~~0001326160us-gaap:FairValueInputsLevel2Memberduk:ProgressEnergyMemberduk:NdtfMember2021-03-31~~0001326160duk:DukeEnergyIndianaMembersrt:MinimumMemberduk:DerivativeFinancialInstrumentsLiabilitiesFinancialTransmissionRightsMemberus-gaap:MarketApproachValuationTechniqueMember2021-12-31

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, ~~2021~~2022


☐			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~~526 South ~~Tryon~~Church 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

☒

☐

Duke Energy Florida, LLC (Duke Energy Florida)

Yes

☒

☐

Duke Energy Carolinas, LLC (Duke Energy Carolinas)

Yes

☒

☐

Duke Energy Ohio, Inc. (Duke Energy Ohio)

Yes

☒

☐

Progress Energy, Inc. (Progress Energy)

Yes

☒

☐

Duke Energy Indiana, LLC (Duke Energy Indiana)

Yes

☒

☐

Duke Energy Progress, LLC (Duke Energy Progress)

Yes

☒

☐

Piedmont Natural Gas Company, Inc. (Piedmont)

Yes

☒

☐

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

☒

☐

Duke Energy Florida

Yes

☒

☐

Duke Energy Carolinas

Yes

☒

☐

Duke Energy Ohio

Yes

☒

☐

Progress Energy

Yes

☒

☐

Duke Energy Indiana

Yes

☒

☐

Duke Energy Progress

Yes

☒

☐

Piedmont

Yes

☒

☐

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

☐

☒

Duke Energy Florida

Yes

☐

☒

Duke Energy Carolinas

Yes

☐

☒

Duke Energy Ohio

Yes

☐

☒

Progress Energy

Yes

☐

☒

Duke Energy Indiana

Yes

☐

☒

Duke Energy Progress

Yes

☐

☒

Piedmont

Yes

☐

☒

Number of shares of common stock outstanding at April 30, ~~2021:~~2022:


Registrant	Description	Shares
Duke Energy	Common stock, $0.001 par value	~~769,218,956~~769,900,482

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	4443
	Note 3 – Regulatory Matters	4645
	Note 4 – Commitments and Contingencies	5549

	Note 5 – Debt and Credit Facilities	5853

	Note 6 – Goodwill	5954
	Note 7 – Related Party Transactions	6055
	Note 8 – Derivatives and Hedging	6156
	Note 9 – Investments in Debt and Equity Securities	6661
	Note 10 – Fair Value Measurements	7066
	Note 11 – Variable Interest Entities	7570
	Note 12 – Revenue	7874
	Note 13 – Stockholders' Equity	8277
	Note 14 – Employee Benefit Plans	8378
	Note 15 – Income Taxes	8479
	Note 16 – Subsequent Events	8479

Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	8580

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	~~100~~93

Item 4.	Controls and Procedures	~~100~~93

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	~~101~~94

Item 1A.	Risk Factors	~~101~~94

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	~~101~~94

Item 6.	Exhibits	~~102~~95

	Signatures	~~105~~99


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, asset retirement and construction costs related to carbon emissions reductions, 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, natural gas building and appliance electrification, 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, natural gas electrification, and distributed generation technologies, such as private solar and battery storage, in Duke Energy service territories could result in a reduced number of 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;

◦Changing investor, customer and other stakeholder expectations and demands including heightened emphasis on environmental, social and governance concerns;

◦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~~U.S. electric grid or generating resources;

◦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, an individual utility's generation mix, 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;


FORWARD-LOOKING STATEMENTS

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

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

◦Asset or business acquisitions and dispositions, including our ability to successfully consummate the second closing of the minority investment in Duke Energy Indiana, may not yield the anticipated benefits;

◦The actions of activist shareholders could disrupt our operations, impact our ability to execute on our business strategy, or cause fluctuations in the trading price of our common stock; and

◦The ability to implement our business strategy, including ~~enhancing existing technology systems.~~its carbon emission reduction goals.

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 Office of Public Counsel and other customer representatives~~

2017 Settlement			Second Revised and Restated Settlement Agreement in 2017 among Duke Energy Florida, the Florida Office of Public Counsel and other customer representatives, which replaces and supplants the 2013 Settlement

2021 Settlement			Settlement Agreement in 2021 among Duke Energy Florida, the Florida Office of Public Counsel, the Florida Industrial Power Users Group, White Springs Agricultural Chemicals, Inc. d/b/a PSC Phosphate and NUCOR Steel Florida, Inc.

ACP			Atlantic Coast Pipeline, LLC, a limited liability company owned by Dominion Energy, Inc. and Duke Energy

~~ACP pipeline~~			~~The approximately 600-mile canceled interstate natural gas pipeline~~

AFS			Available for Sale

AFUDC			Allowance for funds used during construction

ARO			Asset retirement obligations

Bison			Bison Insurance Company Limited

CCR			Coal Combustion Residuals

~~Coal Ash Act~~			~~North Carolina Coal Ash Management Act of 2014~~

the company			Duke Energy Corporation and its subsidiaries

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

DOE			Department of Energy

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~~EPS			~~U.S. Environmental Protection Agency~~Earnings Per Share

~~EPS~~ERCOT			~~Earnings Per Share~~Electric Reliability Council of Texas

ETR			Effective tax rate

Exchange Act			Securities Exchange Act of 1934

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 Earnings Per Share Available to Duke Energy Corporation common stockholders

GIC			GIC Private Limited, Singapore's sovereign wealth fund and an experienced investor in U.S. infrastructure

GWh			Gigawatt-hours

IRS			Internal Revenue Service


GLOSSARY OF TERMS


~~GIC~~			~~GIC Private Limited~~

~~GWh~~			~~Gigawatt-hours~~

~~IGCC~~			~~Integrated Gasification Combined Cycle~~

~~IMR~~			~~Integrity Management Rider~~

~~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

MGP Settlement			Stipulation and Recommendation filed jointly by Duke Energy Ohio the staff of the PUCO, the Office of the Ohio Consumers' Counsel and the Ohio Energy Group on August 31, 2021

MW			Megawatt

MWh			Megawatt-hour

NCUC			North Carolina Utilities Commission

NDTF			Nuclear decommissioning trust funds

NPNS			Normal purchase/normal sale

OPEB			Other Post-Retirement Benefit Obligations

OVEC			Ohio Valley Electric Corporation

PBR			Performance-Based Regulation

Piedmont			Piedmont Natural Gas Company, Inc.

PJM			Pennsylvania-New Jersey-Maryland Interconnection

PPA			Purchase Power Agreement

Progress Energy			Progress Energy, Inc.

PSCSC			Public Service Commission of South Carolina

PUCO			Public Utilities Commission of Ohio

RTO			Regional Transmission Organization

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					Three Months Ended
		March 31,					March 31,
(in millions, except per share amounts)	(in millions, except per share amounts)	2021		2020		(in millions, except per share amounts)		2022		2021
Operating Revenues	Operating Revenues					Operating Revenues
Regulated electric	Regulated electric	$	5,219	$	5,124	Regulated electric		$	5,933	$	5,219
Regulated natural gas	Regulated natural gas	749		638		Regulated natural gas		1,002		749
Nonregulated electric and other	Nonregulated electric and other	182		187		Nonregulated electric and other		197		182
Total operating revenues	Total operating revenues	6,150		5,949		Total operating revenues		7,132		6,150
Operating Expenses	Operating Expenses					Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power	1,443		1,447		Fuel used in electric generation and purchased power		1,817		1,443
Cost of natural gas	Cost of natural gas	276		199		Cost of natural gas		481		276
Operation, maintenance and other	Operation, maintenance and other	1,402		1,339		Operation, maintenance and other		1,630		1,402
Depreciation and amortization	Depreciation and amortization	1,226		1,130		Depreciation and amortization		1,320		1,226
Property and other taxes	Property and other taxes	353		345		Property and other taxes		392		353
Impairment of assets and other charges	Impairment of assets and other charges	—		2		Impairment of assets and other charges		215		—
Total operating expenses	Total operating expenses	4,700		4,462		Total operating expenses		5,855		4,700
Gains on Sales of Other Assets and Other, net	Gains on Sales of Other Assets and Other, net	—		1		Gains on Sales of Other Assets and Other, net		2		—
Operating Income	Operating Income	1,450		1,488		Operating Income		1,279		1,450
Other Income and Expenses	Other Income and Expenses					Other Income and Expenses
Equity in (losses) earnings of unconsolidated affiliates		(17)		44
Equity in earnings (losses) of unconsolidated affiliates						Equity in earnings (losses) of unconsolidated affiliates		25		(17)
Other income and expenses, net	Other income and expenses, net	127		46		Other income and expenses, net		89		127
Total other income and expenses	Total other income and expenses	110		90		Total other income and expenses		114		110
Interest Expense	Interest Expense	535		551		Interest Expense		587		535
Income Before Income Taxes	Income Before Income Taxes	1,025		1,027		Income Before Income Taxes		806		1,025
Income Tax Expense		84		137
Income Tax (Benefit) Expense						Income Tax (Benefit) Expense		(14)		84

Net Income	Net Income	941		890		Net Income		820		941
Add: Net Loss Attributable to Noncontrolling Interests	Add: Net Loss Attributable to Noncontrolling Interests	51		48		Add: Net Loss Attributable to Noncontrolling Interests		37		51
Net Income Attributable to Duke Energy Corporation	Net Income Attributable to Duke Energy Corporation	992		938		Net Income Attributable to Duke Energy Corporation		857		992
Less: Preferred Dividends	Less: Preferred Dividends	39		39		Less: Preferred Dividends		39		39
Net Income Available to Duke Energy Corporation Common Stockholders	Net Income Available to Duke Energy Corporation Common Stockholders	$	953	$	899	Net Income Available to Duke Energy Corporation Common Stockholders		$	818	$	953

Earnings Per Share – Basic and Diluted	Earnings Per Share – Basic and Diluted					Earnings Per Share – Basic and Diluted

Net income available to Duke Energy Corporation common stockholders	Net income available to Duke Energy Corporation common stockholders					Net income available to Duke Energy Corporation common stockholders
Basic and Diluted	Basic and Diluted	$	1.25	$	1.24	Basic and Diluted		$	1.08	$	1.25

Weighted Average Shares Outstanding	Weighted Average Shares Outstanding					Weighted Average Shares Outstanding
Basic		769		734
Diluted		769		736
Basic and Diluted						Basic and Diluted		770		769

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Comprehensive Income

(Unaudited)


		Three Months Ended						Three Months Ended
		March 31,						March 31,
(in millions)	(in millions)		2021		2020		(in millions)		2022		2021
Net Income	Net Income		$	941	$	890	Net Income		$	820	$	941
Other Comprehensive Income (Loss), net of tax(a)	Other Comprehensive Income (Loss), net of tax(a)						Other Comprehensive Income (Loss), net of tax(a)

Pension and OPEB adjustments	Pension and OPEB adjustments		2		1		Pension and OPEB adjustments		2		2
Net unrealized gains (losses) on cash flow hedges			29		(81)
Net unrealized gains on cash flow hedges							Net unrealized gains on cash flow hedges		113		29
Reclassification into earnings from cash flow hedges	Reclassification into earnings from cash flow hedges		3		2		Reclassification into earnings from cash flow hedges		5		3

Unrealized (losses) gains on available-for-sale securities			(8)		1
Unrealized losses on available-for-sale securities							Unrealized losses on available-for-sale securities		(13)		(8)

Other Comprehensive Income (Loss), net of tax			26		(77)
Other Comprehensive Income, net of tax							Other Comprehensive Income, net of tax		107		26
Comprehensive Income	Comprehensive Income		967		813		Comprehensive Income		927		967
Add: Comprehensive Loss Attributable to Noncontrolling Interests	Add: Comprehensive Loss Attributable to Noncontrolling Interests		44		62		Add: Comprehensive Loss Attributable to Noncontrolling Interests		29		44
Comprehensive Income Attributable to Duke Energy	Comprehensive Income Attributable to Duke Energy		1,011		875		Comprehensive Income Attributable to Duke Energy		956		1,011
Less: Preferred Dividends	Less: Preferred Dividends		39		39		Less: Preferred Dividends		39		39
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	Comprehensive Income Available to Duke Energy Corporation Common Stockholders		$	972	$	836	Comprehensive Income Available to Duke Energy Corporation Common Stockholders		$	917	$	972

(a)Net of income tax impacts of approximately $8$32 million and ~~$23~~$8 million for the three months ended March 31, ~~2021,~~2022, and ~~2020,~~2021, respectively.

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and cash equivalents	Cash and cash equivalents	$	379	$	259	Cash and cash equivalents	$	853	$	343

Receivables (net of allowance for doubtful accounts of $31 at 2021 and $29 at 2020)		950		1,009
Receivables of VIEs (net of allowance for doubtful accounts of $116 at 2021 and $117 at 2020)		1,834		2,144
Receivables (net of allowance for doubtful accounts of $68 at 2022 and $46 at 2021)						Receivables (net of allowance for doubtful accounts of $68 at 2022 and $46 at 2021)	1,148		1,173
Receivables of VIEs (net of allowance for doubtful accounts of $72 at 2022 and $76 at 2021)						Receivables of VIEs (net of allowance for doubtful accounts of $72 at 2022 and $76 at 2021)	2,590		2,437
Inventory	Inventory	3,076		3,167		Inventory	3,171		3,199

Regulatory assets (includes $54 at 2021 and $53 at 2020 related to VIEs)		1,650		1,641
Other (includes $333 at 2021 and $296 at 2020 related to VIEs)		619		462
Regulatory assets (includes $105 at 2022 and 2021 related to VIEs)						Regulatory assets (includes $105 at 2022 and 2021 related to VIEs)	2,334		2,150
Other (includes $249 at 2022 and $256 at 2021 related to VIEs)						Other (includes $249 at 2022 and $256 at 2021 related to VIEs)	946		638
Total current assets	Total current assets	8,508		8,682		Total current assets	11,042		9,940
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Cost	Cost	157,372		155,580		Cost	163,700		161,819
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(49,772)		(48,827)		Accumulated depreciation and amortization	(51,517)		(50,555)
Generation facilities to be retired, net		29		29
Facilities to be retired, net						Facilities to be retired, net	133		144
Net property, plant and equipment	Net property, plant and equipment	107,629		106,782		Net property, plant and equipment	112,316		111,408
Other Noncurrent Assets	Other Noncurrent Assets					Other Noncurrent Assets
Goodwill	Goodwill	19,303		19,303		Goodwill	19,303		19,303
Regulatory assets (includes $927 at 2021 and $937 at 2020 related to VIEs)		12,441		12,421
Regulatory assets (includes $1,800 at 2022 and $1,823 at 2021 related to VIEs)						Regulatory assets (includes $1,800 at 2022 and $1,823 at 2021 related to VIEs)	12,506		12,487
Nuclear decommissioning trust funds	Nuclear decommissioning trust funds	9,410		9,114		Nuclear decommissioning trust funds	9,827		10,401
Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	1,540		1,524		Operating lease right-of-use assets, net	1,255		1,266
Investments in equity method unconsolidated affiliates	Investments in equity method unconsolidated affiliates	919		961		Investments in equity method unconsolidated affiliates	976		970

Other (includes $82 at 2021 and $81 at 2020 related to VIEs)		3,715		3,601
Other (includes $111 at 2022 and $92 at 2021 related to VIEs)						Other (includes $111 at 2022 and $92 at 2021 related to VIEs)	3,995		3,812
Total other noncurrent assets	Total other noncurrent assets	47,328		46,924		Total other noncurrent assets	47,862		48,239
Total Assets	Total Assets	$	163,465	$	162,388	Total Assets	$	171,220	$	169,587
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts payable	Accounts payable	$	2,497	$	3,144	Accounts payable	$	3,175	$	3,629
Notes payable and commercial paper	Notes payable and commercial paper	4,064		2,873		Notes payable and commercial paper	3,262		3,304
Taxes accrued	Taxes accrued	574		482		Taxes accrued	642		749
Interest accrued	Interest accrued	536		537		Interest accrued	575		533
Current maturities of long-term debt (includes $472 at 2021 and 2020 related to VIEs)		5,586		4,238
Current maturities of long-term debt (includes $395 at 2022 and $243 at 2021 related to VIEs)						Current maturities of long-term debt (includes $395 at 2022 and $243 at 2021 related to VIEs)	3,884		3,387

Asset retirement obligations	Asset retirement obligations	709		718		Asset retirement obligations	648		647
Regulatory liabilities	Regulatory liabilities	1,509		1,377		Regulatory liabilities	1,238		1,211
Other	Other	1,858		2,936		Other	2,001		2,471
Total current liabilities	Total current liabilities	17,333		16,305		Total current liabilities	15,425		15,931
Long-Term Debt (includes $3,686 at 2021 and $3,535 at 2020 related to VIEs)		54,768		55,625
Long-Term Debt (includes $4,687 at 2022 and $4,854 at 2021 related to VIEs)						Long-Term Debt (includes $4,687 at 2022 and $4,854 at 2021 related to VIEs)	62,196		60,448
Other Noncurrent Liabilities	Other Noncurrent Liabilities					Other Noncurrent Liabilities
Deferred income taxes	Deferred income taxes	9,459		9,244		Deferred income taxes	9,673		9,379
Asset retirement obligations	Asset retirement obligations	12,299		12,286		Asset retirement obligations	12,112		12,129
Regulatory liabilities	Regulatory liabilities	15,070		15,029		Regulatory liabilities	16,037		16,152
Operating lease liabilities	Operating lease liabilities	1,352		1,340		Operating lease liabilities	1,068		1,074
Accrued pension and other post-retirement benefit costs	Accrued pension and other post-retirement benefit costs	1,010		969		Accrued pension and other post-retirement benefit costs	832		855
Investment tax credits	Investment tax credits	747		687		Investment tax credits	831		833

Other (includes $331 at 2021 and $316 at 2020 related to VIEs)		1,769		1,719
Other (includes $360 at 2022 and $319 at 2021 related to VIEs)						Other (includes $360 at 2022 and $319 at 2021 related to VIEs)	1,794		1,650
Total other noncurrent liabilities	Total other noncurrent liabilities	41,706		41,274		Total other noncurrent liabilities	42,347		42,072
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies	0		0
Equity	Equity					Equity
Preferred stock, Series A, $0.001 par value, 40 million depositary shares authorized and outstanding at 2021 and 2020		973		973
Preferred stock, Series B, $0.001 par value, 1 million shares authorized and outstanding at 2021 and 2020		989		989
Common stock, $0.001 par value, 2 billion shares authorized; 769 million shares outstanding at 2021 and 2020		1		1
Preferred stock, Series A, $0.001 par value, 40 million depositary shares authorized and outstanding at 2022 and 2021						Preferred stock, Series A, $0.001 par value, 40 million depositary shares authorized and outstanding at 2022 and 2021	973		973
Preferred stock, Series B, $0.001 par value, 1 million shares authorized and outstanding at 2022 and 2021						Preferred stock, Series B, $0.001 par value, 1 million shares authorized and outstanding at 2022 and 2021	989		989
Common stock, $0.001 par value, 2 billion shares authorized; 770 million shares outstanding at 2022 and 769 million shares outstanding at 2021						Common stock, $0.001 par value, 2 billion shares authorized; 770 million shares outstanding at 2022 and 769 million shares outstanding at 2021	1		1
Additional paid-in capital	Additional paid-in capital	43,761		43,767		Additional paid-in capital	44,364		44,371
Retained earnings	Retained earnings	2,680		2,471		Retained earnings	3,323		3,265
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(218)		(237)		Accumulated other comprehensive loss	(204)		(303)
Total Duke Energy Corporation stockholders' equity	Total Duke Energy Corporation stockholders' equity	48,186		47,964		Total Duke Energy Corporation stockholders' equity	49,446		49,296
Noncontrolling interests	Noncontrolling interests	1,472		1,220		Noncontrolling interests	1,806		1,840
Total equity	Total equity	49,658		49,184		Total equity	51,252		51,136
Total Liabilities and Equity	Total Liabilities and Equity	$	163,465	$	162,388	Total Liabilities and Equity	$	171,220	$	169,587

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)


		Three Months Ended					Three Months Ended
		March 31,					March 31,
(in millions)	(in millions)	2021		2020		(in millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES	CASH FLOWS FROM OPERATING ACTIVITIES					CASH FLOWS FROM OPERATING ACTIVITIES
Net income	Net income	$	941	$	890	Net income	$	820	$	941
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,385		1,301		Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,480		1,385
Equity in losses (earnings) of unconsolidated affiliates		17		(44)
Equity in (earnings) losses of unconsolidated affiliates						Equity in (earnings) losses of unconsolidated affiliates	(25)		17
Equity component of AFUDC	Equity component of AFUDC	(42)		(40)		Equity component of AFUDC	(46)		(42)

Impairment of assets and other charges						Impairment of assets and other charges	215		—
Deferred income taxes	Deferred income taxes	86		422		Deferred income taxes	(11)		86

Payments for asset retirement obligations	Payments for asset retirement obligations	(114)		(132)		Payments for asset retirement obligations	(119)		(114)

