	$ 1	$ 1

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Variable Interest Entities (Pipeline Investments) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Variable Interest Entities [Line Items]
Investments in joint ventures	$ 2,067	$ 1,936
VIE not primary beneficiary
Variable Interest Entities [Line Items]
Investments in joint ventures	$ 1,614	1,479
ACP
Variable Interest Entities [Line Items]
Ownership percentage	47.00%
ACP | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Investments in joint ventures	$ 1,243	1,179
Constitution
Variable Interest Entities [Line Items]
Ownership percentage	24.00%
Pipeline Investments | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Investments in joint ventures	$ 1,243	$ 1,179

XML

Variable Interest Entities (Narrative) (Details) - USD ($)		3 Months Ended	12 Months Ended
	Mar. 31, 2018	Mar. 31, 2020	Dec. 31, 2019
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates		$ 2,067,000,000	$ 1,936,000,000
VIE primary beneficiary
Variable Interest Entities [Line Items]
Variable interest entity, financial or other support, amount		0	0
VIE not primary beneficiary
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates		1,614,000,000	1,479,000,000
FES
Variable Interest Entities [Line Items]
Power participation ratio	4.85%
ACP | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Investments in equity method unconsolidated affiliates		1,243,000,000	$ 1,179,000,000
ACP | Financial guarantee
Variable Interest Entities [Line Items]
Maximum potential amount of future payments associated with guarantees		$ 845,000,000
Percentage of potential amount of future payments associated with guarantees as percent of outstanding borrowings		47.00%
CRC | VIE primary beneficiary
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
OVEC | VIE not primary beneficiary
Variable Interest Entities [Line Items]
Variable interest entity ownership interest		9.00%

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Derivatives and Hedging (Schedule of Offsetting Assets) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	$ 34	$ 25
Net amounts recognized on the Condensed Consolidated Balance Sheet	34	25
Current assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	9	24
Gross amounts offset		(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	9	23
Noncurrent assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	25	1
Gross amounts offset	(3)
Net amounts recognized on the Condensed Consolidated Balance Sheet	2	1
Net amounts presented in NDTF
Offsetting Derivative Assets [Abstract]
Net amounts recognized on the Condensed Consolidated Balance Sheet	20
Duke Energy Carolinas
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2
Net amounts recognized on the Condensed Consolidated Balance Sheet	2
Duke Energy Carolinas | Noncurrent assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2
Gross amounts offset	(2)
Progress Energy
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	25	7
Net amounts recognized on the Condensed Consolidated Balance Sheet	25	7
Progress Energy | Current assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	3	7
Gross amounts offset		(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	3	6
Progress Energy | Noncurrent assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	22
Gross amounts offset	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	1
Progress Energy | Net amounts presented in NDTF
Offsetting Derivative Assets [Abstract]
Net amounts recognized on the Condensed Consolidated Balance Sheet	20
Duke Energy Progress
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	5
Net amounts recognized on the Condensed Consolidated Balance Sheet	5
Duke Energy Progress | Current assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	3
Net amounts recognized on the Condensed Consolidated Balance Sheet	3
Duke Energy Progress | Noncurrent assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2
Gross amounts offset	(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet	1
Duke Energy Florida
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	20	7
Net amounts recognized on the Condensed Consolidated Balance Sheet		7
Duke Energy Florida | Current assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized		7
Gross amounts offset		(1)
Net amounts recognized on the Condensed Consolidated Balance Sheet		6
Duke Energy Florida | Noncurrent assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	20
Duke Energy Florida | Net amounts presented in NDTF
Offsetting Derivative Assets [Abstract]
Net amounts recognized on the Condensed Consolidated Balance Sheet	20
Duke Energy Ohio
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	1	4
Duke Energy Ohio | Current assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized		3
Net amounts recognized on the Condensed Consolidated Balance Sheet		3
Duke Energy Ohio | Noncurrent assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	1	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	1
Duke Energy Indiana
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2	13
Net amounts recognized on the Condensed Consolidated Balance Sheet	2	13
Duke Energy Indiana | Current assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	2	13
Net amounts recognized on the Condensed Consolidated Balance Sheet	2	13
Piedmont Natural Gas
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	3	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	3	1
Piedmont Natural Gas | Current assets
Offsetting Derivative Assets [Abstract]
Gross amounts recognized	3	1
Net amounts recognized on the Condensed Consolidated Balance Sheet	$ 3	$ 1