Provision for rate refunds						Provision for rate refunds	(31)		—

(Increase) decrease in	(Increase) decrease in					(Increase) decrease in

Net realized and unrealized mark-to-market and hedging transactions						Net realized and unrealized mark-to-market and hedging transactions	215		—
Receivables	Receivables	377		466		Receivables	5		377
Inventory	Inventory	91		(92)		Inventory	28		91
Other current assets	Other current assets	(47)		(131)		Other current assets	(327)		(47)
Increase (decrease) in	Increase (decrease) in					Increase (decrease) in
Accounts payable	Accounts payable	(467)		(657)		Accounts payable	(160)		(467)
Taxes accrued	Taxes accrued	104		113		Taxes accrued	(90)		104
Other current liabilities	Other current liabilities	(263)		(455)		Other current liabilities	(269)		(263)
Other assets	Other assets	51		(37)		Other assets	(26)		51
Other liabilities	Other liabilities	(31)		(50)		Other liabilities	136		(31)
Net cash provided by operating activities	Net cash provided by operating activities	2,088		1,554		Net cash provided by operating activities	1,795		2,088
CASH FLOWS FROM INVESTING ACTIVITIES	CASH FLOWS FROM INVESTING ACTIVITIES					CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	Capital expenditures	(2,215)		(2,832)		Capital expenditures	(2,551)		(2,215)

Contributions to equity method investments	Contributions to equity method investments	—		(77)		Contributions to equity method investments	(17)		—

Purchases of debt and equity securities	Purchases of debt and equity securities	(1,584)		(1,392)		Purchases of debt and equity securities	(1,516)		(1,584)
Proceeds from sales and maturities of debt and equity securities	Proceeds from sales and maturities of debt and equity securities	1,601		1,347		Proceeds from sales and maturities of debt and equity securities	1,530		1,601

Disbursements to canceled equity method investments	Disbursements to canceled equity method investments	(855)		—		Disbursements to canceled equity method investments	—		(855)
Other	Other	(84)		(68)		Other	(145)		(84)
Net cash used in investing activities	Net cash used in investing activities	(3,137)		(3,022)		Net cash used in investing activities	(2,699)		(3,137)
CASH FLOWS FROM FINANCING ACTIVITIES	CASH FLOWS FROM FINANCING ACTIVITIES					CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:	Proceeds from the:					Proceeds from the:
Issuance of long-term debt	Issuance of long-term debt	608		1,954		Issuance of long-term debt	3,506		608

Issuance of common stock	Issuance of common stock	5		40		Issuance of common stock	—		5

Payments for the redemption of long-term debt	Payments for the redemption of long-term debt	(76)		(292)		Payments for the redemption of long-term debt	(1,215)		(76)

Proceeds from the issuance of short-term debt with original maturities greater than 90 days	Proceeds from the issuance of short-term debt with original maturities greater than 90 days	50		1,784		Proceeds from the issuance of short-term debt with original maturities greater than 90 days	—		50
Payments for the redemption of short-term debt with original maturities greater than 90 days	Payments for the redemption of short-term debt with original maturities greater than 90 days	(909)		(17)		Payments for the redemption of short-term debt with original maturities greater than 90 days	(257)		(909)
Notes payable and commercial paper	Notes payable and commercial paper	2,046		(198)		Notes payable and commercial paper	213		2,046

Contributions from noncontrolling interests	Contributions from noncontrolling interests	303		103		Contributions from noncontrolling interests	23		303
Dividends paid	Dividends paid	(783)		(707)		Dividends paid	(799)		(783)

Other	Other	(59)		(74)		Other	(67)		(59)
Net cash provided by financing activities	Net cash provided by financing activities	1,185		2,593		Net cash provided by financing activities	1,404		1,185

Net increase in cash, cash equivalents and restricted cash	Net increase in cash, cash equivalents and restricted cash	136		1,125		Net increase in cash, cash equivalents and restricted cash	500		136
Cash, cash equivalents and restricted cash at beginning of period	Cash, cash equivalents and restricted cash at beginning of period	556		573		Cash, cash equivalents and restricted cash at beginning of period	520		556
Cash, cash equivalents and restricted cash at end of period	Cash, cash equivalents and restricted cash at end of period	$	692	$	1,698	Cash, cash equivalents and restricted cash at end of period	$	1,020	$	692
Supplemental Disclosures:	Supplemental Disclosures:					Supplemental Disclosures:

Significant non-cash transactions:	Significant non-cash transactions:					Significant non-cash transactions:
Accrued capital expenditures	Accrued capital expenditures	$	921	$	934	Accrued capital expenditures	$	1,028	$	921
Non-cash dividends		—		27

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Changes in Equity

(Unaudited)


							Three Months Ended March 31, 2021 and 2022
												Accumulated Other Comprehensive																						Accumulated Other Comprehensive
												(Loss) Income																						(Loss) Income
														Net Unrealized				Total																		Net Unrealized				Total
												Net Gains		Gains (Losses)				Duke Energy																Net Gains		Gains (Losses)				Duke Energy
				Common				Additional				(Losses) on		on Available-		Pension and		Corporation									Common			Additional				(Losses) on		on Available-		Pension and		Corporation
		Preferred		Stock	Common			Paid-in		Retained		Cash Flow		for-Sale-		OPEB		Stockholders'		Noncontrolling		Total			Preferred		Stock	Common		Paid-in		Retained		Cash Flow		for-Sale-		OPEB		Stockholders'		Noncontrolling		Total
(in millions)	(in millions)	Stock		Shares	Stock			Capital		Earnings		Hedges		Securities		Adjustments		Equity		Interests		Equity		(in millions)	Stock		Shares	Stock		Capital		Earnings		Hedges		Securities		Adjustments		Equity		Interests		Equity
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 interests, net of transaction costs		—		—	—			—		—		—		—		—		—		103		103
Distributions to noncontrolling interest in subsidiaries		—		—	—			—		—		—		—		—		—		(7)		(7)
Other(a)		—		—	—			(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

Balance at December 31, 2020	Balance at December 31, 2020	$	1,962	769	$	1		$	43,767	$	2,471	$	(167)	$	6	$	(76)	$	47,964	$	1,220	$	49,184	Balance at December 31, 2020	$	1,962	769	$	1	$	43,767	$	2,471	$	(167)	$	6	$	(76)	$	47,964	$	1,220	$	49,184
Net income (loss)	Net income (loss)	—		—	—			—		953		—		—		—		953		(51)		902		Net income (loss)	—		—	—		—		953		—		—		—		953		(51)		902
Other comprehensive income (loss)	Other comprehensive income (loss)	—		—	—			—		—		25		(8)		2		19		7		26		Other comprehensive income (loss)	—		—	—		—		—		25		(8)		2		19		7		26

Common stock issuances, including dividend reinvestment and employee benefits	Common stock issuances, including dividend reinvestment and employee benefits	—		—	—			(3)		—		—		—		—		(3)		—		(3)		Common stock issuances, including dividend reinvestment and employee benefits	—		—	—		(3)		—		—		—		—		(3)		—		(3)

Common stock dividends	Common stock dividends	—		—	—			—		(744)		—		—		—		(744)		—		(744)		Common stock dividends	—		—	—		—		(744)		—		—		—		(744)		—		(744)

Contributions from noncontrolling interests, net of transaction costs		—		—	—			(3)		—		—		—		—		(3)		303		300

Contributions from noncontrolling interests, net of transaction costs(a)																								Contributions from noncontrolling interests, net of transaction costs(a)	—		—	—		(3)		—		—		—		—		(3)		303		300
Distributions to noncontrolling interest in subsidiaries	Distributions to noncontrolling interest in subsidiaries	—		—	—			—		—		—		—		—		—		(7)		(7)		Distributions to noncontrolling interest in subsidiaries	—		—	—		—		—		—		—		—		—		(7)		(7)

Balance at March 31, 2021	Balance at March 31, 2021	$	1,962	769	$	1		$	43,761	$	2,680	$	(142)	$	(2)	$	(74)	$	48,186	$	1,472	$	49,658	Balance at March 31, 2021	$	1,962	769	$	1	$	43,761	$	2,680	$	(142)	$	(2)	$	(74)	$	48,186	$	1,472	$	49,658

Balance at December 31, 2021																								Balance at December 31, 2021	$	1,962	769	$	1	$	44,371	$	3,265	$	(232)	$	(2)	$	(69)	$	49,296	$	1,840	$	51,136
Net income (loss)																								Net income (loss)	—		—	—		—		818		—		—		—		818		(37)		781
Other comprehensive income (loss)																								Other comprehensive income (loss)	—		—	—		—		—		110		(13)		2		99		8		107

Common stock issuances, including dividend reinvestment and employee benefits																								Common stock issuances, including dividend reinvestment and employee benefits	—		1	—		(7)		—		—		—		—		(7)		—		(7)

Common stock dividends																								Common stock dividends	—		—	—		—		(760)		—		—		—		(760)		—		(760)

Contributions from noncontrolling interests, net of transaction costs(a)																								Contributions from noncontrolling interests, net of transaction costs(a)	—		—	—		—		—		—		—		—		—		23		23
Distributions to noncontrolling interest in subsidiaries																								Distributions to noncontrolling interest in subsidiaries	—		—	—		—		—		—		—		—		—		(28)		(28)

Balance at March 31, 2022																								Balance at March 31, 2022	$	1,962	770	$	1	$	44,364	$	3,323	$	(122)	$	(15)	$	(67)	$	49,446	$	1,806	$	51,252

(a) ~~Amounts~~Relates to tax equity financing activity 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.~~the Commercial Renewables segment.

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


		Three Months Ended						Three Months Ended
		March 31,						March 31,
(in millions)	(in millions)		2021		2020		(in millions)		2022		2021
Operating Revenues	Operating Revenues		$	1,716	$	1,748	Operating Revenues		$	1,888	$	1,716
Operating Expenses	Operating Expenses						Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power		422		453		Fuel used in electric generation and purchased power		448		422
Operation, maintenance and other	Operation, maintenance and other		441		386		Operation, maintenance and other		512		441
Depreciation and amortization	Depreciation and amortization		359		343		Depreciation and amortization		379		359
Property and other taxes	Property and other taxes		83		81		Property and other taxes		93		83
Impairment of assets and other charges	Impairment of assets and other charges		—		2		Impairment of assets and other charges		3		—
Total operating expenses	Total operating expenses		1,305		1,265		Total operating expenses		1,435		1,305
Gains on Sales of Other Assets and Other, net			—		1

Operating Income	Operating Income		411		484		Operating Income		453		411
Other Income and Expenses, net	Other Income and Expenses, net		48		43		Other Income and Expenses, net		55		48
Interest Expense	Interest Expense		124		123		Interest Expense		141		124
Income Before Income Taxes	Income Before Income Taxes		335		404		Income Before Income Taxes		367		335
Income Tax Expense	Income Tax Expense		23		65		Income Tax Expense		27		23
Net Income and Comprehensive Income	Net Income and Comprehensive Income		$	312	$	339	Net Income and Comprehensive Income		$	340	$	312

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and cash equivalents	Cash and cash equivalents	$	12	$	21	Cash and cash equivalents	$	4	$	7
Receivables (net of allowance for doubtful accounts of $2 at 2021 and $1 at 2020)		171		247
Receivables of VIEs (net of allowance for doubtful accounts of $32 at 2021 and $22 at 2020)		613		696
Receivables (net of allowance for doubtful accounts of $22 at 2022 and $1 at 2021)						Receivables (net of allowance for doubtful accounts of $22 at 2022 and $1 at 2021)	234		300
Receivables of VIEs (net of allowance for doubtful accounts of $30 at 2022 and $41 at 2021)						Receivables of VIEs (net of allowance for doubtful accounts of $30 at 2022 and $41 at 2021)	858		844
Receivables from affiliated companies	Receivables from affiliated companies	119		124		Receivables from affiliated companies	134		190

Notes receivable from affiliated companies						Notes receivable from affiliated companies	492		—
Inventory	Inventory	1,021		1,010		Inventory	1,040		1,026
Regulatory assets		433		473
Other		90		20
Regulatory assets (includes $12 at 2022 and 2021 related to VIEs)						Regulatory assets (includes $12 at 2022 and 2021 related to VIEs)	652		544
Other (includes $5 at 2022 and $0 at 2021 related to VIEs)						Other (includes $5 at 2022 and $0 at 2021 related to VIEs)	246		95
Total current assets	Total current assets	2,459		2,591		Total current assets	3,660		3,006
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Cost	Cost	51,027		50,640		Cost	52,423		51,874
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(17,690)		(17,453)		Accumulated depreciation and amortization	(18,058)		(17,854)
Facilities to be retired, net						Facilities to be retired, net	98		102
Net property, plant and equipment	Net property, plant and equipment	33,337		33,187		Net property, plant and equipment	34,463		34,122
Other Noncurrent Assets	Other Noncurrent Assets					Other Noncurrent Assets
Regulatory assets		3,028		2,996
Regulatory assets (includes $217 at 2022 and $220 at 2021 related to VIEs)						Regulatory assets (includes $217 at 2022 and $220 at 2021 related to VIEs)	3,085		2,935
Nuclear decommissioning trust funds	Nuclear decommissioning trust funds	5,147		4,977		Nuclear decommissioning trust funds	5,441		5,759
Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	105		110		Operating lease right-of-use assets, net	87		92
Other	Other	1,185		1,187		Other	1,297		1,248
Total other noncurrent assets	Total other noncurrent assets	9,465		9,270		Total other noncurrent assets	9,910		10,034
Total Assets	Total Assets	$	45,261	$	45,048	Total Assets	$	48,033	$	47,162
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts payable	Accounts payable	$	643	$	1,000	Accounts payable	$	752	$	988
Accounts payable to affiliated companies	Accounts payable to affiliated companies	206		199		Accounts payable to affiliated companies	267		266
Notes payable to affiliated companies	Notes payable to affiliated companies	508		506		Notes payable to affiliated companies	—		226
Taxes accrued	Taxes accrued	138		76		Taxes accrued	124		274
Interest accrued	Interest accrued	128		117		Interest accrued	140		125
Current maturities of long-term debt		507		506
Current maturities of long-term debt (includes $10 at 2022 and $5 at 2021 related to VIEs)						Current maturities of long-term debt (includes $10 at 2022 and $5 at 2021 related to VIEs)	1,367		362
Asset retirement obligations	Asset retirement obligations	258		264		Asset retirement obligations	251		249
Regulatory liabilities	Regulatory liabilities	559		473		Regulatory liabilities	465		487
Other	Other	440		546		Other	442		546
Total current liabilities	Total current liabilities	3,387		3,687		Total current liabilities	3,808		3,523
Long-Term Debt		11,522		11,412
Long-Term Debt (includes $722 at 2022 and $703 at 2021 related to VIEs)						Long-Term Debt (includes $722 at 2022 and $703 at 2021 related to VIEs)	12,803		12,595
Long-Term Debt Payable to Affiliated Companies	Long-Term Debt Payable to Affiliated Companies	300		300		Long-Term Debt Payable to Affiliated Companies	300		318
Other Noncurrent Liabilities	Other Noncurrent Liabilities					Other Noncurrent Liabilities
Deferred income taxes	Deferred income taxes	3,913		3,842		Deferred income taxes	3,769		3,634
Asset retirement obligations	Asset retirement obligations	5,117		5,086		Asset retirement obligations	5,067		5,052
Regulatory liabilities	Regulatory liabilities	6,540		6,535		Regulatory liabilities	7,151		7,198
Operating lease liabilities	Operating lease liabilities	93		97		Operating lease liabilities	74		78
Accrued pension and other post-retirement benefit costs	Accrued pension and other post-retirement benefit costs	72		73		Accrued pension and other post-retirement benefit costs	48		50
Investment tax credits	Investment tax credits	235		236		Investment tax credits	286		287
Other	Other	616		626		Other	545		536
Total other noncurrent liabilities	Total other noncurrent liabilities	16,586		16,495		Total other noncurrent liabilities	16,940		16,835
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies	0		0
Equity	Equity					Equity
Member's equity	Member's equity	13,473		13,161		Member's equity	14,188		13,897
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(7)		(7)		Accumulated other comprehensive loss	(6)		(6)
Total equity	Total equity	13,466		13,154		Total equity	14,182		13,891
Total Liabilities and Equity	Total Liabilities and Equity	$	45,261	$	45,048	Total Liabilities and Equity	$	48,033	$	47,162

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)


		Three Months Ended					Three Months Ended
		March 31,					March 31,
(in millions)	(in millions)	2021		2020		(in millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES	CASH FLOWS FROM OPERATING ACTIVITIES					CASH FLOWS FROM OPERATING ACTIVITIES
Net income	Net income	$	312	$	339	Net income	$	340	$	312
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	Depreciation and amortization (including amortization of nuclear fuel)	428		414		Depreciation and amortization (including amortization of nuclear fuel)	447		428
Equity component of AFUDC	Equity component of AFUDC	(16)		(14)		Equity component of AFUDC	(22)		(16)

Impairment of assets and other charges						Impairment of assets and other charges	3		—
Deferred income taxes	Deferred income taxes	(8)		22		Deferred income taxes	44		(8)

Payments for asset retirement obligations	Payments for asset retirement obligations	(35)		(41)		Payments for asset retirement obligations	(35)		(35)

Provision for rate refunds						Provision for rate refunds	(18)		—
(Increase) decrease in	(Increase) decrease in					(Increase) decrease in

Net realized and unrealized mark-to-market and hedging transactions						Net realized and unrealized mark-to-market and hedging transactions	50		—
Receivables	Receivables	156		156		Receivables	77		156
Receivables from affiliated companies	Receivables from affiliated companies	5		27		Receivables from affiliated companies	56		5
Inventory	Inventory	(11)		(72)		Inventory	(13)		(11)
Other current assets	Other current assets	(48)		96		Other current assets	(230)		(48)
Increase (decrease) in	Increase (decrease) in					Increase (decrease) in
Accounts payable	Accounts payable	(255)		(253)		Accounts payable	(225)		(255)
Accounts payable to affiliated companies	Accounts payable to affiliated companies	7		15		Accounts payable to affiliated companies	(17)		7
Taxes accrued	Taxes accrued	62		87		Taxes accrued	(150)		62
Other current liabilities	Other current liabilities	(77)		(108)		Other current liabilities	56		(77)
Other assets	Other assets	43		(60)		Other assets	6		43
Other liabilities	Other liabilities	(17)		(10)		Other liabilities	(44)		(17)
Net cash provided by operating activities	Net cash provided by operating activities	546		598		Net cash provided by operating activities	325		546
CASH FLOWS FROM INVESTING ACTIVITIES	CASH FLOWS FROM INVESTING ACTIVITIES					CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	Capital expenditures	(622)		(724)		Capital expenditures	(717)		(622)

Purchases of debt and equity securities	Purchases of debt and equity securities	(1,128)		(607)		Purchases of debt and equity securities	(1,008)		(1,128)
Proceeds from sales and maturities of debt and equity securities	Proceeds from sales and maturities of debt and equity securities	1,128		607		Proceeds from sales and maturities of debt and equity securities	1,008		1,128
Notes receivable from affiliated companies	Notes receivable from affiliated companies	—		(436)		Notes receivable from affiliated companies	(492)		—
Other	Other	(43)		(18)		Other	(54)		(43)
Net cash used in investing activities	Net cash used in investing activities	(665)		(1,178)		Net cash used in investing activities	(1,263)		(665)
CASH FLOWS FROM FINANCING ACTIVITIES	CASH FLOWS FROM FINANCING ACTIVITIES					CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	Proceeds from the issuance of long-term debt	142		910		Proceeds from the issuance of long-term debt	1,217		142
Payments for the redemption of long-term debt	Payments for the redemption of long-term debt	(33)		(2)		Payments for the redemption of long-term debt	(1)		(33)
Notes payable to affiliated companies	Notes payable to affiliated companies	2		(29)		Notes payable to affiliated companies	(226)		2
Distributions to parent	Distributions to parent	—		(300)		Distributions to parent	(50)		—
Other	Other	(1)		(1)		Other	(1)		(1)
Net cash provided by financing activities	Net cash provided by financing activities	110		578		Net cash provided by financing activities	939		110
Net decrease in cash and cash equivalents		(9)		(2)
Cash and cash equivalents at beginning of period		21		18
Cash and cash equivalents at end of period		$	12	$	16
Net increase (decrease) in cash, cash equivalents and restricted cash						Net increase (decrease) in cash, cash equivalents and restricted cash	1		(9)
Cash, cash equivalents and restricted cash at beginning of period						Cash, cash equivalents and restricted cash at beginning of period	8		21
Cash, cash equivalents and restricted cash at end of period						Cash, cash equivalents and restricted cash at end of period	$	9	$	12
Supplemental Disclosures:	Supplemental Disclosures:					Supplemental Disclosures:
Significant non-cash transactions:	Significant non-cash transactions:					Significant non-cash transactions:
Accrued capital expenditures	Accrued capital expenditures	$	268	$	254	Accrued capital expenditures	$	352	$	268

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)


				Three Months Ended March 31, 2021 and 2022
					Accumulated Other							Accumulated Other
					Comprehensive							Comprehensive
					Loss							Loss
		Member's			Net Losses on		Total			Member's		Net Losses on		Total
(in millions)	(in millions)	Equity			Cash Flow Hedges		Equity		(in millions)	Equity		Cash Flow Hedges		Equity
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

Balance at December 31, 2020	Balance at December 31, 2020	$	13,161		$	(7)	$	13,154	Balance at December 31, 2020	$	13,161	$	(7)	$	13,154
Net income	Net income	312			—		312		Net income	312		—		312

Balance at March 31, 2021	Balance at March 31, 2021	$	13,473		$	(7)	$	13,466	Balance at March 31, 2021	$	13,473	$	(7)	$	13,466

Balance at December 31, 2021									Balance at December 31, 2021	$	13,897	$	(6)	$	13,891
Net income									Net income	340		—		340

Distributions to parent									Distributions to parent	(50)		—		(50)
Other									Other	1		—		1
Balance at March 31, 2022									Balance at March 31, 2022	$	14,188	$	(6)	$	14,182