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Business Segments (Narrative) (Details)	3 Months Ended
	Mar. 31, 2020 segment
Duke Energy Ohio
Segment Reporting Information [Line Items]
Number of reportable segments	2

XML

Organization and Basis of Presentation (Schedule of Cash and Cash Equivalents) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019	Dec. 31, 2018
Current Assets
Cash and cash equivalents	$ 1,450	$ 311
Other	185	222
Other Noncurrent Assets
Other	63	40
Total cash, cash equivalents and restricted cash	1,698	573	$ 550	$ 591
Progress Energy
Current Assets
Cash and cash equivalents	52	48
Other	13	39
Other Noncurrent Assets
Other	60	39
Total cash, cash equivalents and restricted cash	125	126	95	112
Duke Energy Florida
Current Assets
Cash and cash equivalents	12	17
Other	13	39
Other Noncurrent Assets
Total cash, cash equivalents and restricted cash	$ 25	$ 56	$ 20	$ 75

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Debt and Credit Facilities (Summary of Current Maturities of Long-term Debt) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 5,077	$ 3,141
Other debt obligations
Debt Instrument [Line Items]
Current maturities of long-term debt	359
Duke Energy Progress
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 1,006	1,006
Duke Energy Progress | Unsecured Debt | Debt maturing December 2020, floating interest rate
Debt Instrument [Line Items]
Interest Rate	2.292%
Current maturities of long-term debt	$ 700
Duke Energy Progress | First Mortgage Bonds | Bonds maturing September 2020, floating interest rate
Debt Instrument [Line Items]
Interest Rate	1.076%
Current maturities of long-term debt	$ 300
Progress Energy
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 1,828	1,577
Progress Energy | Unsecured Debt | Debt maturing January 2021, 4.400% interest rate
Debt Instrument [Line Items]
Interest Rate	4.40%
Current maturities of long-term debt	$ 500
Duke Energy Florida
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 322	571
Duke Energy Florida | First Mortgage Bonds | Bonds maturing April 2020, 4.550% interest rate
Debt Instrument [Line Items]
Interest Rate	4.55%
Current maturities of long-term debt	$ 250
Duke Energy Carolinas
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 457	458
Duke Energy Carolinas | First Mortgage Bonds | Bonds maturing June 2020, 4.300% interest rate
Debt Instrument [Line Items]
Interest Rate	4.30%
Current maturities of long-term debt	$ 450
Duke Energy Indiana
Debt Instrument [Line Items]
Current maturities of long-term debt	$ 503	$ 503
Duke Energy Indiana | First Mortgage Bonds | Bonds maturing July 2020, 3.750% interest rate
Debt Instrument [Line Items]
Interest Rate	3.75%
Current maturities of long-term debt	$ 500
Duke Energy (Parent) | Unsecured Debt | Debt maturing June 2020, 2.100% interest rate
Debt Instrument [Line Items]
Interest Rate	2.10%
Current maturities of long-term debt	$ 330
Duke Energy (Parent) | Unsecured Debt | Debt maturing March 2021, floating interest rate
Debt Instrument [Line Items]
Interest Rate	1.40%
Current maturities of long-term debt	$ 1,688

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Revenue (Disaggregation of Revenue) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 5,800	$ 5,998
Revenue from sources other than contracts with customers	149	165
Total operating revenues	5,949	6,163
Electric Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	5,134	5,221
Total operating revenues	5,174	5,321
Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,261	2,370
Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | General
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,492	1,427
Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	693	711
Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	497	541
Electric Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	191	172
Gas Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	602	731
Total operating revenues	640	732
Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	362	414
Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	169	206
Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	41	48
Gas Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	30	63
Commercial Renewables
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	58	42
Total operating revenues	129	106
Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6	4
Total operating revenues	6	4
Duke Energy Carolinas
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,748	1,719
Revenue from sources other than contracts with customers		25
Total operating revenues	1,748	1,744
Duke Energy Carolinas | Electric Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,748	1,719
Duke Energy Carolinas | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	756	760
Duke Energy Carolinas | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | General
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	549	496
Duke Energy Carolinas | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	269	266
Duke Energy Carolinas | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	114	119
Duke Energy Carolinas | Electric Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	60	78
Progress Energy
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,367	2,493
Revenue from sources other than contracts with customers	55	79
Total operating revenues	2,422	2,572
Progress Energy | Electric Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,367	2,493
Progress Energy | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,064	1,114
Progress Energy | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | General
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	648	632
Progress Energy | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	216	222
Progress Energy | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	321	353
Progress Energy | Electric Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	118	172
Duke Energy Progress
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,317	1,443
Revenue from sources other than contracts with customers	21	41
Total operating revenues	1,338	1,484
Duke Energy Progress | Electric Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,317	1,443
Duke Energy Progress | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	502	536
Duke Energy Progress | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | General
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	319	306
Duke Energy Progress | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	154	161
Duke Energy Progress | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	279	315
Duke Energy Progress | Electric Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	63	125
Duke Energy Florida
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,050	1,050
Revenue from sources other than contracts with customers	30	36
Total operating revenues	1,080	1,086
Duke Energy Florida | Electric Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,050	1,050
Duke Energy Florida | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	562	578
Duke Energy Florida | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | General
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	329	326
Duke Energy Florida | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	62	61
Duke Energy Florida | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	42	38
Duke Energy Florida | Electric Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	55	47
Duke Energy Ohio
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	504	531
Revenue from sources other than contracts with customers	(6)
Total operating revenues	498	531
Duke Energy Ohio | Electric Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	352	355
Duke Energy Ohio | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	176	189
Duke Energy Ohio | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | General
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	114	103
Duke Energy Ohio | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	35	33
Duke Energy Ohio | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	7	14
Duke Energy Ohio | Electric Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	20	16
Duke Energy Ohio | Gas Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	152	176
Duke Energy Ohio | Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	97	112
Duke Energy Ohio | Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	43	49
Duke Energy Ohio | Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6	7
Duke Energy Ohio | Gas Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6	8
Duke Energy Indiana
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	692	764
Revenue from sources other than contracts with customers		4
Total operating revenues	692	768
Duke Energy Indiana | Electric Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	692	764
Duke Energy Indiana | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	265	306
Duke Energy Indiana | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | General
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	181	197
Duke Energy Indiana | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	175	190
Duke Energy Indiana | Electric Utilities and Infrastructure | Electric Utilities and Infrastructure | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	55	54
Duke Energy Indiana | Electric Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	16	17
Duke Energy Indiana | Gas Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers		0
Piedmont Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	461	570
Revenue from sources other than contracts with customers	51	9
Total operating revenues	512	579
Piedmont Natural Gas | Gas Utilities and Infrastructure
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	461	570
Piedmont Natural Gas | Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	264	302
Piedmont Natural Gas | Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	126	157
Piedmont Natural Gas | Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	36	42
Piedmont Natural Gas | Gas Utilities and Infrastructure | Gas Utilities and Infrastructure | Power Generation
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	11	13
Piedmont Natural Gas | Gas Utilities and Infrastructure | Other revenues
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 24	$ 56

XML

Stockholders' Equity (Earnings Per Share Data) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Class of Stock [Line Items]
Income from continuing operations available to Duke Energy common stockholders excluding impact of participating securities and including accumulated preferred stock dividends adjustment	$ 911	$ 898
Weighted average common shares outstanding – basic (in shares)	734	727
Equity Forwards (in shares)	2
Weighted average common shares outstanding – diluted (in shares)	736	727
Basic and diluted (in usd per share)	$ 1.24	$ 1.24
Potentially dilutive items excluded from the calculation (in shares)	2	2
Common Stock
Class of Stock [Line Items]
Dividends declared per common share (in usd per share)	$ 0.945	$ 0.9275
Preferred stock, Series A
Class of Stock [Line Items]
Dividends declared on preferred stock per depositary share (in usd per share)	$ 0.359
Cumulative dividend rate per annum	5.75%
Price per share (in usd per share)	$ 25
Preferred stock, Series B
Class of Stock [Line Items]
Dividends declared on preferred stock per depositary share (in usd per share)	$ 24.917
Cumulative dividend rate per annum	4.875%
Liquidation preference per share (in usd per share)	$ 1,000