~~(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


FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


		Three Months Ended						Three Months Ended
		March 31,						March 31,
(in millions)	(in millions)		2021		2020		(in millions)		2022		2021
Operating Revenues	Operating Revenues		$	2,505	$	2,422	Operating Revenues		$	2,992	$	2,505
Operating Expenses	Operating Expenses						Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power		795		763		Fuel used in electric generation and purchased power		1,064		795
Operation, maintenance and other	Operation, maintenance and other		601		554		Operation, maintenance and other		645		601
Depreciation and amortization	Depreciation and amortization		485		452		Depreciation and amortization		536		485
Property and other taxes	Property and other taxes		142		135		Property and other taxes		152		142

Total operating expenses	Total operating expenses		2,023		1,904		Total operating expenses		2,397		2,023
Losses on Sales of Other Assets and Other, net			—		(1)
Gains on Sales of Other Assets and Other, net							Gains on Sales of Other Assets and Other, net		2		—
Operating Income	Operating Income		482		517		Operating Income		597		482
Other Income and Expenses, net	Other Income and Expenses, net		43		32		Other Income and Expenses, net		35		43
Interest Expense	Interest Expense		192		206		Interest Expense		211		192
Income Before Income Taxes	Income Before Income Taxes		333		343		Income Before Income Taxes		421		333
Income Tax Expense	Income Tax Expense		43		60		Income Tax Expense		67		43

Net Income	Net Income		$	290	$	283	Net Income		$	354	$	290

Net Income	Net Income		$	290	$	283	Net Income		$	354	$	290
Other Comprehensive Income, net of tax	Other Comprehensive Income, net of tax						Other Comprehensive Income, net of tax

Net unrealized gains on cash flow hedges	Net unrealized gains on cash flow hedges		1		1		Net unrealized gains on cash flow hedges		1		1

Unrealized (losses) gains on available-for-sale securities			(1)		1
Unrealized losses on available-for-sale securities							Unrealized losses on available-for-sale securities		(2)		(1)

Other Comprehensive Income, net of tax			—		2
Other Comprehensive Loss, net of tax							Other Comprehensive Loss, net of tax		(1)		—
Comprehensive Income	Comprehensive Income		$	290	$	285	Comprehensive Income		$	353	$	290

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and cash equivalents	Cash and cash equivalents	$	74	$	59	Cash and cash equivalents	$	63	$	70
Receivables (net of allowance for doubtful accounts of $8 at 2021 and 2020)		166		228
Receivables of VIEs (net of allowance for doubtful accounts of $29 at 2021 and 2020)		749		901
Receivables (net of allowance for doubtful accounts of $11 at 2022 and 2021)						Receivables (net of allowance for doubtful accounts of $11 at 2022 and 2021)	286		247
Receivables of VIEs (net of allowance for doubtful accounts of $40 at 2022 and $25 at 2021)						Receivables of VIEs (net of allowance for doubtful accounts of $40 at 2022 and $25 at 2021)	1,166		1,006
Receivables from affiliated companies	Receivables from affiliated companies	76		157		Receivables from affiliated companies	37		121

Notes receivable from affiliated companies						Notes receivable from affiliated companies	237		—
Inventory	Inventory	1,336		1,375		Inventory	1,403		1,398
Regulatory assets (includes $54 at 2021 and $53 at 2020 related to VIEs)		821		758
Other (includes $14 at 2021 and $39 at 2020 related to VIEs)		257		109
Regulatory assets (includes $93 at 2022 and 2021 related to VIEs)						Regulatory assets (includes $93 at 2022 and 2021 related to VIEs)	1,101		1,030
Other (includes $27 at 2022 and $39 at 2021 related to VIEs)						Other (includes $27 at 2022 and $39 at 2021 related to VIEs)	319		125
Total current assets	Total current assets	3,479		3,587		Total current assets	4,612		3,997
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Cost	Cost	58,546		57,892		Cost	61,629		60,894
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(18,718)		(18,368)		Accumulated depreciation and amortization	(19,702)		(19,214)
Generation facilities to be retired, net		29		29
Facilities to be retired, net						Facilities to be retired, net	24		26
Net property, plant and equipment	Net property, plant and equipment	39,857		39,553		Net property, plant and equipment	41,951		41,706
Other Noncurrent Assets	Other Noncurrent Assets					Other Noncurrent Assets
Goodwill	Goodwill	3,655		3,655		Goodwill	3,655		3,655
Regulatory assets (includes $927 at 2021 and $937 at 2020 related to VIEs)		5,749		5,775
Regulatory assets (includes $1,583 at 2022 and $1,603 at 2021 related to VIEs)						Regulatory assets (includes $1,583 at 2022 and $1,603 at 2021 related to VIEs)	6,024		5,909
Nuclear decommissioning trust funds	Nuclear decommissioning trust funds	4,263		4,137		Nuclear decommissioning trust funds	4,385		4,642
Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	720		690		Operating lease right-of-use assets, net	701		691
Other	Other	1,267		1,227		Other	1,336		1,242
Total other noncurrent assets	Total other noncurrent assets	15,654		15,484		Total other noncurrent assets	16,101		16,139
Total Assets	Total Assets	$	58,990	$	58,624	Total Assets	$	62,664	$	61,842
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts payable	Accounts payable	$	796	$	919	Accounts payable	$	982	$	1,099
Accounts payable to affiliated companies	Accounts payable to affiliated companies	321		289		Accounts payable to affiliated companies	364		506
Notes payable to affiliated companies	Notes payable to affiliated companies	2,844		2,969		Notes payable to affiliated companies	377		2,809
Taxes accrued	Taxes accrued	143		121		Taxes accrued	157		128
Interest accrued	Interest accrued	187		202		Interest accrued	195		192
Current maturities of long-term debt (includes $305 at 2021 and 2020 related to VIEs)		2,127		1,426
Current maturities of long-term debt (includes $88 at 2022 and $71 at 2021 related to VIEs)						Current maturities of long-term debt (includes $88 at 2022 and $71 at 2021 related to VIEs)	1,095		1,082
Asset retirement obligations	Asset retirement obligations	267		283		Asset retirement obligations	268		275
Regulatory liabilities	Regulatory liabilities	702		640		Regulatory liabilities	469		478
Other	Other	744		793		Other	760		868
Total current liabilities	Total current liabilities	8,131		7,642		Total current liabilities	4,667		7,437
Long-Term Debt (includes $1,322 at 2021 and $1,252 at 2020 related to VIEs)		17,056		17,688
Long-Term Debt (includes $2,246 at 2022 and $2,293 at 2021 related to VIEs)						Long-Term Debt (includes $2,246 at 2022 and $2,293 at 2021 related to VIEs)	20,412		19,591
Long-Term Debt Payable to Affiliated Companies	Long-Term Debt Payable to Affiliated Companies	150		150		Long-Term Debt Payable to Affiliated Companies	150		150
Other Noncurrent Liabilities	Other Noncurrent Liabilities					Other Noncurrent Liabilities
Deferred income taxes	Deferred income taxes	4,489		4,396		Deferred income taxes	4,702		4,564
Asset retirement obligations	Asset retirement obligations	5,859		5,866		Asset retirement obligations	5,821		5,837
Regulatory liabilities	Regulatory liabilities	5,126		5,051		Regulatory liabilities	5,671		5,566
Operating lease liabilities	Operating lease liabilities	648		623		Operating lease liabilities	619		606
Accrued pension and other post-retirement benefit costs	Accrued pension and other post-retirement benefit costs	501		505		Accrued pension and other post-retirement benefit costs	409		417
Other	Other	500		462		Other	531		526
Total other noncurrent liabilities	Total other noncurrent liabilities	17,123		16,903		Total other noncurrent liabilities	17,753		17,516
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies	0		0
Equity	Equity					Equity
Common Stock, $0.01 par value, 100 shares authorized and outstanding at 2021 and 2020		—		—
Common Stock, $0.01 par value, 100 shares authorized and outstanding at 2022 and 2021						Common Stock, $0.01 par value, 100 shares authorized and outstanding at 2022 and 2021	—		—
Additional paid-in capital	Additional paid-in capital	9,143		9,143		Additional paid-in capital	9,149		9,149
Retained earnings	Retained earnings	7,400		7,109		Retained earnings	10,543		8,007
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(15)		(15)		Accumulated other comprehensive loss	(12)		(11)
Total Progress Energy, Inc. stockholders' equity	Total Progress Energy, Inc. stockholders' equity	16,528		16,237		Total Progress Energy, Inc. stockholders' equity	19,680		17,145
Noncontrolling interests	Noncontrolling interests	2		4		Noncontrolling interests	2		3
Total equity	Total equity	16,530		16,241		Total equity	19,682		17,148
Total Liabilities and Equity	Total Liabilities and Equity	$	58,990	$	58,624	Total Liabilities and Equity	$	62,664	$	61,842

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)


		Three Months Ended					Three Months Ended
		March 31,					March 31,
(in millions)	(in millions)	2021		2020		(in millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES	CASH FLOWS FROM OPERATING ACTIVITIES					CASH FLOWS FROM OPERATING ACTIVITIES
Net income	Net income	$	290	$	283	Net income	$	354	$	290
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	Depreciation, amortization and accretion (including amortization of nuclear fuel)	575		552		Depreciation, amortization and accretion (including amortization of nuclear fuel)	625		575
Equity component of AFUDC	Equity component of AFUDC	(13)		(14)		Equity component of AFUDC	(12)		(13)

Deferred income taxes	Deferred income taxes	79		80		Deferred income taxes	72		79

Payments for asset retirement obligations	Payments for asset retirement obligations	(69)		(79)		Payments for asset retirement obligations	(68)		(69)

Provision for rate refunds						Provision for rate refunds	(16)		—
(Increase) decrease in	(Increase) decrease in					(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	Net realized and unrealized mark-to-market and hedging transactions	6		1		Net realized and unrealized mark-to-market and hedging transactions	164		6
Receivables	Receivables	214		149		Receivables	(123)		214
Receivables from affiliated companies	Receivables from affiliated companies	81		27		Receivables from affiliated companies	102		81
Inventory	Inventory	39		(40)		Inventory	(5)		39
Other current assets	Other current assets	(150)		43		Other current assets	(224)		(150)
Increase (decrease) in	Increase (decrease) in					Increase (decrease) in
Accounts payable	Accounts payable	(69)		(211)		Accounts payable	26		(69)
Accounts payable to affiliated companies	Accounts payable to affiliated companies	32		19		Accounts payable to affiliated companies	(142)		32
Taxes accrued	Taxes accrued	23		71		Taxes accrued	30		23
Other current liabilities	Other current liabilities	(60)		(128)		Other current liabilities	(113)		(60)
Other assets	Other assets	(27)		(38)		Other assets	(80)		(27)
Other liabilities	Other liabilities	(64)		(56)		Other liabilities	40		(64)
Net cash provided by operating activities	Net cash provided by operating activities	887		659		Net cash provided by operating activities	630		887
CASH FLOWS FROM INVESTING ACTIVITIES	CASH FLOWS FROM INVESTING ACTIVITIES					CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	Capital expenditures	(796)		(972)		Capital expenditures	(981)		(796)

Purchases of debt and equity securities	Purchases of debt and equity securities	(517)		(651)		Purchases of debt and equity securities	(531)		(517)
Proceeds from sales and maturities of debt and equity securities	Proceeds from sales and maturities of debt and equity securities	537		643		Proceeds from sales and maturities of debt and equity securities	548		537

Notes receivable from affiliated companies	Notes receivable from affiliated companies	—		164		Notes receivable from affiliated companies	(237)		—

Other	Other	(59)		(39)		Other	(28)		(59)
Net cash used in investing activities	Net cash used in investing activities	(835)		(855)		Net cash used in investing activities	(1,229)		(835)
CASH FLOWS FROM FINANCING ACTIVITIES	CASH FLOWS FROM FINANCING ACTIVITIES					CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	Proceeds from the issuance of long-term debt	98		—		Proceeds from the issuance of long-term debt	889		98

Payments for the redemption of long-term debt	Payments for the redemption of long-term debt	(34)		(283)		Payments for the redemption of long-term debt	(54)		(34)

Notes payable to affiliated companies	Notes payable to affiliated companies	(125)		479		Notes payable to affiliated companies	(1)		(125)

Dividends to parent						Dividends to parent	(250)		—
Other	Other	(2)		(1)		Other	(3)		(2)
Net cash (used in) provided by financing activities		(63)		195
Net decrease in cash, cash equivalents and restricted cash		(11)		(1)
Net cash provided by (used in) financing activities						Net cash provided by (used in) financing activities	581		(63)
Net (decrease) increase in cash, cash equivalents and restricted cash						Net (decrease) increase in cash, cash equivalents and restricted cash	(18)		(11)
Cash, cash equivalents and restricted cash at beginning of period	Cash, cash equivalents and restricted cash at beginning of period	200		126		Cash, cash equivalents and restricted cash at beginning of period	113		200
Cash, cash equivalents and restricted cash at end of period	Cash, cash equivalents and restricted cash at end of period	$	189	$	125	Cash, cash equivalents and restricted cash at end of period	$	95	$	189
Supplemental Disclosures:	Supplemental Disclosures:					Supplemental Disclosures:

Significant non-cash transactions:	Significant non-cash transactions:					Significant non-cash transactions:
Accrued capital expenditures	Accrued capital expenditures	$	317	$	310	Accrued capital expenditures	$	349	$	317

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

Accumulated Other Comprehensive Income (Loss)
Net Gains Net Unrealized Total Progress
Additional (Losses) on Gains (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, 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
Balance at December 31, 2020 $ 9,143 $ 7,109 $ (5) $ (2) $ (8) $ 16,237 $ 4 $ 16,241
Net income — 290 — — — 290 — 290
Other comprehensive income (loss) — — 1 (1) — — — —
Distributions to noncontrolling interests — — — — — — (1) (1)
Other — 1 — — — 1 (1) —
Balance at March 31, 2021 $ 9,143 $ 7,400 $ (4) $ (3) $ (8) $ 16,528 $ 2 $ 16,530

























	Three Months Ended March 31, 2021 and 2022
					Accumulated Other Comprehensive Loss
					Net Gains		Net Unrealized				Total Progress
	Additional				(Losses) on		Gains (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, 2020	$	9,143	$	7,109	$	(5)	$	(2)	$	(8)	$	16,237	$	4	$	16,241
Net income	—		290		—		—		—		290		—		290
Other comprehensive income (loss)	—		—		1		(1)		—		—		—		—

Distributions to noncontrolling interests	—		—		—		—		—		—		(1)		(1)



Other	—		1		—		—		—		1		(1)		—
Balance at March 31, 2021	$	9,143	$	7,400	$	(4)	$	(3)	$	(8)	$	16,528	$	2	$	16,530

Balance at December 31, 2021	$	9,149	$	8,007	$	(2)	$	(2)	$	(7)	$	17,145	$	3	$	17,148
Net income	—		354		—		—		—		354		—		354
Other comprehensive income (loss)	—		—		1		(2)		—		(1)		—		(1)
Distributions to noncontrolling interests	—		—		—		—		—		—		(1)		(1)
Dividends to parent	—		(250)		—		—		—		(250)		—		(250)
Equitization of certain notes payable to affiliates	—		2,431		—		—		—		2,431		—		2,431
Other	—		1		—		—		—		1		—		1
Balance at March 31, 2022	$	9,149	$	10,543	$	(1)	$	(4)	$	(7)	$	19,680	$	2	$	19,682

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


		Three Months Ended						Three Months Ended
		March 31,						March 31,
(in millions)	(in millions)		2021		2020		(in millions)		2022		2021
Operating Revenues	Operating Revenues		$	1,401	$	1,338	Operating Revenues		$	1,632	$	1,401
Operating Expenses	Operating Expenses						Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power		436		405		Fuel used in electric generation and purchased power		574		436
Operation, maintenance and other	Operation, maintenance and other		357		305		Operation, maintenance and other		391		357
Depreciation and amortization	Depreciation and amortization		285		287		Depreciation and amortization		306		285
Property and other taxes	Property and other taxes		49		47		Property and other taxes		49		49

Total operating expenses	Total operating expenses		1,127		1,044		Total operating expenses		1,320		1,127
Losses on Sales of Other Assets and Other, net			—		(1)
Gains on Sales of Other Assets and Other, net							Gains on Sales of Other Assets and Other, net		1		—
Operating Income	Operating Income		274		293		Operating Income		313		274
Other Income and Expenses, net	Other Income and Expenses, net		24		22		Other Income and Expenses, net		22		24
Interest Expense	Interest Expense		69		69		Interest Expense		85		69
Income Before Income Taxes	Income Before Income Taxes		229		246		Income Before Income Taxes		250		229
Income Tax Expense	Income Tax Expense		19		42		Income Tax Expense		35		19
Net Income and Comprehensive Income	Net Income and Comprehensive Income		$	210	$	204	Net Income and Comprehensive Income		$	215	$	210

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and cash equivalents	Cash and cash equivalents	$	46	$	39	Cash and cash equivalents	$	42	$	35
Receivables (net of allowance for doubtful accounts of $4 at 2021 and 2020)		80		132
Receivables of VIEs (net of allowance for doubtful accounts of $19 at 2021 and 2020)		422		500
Receivables (net of allowance for doubtful accounts of $4 at 2022 and 2021)						Receivables (net of allowance for doubtful accounts of $4 at 2022 and 2021)	188		127
Receivables of VIEs (net of allowance for doubtful accounts of $27 at 2022 and $17 at 2021)						Receivables of VIEs (net of allowance for doubtful accounts of $27 at 2022 and $17 at 2021)	658		574
Receivables from affiliated companies	Receivables from affiliated companies	70		50		Receivables from affiliated companies	20		65

Notes receivable from affiliated companies						Notes receivable from affiliated companies	328		—
Inventory	Inventory	882		911		Inventory	940		921
Regulatory assets		469		492
Other		138		60
Regulatory assets (includes $39 at 2022 and 2021 related to VIEs)						Regulatory assets (includes $39 at 2022 and 2021 related to VIEs)	595		533
Other (includes $14 in 2022 and $0 in 2021 related to VIEs)						Other (includes $14 in 2022 and $0 in 2021 related to VIEs)	200		83
Total current assets	Total current assets	2,107		2,184		Total current assets	2,971		2,338
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Cost	Cost	36,077		35,759		Cost	37,361		37,018
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(13,064)		(12,801)		Accumulated depreciation and amortization	(13,691)		(13,387)
Generation facilities to be retired, net		29		29
Facilities to be retired, net						Facilities to be retired, net	24		26
Net property, plant and equipment	Net property, plant and equipment	23,042		22,987		Net property, plant and equipment	23,694		23,657
Other Noncurrent Assets	Other Noncurrent Assets					Other Noncurrent Assets
Regulatory assets		4,033		3,976
Regulatory assets (includes $711 at 2022 and $720 at 2021 related to VIEs)						Regulatory assets (includes $711 at 2022 and $720 at 2021 related to VIEs)	4,124		4,118
Nuclear decommissioning trust funds	Nuclear decommissioning trust funds	3,645		3,500		Nuclear decommissioning trust funds	3,872		4,089
Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	386		346		Operating lease right-of-use assets, net	410		389
Other	Other	759		740		Other	867		792
Total other noncurrent assets	Total other noncurrent assets	8,823		8,562		Total other noncurrent assets	9,273		9,388
Total Assets	Total Assets	$	33,972	$	33,733	Total Assets	$	35,938	$	35,383
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts payable	Accounts payable	$	339	$	454	Accounts payable	$	450	$	476
Accounts payable to affiliated companies	Accounts payable to affiliated companies	225		215		Accounts payable to affiliated companies	260		310
Notes payable to affiliated companies	Notes payable to affiliated companies	163		295		Notes payable to affiliated companies	—		172
Taxes accrued	Taxes accrued	73		85		Taxes accrued	77		163
Interest accrued	Interest accrued	71		99		Interest accrued	76		96
Current maturities of long-term debt		1,302		603
Current maturities of long-term debt (includes $32 at 2022 and $15 at 2021 related to VIEs)						Current maturities of long-term debt (includes $32 at 2022 and $15 at 2021 related to VIEs)	568		556
Asset retirement obligations	Asset retirement obligations	267		283		Asset retirement obligations	268		274
Regulatory liabilities	Regulatory liabilities	618		530		Regulatory liabilities	378		381
Other	Other	383		411		Other	400		448
Total current liabilities	Total current liabilities	3,441		2,975		Total current liabilities	2,477		2,876
Long-Term Debt		7,904		8,505
Long-Term Debt (includes $1,080 at 2022 and $1,097 at 2021 related to VIEs)						Long-Term Debt (includes $1,080 at 2022 and $1,097 at 2021 related to VIEs)	10,396		9,543
Long-Term Debt Payable to Affiliated Companies	Long-Term Debt Payable to Affiliated Companies	150		150		Long-Term Debt Payable to Affiliated Companies	150		150
Other Noncurrent Liabilities	Other Noncurrent Liabilities					Other Noncurrent Liabilities
Deferred income taxes	Deferred income taxes	2,374		2,298		Deferred income taxes	2,275		2,208
Asset retirement obligations	Asset retirement obligations	5,366		5,352		Asset retirement obligations	5,411		5,401
Regulatory liabilities	Regulatory liabilities	4,454		4,394		Regulatory liabilities	4,898		4,868
Operating lease liabilities	Operating lease liabilities	356		323		Operating lease liabilities	372		350
Accrued pension and other post-retirement benefit costs	Accrued pension and other post-retirement benefit costs	240		242		Accrued pension and other post-retirement benefit costs	218		221
Investment tax credits	Investment tax credits	131		132		Investment tax credits	128		128
Other	Other	86		102		Other	96		87
Total other noncurrent liabilities	Total other noncurrent liabilities	13,007		12,843		Total other noncurrent liabilities	13,398		13,263
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies	0		0
Equity	Equity					Equity
Member's Equity	Member's Equity	9,470		9,260		Member's Equity	9,517		9,551