XML

Goodwill (Rollforward of Goodwill) (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Goodwill [Line Items]
Goodwill balance	$ 19,425	$ 19,425
Accumulated impairment charges	(122)	(122)
Goodwill, adjusted for accumulated impairment charges	19,303	19,303
Electric Utilities and Infrastructure
Goodwill [Line Items]
Goodwill balance	17,379	17,379
Goodwill, adjusted for accumulated impairment charges	17,379	17,379
Gas Utilities and Infrastructure
Goodwill [Line Items]
Goodwill balance	1,924	1,924
Goodwill, adjusted for accumulated impairment charges	1,924	1,924
Commercial Renewables
Goodwill [Line Items]
Goodwill balance	122	122
Accumulated impairment charges	$ (122)	$ (122)

XML

Derivatives and Hedging (Notional Amounts of Derivative Instruments) (Details) Mcf in Millions, $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020 USD ($) GWh Mcf	Dec. 31, 2019 USD ($) GWh Mcf
Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 3,018	$ 2,270
Commodity contracts | Electricity (GWh)
Derivative [Line Items]
Notional amount, energy measure (in gigawatt-hours) | GWh	6,737	15,858
Commodity contracts | Natural gas (millions of dekatherms)
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	709	704
Designated contracts | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 991	$ 993
Undesignated contracts | Interest Rate Contracts
Derivative [Line Items]
Notional amount	2,027	1,277
VIE primary beneficiary | Designated contracts | Interest Rate Contracts
Derivative [Line Items]
Notional amount	691	693
Duke Energy Carolinas | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 400	$ 450
Duke Energy Carolinas | Commodity contracts | Natural gas (millions of dekatherms)
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	145	130
Duke Energy Carolinas | Undesignated contracts | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 400	$ 450
Progress Energy | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 1,600	$ 800
Progress Energy | Commodity contracts | Natural gas (millions of dekatherms)
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	158	160
Progress Energy | Undesignated contracts | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 1,600	$ 800
Duke Energy Progress | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 1,050	$ 250
Duke Energy Progress | Commodity contracts | Natural gas (millions of dekatherms)
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	158	160
Duke Energy Progress | Undesignated contracts | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 1,050	$ 250
Duke Energy Florida | Interest Rate Contracts
Derivative [Line Items]
Notional amount	550	550
Duke Energy Florida | Undesignated contracts | Interest Rate Contracts
Derivative [Line Items]
Notional amount	550	550
Duke Energy Ohio | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 27	$ 27
Duke Energy Ohio | Commodity contracts | Electricity (GWh)
Derivative [Line Items]
Notional amount, energy measure (in gigawatt-hours) | GWh	977	1,887
Duke Energy Ohio | Undesignated contracts | Interest Rate Contracts
Derivative [Line Items]
Notional amount	$ 27	$ 27
Duke Energy Indiana | Commodity contracts | Electricity (GWh)
Derivative [Line Items]
Notional amount, energy measure (in gigawatt-hours) | GWh	5,760	13,971
Duke Energy Indiana | Commodity contracts | Natural gas (millions of dekatherms)
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	4	3
Piedmont Natural Gas | Commodity contracts | Natural gas (millions of dekatherms)
Derivative [Line Items]
Notional amount, volume (in millions of decatherms) | Mcf	402	411

XML

Income Taxes (Narrative) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($)
AMT credit carryforwards
Tax Credit Carryforward [Line Items]
Tax refund	$ 572

XML

Stockholders' Equity

3 Months Ended

Mar. 31, 2020

Equity [Abstract]

Stockholders' Equity

STOCKHOLDERS' EQUITY

Basic EPS is computed by dividing net income available 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 available 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. Dividends declared on preferred stock are recorded on the Condensed Consolidated Statements of Operations as a reduction of net income to arrive at net income available to Duke Energy common stockholders. Dividends accumulated on preferred stock are an adjustment to net income used in the calculation of basic and diluted EPS.

The following table presents Duke Energy’s basic and diluted EPS calculations, the weighted average number of common shares outstanding and common and preferred share dividends declared.

	Three Months Ended March 31,
(in millions, except per share amounts)	2020		2019
Income from continuing operations available to Duke Energy common stockholders excluding impact of participating securities and including accumulated preferred stock dividends adjustment	$	911	$	898
Weighted average common shares outstanding – basic	734		727
Equity forwards	2		—
Weighted average common shares outstanding – diluted	736		727
EPS from continuing operations available to Duke Energy common stockholders
Basic and diluted	$	1.24	$	1.24
Potentially dilutive items excluded from the calculation(a)	2		2
Dividends declared per common share	$	0.945	$	0.9275
Dividends declared on Series A preferred stock per depositary share(b)	$	0.359	$	—
Dividends declared on Series B preferred stock per share(c)	$	24.917	$	—

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

(b) 5.75% Series A Cumulative Redeemable Perpetual Preferred Stock dividends are payable quarterly in arrears on the 16th day of March, June, September and December. The preferred stock has a $25 liquidation preference per depositary share.

(c) 4.875% Series B Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock dividends are payable semiannually in arrears on the 16th day of March and September. The preferred stock has a $1,000 liquidation preference per share.

Common Stock

In November 2019, Duke Energy filed a prospectus supplement and executed an Equity Distribution Agreement (EDA) under which it may sell up to $1.5 billion of its common stock through an at-the-market (ATM) offering program, including an equity forward sales component. Under the terms of the EDA, Duke Energy may issue and sell shares of common stock through September 2022. In March 2020, Duke Energy marketed approximately 940,000 shares of common stock through an equity forward transaction under the ATM with an initial forward price of $89.76 per share.

Separately, in November 2019, Duke Energy marketed an equity offering of 28.75 million shares of common stock through an Underwriting Agreement. In connection with the offering, Duke Energy entered into an equity forward sales agreement with an initial forward price of $85.99 per share.

The equity forward sales agreements require Duke Energy to either physically settle the transaction by issuing shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement, or net settle in whole or in part through the delivery or receipt of cash or shares. The settlement alternatives are at Duke Energy's election. Settlement of the forward sales agreements are expected to occur on or prior to December 31, 2020. Until settlement of the equity forwards, EPS dilution resulting from the agreements, if any, will be determined under the treasury stock method.

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Organization and Basis of Presentation (Policy)

3 Months Ended

Mar. 31, 2020

Policy Text Block [Line Items]

Basis of Presentation

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with 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 and should be read in conjunction with the Consolidated Financial Statements in the Duke Energy Registrants’ combined Annual Report on Form 10-K for the year ended December 31, 2019.

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.

Basis of Consolidation and Noncontrolling Interest

BASIS OF CONSOLIDATION

These Condensed Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and subsidiaries or VIEs where the respective Duke Energy Registrants have control. See Note 11 for additional information on VIEs. These Condensed Consolidated Financial Statements also reflect the Duke Energy Registrants’ proportionate share of certain jointly owned generation and transmission facilities.

COVID-19

The COVID-19 pandemic is having a significant impact on global health and economic environments. In March 2020, the World Health Organization (WHO) declared COVID-19 a global pandemic, and President Trump proclaimed that the COVID-19 outbreak in the United States constitutes a national emergency. The COVID-19 pandemic has not had a material financial impact on the Duke Energy Registrants as of March 31, 2020; however, the extent to which the COVID-19 pandemic will impact the Duke Energy Registrants during 2020 and beyond is uncertain at this time. The Duke Energy Registrants are monitoring developments closely. See Notes 3, 5, 11, 12 and 15 for information on COVID-19 and steps taken to mitigate the impacts to our business and customers.

NONCONTROLLING INTEREST

Duke Energy maintains a controlling financial interest in certain less than wholly owned nonregulated subsidiaries. As a result, Duke Energy consolidates these subsidiaries and presents the third-party investors' portion of Duke Energy's net income (loss), net assets and comprehensive income (loss) as noncontrolling interest. Noncontrolling interest is included as a component of equity on the Condensed Consolidated Balance Sheet.