Total Liabilities and Equity	Total Liabilities and Equity	$	33,972	$	33,733	Total Liabilities and Equity	$	35,938	$	35,383

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)


		Three Months Ended					Three Months Ended
		March 31,					March 31,
(in millions)	(in millions)	2021		2020		(in millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES	CASH FLOWS FROM OPERATING ACTIVITIES					CASH FLOWS FROM OPERATING ACTIVITIES
Net income	Net income	$	210	$	204	Net income	$	215	$	210
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	Depreciation and amortization (including amortization of nuclear fuel)	331		331		Depreciation and amortization (including amortization of nuclear fuel)	350		331
Equity component of AFUDC	Equity component of AFUDC	(8)		(10)		Equity component of AFUDC	(7)		(8)

Deferred income taxes	Deferred income taxes	6		43		Deferred income taxes	19		6

Payments for asset retirement obligations	Payments for asset retirement obligations	(46)		(75)		Payments for asset retirement obligations	(41)		(46)

Provision for rate refunds						Provision for rate refunds	(16)		—
(Increase) decrease in	(Increase) decrease in					(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	Net realized and unrealized mark-to-market and hedging transactions	2		(2)		Net realized and unrealized mark-to-market and hedging transactions	164		2
Receivables	Receivables	131		133		Receivables	(70)		131
Receivables from affiliated companies	Receivables from affiliated companies	(20)		2		Receivables from affiliated companies	63		(20)
Inventory	Inventory	29		(22)		Inventory	(19)		29
Other current assets	Other current assets	(21)		54		Other current assets	(75)		(21)
Increase (decrease) in	Increase (decrease) in					Increase (decrease) in
Accounts payable	Accounts payable	(62)		(220)		Accounts payable	18		(62)
Accounts payable to affiliated companies	Accounts payable to affiliated companies	10		5		Accounts payable to affiliated companies	(50)		10
Taxes accrued	Taxes accrued	(12)		26		Taxes accrued	(85)		(12)
Other current liabilities	Other current liabilities	(25)		(73)		Other current liabilities	(67)		(25)
Other assets	Other assets	(35)		(48)		Other assets	(56)		(35)
Other liabilities	Other liabilities	(15)		(8)		Other liabilities	47		(15)
Net cash provided by operating activities	Net cash provided by operating activities	475		340		Net cash provided by operating activities	390		475
CASH FLOWS FROM INVESTING ACTIVITIES	CASH FLOWS FROM INVESTING ACTIVITIES					CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	Capital expenditures	(400)		(466)		Capital expenditures	(467)		(400)

Purchases of debt and equity securities	Purchases of debt and equity securities	(382)		(550)		Purchases of debt and equity securities	(481)		(382)
Proceeds from sales and maturities of debt and equity securities	Proceeds from sales and maturities of debt and equity securities	380		540		Proceeds from sales and maturities of debt and equity securities	480		380

Notes receivable from affiliated companies						Notes receivable from affiliated companies	(328)		—

Other	Other	(29)		(16)		Other	(19)		(29)
Net cash used in investing activities	Net cash used in investing activities	(431)		(492)		Net cash used in investing activities	(815)		(431)
CASH FLOWS FROM FINANCING ACTIVITIES	CASH FLOWS FROM FINANCING ACTIVITIES					CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	Proceeds from the issuance of long-term debt	98		—		Proceeds from the issuance of long-term debt	889		98

Payments for the:						Payments for the:
Payments for the redemption of long-term debt	Payments for the redemption of long-term debt	(2)		(1)		Payments for the redemption of long-term debt	(21)		(2)

Notes payable to affiliated companies	Notes payable to affiliated companies	(132)		163		Notes payable to affiliated companies	(172)		(132)

Distributions to parent						Distributions to parent	(250)		—

Other	Other	(1)		—		Other	(1)		(1)
Net cash (used in) provided by financing activities		(37)		162
Net increase in cash and cash equivalents		7		10
Cash and cash equivalents at beginning of period		39		22
Cash and cash equivalents at end of period		$	46	$	32
Net cash provided by (used in) financing activities						Net cash provided by (used in) financing activities	445		(37)
Net increase in cash, cash equivalents and restricted cash						Net increase in cash, cash equivalents and restricted cash	20		7
Cash, cash equivalents and restricted cash at beginning of period						Cash, cash equivalents and restricted cash at beginning of period	39		39
Cash, cash equivalents and restricted cash at end of period						Cash, cash equivalents and restricted cash at end of period	$	59	$	46
Supplemental Disclosures:	Supplemental Disclosures:					Supplemental Disclosures:
Significant non-cash transactions:	Significant non-cash transactions:					Significant non-cash transactions:
Accrued capital expenditures	Accrued capital expenditures	$	96	$	87	Accrued capital expenditures	$	111	$	96

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)





















	Three Months Ended
	~~Member's~~
~~(in millions)~~	~~Equity~~
~~Balance at December~~March 31, ~~2019~~2021 and 2022	$	~~9,246~~
~~Net income~~	~~204~~



~~Balance at March 31, 2020~~(in millions)	$Member's Equity		~~9,450~~

Balance at December 31, 2020	$	9,260
Net income	210




Balance at March 31, 2021	$	9,470

Balance at December 31, 2021	$	9,551
Net income	215


Distributions to parent	(250)
Other	1
Balance at March 31, 2022	$	9,517

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


		Three Months Ended						Three Months Ended
		March 31,						March 31,
(in millions)	(in millions)		2021		2020		(in millions)		2022		2021
Operating Revenues	Operating Revenues		$	1,101	$	1,080	Operating Revenues		$	1,355	$	1,101
Operating Expenses	Operating Expenses						Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power		359		358		Fuel used in electric generation and purchased power		490		359
Operation, maintenance and other	Operation, maintenance and other		242		245		Operation, maintenance and other		249		242
Depreciation and amortization	Depreciation and amortization		200		165		Depreciation and amortization		231		200
Property and other taxes	Property and other taxes		93		88		Property and other taxes		103		93

Total operating expenses	Total operating expenses		894		856		Total operating expenses		1,073		894

Gains on Sales of Other Assets and Other, net							Gains on Sales of Other Assets and Other, net		1		—
Operating Income	Operating Income		207		224		Operating Income		283		207
Other Income and Expenses, net	Other Income and Expenses, net		18		10		Other Income and Expenses, net		15		18
Interest Expense	Interest Expense		80		84		Interest Expense		84		80
Income Before Income Taxes	Income Before Income Taxes		145		150		Income Before Income Taxes		214		145
Income Tax Expense	Income Tax Expense		28		30		Income Tax Expense		43		28
Net Income	Net Income		$	117	$	120	Net Income		$	171	$	117

Other Comprehensive Income, net of tax
Other Comprehensive Loss, net of tax							Other Comprehensive Loss, net of tax

Unrealized (losses) gains on available-for-sale securities			(1)		1
Unrealized losses on available-for-sale securities							Unrealized losses on available-for-sale securities		(1)		(1)

Comprehensive Income	Comprehensive Income		$	116	$	121	Comprehensive Income		$	170	$	116

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and cash equivalents	Cash and cash equivalents	$	22	$	11	Cash and cash equivalents	$	13	$	23
Receivables (net of allowance for doubtful accounts of $5 at 2021 and $4 at 2020)		84		94
Receivables of VIEs (net of allowance for doubtful accounts of $10 at 2021 and 2020)		327		401
Receivables (net of allowance for doubtful accounts of $8 at 2022 and 2021)						Receivables (net of allowance for doubtful accounts of $8 at 2022 and 2021)	97		117
Receivables of VIEs (net of allowance for doubtful accounts of $13 at 2022 and $8 at 2021)						Receivables of VIEs (net of allowance for doubtful accounts of $13 at 2022 and $8 at 2021)	508		432
Receivables from affiliated companies	Receivables from affiliated companies	7		3		Receivables from affiliated companies	16		16

Inventory	Inventory	455		464		Inventory	463		477
Regulatory assets (includes $54 at 2021 and $53 at 2020 related to VIEs)		352		265
Other (includes $14 at 2021 and $39 at 2020 related to VIEs)		82		41
Regulatory assets (includes $54 at 2022 and 2021 related to VIEs)						Regulatory assets (includes $54 at 2022 and 2021 related to VIEs)	505		497
Other (includes $13 at 2022 and $39 at 2021 related to VIEs)						Other (includes $13 at 2022 and $39 at 2021 related to VIEs)	79		80
Total current assets	Total current assets	1,329		1,279		Total current assets	1,681		1,642
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Cost	Cost	22,459		22,123		Cost	24,257		23,865
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(5,646)		(5,560)		Accumulated depreciation and amortization	(6,003)		(5,819)
Net property, plant and equipment	Net property, plant and equipment	16,813		16,563		Net property, plant and equipment	18,254		18,046
Other Noncurrent Assets	Other Noncurrent Assets					Other Noncurrent Assets
Regulatory assets (includes $927 at 2021 and $937 at 2020 related to VIEs)		1,717		1,799
Regulatory assets (includes $872 at 2022 and $883 at 2021 related to VIEs)						Regulatory assets (includes $872 at 2022 and $883 at 2021 related to VIEs)	1,899		1,791
Nuclear decommissioning trust funds	Nuclear decommissioning trust funds	617		637		Nuclear decommissioning trust funds	514		553
Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	333		344		Operating lease right-of-use assets, net	291		302
Other	Other	355		335		Other	418		399
Total other noncurrent assets	Total other noncurrent assets	3,022		3,115		Total other noncurrent assets	3,122		3,045
Total Assets	Total Assets	$	21,164	$	20,957	Total Assets	$	23,057	$	22,733
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts payable	Accounts payable	$	457	$	465	Accounts payable	$	532	$	623
Accounts payable to affiliated companies	Accounts payable to affiliated companies	108		85		Accounts payable to affiliated companies	120		209
Notes payable to affiliated companies	Notes payable to affiliated companies	279		196		Notes payable to affiliated companies	468		199
Taxes accrued	Taxes accrued	84		82		Taxes accrued	96		51
Interest accrued	Interest accrued	75		69		Interest accrued	84		68
Current maturities of long-term debt (includes $305 at 2021 and 2020 related to VIEs)		824		823

Current maturities of long-term debt (includes $56 at 2022 and 2021 related to VIEs)						Current maturities of long-term debt (includes $56 at 2022 and 2021 related to VIEs)	77		76
Asset retirement obligations						Asset retirement obligations	1		1
Regulatory liabilities	Regulatory liabilities	84		110		Regulatory liabilities	91		98
Other	Other	356		374		Other	349		408
Total current liabilities	Total current liabilities	2,267		2,204		Total current liabilities	1,818		1,733
Long-Term Debt (includes $972 at 2021 and $1,002 at 2020 related to VIEs)		7,060		7,092
Long-Term Debt (includes $1,166 at 2022 and $1,196 at 2021 related to VIEs)						Long-Term Debt (includes $1,166 at 2022 and $1,196 at 2021 related to VIEs)	8,374		8,406
Other Noncurrent Liabilities	Other Noncurrent Liabilities					Other Noncurrent Liabilities
Deferred income taxes	Deferred income taxes	2,209		2,191		Deferred income taxes	2,503		2,434
Asset retirement obligations	Asset retirement obligations	493		514		Asset retirement obligations	411		436
Regulatory liabilities	Regulatory liabilities	672		658		Regulatory liabilities	772		698
Operating lease liabilities	Operating lease liabilities	292		300		Operating lease liabilities	247		256
Accrued pension and other post-retirement benefit costs	Accrued pension and other post-retirement benefit costs	230		231		Accrued pension and other post-retirement benefit costs	161		166
Other	Other	267		209		Other	306		309
Total other noncurrent liabilities	Total other noncurrent liabilities	4,163		4,103		Total other noncurrent liabilities	4,400		4,299
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies	0		0
Equity	Equity					Equity
Member's equity	Member's equity	7,677		7,560		Member's equity	8,469		8,298
Accumulated other comprehensive loss	Accumulated other comprehensive loss	(3)		(2)		Accumulated other comprehensive loss	(4)		(3)
Total equity	Total equity	7,674		7,558		Total equity	8,465		8,295
Total Liabilities and Equity	Total Liabilities and Equity	$	21,164	$	20,957	Total Liabilities and Equity	$	23,057	$	22,733

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)


		Three Months Ended					Three Months Ended
		March 31,					March 31,
(in millions)	(in millions)	2021		2020		(in millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES	CASH FLOWS FROM OPERATING ACTIVITIES					CASH FLOWS FROM OPERATING ACTIVITIES
Net income	Net income	$	117	$	120	Net income	$	171	$	117
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	Depreciation, amortization and accretion	243		219		Depreciation, amortization and accretion	273		243
Equity component of AFUDC	Equity component of AFUDC	(4)		(4)		Equity component of AFUDC	(5)		(4)

Deferred income taxes	Deferred income taxes	74		34		Deferred income taxes	52		74

Payments for asset retirement obligations	Payments for asset retirement obligations	(24)		(5)		Payments for asset retirement obligations	(28)		(24)
(Increase) decrease in	(Increase) decrease in					(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	Net realized and unrealized mark-to-market and hedging transactions	2		3		Net realized and unrealized mark-to-market and hedging transactions	—		2
Receivables	Receivables	83		15		Receivables	(54)		83
Receivables from affiliated companies	Receivables from affiliated companies	(4)		—		Receivables from affiliated companies	—		(4)
Inventory	Inventory	10		(19)		Inventory	14		10
Other current assets	Other current assets	(101)		7		Other current assets	(72)		(101)
Increase (decrease) in	Increase (decrease) in					Increase (decrease) in
Accounts payable	Accounts payable	(7)		11		Accounts payable	9		(7)
Accounts payable to affiliated companies	Accounts payable to affiliated companies	23		(20)		Accounts payable to affiliated companies	(89)		23
Taxes accrued	Taxes accrued	3		31		Taxes accrued	45		3
Other current liabilities	Other current liabilities	(41)		(58)		Other current liabilities	(52)		(41)
Other assets	Other assets	12		13		Other assets	(24)		12
Other liabilities	Other liabilities	(48)		(46)		Other liabilities	(6)		(48)
Net cash provided by operating activities	Net cash provided by operating activities	338		301		Net cash provided by operating activities	234		338
CASH FLOWS FROM INVESTING ACTIVITIES	CASH FLOWS FROM INVESTING ACTIVITIES					CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	Capital expenditures	(396)		(506)		Capital expenditures	(514)		(396)

Purchases of debt and equity securities	Purchases of debt and equity securities	(134)		(101)		Purchases of debt and equity securities	(49)		(134)
Proceeds from sales and maturities of debt and equity securities	Proceeds from sales and maturities of debt and equity securities	157		103		Proceeds from sales and maturities of debt and equity securities	69		157

Notes receivable from affiliated companies		—		173

Other	Other	(30)		(23)		Other	(10)		(30)
Net cash used in investing activities	Net cash used in investing activities	(403)		(354)		Net cash used in investing activities	(504)		(403)
CASH FLOWS FROM FINANCING ACTIVITIES	CASH FLOWS FROM FINANCING ACTIVITIES					CASH FLOWS FROM FINANCING ACTIVITIES

Payments for the redemption of long-term debt	Payments for the redemption of long-term debt	(33)		(282)		Payments for the redemption of long-term debt	(34)		(33)

Notes payable to affiliated companies	Notes payable to affiliated companies	83		305		Notes payable to affiliated companies	269		83

Other	Other	—		(1)		Other	(1)		—
Net cash provided by financing activities	Net cash provided by financing activities	50		22		Net cash provided by financing activities	234		50
Net decrease in cash, cash equivalents and restricted cash	Net decrease in cash, cash equivalents and restricted cash	(15)		(31)		Net decrease in cash, cash equivalents and restricted cash	(36)		(15)
Cash, cash equivalents and restricted cash at beginning of period	Cash, cash equivalents and restricted cash at beginning of period	50		56		Cash, cash equivalents and restricted cash at beginning of period	62		50
Cash, cash equivalents and restricted cash at end of period	Cash, cash equivalents and restricted cash at end of period	$	35	$	25	Cash, cash equivalents and restricted cash at end of period	$	26	$	35
Supplemental Disclosures:	Supplemental Disclosures:					Supplemental Disclosures:
Significant non-cash transactions:	Significant non-cash transactions:					Significant non-cash transactions:
Accrued capital expenditures	Accrued capital expenditures	$	222	$	223	Accrued capital expenditures	$	237	$	222

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)


				Three Months Ended March 31, 2021 and 2022
					Accumulated							Accumulated
					Other							Other
					Comprehensive							Comprehensive
					Income (Loss)							Loss
					Net Unrealized							Net Unrealized
					Gains (Losses) on							Losses on
		Member's			Available-for-Sale		Total			Member's		Available-for-Sale		Total
(in millions)	(in millions)	Equity			Securities		Equity		(in millions)	Equity		Securities		Equity
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

Balance at December 31, 2020	Balance at December 31, 2020	$	7,560		$	(2)	$	7,558	Balance at December 31, 2020	$	7,560	$	(2)	$	7,558
Net income	Net income	117			—		117		Net income	117		—		117
Other comprehensive loss	Other comprehensive loss	—			(1)		(1)		Other comprehensive loss	—		(1)		(1)

Balance at March 31, 2021	Balance at March 31, 2021	$	7,677		$	(3)	$	7,674	Balance at March 31, 2021	$	7,677	$	(3)	$	7,674

Balance at December 31, 2021									Balance at December 31, 2021	$	8,298	$	(3)	$	8,295
Net income									Net income	171		—		171
Other comprehensive loss									Other comprehensive loss	—		(1)		(1)

Balance at March 31, 2022									Balance at March 31, 2022	$	8,469	$	(4)	$	8,465

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


		Three Months Ended			Three Months Ended
		March 31,			March 31,
(in millions)	(in millions)		2021			2020		(in millions)	2022		2021
Operating Revenues	Operating Revenues							Operating Revenues
Regulated electric	Regulated electric		$	363		$	346	Regulated electric	$	412	$	363
Regulated natural gas	Regulated natural gas		169			152		Regulated natural gas	226		169

Total operating revenues	Total operating revenues		532			498		Total operating revenues	638		532
Operating Expenses	Operating Expenses							Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power		82			87		Fuel used in electric generation and purchased power	127		82

Cost of natural gas	Cost of natural gas		51			37		Cost of natural gas	107		51
Operation, maintenance and other	Operation, maintenance and other		108			123		Operation, maintenance and other	178		108
Depreciation and amortization	Depreciation and amortization		74			68		Depreciation and amortization	80		74
Property and other taxes	Property and other taxes		92			83		Property and other taxes	101		92

Total operating expenses	Total operating expenses		407			398		Total operating expenses	593		407

Operating Income	Operating Income		125			100		Operating Income	45		125
Other Income and Expenses, net	Other Income and Expenses, net		5			3		Other Income and Expenses, net	6		5
Interest Expense	Interest Expense		25			24		Interest Expense	30		25
Income Before Income Taxes	Income Before Income Taxes		105			79		Income Before Income Taxes	21		105
Income Tax Expense			14			14
Income Tax (Benefit) Expense								Income Tax (Benefit) Expense	(56)		14

Net Income and Comprehensive Income	Net Income and Comprehensive Income		$	91		$	65	Net Income and Comprehensive Income	$	77	$	91

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and cash equivalents	Cash and cash equivalents	$	18	$	14	Cash and cash equivalents	$	15	$	13
Receivables (net of allowance for doubtful accounts of $4 at 2021 and 2020)		98		98
Receivables (net of allowance for doubtful accounts of $4 at 2022 and 2021)						Receivables (net of allowance for doubtful accounts of $4 at 2022 and 2021)	101		96
Receivables from affiliated companies	Receivables from affiliated companies	60		102		Receivables from affiliated companies	93		122

Notes receivable from affiliated companies						Notes receivable from affiliated companies	—		15
Inventory	Inventory	108		110		Inventory	114		116

Regulatory assets	Regulatory assets	54		39		Regulatory assets	60		72
Other	Other	18		31		Other	23		57
Total current assets	Total current assets	356		394		Total current assets	406		491
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Cost	Cost	11,199		11,022		Cost	11,818		11,725
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(3,049)		(3,013)		Accumulated depreciation and amortization	(3,102)		(3,106)

Generation facilities to be retired, net						Generation facilities to be retired, net	—		6
Net property, plant and equipment	Net property, plant and equipment	8,150		8,009		Net property, plant and equipment	8,716		8,625
Other Noncurrent Assets	Other Noncurrent Assets					Other Noncurrent Assets
Goodwill	Goodwill	920		920		Goodwill	920		920
Regulatory assets	Regulatory assets	620		610		Regulatory assets	584		635

Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	20		20		Operating lease right-of-use assets, net	18		19