Several operating agreements of Duke Energy's subsidiaries with noncontrolling interest are subject to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements that vary throughout the lives of the subsidiaries. Therefore, Duke Energy and the other investors' (the owners) interests in the subsidiaries are not fixed, and the subsidiaries apply the Hypothetical Liquidation at Book Value (HLBV) method in allocating income or loss and other comprehensive income or loss (all measured on a pretax basis) to the owners. The HLBV method measures the amounts that each owner would hypothetically claim at each balance sheet reporting date, including tax benefits realized by the owners, upon a hypothetical liquidation of the subsidiary at the net book value of its underlying assets. The change in the amount that each owner would hypothetically receive at the reporting date compared to the amount it would have received on the previous reporting date represents the amount of income or loss allocated to each owner for the reporting period. Duke Energy has received $103 million for the sale of noncontrolling interests to tax equity members for the three months ended March 31, 2020. Duke Energy allocated approximately $49 million and $7 million of losses to noncontrolling tax equity members utilizing the HLBV method for the three months ended March 31, 2020, and March 31, 2019, respectively.

Other operating agreements of Duke Energy's subsidiaries with noncontrolling interest allocate profit and loss based on their pro rata shares of the ownership interest in the respective subsidiary. Therefore, Duke Energy allocates net income or loss and other comprehensive income or loss of these subsidiaries to the owners based on their pro rata shares.

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 VIEs. See Note 11 for additional information. Restricted cash amounts are included in Other within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.

New Accounting Standards

NEW ACCOUNTING STANDARDS

The following new accounting standard was adopted by the Duke Energy Registrants in 2020.

Current Expected Credit Losses. In June 2016, the FASB issued new accounting guidance for credit losses. Duke Energy adopted the new accounting guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year results. Duke Energy did not adopt any practical expedients.

Duke Energy recognizes allowances for credit losses based on management's estimate of losses expected to be incurred over the lives of certain assets or guarantees. Management monitors credit quality, changes in expected credit losses and the appropriateness of the allowance for credit losses on a forward-looking basis. Management reviews the risk of loss periodically as part of the existing assessment of collectability of receivables.

Duke Energy reviews the credit quality of its counterparties as part of its regular risk management process and requires credit enhancements, such as deposits or letters of credit, as appropriate and as allowed by regulators.

Duke Energy recorded cumulative effects of changes in accounting principles related to the adoption of new credit loss standard, for allowances for credit losses of trade and other receivables, insurance receivables and financial guarantees. These amounts are included in the Condensed Consolidated Balance Sheets in Receivables, Receivables of VIEs, Other Noncurrent Assets and Other Noncurrent Liabilities. See Notes 4 and 12 for more information.

Duke Energy recorded an adjustment for the cumulative effect of a change in accounting principle due to the adoption of this standard on January 1, 2020, as shown in the table below:

	January 1, 2020
			Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Piedmont
Total pretax impact to Retained Earnings	$	120	$	16	$	2	$	1	$	1	$	1

The following new accounting standard has been issued but not yet adopted by the Duke Energy Registrants as of March 31, 2020.

Reference Rate Reform. In March 2020, the FASB issued new accounting guidance for reference rate reform. This guidance is elective and provides expedients to facilitate financial reporting for the anticipated transition away from the London Inter-bank Offered Rate (LIBOR) and other interbank reference rates by the end of 2021. The optional expedients are effective for modification of existing contracts or new arrangements executed between March 12, 2020, through December 31, 2022.

Duke Energy has variable-rate debt and manages interest rate risk by entering into financial contracts including interest rate swaps that are generally indexed to LIBOR. Impacted financial arrangements extending beyond 2021 may require contractual amendment or termination to fully adapt to a post-LIBOR environment. Duke Energy is assessing these financial arrangements and is evaluating the use of optional expedients outlined in the new accounting guidance. Alternative index provisions are also being assessed and incorporated into new financial arrangements that extend beyond 2021.

Environmental Costs

Liabilities are recorded when losses become probable and are reasonably estimable.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.

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

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 has a credit loss. The Duke Energy Registrants analyze all investment holdings each reporting period to determine whether a decline in fair value is related to a credit loss. If an credit loss exists, the unrealized credit loss is included in earnings.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 recognized immediately and deferred to regulatory accounts where appropriate.

Revenue from Contract with Customer

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 account for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana.

Earnings Per Share

Basic EPS is computed by dividing net income available 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 available 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. Dividends declared on preferred stock are recorded on the Condensed Consolidated Statements of Operations as a reduction of net income to arrive at net income available to Duke Energy common stockholders. Dividends accumulated on preferred stock are an adjustment to net income used in the calculation of basic and diluted EPS.