Other	Other	75		72		Other	87		84
Total other noncurrent assets	Total other noncurrent assets	1,635		1,622		Total other noncurrent assets	1,609		1,658
Total Assets	Total Assets	$	10,141	$	10,025	Total Assets	$	10,731	$	10,774
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts payable	Accounts payable	$	266	$	279	Accounts payable	$	379	$	348
Accounts payable to affiliated companies	Accounts payable to affiliated companies	56		68		Accounts payable to affiliated companies	68		64
Notes payable to affiliated companies	Notes payable to affiliated companies	270		169		Notes payable to affiliated companies	123		103
Taxes accrued	Taxes accrued	192		247		Taxes accrued	219		275
Interest accrued	Interest accrued	32		31		Interest accrued	32		30
Current maturities of long-term debt		50		50

Asset retirement obligations	Asset retirement obligations	8		3		Asset retirement obligations	13		13
Regulatory liabilities	Regulatory liabilities	59		65		Regulatory liabilities	67		62
Other	Other	67		70		Other	73		82
Total current liabilities	Total current liabilities	1,000		982		Total current liabilities	974		977
Long-Term Debt	Long-Term Debt	3,015		3,014		Long-Term Debt	3,168		3,168
Long-Term Debt Payable to Affiliated Companies	Long-Term Debt Payable to Affiliated Companies	25		25		Long-Term Debt Payable to Affiliated Companies	25		25
Other Noncurrent Liabilities	Other Noncurrent Liabilities					Other Noncurrent Liabilities
Deferred income taxes	Deferred income taxes	1,001		981		Deferred income taxes	1,078		1,050
Asset retirement obligations	Asset retirement obligations	104		108		Asset retirement obligations	124		123
Regulatory liabilities	Regulatory liabilities	739		748		Regulatory liabilities	593		739
Operating lease liabilities	Operating lease liabilities	20		20		Operating lease liabilities	18		18
Accrued pension and other post-retirement benefit costs	Accrued pension and other post-retirement benefit costs	114		113		Accrued pension and other post-retirement benefit costs	109		109

Other	Other	97		99		Other	100		101
Total other noncurrent liabilities	Total other noncurrent liabilities	2,075		2,069		Total other noncurrent liabilities	2,022		2,140
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies	0		0
Equity	Equity					Equity
Common Stock, $8.50 par value, 120 million shares authorized; 90 million shares outstanding at 2021 and 2020		762		762
Common Stock, $8.50 par value, 120 million shares authorized; 90 million shares outstanding at 2022 and 2021						Common Stock, $8.50 par value, 120 million shares authorized; 90 million shares outstanding at 2022 and 2021	762		762
Additional paid-in capital	Additional paid-in capital	2,776		2,776		Additional paid-in capital	3,100		3,100
Retained earnings	Retained earnings	488		397		Retained earnings	680		602

Total equity	Total equity	4,026		3,935		Total equity	4,542		4,464
Total Liabilities and Equity	Total Liabilities and Equity	$	10,141	$	10,025	Total Liabilities and Equity	$	10,731	$	10,774

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)


		Three Months Ended					Three Months Ended
		March 31,					March 31,
(in millions)	(in millions)	2021		2020		(in millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES	CASH FLOWS FROM OPERATING ACTIVITIES					CASH FLOWS FROM OPERATING ACTIVITIES
Net income	Net income	$	91	$	65	Net income	$	77	$	91
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	75		69		Depreciation and amortization	81		75
Equity component of AFUDC	Equity component of AFUDC	(2)		(1)		Equity component of AFUDC	(3)		(2)

Deferred income taxes	Deferred income taxes	12		14		Deferred income taxes	(51)		12

Provision for rate refunds						Provision for rate refunds	5		—
(Increase) decrease in	(Increase) decrease in					(Increase) decrease in

Receivables	Receivables	—		1		Receivables	(5)		—
Receivables from affiliated companies	Receivables from affiliated companies	5		40		Receivables from affiliated companies	15		5
Inventory	Inventory	2		14		Inventory	2		2
Other current assets	Other current assets	(5)		8		Other current assets	48		(5)
Increase (decrease) in	Increase (decrease) in					Increase (decrease) in
Accounts payable	Accounts payable	8		(19)		Accounts payable	88		8
Accounts payable to affiliated companies	Accounts payable to affiliated companies	(12)		—		Accounts payable to affiliated companies	—		(12)
Taxes accrued	Taxes accrued	(55)		(49)		Taxes accrued	(56)		(55)
Other current liabilities	Other current liabilities	(8)		2		Other current liabilities	(89)		(8)
Other assets	Other assets	(16)		(2)		Other assets	(17)		(16)
Other liabilities	Other liabilities	1		(5)		Other liabilities	74		1
Net cash provided by operating activities	Net cash provided by operating activities	96		137		Net cash provided by operating activities	169		96
CASH FLOWS FROM INVESTING ACTIVITIES	CASH FLOWS FROM INVESTING ACTIVITIES					CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	Capital expenditures	(220)		(217)		Capital expenditures	(210)		(220)

Notes receivable from affiliated companies	Notes receivable from affiliated companies	37		—		Notes receivable from affiliated companies	29		37

Other	Other	(10)		(10)		Other	(6)		(10)
Net cash used in investing activities	Net cash used in investing activities	(193)		(227)		Net cash used in investing activities	(187)		(193)
CASH FLOWS FROM FINANCING ACTIVITIES	CASH FLOWS FROM FINANCING ACTIVITIES					CASH FLOWS FROM FINANCING ACTIVITIES

Notes payable to affiliated companies	Notes payable to affiliated companies	101		87		Notes payable to affiliated companies	21		101

Other						Other	(1)		—
Net cash provided by financing activities	Net cash provided by financing activities	101		87		Net cash provided by financing activities	20		101
Net increase (decrease) in cash and cash equivalents		4		(3)
Net increase in cash and cash equivalents						Net increase in cash and cash equivalents	2		4
Cash and cash equivalents at beginning of period	Cash and cash equivalents at beginning of period	14		17		Cash and cash equivalents at beginning of period	13		14
Cash and cash equivalents at end of period	Cash and cash equivalents at end of period	$	18	$	14	Cash and cash equivalents at end of period	$	15	$	18
Supplemental Disclosures:	Supplemental Disclosures:					Supplemental Disclosures:
Significant non-cash transactions:	Significant non-cash transactions:					Significant non-cash transactions:
Accrued capital expenditures	Accrued capital expenditures	$	84	$	66	Accrued capital expenditures	$	82	$	84

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)


				Three Months Ended March 31, 2021 and 2022
					Additional									Additional
		Common			Paid-in		Retained		Total			Common		Paid-in		Retained		Total
(in millions)	(in millions)	Stock			Capital		Earnings		Equity		(in millions)	Stock		Capital		Earnings		Equity
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

Balance at December 31, 2020	Balance at December 31, 2020	$	762		$	2,776	$	397	$	3,935	Balance at December 31, 2020	$	762	$	2,776	$	397	$	3,935
Net income	Net income	—			—		91		91		Net income	—		—		91		91

Balance at March 31, 2021											Balance at March 31, 2021	$	762	$	2,776	$	488	$	4,026

Balance at March 31, 2021		$	762		$	2,776	$	488	$	4,026
Balance at December 31, 2021											Balance at December 31, 2021	$	762	$	3,100	$	602	$	4,464
Net income											Net income	—		—		77		77

Other											Other	—		—		1		1
Balance at March 31, 2022											Balance at March 31, 2022	$	762	$	3,100	$	680	$	4,542

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


		Three Months Ended						Three Months Ended
		March 31,						March 31,
(in millions)	(in millions)		2021		2020		(in millions)		2022		2021
Operating Revenues	Operating Revenues		$	745	$	692	Operating Revenues		$	822	$	745
Operating Expenses	Operating Expenses						Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power		217		194		Fuel used in electric generation and purchased power		319		217
Operation, maintenance and other	Operation, maintenance and other		178		186		Operation, maintenance and other		192		178
Depreciation and amortization	Depreciation and amortization		152		132		Depreciation and amortization		156		152
Property and other taxes	Property and other taxes		21		22		Property and other taxes		25		21

Impairment of assets and other charges							Impairment of assets and other charges		211		—
Total operating expenses	Total operating expenses		568		534		Total operating expenses		903		568

Operating Income			177		158
Operating (Loss) Income							Operating (Loss) Income		(81)		177
Other Income and Expenses, net	Other Income and Expenses, net		9		10		Other Income and Expenses, net		10		9
Interest Expense	Interest Expense		50		43		Interest Expense		45		50
Income Before Income Taxes			136		125
Income Tax Expense			24		26
Net Income and Comprehensive Income			$	112	$	99
(Loss) Income Before Income Taxes							(Loss) Income Before Income Taxes		(116)		136
Income Tax (Benefit) Expense							Income Tax (Benefit) Expense		(37)		24
Net (Loss) Income and Comprehensive (Loss) Income							Net (Loss) Income and Comprehensive (Loss) Income		$	(79)	$	112

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and cash equivalents	Cash and cash equivalents	$	17	$	7	Cash and cash equivalents	$	19	$	6
Receivables (net of allowance for doubtful accounts of $3 at 2021 and 2020)		63		55
Receivables (net of allowance for doubtful accounts of $3 at 2022 and 2021)						Receivables (net of allowance for doubtful accounts of $3 at 2022 and 2021)	83		100
Receivables from affiliated companies	Receivables from affiliated companies	62		112		Receivables from affiliated companies	69		98
Notes receivable from affiliated companies	Notes receivable from affiliated companies	51		—		Notes receivable from affiliated companies	20		134
Inventory	Inventory	436		473		Inventory	430		418
Regulatory assets	Regulatory assets	151		125		Regulatory assets	301		277
Other	Other	34		37		Other	72		68
Total current assets	Total current assets	814		809		Total current assets	994		1,101
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Cost	Cost	17,548		17,382		Cost	17,494		17,343
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(5,821)		(5,661)		Accumulated depreciation and amortization	(5,693)		(5,583)

Net property, plant and equipment	Net property, plant and equipment	11,727		11,721		Net property, plant and equipment	11,801		11,760
Other Noncurrent Assets	Other Noncurrent Assets					Other Noncurrent Assets
Regulatory assets	Regulatory assets	1,217		1,203		Regulatory assets	1,077		1,278

Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	54		55		Operating lease right-of-use assets, net	52		53
Other	Other	251		253		Other	295		296
Total other noncurrent assets	Total other noncurrent assets	1,522		1,511		Total other noncurrent assets	1,424		1,627
Total Assets	Total Assets	$	14,063	$	14,041	Total Assets	$	14,219	$	14,488
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts payable	Accounts payable	$	163	$	188	Accounts payable	$	268	$	282
Accounts payable to affiliated companies	Accounts payable to affiliated companies	72		88		Accounts payable to affiliated companies	187		221
Notes payable to affiliated companies		—		131

Taxes accrued	Taxes accrued	122		62		Taxes accrued	131		73
Interest accrued	Interest accrued	59		51		Interest accrued	56		49
Current maturities of long-term debt	Current maturities of long-term debt	123		70		Current maturities of long-term debt	31		84
Asset retirement obligations	Asset retirement obligations	176		168		Asset retirement obligations	115		110
Regulatory liabilities	Regulatory liabilities	119		111		Regulatory liabilities	140		127
Other	Other	82		83		Other	108		105
Total current liabilities	Total current liabilities	916		952		Total current liabilities	1,036		1,051
Long-Term Debt	Long-Term Debt	3,818		3,871		Long-Term Debt	4,089		4,089
Long-Term Debt Payable to Affiliated Companies	Long-Term Debt Payable to Affiliated Companies	150		150		Long-Term Debt Payable to Affiliated Companies	150		150
Other Noncurrent Liabilities	Other Noncurrent Liabilities					Other Noncurrent Liabilities
Deferred income taxes	Deferred income taxes	1,230		1,228		Deferred income taxes	1,234		1,303
Asset retirement obligations	Asset retirement obligations	997		1,008		Asset retirement obligations	861		877
Regulatory liabilities	Regulatory liabilities	1,629		1,627		Regulatory liabilities	1,557		1,565
Operating lease liabilities	Operating lease liabilities	52		53		Operating lease liabilities	49		50
Accrued pension and other post-retirement benefit costs	Accrued pension and other post-retirement benefit costs	172		171		Accrued pension and other post-retirement benefit costs	168		167
Investment tax credits	Investment tax credits	168		168		Investment tax credits	177		177
Other	Other	35		30		Other	74		44
Total other noncurrent liabilities	Total other noncurrent liabilities	4,283		4,285		Total other noncurrent liabilities	4,120		4,183
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies	0		0
Equity	Equity					Equity
Member's Equity	Member's Equity	4,896		4,783		Member's Equity	4,824		5,015
Total Liabilities and Equity	Total Liabilities and Equity	$	14,063	$	14,041	Total Liabilities and Equity	$	14,219	$	14,488

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

Three Months Ended
March 31,
(in millions) 2021 2020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 112 $ 99
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion 153 133
Equity component of AFUDC (5) (6)
Deferred income taxes (12) 16
Payments for asset retirement obligations (10) (12)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions 1 —
Receivables (9) 15
Receivables from affiliated companies — 3
Inventory 38 (21)
Other current assets (23) 25
Increase (decrease) in
Accounts payable 1 (13)
Accounts payable to affiliated companies (16) (21)
Taxes accrued 71 43
Other current liabilities 20 (27)
Other assets 3 (4)
Other liabilities 12 8
Net cash provided by operating activities 336 238
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (186) (210)
Purchases of debt and equity securities (5) (5)
Proceeds from sales and maturities of debt and equity securities 4 2
Notes receivable from affiliated companies (1) (543)
Other (7) (6)
Net cash used in investing activities (195) (762)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt — 544
Notes payable to affiliated companies (131) (30)
Net cash (used in) provided by financing activities (131) 514
Net increase (decrease) in cash and cash equivalents 10 (10)
Cash and cash equivalents at beginning of period 7 25
Cash and cash equivalents at end of period $ 17 $ 15
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures $ 74 $ 70


	Three Months Ended
	March 31,
(in millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$	(79)	$	112
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	157		153
Equity component of AFUDC	(7)		(5)

Impairment of assets and other charges	211		—
Deferred income taxes	(81)		(12)


Payments for asset retirement obligations	(15)		(10)

(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	—		1
Receivables	4		(9)
Receivables from affiliated companies	12		—
Inventory	(12)		38
Other current assets	(22)		(23)
Increase (decrease) in
Accounts payable	19		1
Accounts payable to affiliated companies	(22)		(16)
Taxes accrued	74		71
Other current liabilities	14		20
Other assets	(10)		3
Other liabilities	50		12
Net cash provided by operating activities	293		336
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(212)		(186)

Purchases of debt and equity securities	(16)		(5)
Proceeds from sales and maturities of debt and equity securities	13		4

Notes receivable from affiliated companies	131		(1)
Other	(17)		(7)
Net cash used in investing activities	(101)		(195)
CASH FLOWS FROM FINANCING ACTIVITIES

Payments for the redemption of long-term debt	(53)		—
Notes payable to affiliated companies	—		(131)

Distributions to parent	(125)		—
Other	(1)		—
Net cash used in financing activities	(179)		(131)
Net increase in cash and cash equivalents	13		10
Cash and cash equivalents at beginning of period	6		7
Cash and cash equivalents at end of period	$	19	$	17
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	82	$	74

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)


















	Three Months Ended
	~~Member's~~March 31, 2021 and 2022

(in millions)	Member's Equity
~~Balance at December 31, 2019~~	$	~~4,575~~
~~Net income~~	99



~~Balance at March 31, 2020~~	$	~~4,674~~

Balance at December 31, 2020	$	4,783
Net income	112


Other	1

Balance at March 31, 2021	$	4,896

Balance at December 31, 2021	$	5,015
Net loss	(79)

Distributions to parent	(113)
Other	1

Balance at March 31, 2022	$	4,824

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


		Three Months Ended						Three Months Ended
		March 31,						March 31,
(in millions)	(in millions)		2021		2020		(in millions)		2022		2021

Operating Revenues	Operating Revenues		$	606	$	512	Operating Revenues		$	805	$	606
Operating Expenses	Operating Expenses						Operating Expenses
Cost of natural gas	Cost of natural gas		225		162		Cost of natural gas		374		225
Operation, maintenance and other	Operation, maintenance and other		78		80		Operation, maintenance and other		95		78
Depreciation and amortization	Depreciation and amortization		48		45		Depreciation and amortization		54		48
Property and other taxes	Property and other taxes		14		12		Property and other taxes		16		14

Total operating expenses	Total operating expenses		365		299		Total operating expenses		539		365

Operating Income	Operating Income		241		213		Operating Income		266		241

Other Income and Expenses, net	Other Income and Expenses, net		17		12		Other Income and Expenses, net		13		17

Interest Expense	Interest Expense		29		27		Interest Expense		32		29
Income Before Income Taxes	Income Before Income Taxes		229		198		Income Before Income Taxes		247		229
Income Tax Expense	Income Tax Expense		26		20		Income Tax Expense		33		26
Net Income and Comprehensive Income	Net Income and Comprehensive Income		$	203	$	178	Net Income and Comprehensive Income		$	214	$	203

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current Assets	Current Assets					Current Assets
Cash and cash equivalents		$	1	$	0
Receivables (net of allowance for doubtful accounts of $14 at 2021 and $12 at 2020)		257		250

Receivables (net of allowance for doubtful accounts of $17 at 2022 and $15 at 2021)						Receivables (net of allowance for doubtful accounts of $17 at 2022 and $15 at 2021)	$	303	$	318
Receivables from affiliated companies	Receivables from affiliated companies	10		10		Receivables from affiliated companies	13		11
Notes receivable from affiliated companies		198		0

Inventory	Inventory	37		68		Inventory	51		109
Regulatory assets	Regulatory assets	100		153		Regulatory assets	133		141

Other	Other	12		20		Other	16		9
Total current assets	Total current assets	615		501		Total current assets	516		588
Property, Plant and Equipment	Property, Plant and Equipment					Property, Plant and Equipment
Cost	Cost	9,358		9,134		Cost	10,110		9,918
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(1,809)		(1,749)		Accumulated depreciation and amortization	(1,952)		(1,899)
Facilities to be retired, net						Facilities to be retired, net	10		11
Net property, plant and equipment	Net property, plant and equipment	7,549		7,385		Net property, plant and equipment	8,168		8,030
Other Noncurrent Assets	Other Noncurrent Assets					Other Noncurrent Assets
Goodwill	Goodwill	49		49		Goodwill	49		49
Regulatory assets	Regulatory assets	324		302		Regulatory assets	349		316
Operating lease right-of-use assets, net	Operating lease right-of-use assets, net	19		20		Operating lease right-of-use assets, net	15		16
Investments in equity method unconsolidated affiliates	Investments in equity method unconsolidated affiliates	88		88		Investments in equity method unconsolidated affiliates	97		95
Other	Other	274		270		Other	307		288
Total other noncurrent assets	Total other noncurrent assets	754		729		Total other noncurrent assets	817		764
Total Assets	Total Assets	$	8,918	$	8,615	Total Assets	$	9,501	$	9,382
LIABILITIES AND EQUITY	LIABILITIES AND EQUITY					LIABILITIES AND EQUITY
Current Liabilities	Current Liabilities					Current Liabilities
Accounts payable	Accounts payable	$	166	$	230	Accounts payable	$	170	$	196
Accounts payable to affiliated companies	Accounts payable to affiliated companies	58		79		Accounts payable to affiliated companies	52		40

Notes payable to affiliated companies	Notes payable to affiliated companies	—		530		Notes payable to affiliated companies	360		518
Taxes accrued	Taxes accrued	68		23		Taxes accrued	79		63
Interest accrued	Interest accrued	37		34		Interest accrued	35		37
Current maturities of long-term debt		160		160

Regulatory liabilities	Regulatory liabilities	70		88		Regulatory liabilities	98		56
Other	Other	73		69		Other	73		81
Total current liabilities	Total current liabilities	632		1,213		Total current liabilities	867		991
Long-Term Debt	Long-Term Debt	2,967		2,620		Long-Term Debt	2,969		2,968

Other Noncurrent Liabilities	Other Noncurrent Liabilities					Other Noncurrent Liabilities
Deferred income taxes	Deferred income taxes	837		821		Deferred income taxes	831		815
Asset retirement obligations	Asset retirement obligations	20		20		Asset retirement obligations	22		22
Regulatory liabilities	Regulatory liabilities	1,015		1,044		Regulatory liabilities	1,041		1,058
Operating lease liabilities	Operating lease liabilities	17		19		Operating lease liabilities	13		14
Accrued pension and other post-retirement benefit costs	Accrued pension and other post-retirement benefit costs	8		8		Accrued pension and other post-retirement benefit costs	7		7

Other	Other	179		155		Other	188		158
Total other noncurrent liabilities	Total other noncurrent liabilities	2,076		2,067		Total other noncurrent liabilities	2,102		2,074
Commitments and Contingencies	Commitments and Contingencies	0		0		Commitments and Contingencies	0		0
Equity	Equity					Equity
Common stock, no par value: 100 shares authorized and outstanding at 2021 and 2020		1,635		1,310
Common stock, no par value: 100 shares authorized and outstanding at 2022 and 2021						Common stock, no par value: 100 shares authorized and outstanding at 2022 and 2021	1,635		1,635

Retained earnings	Retained earnings	1,608		1,405		Retained earnings	1,928		1,714

Total equity	Total equity	3,243		2,715		Total equity	3,563		3,349
Total Liabilities and Equity	Total Liabilities and Equity	$	8,918	$	8,615	Total Liabilities and Equity	$	9,501	$	9,382

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)


		Three Months Ended					Three Months Ended
		March 31,					March 31,
(in millions)	(in millions)	2021		2020		(in millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES	CASH FLOWS FROM OPERATING ACTIVITIES					CASH FLOWS FROM OPERATING ACTIVITIES
Net income	Net income	$	203	$	178	Net income	$	214	$	203
Adjustments to reconcile net income to net cash provided by operating activities:	Adjustments to reconcile net income to net cash provided by operating activities:					Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	48		46		Depreciation and amortization	55		48
Equity component of AFUDC	Equity component of AFUDC	(6)		(5)		Equity component of AFUDC	(1)		(6)

Deferred income taxes	Deferred income taxes	(12)		12		Deferred income taxes	(11)		(12)
Equity in earnings from unconsolidated affiliates	Equity in earnings from unconsolidated affiliates	(2)		(2)		Equity in earnings from unconsolidated affiliates	(2)		(2)

Provision for rate refunds						Provision for rate refunds	(2)		—
(Increase) decrease in	(Increase) decrease in					(Increase) decrease in

Receivables	Receivables	(8)		65		Receivables	15		(8)
Receivables from affiliated companies	Receivables from affiliated companies	—		(3)		Receivables from affiliated companies	(2)		—
Inventory	Inventory	31		33		Inventory	58		31
Other current assets	Other current assets	66		(9)		Other current assets	7		66
Increase (decrease) in	Increase (decrease) in					Increase (decrease) in
Accounts payable	Accounts payable	(63)		(76)		Accounts payable	(16)		(63)
Accounts payable to affiliated companies	Accounts payable to affiliated companies	(21)		9		Accounts payable to affiliated companies	12		(21)
Taxes accrued	Taxes accrued	45		12		Taxes accrued	16		45
Other current liabilities	Other current liabilities	(16)		(12)		Other current liabilities	36		(16)
Other assets	Other assets	2		1		Other assets	(13)		2
Other liabilities	Other liabilities	(2)		(19)		Other liabilities	—		(2)
Net cash provided by operating activities	Net cash provided by operating activities	265		230		Net cash provided by operating activities	366		265
CASH FLOWS FROM INVESTING ACTIVITIES	CASH FLOWS FROM INVESTING ACTIVITIES					CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	Capital expenditures	(200)		(231)		Capital expenditures	(199)		(200)

Notes receivable from affiliated companies	Notes receivable from affiliated companies	(198)		—		Notes receivable from affiliated companies	—		(198)

Other	Other	(8)		(5)		Other	(8)		(8)
Net cash used in investing activities	Net cash used in investing activities	(406)		(236)		Net cash used in investing activities	(207)		(406)
CASH FLOWS FROM FINANCING ACTIVITIES	CASH FLOWS FROM FINANCING ACTIVITIES					CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	Proceeds from the issuance of long-term debt	347		—		Proceeds from the issuance of long-term debt	—		347

Notes payable to affiliated companies	Notes payable to affiliated companies	(530)		10		Notes payable to affiliated companies	(158)		(530)

Capital contributions from parent	Capital contributions from parent	325		—		Capital contributions from parent	—		325

Net cash provided by financing activities		142		10
Other						Other	(1)		—
Net cash (used in) provided by financing activities						Net cash (used in) provided by financing activities	(159)		142
Net increase in cash and cash equivalents	Net increase in cash and cash equivalents	1		4		Net increase in cash and cash equivalents	—		1
Cash and cash equivalents at beginning of period	Cash and cash equivalents at beginning of period	—		—		Cash and cash equivalents at beginning of period	—		—
Cash and cash equivalents at end of period	Cash and cash equivalents at end of period	$	1	$	4	Cash and cash equivalents at end of period	$	—	$	1
Supplemental Disclosures:	Supplemental Disclosures:					Supplemental Disclosures:

Significant non-cash transactions:	Significant non-cash transactions:					Significant non-cash transactions:
Accrued capital expenditures	Accrued capital expenditures	$	106	$	114	Accrued capital expenditures	$	87	$	106

See Notes to Condensed Consolidated Financial Statements


FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)


				Three Months Ended March 31, 2021 and 2022
		Common			Retained		Total			Common		Retained		Total
(in millions)	(in millions)	Stock			Earnings		Equity		(in millions)	Stock		Earnings		Equity
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

Balance at December 31, 2020	Balance at December 31, 2020	$	1,310		$	1,405	$	2,715	Balance at December 31, 2020	$	1,310	$	1,405	$	2,715
Net income	Net income	—			203		203		Net income	—		203		203

Contribution from parent	Contribution from parent	325			—		325		Contribution from parent	325		—		325

Balance at March 31, 2021	Balance at March 31, 2021	$	1,635		$	1,608	$	3,243	Balance at March 31, 2021	$	1,635	$	1,608	$	3,243

Balance at December 31, 2021									Balance at December 31, 2021	$	1,635	$	1,714	$	3,349
Net income									Net income	—		214		214

Balance at March 31, 2022									Balance at March 31, 2022	$	1,635	$	1,928	$	3,563

See Notes to Condensed Consolidated Financial Statements


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

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, ~~2020.~~2021.

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.

~~OTHER CURRENT LIABILITIES~~

Included in Other within Current Liabilities on the Duke Energy Condensed Consolidated Balance Sheet is a current liability of $46 million and $936 million as of March 31, 2021, and December 31, 2020, respectively. The current liability, initially recorded in 2020, primarily represented Duke Energy's share of ACP's obligations of outstanding debt and to satisfy ARO requirements to restore construction sites. See Notes 3 and 11 for further information.

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.~~Sheets.

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 over the IRS recapture period, 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.


~~FINANCIAL STATEMENTS~~			~~ORGANIZATION AND BASIS OF PRESENTATION~~

During September 2021, Duke Energy completed the initial minority interest investment in a portion of Duke Energy Indiana to an affiliate of GIC. GIC's ownership interest in Duke Energy Indiana represents a noncontrolling interest. See Note 2 for additional information on the sale.

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.


FINANCIAL STATEMENTS			ORGANIZATION AND BASIS OF PRESENTATION

The following table presents ~~cash received for the sale of noncontrolling interest and~~ allocated losses to noncontrolling interest for the three months ended March 31, ~~2021,~~2022, and ~~2020.~~2021.

Three Months Ended March 31,
(in millions) 2021 2020
Noncontrolling Interest Capital Contributions
Cash received for the sale of noncontrolling interest to tax equity members $ 303 $ 103
Cash received for the sale of noncontrolling interest to pro rata share members 0 0
Total Noncontrolling Interest Capital Contributions 303 103
Noncontrolling Interest Allocation of Income
Allocated losses to noncontrolling tax equity members utilizing the HLBV method 43 49
Allocated losses (gains) to noncontrolling members based on pro rata shares of ownership 8 (1)
Total Noncontrolling Interest Allocated Losses $ 51 $ 48


	Three Months Ended March 31,
(in millions)	2022		2021




Noncontrolling Interest Allocation of Income
Allocated losses to noncontrolling tax equity members utilizing the HLBV method	$	24	$	43
Allocated losses to noncontrolling members based on pro rata shares of ownership	13		8
Total Noncontrolling Interest Allocated Losses	$	37	$	51

CASH, CASH EQUIVALENTS AND RESTRICTED CASH

Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress and Duke Energy Florida have restricted cash balances related primarily to collateral assets, escrow deposits and VIEs. See Notes 9 and 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, 2021						December 31, 2020							March 31, 2022										December 31, 2021
						Duke						Duke					Duke				Duke						Duke				Duke
		Duke		Progress		Energy		Duke		Progress		Energy			Duke		Energy		Progress		Energy				Duke		Energy		Progress		Energy
		Energy				Florida		Energy				Florida			Energy		Carolinas		Energy		Progress		Florida		Energy		Carolinas		Energy		Progress		Florida
Current Assets	Current Assets													Current Assets
Cash and cash equivalents	Cash and cash equivalents	$	379	$	74	$	22	$	259	$	59	$	11	Cash and cash equivalents	$	853	$	4	$	63	$	42	$	13	$	343	$	7	$	70	$	35	$	23
Other	Other	210		13		13		194		39		39		Other	151		4		28		13		13		170		—		39		—		39
Other Noncurrent Assets	Other Noncurrent Assets													Other Noncurrent Assets
Other	Other	103		102		—		103		102		—		Other	16		1		4		4		—		7		1		4		4		—
Total cash, cash equivalents and restricted cash	Total cash, cash equivalents and restricted cash	$	692	$	189	$	35	$	556	$	200	$	50	Total cash, cash equivalents and restricted cash	$	1,020	$	9	$	95	$	59	$	26	$	520	$	8	$	113	$	39	$	62

INVENTORY

Provisions for inventory write-offs were not material at March 31, ~~2021,~~2022, and December 31, ~~2020.~~2021. The components of inventory are presented in the tables below.


		March 31, 2021																	March 31, 2022
				Duke				Duke		Duke		Duke		Duke							Duke				Duke		Duke		Duke		Duke
		Duke		Energy		Progress		Energy		Energy		Energy		Energy					Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Materials and supplies	Materials and supplies	$	2,365	$	816	$	1,011	$	680	$	332	$	77	$	313	$	11	Materials and supplies	$	2,455	$	810	$	1,089	$	744	$	345	$	89	$	320	$	14
Coal	Coal	464		170		160		101		59		12		122		—		Coal	469		196		149		93		56		16		108		—
Natural gas, oil and other fuel	Natural gas, oil and other fuel	247		35		165		101		64		19		1		26		Natural gas, oil and other fuel	247		34		165		103		62		9		2		37
Total inventory	Total inventory	$	3,076	$	1,021	$	1,336	$	882	$	455	$	108	$	436	$	37	Total inventory	$	3,171	$	1,040	$	1,403	$	940	$	463	$	114	$	430	$	51

December 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 $ 2,312 $ 785 $ 999 $ 673 $ 325 $ 78 $ 307 $ 12
Coal 561 186 193 131 63 16 165 —
Natural gas, oil and other fuel 294 39 183 107 76 16 1 56
Total inventory $ 3,167 $ 1,010 $ 1,375 $ 911 $ 464 $ 110 $ 473 $ 68


~~FINANCIAL STATEMENTS~~			~~ORGANIZATION AND BASIS OF PRESENTATION~~


	December 31, 2021
			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	$	2,397	$	793	$	1,067	$	729	$	338	$	80	$	311	$	14
Coal	486		195		167		94		73		19		105		—
Natural gas, oil and other fuel	316		38		164		98		66		17		2		95
Total inventory	$	3,199	$	1,026	$	1,398	$	921	$	477	$	116	$	418	$	109

NEW ACCOUNTING STANDARDS

No new accounting standards were adopted by the Duke Energy Registrants in ~~2021, but the following accounting standard was adopted by the Duke Energy Registrants in 2020.~~

~~Current Expected Credit Losses.~~ In June 2016, the Financial Accounting Standards Board (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, 2021.~~

~~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. The full outcome of the transition away from LIBOR cannot be determined at this time, but is not expected to have a material impact on the financial statements.

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.


FINANCIAL STATEMENTS			BUSINESS SEGMENTS

The Electric Utilities and Infrastructure segment primarily includes Duke Energy's regulated electric utilities in the Carolinas, Florida and the Midwest. On January 28, 2021, Duke Energy executed an agreement providing for an investment by an affiliate of GIC in Duke Energy Indiana in exchange for a 19.9% minority interest issued by Duke Energy Indiana Holdco, LLC, the holding company for Duke Energy Indiana. The transaction will be completed following 2 closings for an aggregate purchase price of approximately $2 billion. The first closing, which occurred on September 8, 2021, resulted in Duke Energy Indiana Holdco, LLC issuing 11.05% of its membership interests in exchange for approximately $1,025 million or 50% of the purchase price. Duke Energy retained indirect control of these assets, and, therefore, no gain or loss was recognized on the Condensed Consolidated Statements of Operations. Duke Energy has the discretion to determine the timing of the second closing, but it will occur no later than January 2023. At the second closing, Duke Energy will issue and sell additional membership interests such that GIC will own 19.9% of the membership interests for the remaining 50% of the purchase price.

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 and renewable natural gas investments.

The Commercial Renewables segment is primarily comprised of nonregulated utility-scale wind and solar generation assets located throughout the U.S. ~~In 2021,~~ Duke Energy continues to monitor recoverability of its renewable merchant plants located in the ~~Electric Reliability Council of Texas~~ERCOT West market and in the PJM West market due to ~~declining~~fluctuating market pricing and ~~declining~~ long-term forecasted energy ~~prices, primarily driven by lower forecasted natural gas~~ prices. The assets were not impaired as of March 31, ~~2021,~~2022, because the carrying value of approximately ~~$210~~$200 million continues to approximate the aggregate estimated future undiscounted cash flows. Duke Energy has a 51% ownership interest in these assets. A continued decline in energy market pricing or other factors unfavorably impacting the economics would likely result in a future impairment. ~~Duke Energy retained 51% ownership interest in these facilities following the 2019 transaction to sell a minority interest in certain renewable assets.~~

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 ownership interest in National Methanol Company.


~~FINANCIAL STATEMENTS~~			~~BUSINESS SEGMENTS~~

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


		Three Months Ended March 31, 2021															Three Months Ended March 31, 2022
		Electric		Gas				Total									Electric		Gas				Total
		Utilities and		Utilities and		Commercial		Reportable									Utilities and		Utilities and		Commercial		Reportable
(in millions)	(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other		Eliminations		Total		(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other		Eliminations		Total
Unaffiliated revenues	Unaffiliated revenues	$	5,273	$	752	$	119	$	6,144	$	6	$	—	$	6,150	Unaffiliated revenues	$	5,995	$	1,009	$	121	$	7,125	$	7	$	—	$	7,132
Intersegment revenues	Intersegment revenues	8		23		—		31		20		(51)		—		Intersegment revenues	7		23		—		30		23		(53)		—
Total revenues	Total revenues	$	5,281	$	775	$	119	$	6,175	$	26	$	(51)	$	6,150	Total revenues	$	6,002	$	1,032	$	121	$	7,155	$	30	$	(53)	$	7,132
Segment income (loss)(a)	Segment income (loss)(a)	$	820	$	245	$	27	$	1,092	$	(139)	$	—	$	953	Segment income (loss)(a)	$	723	$	254	$	11	$	988	$	(170)	$	—	$	818
Less: Noncontrolling interests	Less: Noncontrolling interests													51		Less: Noncontrolling interests													37
Add: Preferred stock dividend	Add: Preferred stock dividend													39		Add: Preferred stock dividend													39

Net Income	Net Income													$	941	Net Income													$	820
Segment assets	Segment assets	$	138,734	$	14,139	$	6,894	$	159,767	$	3,710	$	(12)	$	163,465	Segment assets	$	144,790	$	15,170	$	7,021	$	166,981	$	4,251	$	(12)	$	171,220


		Three Months Ended March 31, 2020															Three Months Ended March 31, 2021
		Electric		Gas				Total									Electric		Gas				Total
		Utilities and		Utilities and		Commercial		Reportable									Utilities and		Utilities and		Commercial		Reportable
(in millions)	(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other		Eliminations		Total		(in millions)	Infrastructure		Infrastructure		Renewables		Segments		Other		Eliminations		Total
Unaffiliated revenues	Unaffiliated revenues	$	5,174	$	640	$	129	$	5,943	$	6	$	—	$	5,949	Unaffiliated revenues	$	5,273	$	752	$	119	$	6,144	$	6	$	—	$	6,150
Intersegment revenues	Intersegment revenues	9		24		—		33		17		(50)		—		Intersegment revenues	8		23		—		31		20		(51)		—
Total revenues	Total revenues	$	5,183	$	664	$	129	$	5,976	$	23	$	(50)	$	5,949	Total revenues	$	5,281	$	775	$	119	$	6,175	$	26	$	(51)	$	6,150
Segment income (loss)(b)	Segment income (loss)(b)	$	705	$	249	$	57	$	1,011	$	(112)	$	—	$	899	Segment income (loss)(b)	$	820	$	245	$	27	$	1,092	$	(139)	$	—	$	953
Less: Noncontrolling interests	Less: Noncontrolling interests													48		Less: Noncontrolling interests													51
Add: Preferred stock dividend	Add: Preferred stock dividend													39		Add: Preferred stock dividend													39

Net Income	Net Income													$	890	Net Income													$	941

(a)Electric Utilities and Infrastructure includes $211 million recorded within Impairment of assets and other charges, $46 million within Operating revenues and $22 million within Noncontrolling Interests related to the Duke Energy Supreme Court ruling on the Condensed Consolidated Statements of Operations. See Note 3 for additional information.

(b)Commercial Renewables includes a $35 million loss related to Texas Storm Uri, of which $8 million is recorded within Nonregulated electric and other revenues, $2 million within ~~Operations,~~Operation, maintenance and other, $29 million within Equity in earnings (losses) ~~earnings~~ of unconsolidated affiliates and $12 million within Net Loss Attributable to Noncontrolling Interests on the Condensed Consolidated Statements of Operations. See Note 4 for additional information. Gas Utilities and Infrastructure includes $6 million, recorded within Equity in earnings (losses) ~~earnings~~ of unconsolidated affiliates on the Condensed Consolidated Statements of Operations, related to gas pipeline investments. ~~See Note 3 for additional information.~~

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


FINANCIAL STATEMENTS			BUSINESS SEGMENTS

Duke Energy Ohio

Duke Energy Ohio has 2 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, 2021													Three Months Ended March 31, 2022
		Electric		Gas		Total									Electric		Gas		Total
		Utilities and		Utilities and		Reportable									Utilities and		Utilities and		Reportable
(in millions)	(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations		Total		(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations		Total

Total revenues	Total revenues	$	363	$	169	$	532	$	—	$	—	$	532	Total revenues	$	412	$	226	$	638	$	—	$	—	$	638
Segment income/Net income		$	50	$	43	$	93	$	(2)	$	—	$	91
Segment income/Net (loss) income														Segment income/Net (loss) income	$	41	$	38	$	79	$	(2)	$	—	$	77

Segment assets	Segment assets	$	6,544	$	3,575	$	10,119	$	29	$	(7)	$	10,141	Segment assets	$	7,101	$	3,784	$	10,885	$	14	$	(168)	$	10,731


		Three Months Ended March 31, 2020								Three Months Ended March 31, 2021
		Electric		Gas		Total								Electric		Gas		Total
		Utilities and		Utilities and		Reportable								Utilities and		Utilities and		Reportable
(in millions)	(in millions)	Infrastructure		Infrastructure		Segments		Other			Total		(in millions)	Infrastructure		Infrastructure		Segments		Other		Total

Total revenues	Total revenues	$	346	$	152	$	498	$	—		$	498	Total revenues	$	363	$	169	$	532	$	—	$	532
Segment income/Net income		$	30	$	36	$	66	$	(1)		$	65
Segment income/Net (loss) income													Segment income/Net (loss) income	$	50	$	43	$	93	$	(2)	$	91


~~FINANCIAL STATEMENTS~~			~~REGULATORY MATTERS~~

3. REGULATORY MATTERS

RATE-RELATED INFORMATION

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

Duke Energy Carolinas and Duke Energy Progress

~~2021 Coal Ash Settlement~~HB 951

~~On January 22~~, ~~2021,~~The NCUC is required by North Carolina House Bill 951 (HB 951) to adopt an initial Carbon Plan on or before December 31, 2022. The NCUC has directed Duke Energy Carolinas and Duke Energy Progress entered into the Coal Combustion Residuals Settlement Agreement (the “CCR Settlement Agreement”) with the North Carolina Public Staff (Public Staff), the North Carolina Attorney General’s Office and the Sierra Club (collectively, the "Settling Parties"), which was filed with the NCUC on January 25, 2021. The CCR Settlement Agreement resolves all coal ash prudence and cost recovery issues in connection with 2019 rate cases filed by Duke Energy Carolinas and Duke Energy Progress with the NCUC, as well as the equitable sharing issue on remand from the 2017 Duke Energy Carolinas and Duke Energy Progress North Carolina rate cases as a result of the December 11, 2020, North Carolina Supreme Court opinion. The settlement also provides clarity on coal ash cost recovery in North Carolina for Duke Energy Carolinas and Duke Energy Progress through January 2030 and February 2030 (the "Term"), respectively.

~~Duke Energy Carolinas and Duke Energy Progress agreed not~~ to seek recovery of approximately $1 billion of systemwide deferred coal ash expenditures, but will retain the ability to earn a debt and equity return during the amortization period, which shall be five years in the pending 2019 North Carolina rate cases and will be set by the NCUC in future rate case proceedings. The equity return and the amortization period on deferred coal ash costs under the 2017 Duke Energy Carolinas and Duke Energy Progress North Carolina rate cases will remain unaffected. The equity return on deferred coal ash costs under the 2019 North Carolina rate cases and future rate cases in North Carolina will be set at 150 basis points lower than the authorized return on equity (ROE) then in effect, with a capital structure composed of 48% debt and 52% equity. Duke Energy Carolinas and Duke Energy Progress retain the ability to earn a full WACC return during the deferral period, which is the period from when costs are incurred until they are recovered in rates.

The Settling Parties agreed that execution by Duke Energy Carolinas and Duke Energy Progress of a settlement agreement between themselves and the NCDEQ dated December 31, 2019, (the “DEQ Settlement”) and the coal ash management plans included therein or subsequently approved by DEQ are reasonable and prudent. The Settling Parties retain the right to challenge the reasonableness and prudence of actions taken by Duke Energy Carolinas and Duke Energy Progress and costs incurred to implement the scope of work agreed upon in the DEQ Settlement, after February 1, 2020, and March 1, 2020, for Duke Energy Carolinas and Duke Energy Progress, respectively. The Settling Parties further agreed to waive rights through the Term to challenge the reasonableness or prudence of Duke Energy Carolinas’ and Duke Energy Progress’ historical coal ash management practices, and to waive the right to assert any arguments that future coal ash costs, including financing costs, shall be shared between either company and customers through equitable sharing or any other rate base or return adjustment that shares the revenue requirement burden of coal ash costs not otherwise disallowed due to imprudence.

~~The Settling Parties agreed to a sharing arrangement for future coal ash insurance litigation proceeds between Duke Energy Carolinas and Duke Energy Progress and North Carolina customers, if achieved.~~

On January 29, 2021, Duke Energy Carolinas and Duke Energy Progress filed joint motions with the Settling Parties seeking approval of the CCR Settlement Agreement, along with supporting testimony and exhibits from Duke Energy Carolinas and Duke Energy Progress. On February 5, 2021, the Public Staff filed testimony and exhibits supporting the CCR Settlement Agreement.

As a result of the CCR Settlement Agreement, Duke Energy Carolinas and Duke Energy Progress recorded a pretax charge of approximately $454 million and $494 million, respectively, in the fourth quarter of 2020 to Impairment charges and a reversal of approximately $50 million and $102 million, respectively, to Regulated electric operating revenues on the respective Consolidated Statements of Operations.

The Coal Ash Settlement was approved without modification in the NCUC Orders in the 2019 rate cases on March 31, 2021, and April 16, 2021, for Duke Energy Carolinas and Duke Energy Progress, respectively.

~~2020 North Carolina Storm Securitization Filings~~

On October 26, 2020, Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the NCUC, as agreed to in partial settlements reached in the 2019 North Carolina Rate Cases for Duke Energy Carolinas and Duke Energy Progress, seeking authorization for the financing of the costs of each utility's storm recovery activities required as a result of Hurricane Florence, Hurricane Michael, Hurricane Dorian and Winter Storm Diego. Specifically, Duke Energy Carolinas and Duke Energy Progress requested that the NCUC find that their storm recovery costs and related financing costs are appropriately financed by debt secured by storm recovery property, and that the commission issue financing orders by which each utility may accomplish such financing using a securitization structure. On January 27, 2021, Duke Energy Carolinas, Duke Energy Progress and the Public Staff filed an Agreement and Stipulation of Partial Settlement, which is subject to review and approval of the NCUC, resolving certain accounting issues, including agreement to support an 18- to 20-year bond period. The total revenue requirement overfile a proposed ~~20-year bond period for the storm recovery charges is approximately $287 million for Duke Energy Carolinas and $920 million for Duke Energy Progress. A remote evidentiary hearing ended~~Carbon Plan on January 29, 2021, and on February 1, 2021, the NCUC granted a motion by Duke Energy Carolinas and Duke Energy Progress for a temporary 30-day waiver of the 135-day time frame for the NCUC to issue orders on the joint petition, extending the deadline for the NCUC to issue an order toor before May ~~10, 2021. In the NCUC Orders in the 2019 rate cases on March 31, 2021, and April~~ 16, ~~2021, for Duke Energy Carolinas and Duke Energy Progress, respectively, the reasonableness and prudence of the deferred storm costs was approved.~~2022. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

On February 10, 2022, the NCUC adopted rules to govern the application and review process for the PBR authorized under HB 951. On April 5, 2022, the NCUC adopted rules to govern the securitization of 50% of the North Carolina retail portion of the remaining net book value of retiring coal plants pursuant to HB 951. The rules are constructive and consistent with the policy objectives of HB 951.

Duke Energy Carolinas

Oconee Nuclear Station Subsequent License Renewal

On June 7, 2021, Duke Energy Carolinas filed a subsequent license renewal (SLR) application for the Oconee Nuclear Station (ONS) with the U.S. Nuclear Regulatory Commission (NRC) to renew ONS’s operating license for an additional 20 years. The SLR would extend operations of the facility from 60 to 80 years. The current licenses for units 1 and 2 expire in 2033 and the license for unit 3 expires in 2034. By a Federal Register Notice dated July 28, 2021, the NRC provided a 60-day comment period for persons whose interest may be affected by the issuance of a subsequent renewed license for ONS to file a request for a hearing and a petition for leave to intervene. On September 27, 2021, Beyond Nuclear and Sierra Club (Petitioners) filed a Hearing Request and Petition to Intervene (Hearing Request) and a Petition for Waiver. The Hearing Request proposed 3 contentions purporting to challenge Duke Energy Carolinas’ environmental report (ER). In general, the proposed contentions claimed that the ER did not consider certain information regarding the environmental aspects of severe accidents caused by a hypothetical failure of the Jocassee Dam, and therefore did not satisfy the National Environmental Policy Act (NEPA) of 1969, as amended, or the NRC’s NEPA-implementing regulations. Duke Energy Carolinas filed its answer to the proposed contentions on October 22, 2021, and the Petitioners filed their reply to Duke Energy Carolinas’ answer on November 5, 2021. On February 11, 2022, the Atomic Safety and Licensing Board (ASLB) issued its decision on the Hearing Request and found that the Petitioners failed to establish that the proposed contentions are litigable. The ASLB also denied the Petitioners' Petition for Waiver and terminated the proceeding.

On February 24, 2022, the NRC issued a decision in the Turkey Point SLR appeal and ruled that the NRC’s license renewal Generic Environmental Impact Statement (GEIS) does not apply to SLR because the GEIS does not address SLR.The decision overturned a 2020 NRC decision that found the GEIS applies to SLR. While Turkey Point is not owned or operated by a Duke Energy Registrant, the NRC’s order applies to all SLR applicants, including ONS. The NRC order also indicated no subsequent renewed licenses will be issued until the NRC staff has completed an adequate NEPA review for each application. On April 5, 2022, the NRC approved a 24-month rulemaking plan that will enable the NRC staff to complete an adequate NEPA review. Although an SLR applicant may wait until the rulemaking is completed, the NRC also noted that an applicant may submit a revised environmental report providing information on environmental impacts during the SLR period prior to the rulemaking being completed. Duke Energy Carolinas is evaluating the two options to determine which is preferable for ONS.Although the NRC’s decision will delay completion of the SLR proceeding, Duke Energy Carolinas does not believe it changes the probability that the ONS subsequent renewed licenses will ultimately be issued, though Duke Energy Carolinas cannot guaranty the outcome of the license application process.


FINANCIAL STATEMENTS			REGULATORY MATTERS

~~COVID-19 Filings~~

~~North Carolina~~

Duke Energy Carolinas and Duke Energy Progress ~~filed a joint petition on August 7, 2020, with~~intend to seek renewal of operating licenses and 20-year license extensions for all of their nuclear stations. New depreciation rates were implemented for all of the NCUC for deferral treatment of incremental costs and waived customer fees due to the COVID-19 pandemic. Comments on the joint petition were filed on November 5, 2020, and reply comments were filed on November 30, 2020. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.

~~South Carolina~~

Duke Energy Carolinas and Duke Energy Progress filed a report on June 30, 2020, as required by PSCSC order, reporting revenue impact, costs and savings related to COVID-19 to date. On August 14, 2020, Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the PSCSC for approval of an accounting order to defer incremental COVID-19 related costs incurred through June 30, 2020, and for the ongoing monthsnuclear facilities during the ~~duration~~second quarter of the COVID-19 pandemic. The deferral request did not include lost revenues. Updates on cost impacts were filed on September 30, 2020, and included financial impacts through the end of August 2020. On October 16, 2020, the South Carolina Office of Regulatory Staff (ORS) requested the PSCSC delay taking formal action on the deferral request until the ORS and any intervenors complete discovery. The PSCSC issued an order on October 21, 2020, to grant additional time to complete discovery until January 20, 2021, and to establish a procedural schedule. Updates on cost impacts were filed on December 30, 2020, and included financial impacts through November 30, 2020. On January 15, 2021, the ORS requested the PSCSC suspend the dates for the ORS report and public hearing. The ORS conferred with the companies regarding the status of the docket, and the parties mutually agreed that recently enacted federal laws addressing COVID-19 aid and recovery should be studied before further action is taken in this docket. On January 27, 2021, the PSCSC voted to grant the ORS request to suspend the virtual public hearing. The ORS filed its report on April 16, 2021. 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. 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 an ROE 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.

The North Carolina Attorney General and other parties separately filed Notices of Appeal to the North Carolina Supreme Court. The North Carolina Supreme Court consolidated the Duke Energy Carolinas and Duke Energy Progress appeals. On December 11, 2020, the North Carolina Supreme Court issued an opinion, which affirmed, in part, and reversed and remanded, in part, the NCUC’s decisions. In the Opinion, the court upheld the NCUC's decision to include coal ash costs in the cost of service, as well as the NCUC’s discretion to allow a return on the unamortized balance of coal ash costs. The court also remanded to the NCUC a single issue to consider the assessment of support for the Public Staff’s equitable sharing argument. In response to a NCUC order seeking comments on the proposed procedure on remand, on January 11, 2021, Duke Energy Carolinas, Duke Energy Progress, the Public Staff, the North Carolina Attorney General, Sierra Club and Carolina Industrial Group for Fair Utility Rates II and III filed joint comments proposing that the NCUC not hold additional evidentiary hearings, but instead rely upon existing records in the 2017 North Carolina rate cases, or in the alternative the records in the 2019 North Carolina rate cases, in deciding the issue on remand. On January 22, 2021, Duke Energy Carolinas and Duke Energy Progress entered into the CCR Settlement Agreement with the Settling Parties, which was filed with the NCUC on January 25, 2021, and approved by the NCUC on March 31, 2021.

~~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 a 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, subject to review and approval of the NCUC, resolving certain issues in the base rate proceeding. On July 24, 2020, Duke Energy Carolinas filed its request for approval of its notice to customers required to implement temporary rates. On July 27, 2020, Duke Energy Carolinas filed a joint motion with Duke Energy Progress and the Public Staff notifying the commission that the parties reached a joint partial settlement with the Public Staff. Also on July 27, 2020, Duke Energy Carolinas filed a letter stating that it intended to update its temporary rates calculation to reflect the terms of the partial settlement. On July 31, 2020, Duke Energy Carolinas and the Public Staff filed a Second Agreement and Stipulation of Partial Settlement (Second Partial Settlement), subject to review and approval of the NCUC, resolving certain remaining issues in the base rate proceeding. The remaining items litigated at hearing included recovery of deferred coal ash compliance costs that are subject to asset retirement obligation accounting, implementation of new depreciation rates and the amortization period of the loss on the hydro station sale.

On August 4, 2020, Duke Energy Carolinas filed an amended motion for approval of its amended notice to customers, seeking to exercise its statutory right to implement temporary rates subject to refund on or after August 24, 2020. The revenue requirement to be recovered, subject to refund, through the temporary rates was based on and consistent with the base rate component of the Second Partial Settlement and excluded the items to be litigated noted above. The NCUC approved the August 4, 2020 amended temporary rates motion on August 6, 2020, and temporary rates went into effect on August 24, 2020.


~~FINANCIAL STATEMENTS~~			~~REGULATORY MATTERS~~

The Duke Energy Carolinas evidentiary hearing concluded on September 18, 2020, and post-hearing filings were made with the NCUC from all parties by November 4, 2020. On January 22, 2021, Duke Energy Carolinas and Duke Energy Progress entered into the CCR Settlement Agreement with the Settling Parties, which was filed with the NCUC on January 25, 2021.

On March 31, 2021, the NCUC issued an order approving the March 25, 2020, and July 31, 2020, partial settlements. The order includes approval of 1) an ROE of 9.6% based upon a capital structure of 52% equity and 48% debt; 2) deferral treatment of approximately $800 million of grid improvement projects with a return; 3) a flow back period of five years for unprotected federal EDIT; and 4) the reasonableness and prudence of $213 million of deferred storm costs, which were removed from the rate case and for which Duke Energy Carolinas filed a petition seeking securitization in October 2020. Additionally, the order approved without modification the CCR Settlement Agreement.

The order denied Duke Energy Carolinas' proposal to shorten the remaining depreciable lives of certain Duke Energy Carolinas coal-fired generating units, indicating the appropriate proceeding for the review of generating plant retirements is Duke Energy Carolinas' integrated resource planning (IRP) proceeding.

On April 12, 2021, Duke Energy Carolinas filed its final revenue requirement with the NCUC, which results in a net increase of approximately $33 million. Revised customer rates are expected to become effective in June 2021.

~~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.~~

After hearings in March 2019, the PSCSC issued an order on May 21, 2019, which included an ROE 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 PSCSC 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, ROE 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 with the Supreme Court of South Carolina. Initial briefs were filed on April 21, 2020, which included the South Carolina Energy User's Committee brief arguing that the PSCSC erred in allowing Duke Energy Carolinas' recovery of costs related to the Lee Nuclear Station. Response briefs were filed on July 6, 2020, and reply briefs were filed on August 11, 2020. Oral arguments before the Supreme Court of South Carolina have been scheduled to occur on May 26, 2021. Based on legal analysis and the filing of the appeal, Duke Energy Carolinas has not recorded an adjustment for its deferred coal ash costs in this matter. 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 was subsequently adjusted to $420 million. 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 an ROE 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. The Public Staff, the North Carolina Attorney General and the Sierra Club filed notices of appeal to the North Carolina Supreme Court.


~~FINANCIAL STATEMENTS~~			~~REGULATORY MATTERS~~

The North Carolina Supreme Court consolidated the Duke Energy Carolinas and Duke Energy Progress appeals. On December 11, 2020, the North Carolina Supreme Court issued an opinion, which affirmed, in part, and reversed and remanded, in part, the NCUC’s decisions. In the Opinion, the court upheld the NCUC's decision to include coal ash costs in the cost of service, as well as the NCUC’s discretion to allow a return on the unamortized balance of coal ash costs. The court also remanded to the NCUC a single issue to consider the assessment of support for the Public Staff’s equitable sharing argument. In response to a NCUC order seeking comments on the proposed procedure on remand, on January 11, 2021, Duke Energy Carolinas, Duke Energy Progress, the Public Staff, the North Carolina Attorney General, Sierra Club and Carolina Industrial Group for Fair Utility Rates II and III filed joint comments proposing that the NCUC not hold additional evidentiary hearings, but instead rely upon existing records in the 2017 North Carolina rate cases or in the alternative the records in the 2019 North Carolina rate cases, in deciding the issue on remand. On January 22, 2021, Duke Energy Progress and Duke Energy Carolinas entered into the CCR Settlement Agreement with the Settling Parties, which was filed with the NCUC on January 25, 2021, and approved by the NCUC on April 16, 2021.

~~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 sought to defer and recover incremental Hurricane Dorian storm costs in this proceeding and requested 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 June 2, 2020, Duke Energy Progress and the Public Staff filed an Agreement and Stipulation of Partial Settlement, subject to review and approval of the NCUC, resolving certain issues in the base rate proceeding. On July 27, 2020, Duke Energy Progress filed a joint motion with Duke Energy Carolinas and the Public Staff notifying the commission that the parties reached a joint partial settlement with the Public Staff. On July 31, 2020, Duke Energy Progress and the Public Staff filed a Second Agreement and Stipulation of Partial Settlement, subject to review and approval of the NCUC, resolving certain remaining issues in the base rate proceeding. The remaining items litigated at hearing included recovery of deferred coal ash compliance costs that are subject to asset retirement obligation accounting and implementation of new depreciation rates.

On August 7, 2020, Duke Energy Progress filed a motion for approval of notice required to implement temporary rates, seeking to exercise its statutory right to implement temporary rates subject to refund on or after September 1, 2020. The revenue requirement to be recovered subject to refund through the temporary rates was based on and consistent with the terms of the base rate component of the settlement agreements with the Public Staff and excluded items to be litigated noted above. Duke Energy Progress will not begin the amortization or implementation of these items until a final determination is issued in the rate case and new base rates are implemented. These items will also be excluded when determining whether a refund of amounts collected through these temporary rates is needed. In addition, Duke Energy Progress also sought authorization to place a temporary decrement EDIT Rider into effect, concurrent with the temporary base rate change. The temporary rate changes are not final rates and remain subject to the NCUC's determination of the just and reasonable rates to be charged by Duke Energy Progress on a permanent basis. The NCUC approved the August 7, 2020 temporary rates motion on August 11, 2020, and temporary rates went into effect on September 1, 2020.

The Duke Energy Progress evidentiary hearing concluded on October 6, 2020, and post-hearing filings were filed with the NCUC from all parties by December 4, 2020. On January 22, 2021, Duke Energy Progress and Duke Energy Carolinas entered into the CCR Settlement Agreement with the Settling Parties, which was filed with the NCUC on January 25, 2021.

On April 16, 2021, the NCUC issued an order approving the June 2, 2020, and July 31, 2020, partial settlements. The order includes approval of 1) an ROE of 9.6% based upon a capital structure of 52% equity and 48% debt; 2) deferral treatment of approximately $400 million of grid improvement projects with a return; 3) a flow back period of five years for unprotected federal EDIT; and 4) the reasonableness and prudence of approximately $714 million of deferred storm costs, which were removed from the rate case and for which Duke Energy Progress filed a petition seeking securitization in October 2020. Additionally, the order approved without modification the CCR Settlement Agreement.

The order denied Duke Energy Progress' proposal to shorten the remaining depreciable lives of certain Duke Energy Progress coal-fired generating units, indicating the appropriate proceeding for the review of generating plant retirements is Duke Energy Progress' IRP proceeding.

On April 26, 2021, Duke Energy Progress filed its final revenue requirement with the NCUC, which results in a net increase of approximately $178 million. Revised customer rates are expected to become effective in June 2021.

~~Hurricane Dorian~~

Hurricane Dorian reached the Carolinas in September 2019 as a Category 2 hurricane making landfall within Duke Energy Progress’ service territory. Total estimated incremental operation and maintenance expenses incurred to repair and restore the system are approximately $168 million with an additional $4 million in capital investments made for restoration efforts. Approximately $145 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, 2021, and December 31, 2020. 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. Terms of the June 2, 2020, Agreement and Stipulation of Partial Settlement removed incremental storm costs from the general rate case. A petition seeking to securitize these costs, along with costs from Hurricane Florence, Hurricane Michael and Winter Storm Diego, was filed on October 26, 2020, with the NCUC. For information on the securitization filing, see "2020 North Carolina Storm Securitization Filings." Duke Energy Progress cannot predict the outcome of this matter.


~~FINANCIAL STATEMENTS~~			~~REGULATORY MATTERS~~

~~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.~~

After hearings in April 2019, the PSCSC issued an order on May 21, 2019, which included an ROE 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 PSCSC 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, ROE 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. Initial briefs were filed on April 21, 2020. Response briefs were filed on July 6, 2020, and reply briefs were filed on August 11, 2020. Oral arguments before the Supreme Court of South Carolina have been scheduled to occur on May 26, 2021. Based on legal analysis and the filing of the appeal, Duke Energy Progress has not recorded an adjustment for its deferred coal ash costs in this matter. Duke Energy Progress cannot predict the outcome of this matter.

~~Western Carolinas Modernization Plan~~

~~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, which was approved with certain conditions on May 10, 2019.~~ ~~A hearing to update the NCUC on the status of the project was held on March 5, 2020. Construction began in May 2020 with commercial operation expected to begin in October 2021.~~

On July 27, 2020, Duke Energy Progress filed an application with the NCUC for a CPCN to construct the Woodfin Solar Facility, a 5-MW solar generating facility to be constructed on a closed landfill in Buncombe County. The expert hearing was held on November 18, 2020. The application was approved and a CPCN was granted by order of the NCUC on April 20, 2021.

FERC Return on Equity ~~Complaints~~

On October 11, 2019, North Carolina Eastern Municipal Power Agency (NCEMPA) filed a complaint at the FERC against Duke Energy Progress pursuant to Section 206 of the Federal Power Act (FPA), alleging that the 11% stated ROE component contained in the demand formula rate in the Full Requirements Power Purchase Agreement (FRPPA) between NCEMPA and Duke Energy Progress is unjust and unreasonable. On July 16, 2020, the FERC set this matter for hearing and settlement judge procedures and established a refund effective date of October 11, 2019. In its order setting the matter for settlement, the FERC allowed for the consideration of variations to the base transmission-related ROE methodology developed in its Order No. 569-A, through the introduction of “specific facts and circumstances” involving issues specific to the case. The parties reached a settlement in principle at a settlement conference on January 7, 2021, and filed a settlement package on March 10, 2021. The FERC Trial Staff filed comments in support of the settlement. On April 19, 2021, the Settlement Judge certified the settlement to the FERC as an uncontested settlement and recommended approval by the FERC. Duke Energy Progress cannot predict the outcome of this matter.Complaint

On October 16, 2020, North Carolina Electric Membership Corporation (NCEMC) filed a complaint at the FERC against Duke Energy Progress pursuant to Section 206 of the ~~FPA,~~Federal Power Act (FPA), alleging that the 11% stated ~~ROE~~return on equity (ROE) component in the demand formula rate in the Power Supply and Coordination Agreement between NCEMC and Duke Energy Progress is unjust and unreasonable. Under FPA Section 206, the earliest refund effective date that the FERC can establish is the date of the filing of the complaint. ~~Duke Energy Progress responded to the~~A series of responses and answers were filed at FERC. The complaint proceeding is currently held in abeyance until June 1, 2022, based on ~~November 20, 2020, seeking dismissal, demonstrating~~representations that the ~~11% ROE is just~~parties have reached an agreement in principle and ~~reasonable for~~need additional time to finalize the ~~service provided. The parties filed responsive pleadings and are awaiting an order from the FERC.~~filing. Duke Energy Progress cannot predict the outcome of this matter.

Duke Energy Florida

2021 Settlement Agreement

On January 14, 2021, Duke Energy Florida filed a Settlement Agreement (the ~~“Settlement”~~“2021 Settlement”) with the FPSC. The parties to the 2021 Settlement include Duke Energy Florida, the Office of Public Counsel (OPC), the Florida Industrial Power Users Group, White Springs Agricultural Chemicals, Inc. d/b/a PCS Phosphate and NUCOR Steel Florida, Inc. (collectively, the “Parties”).


~~FINANCIAL STATEMENTS~~			~~REGULATORY MATTERS~~

Pursuant to the 2021 Settlement, the ~~parties~~Parties agreed to a base rate stay-out provision that expires year-end 2024; however, Duke Energy Florida is allowed an increase to its base rates of an incremental $67 million in 2022, $49 million in 2023 and $79 million in 2024, subject to adjustment in the event of tax reform during the years 2021, 2022 and 2023. The ~~parties~~Parties also agreed to aan ROE band of 8.85% to 10.85% with a midpoint of 9.85% based on a capital structure of 53% equity and 47% debt. The ROE band can be increased by 25 basis points if the average 30-year U.S. Treasury rate increases 50 basis points or more over a six-month period in which case the midpoint ROE would rise from 9.85% to 10.10%. Duke Energy Florida will also be able to retain the retail portion of the DOE award of approximately $173 million for spent nuclear fuel, which is expected to be received in 2022, in order to mitigate customer rates over the term of the 2021 Settlement. In return, Duke Energy Florida will be able to recognize the $173 million into earnings from 2022 through 2024.

In addition to these terms, the 2021 Settlement ~~contains~~contained provisions related to the accelerated depreciation of Crystal River Units 4-5, the approval of approximately $1 billion in future investments in new ~~cost effective~~cost-effective solar power, the implementation of a new Electric Vehicle Charging Station Program and the deferral and recovery of costs in connection with the implementation of Duke Energy Florida’s Vision Florida program, which explores various emerging non-carbon emitting generation technology, distributed technologies and resiliency projects, among other things. The 2021 Settlement also ~~resolves~~resolved remaining unrecovered storm costs for ~~hurricanes Dorian~~Hurricane Michael and ~~Michael.~~Hurricane Dorian.

The FPSC approved the 2021 Settlement on May 4, 2021, issuing an order on June 4, 2021. Revised customer rates ~~will be~~became effective January 1, 2022, with subsequent base rate increases effective January 1, 2023, and January 1, 2024.

~~Storm Restoration Cost Recovery~~

Duke Energy Florida filed a petition with the FPSC on April 30, 2019, to recover $223 million of estimated retail incremental storm restoration costs for Hurricane Michael, consistent with the provisions in the 2017 Settlement, and the FPSC approved the petition on June 11, 2019. The FPSC also approved allowing 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. On May 19, 2020, Duke Energy Florida filed a supplemental true up reducing the actual retail recoverable storm restoration costs related to Hurricane Michael by approximately $3 million, resulting in a total request to recover $188 million actual retail recoverable storm restoration costs, plus interest. Approximately $42 million and $80 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, 2021, and December 31, 2020, respectively.

Duke Energy Florida filed a petition with the FPSC on December 19, 2019, to recover $169 million of estimated retail incremental storm restoration costs for Hurricane Dorian, consistent with the provisions in the 2017 Settlement and the FPSC approved the petition on February 24, 2020. The final actual amount of $145 million was filed on September 30, 2020. The Settlement was approved by the FPSC and all matters regarding storm cost recovery relating to Hurricane Michael and Hurricane Dorian are resolved.

Clean Energy Connection

On July 1, 2020, Duke Energy Florida petitioned the FPSC for approval of a voluntary solar program. The program consists of 10 new solar generating facilities with combined capacity of approximately 750 MW. The program allows participants to support cost-effective solar development in Florida by paying a subscription fee based on per kilowatt-subscriptions and receiving a credit on their bill based on the actual generation associated with their portion of the solar portfolio. The estimated cost of the 10 new solar generation facilities is approximately $1 billion over the next ~~four~~three years, and this investment will be included in base rates offset by the revenue from the subscription fees. The credits will be included for recovery in the fuel cost recovery clause. ~~A remote hearing was held on November 17, 2020, and post-hearing briefs were filed with the FPSC from all parties by December 9, 2020.~~ The FPSC ~~voted to approve~~approved the program onin January ~~5, 2021, and issued its written order on January 26,~~ 2021.

On February 24, 2021, the League of United Latin American Citizens (LULAC) filed a notice of appeal of the FPSC’s ~~Order~~order approving the Clean Energy Connection to the Supreme Court of Florida. LULAC's initial brief was filed on May 26, 2021, and Appellees' response briefs were filed on July 26, 2021. LULAC's reply brief was filed on September 24, 2021, and its request for oral argument was filed on September 28, 2021. The Supreme Court of Florida ~~Supreme Court.~~heard the oral argument on February 9, 2022. The FPSC approval order remains in effect pending the outcome of the appeal. Duke Energy Florida cannot predict the outcome of this matter.

Storm Protection Plan

On April 11, 2022, Duke Energy Florida filed a Storm Protection Plan for approval with the FPSC. The plan, which covers investments for the 2023-2032 time frame, reflects approximately $7 billion of capital investment in transmission and distribution meant to strengthen its infrastructure, reduce outage times associated with extreme weather events, reduce restoration costs and improve overall service reliability. The FPSC has scheduled a hearing to begin on August 2, 2022. Duke Energy Florida cannot predict the outcome of this matter.

Duke Energy Ohio

~~Ohio House Bill 6~~

On July 23, 2019, House Bill 6 was signed into law that became effective January 1, 2020. Among other things, the bill allows for funding, through a rider mechanism referred to as the Clean Air Fund (Rider CAF), of 2 nuclear generating facilities located in Northern Ohio owned by Energy Harbor (f/k/a FirstEnergy Solutions), repeal of energy efficiency mandates and recovery of prudently incurred costs, net of any revenues, for Ohio investor-owned utilities that are participants under the OVEC power agreement. The recovery is through a non-bypassable rider that replaced any existing recovery mechanism approved by the PUCO and will remain in place through 2030. As such, Duke Energy Ohio ~~created~~Electric Base Rate Case

Duke Energy Ohio filed with the ~~Legacy Generation Rider (Rider LGR) that replaced Rider PSR effective January~~PUCO an electric distribution base rate case application on October 1, ~~2020.~~2021, with supporting testimony filed on October 15, 2021, requesting an increase in electric distribution base rates of approximately $55 million and an ROE of 10.3%. This is an approximate 3.3% average increase in the customer's total bill across all customer classes. The ~~amounts recoverable from customers~~drivers for this case are ~~subject to an annual cap, with incremental costs that exceed such cap eligible for deferral and recovery subject to review. See Note 11 for additional discussion of~~capital invested since Duke Energy Ohio's ~~ownership interest~~last electric distribution base rate case in ~~OVEC. House Bill 128 was signed into law~~2017. Duke Energy Ohio is also seeking to adjust the caps on ~~March 31, 2021, which becomes effective June 30, 2021. The bill removes nuclear plant funding from~~its Distribution Capital Investment Rider ~~CAF and does not impact OVEC cost recovery.~~(DCI Rider). Duke Energy Ohio anticipates the PUCO will rule on the request in 2022. Duke Energy Ohio cannot predict the outcome of this matter.

5146


FINANCIAL STATEMENTS			REGULATORY MATTERS

Energy Efficiency Cost Recovery

~~On February 26, 2020,~~In response to changes in Ohio law that eliminated Ohio's energy efficiency mandates, the PUCO issued an order on February 26, 2020, 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~~2020. Duke Energy Ohio ~~law that eliminated Ohio's energy efficiency mandates.~~ took the following actions:

•On March 27, 2020, Duke Energy Ohio filed an ~~Application~~application for ~~Rehearing~~rehearing seeking clarification on the final true up and reconciliation process after 2020. On November 18, 2020, the PUCO issued ~~two orders on the application for rehearing. The first~~an order ~~was a Third Entry on Rehearing on the Duke Energy Ohio portfolio holding~~replacing the cost cap previously imposed ~~was unlawful,~~upon Duke Energy Ohio with a cap on shared savings recovery. On December 18, 2020, Duke Energy Ohio filed an additional application for rehearing challenging, among other things, the imposition of the cap on shared savings. On January 13, 2021, the application for rehearing was granted for further consideration.

•On October 9, 2020, Duke Energy Ohio filed an application to implement a voluntary energy efficiency program portfolio to commence on January 1, 2021. The application proposed a mechanism for recovery of ~~$8 million pretax should be imposed~~program costs and ~~lost~~a benefit associated with avoided transmission and distribution ~~revenues could not be recovered after December 31, 2020.~~costs. The ~~second~~application remains under review.

•On November 18, 2020, the PUCO issued an order ~~directs~~directing all utilities to set ~~the rider~~their energy efficiency riders to zero effective January 1, 2021, and to file a separate application for final reconciliation of all energy efficiency costs prior to December 31, 2020. On December 18, 2020, Duke Energy Ohio filed an application for rehearing. On January 13, 2021, the application for rehearing was granted for further consideration. Duke Energy Ohio cannot predict the outcome of this matter.

On October 9, 2020, Duke Energy Ohio filed an application to implement a voluntary efficiency program portfolio to commence on January 1, 2021. The application proposes a mechanism for recovery of program costs and a benefit associated with avoided transmission and distribution costs. The application remains under review. As ofEffective January 1, 2021, Duke Energy Ohio suspended its energy efficiency programs.

•On June 14, 2021, the PUCO issued an entry for each utility to file by July 15, 2021, a proposal to reestablish low-income programs ~~due~~through December 31, 2021. Duke Energy Ohio filed its application on July 14, 2021.

•On February 23, 2022, the PUCO issued its Fifth Entry on Rehearing that 1) affirmed its reduction in Duke Energy Ohio's shared savings cap; 2) denied rehearing/clarification regarding lost distribution revenues and shared savings recovery for periods after December 31, 2020; and 3) directed Duke Energy Ohio to ~~changes in~~submit an updated application with exhibits.

•On March 25, 2022, Duke Energy Ohio ~~law.~~ filed its Amended Application consistent with the PUCO's order.

Duke Energy Ohio cannot predict the outcome of this matter.

Natural Gas Pipeline Extension

Duke Energy Ohio ~~is installing~~installed 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. Construction of the pipeline extension was completed and placed in service on March 14, 2022. Duke Energy Ohio ~~currently estimates~~expects the final cost for the pipeline development ~~costs~~ and construction activities ~~will range from $163~~to be approximately $185 million ~~to $245 million in direct costs~~ (excluding overheads and AFUDC) and that construction of the pipeline extension will be completed before the 2021/2022 winter season. An evidentiary hearing for a Certificate of Environmental Compatibility and Public Need concluded on April 11, 2019. On November 21, 2019, the Ohio Power Siting Board (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. On February 20, 2020, the OPSB denied the rehearing requests. 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. The appeal was fully briefed and the Ohio Supreme Court oral argument was held on March 31, 2021. Duke Energy Ohio cannot predict the outcome of this matter.

On September 22, 2020, Duke Energy Ohio filed an application with the OPSB for approval to amend the certificated pipeline route due to changes in the route negotiated with property owners and municipalities. On January 21, 2021, the OPSB approved the amended filing with recommended conditions that reaffirm previous conditions and provide guidance regarding local permitting and construction supervision. Duke Energy Ohio cannot predict the outcome of this matter..

MGP Cost Recovery

In an order issued in 2013, the PUCO approved Duke Energy Ohio's deferral and recovery of costs related to environmental remediation at 2 sites (East End and West End) that housed former MGP operations. Duke Energy Ohio ~~has collected approximately $55 million in environmental remediation costs incurred between 2009 through 2012 through 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 base rate case. ~~To date, the PUCO has not ruled on Duke Energy Ohio’s annual applications for the calendar years 2013 through 2019. On September 28, 2018, the staff~~The Staff of the PUCO (Staff) issued ~~a report~~reports recommending a disallowance of ~~approximately $12 million of the $26 million in~~ MGP remediation costs incurred ~~between 2013 through 2017~~ that ~~staff~~the Staff believes are not eligible for recovery. The Staff interprets the PUCO’s ~~2012~~2013 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~~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. ~~On March 29, 2019, Duke Energy Ohio filed its annual application to recover incremental remediation expense for~~Additionally, 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, staffStaff 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 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. On July 23, 2020, the staff recommended a disallowance of approximately $4 million for work the staff believes occurred in areas not authorized for recovery. Additionally, the staff recommended insurance proceeds, net of litigation costs and attorney fees, should be reimbursed to customers and not be held by Duke Energy Ohio until all investigation and remediation is complete. Duke Energy Ohio filed comments in response to the staff report on August 21, 2020, and intervenor comments were filed on November 9, 2020. Duke Energy Ohio cannot predict the outcome of this matter.

The ~~2012~~2013 PUCO order also contained conditional deadlines for completing the MGP environmental remediation and the deferral of related remediation ~~costs at the MGP sites.~~costs. 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 that must occur after December 31, 2019. On July 12, 2019, ~~staff~~the Staff recommended the commission deny the deferral authority request. 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.

A Stipulation and Recommendation was filed jointly by Duke Energy Ohio, the Staff, the Office of the Ohio Consumers' Counsel and the Ohio Energy Group on August 31, 2021, which was approved without modification by the PUCO on April 20, 2022. The Stipulation and Recommendation resolved all open issues regarding MGP remediation costs incurred between 2013 and 2019, Duke Energy Ohio’s request for additional deferral authority beyond 2019 and the pending issues related to the Tax Act described below as it related to Duke Energy Ohio’s natural gas operations. As a result of the approval of the Stipulation and Recommendation, Duke Energy Ohio recognized pretax charges of approximately $15 million to Operating revenues, regulated natural gas and $58 million to Operation, maintenance and other and a tax benefit of $72 million to Income Tax (Benefit) Expense in the Condensed Consolidated Statements of Operations for the three months ended March 31, 2022. The Stipulation and Recommendation further acknowledged Duke Energy Ohio’s ability to file a request for additional deferral authority in the future related to environmental remediation of any MGP impacts in the Ohio River if necessary, subject to specific conditions. Intervenors have 30 days to file for rehearing. Duke Energy Ohio cannot predict the outcome of this matter.

5247


FINANCIAL STATEMENTS			REGULATORY MATTERS

Tax Act – Ohio

On December 21, 2018, Duke Energy Ohio filed an application to change its base rate tariffs and establish a new rider to implement the benefits of the Tax Act for natural gas customers. Duke Energy Ohio requested commission approval to implement the tariff changes and rider effective April 1, 2019. The new rider ~~will~~would flow through to customers the benefit of the ~~lower~~reduction in the statutory federal tax rate from 35% to 21% since January 1, 2018, all future benefits of the lower tax rates and a full refund of deferred income taxes collected at the higher tax rates in prior years. Deferred income taxes subject to normalization rules ~~will~~would be refunded consistent with federal law and deferred income taxes not subject to normalization rules will be refunded over a 10-year period. The PUCO established a procedural schedule and testimony was filed on July 31, 2019. An evidentiary hearing occurred on August 7, 2019. ~~Initial briefs were~~The Stipulation and Recommendation filed on ~~September 11, 2019. Reply briefs~~August 31, 2021, and approved on April 20, 2022, disclosed in the MGP Cost Recovery matter above, resolves the outstanding issues in this proceeding by providing customers a one-time bill credit for the reduction in the statutory federal tax rate from 35% to 21% since January 1, 2018, through June 1, 2022, and reducing base rates going forward. Deferred income taxes subject to normalization rules will be refunded consistent with federal law through a new rider. Deferred income taxes not subject to normalization rules were ~~filed on September 25, 2019.~~written off. Intervenors have 30 days to file for rehearing. Duke Energy Ohio cannot predict the outcome of this matter.

Midwest Propane Caverns

Duke Energy ~~Kentucky Natural Gas Base Rate Case~~

Ohio used propane stored in caverns to meet peak demand during winter. Because the Central Corridor Project is complete and placed in service, the propane peaking facilities will no longer be necessary and have been retired. On ~~April 30,~~October 7, 2021, Duke Energy ~~Kentucky~~Ohio requested deferral treatment of the property, plant and equipment as well as costs related to propane inventory and decommissioning costs. On January 6, 2022, the Staff issued a report recommending deferral authority for costs related to propane inventory and decommissioning costs, but not for the net book value of the remaining plant assets. As a result of the Staff's report, Duke Energy Ohio recorded a $19 million charge to Impairment of assets and other charges on the Consolidated Statements of Operations and Comprehensive Income in the fourth quarter of 2021. A Stipulation and Recommendation was filed jointly by Duke Energy Ohio and the Staff on April 27, 2022, recommending, among other things, approval of deferral treatment of a ~~Notice~~portion of ~~Intent with~~ the ~~KPSC~~net book value of the property, plant and equipment prior to ~~file a general~~the 2021 impairment at the time of the next natural gas base rate case, ~~no earlier than 30 days from the date~~excluding operations and maintenance savings, decommissioning costs not to exceed $7 million and costs related to propane inventory. The Stipulation and Recommendation states that Duke Energy Ohio will seek recovery of the ~~notice.~~deferral through its next gas base rate case proceeding with a proposed amortization period of at least ten years and include an independent engineering study analyzing the necessity and prudency of the incremental investments made at the facilities since March 31, 2012. Duke Energy Ohio will not seek a return on the deferred amounts. Duke Energy Ohio cannot predict the outcome of this matter.

Duke Energy Indiana

2019 Indiana Rate Case

On July 2, 2019, Duke Energy Indiana filed a general rate case with the IURC for a rate increase for retail customers of approximately $395 million. 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. On June 29, 2020, the IURC issued ~~the~~an order in the rate case approving a revenue increase of $146 million before certain adjustments and ratemaking refinements. The order ~~provided for an overall cost of capital of 5.7% based on an ROE of 9.7% and a 53% equity component of the capital structure, and~~ approved Duke Energy Indiana’s requested forecasted rate base of $10.2 billion as of December 31, 2020, including the Edwardsport ~~IGCC~~Integrated Gasification Combined Cycle (IGCC) Plant. The IURC reduced Duke Energy Indiana’s request by slightly more than $200 million, when accounting for the utility receipts tax and other adjustments. Approximately 50% of the reduction iswas due to a prospective change in depreciation and use of regulatory asset for the end-of-life inventory at retired generating plants, approximately 20% is due to the approved ROE of 9.7%versus the requested ROE of 10.4% and approximately 20% iswas related to miscellaneous earnings neutral adjustments. Step one rates ~~are~~were estimated to be approximately 75% of the total and became effective on July 30, 2020. Step two rates are estimated to be the remaining 25% of the total rate ~~increase~~increase. Step two rates were approved on July 28, 2021, and ~~will be~~ implemented in ~~mid-2021.~~ August 2021. Step two rates are based on an ROE of 9.7% and actual December 31, 2020 capital structure with a 54% equity component. Step two rates were reconciled to January 1, 2021.

Several groups appealed the IURC order to the Indiana Court of Appeals. Appellate briefs were filed on October 14, 2020, focusing on three issues: wholesale sales allocations, coal ash basin cost recovery and the Edwardsport IGCC operating and maintenance expense level approved. The appeal was fully briefed in January 2021 and an oral argument was held on April 8, 2021. AThe Indiana Court of Appeals affirmed the IURC decision ~~is expected~~on May 13, 2021. The Indiana Office of Utility Consumer Counselor (OUCC) and the Duke Industrial Group filed a joint petition to transfer the rate case appeal to the Indiana Supreme Court on June 28, 2021. Response briefs were filed July 19, 2021. The Indiana Supreme Court issued its opinion on March 10, 2022, finding that the IURC erred in allowing Duke Energy Indiana to recover coal ash costs incurred before the IURC’s rate case order in June 2020. The Indiana Supreme Court found that allowing Duke Energy Indiana to recover coal ash costs incurred between rate cases that exceeded the amount built into base rates violated the prohibition against retroactive ratemaking. The IURC’s order has been remanded to the IURC for additional proceedings consistent with the Indiana Supreme Court’s opinion. As a result of the court's opinion, Duke Energy Indiana recognized pretax charges of approximately $211 million to Impairment of assets and other charges and $46 million to Operating revenues in the ~~second or third quarter~~Condensed Consolidated Statements of ~~2021.~~Operations for the three months ended March 31, 2022. Duke Energy Indiana filed a request for rehearing with the Supreme Court on April 11, 2022. Until the Indiana Supreme Court acts on the petition for rehearing, the IURC may not act on the Supreme Court's initial remedy. Duke Energy Indiana cannot predict the outcome of this matter.

2020 Indiana Coal Ash Recovery Case

In Duke Energy Indiana’s 2019 rate case, the IURC ~~approved coal ash basin closure costs expended through 2018 including financing costs as a regulatory asset and included in rate base. The IURC~~also opened a subdocket ~~to deal with the~~for post-2018 coal ash related expenditures. 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 (IDEM) as well as continuing deferral, with carrying costs, on the balance. An evidentiary hearing was held on September 14, ~~2020, and~~2020. Briefing was completed by mid-September 2021. On November 3, 2021, the ~~parties have agreed on a delayed briefing schedule that allows~~IURC issued an order allowing recovery for post-2018 coal ash basin closure costs for the ~~Indiana Rate Case~~plans that have been approved by IDEM, as well as continuing deferral, with carrying costs, on the balance. The OUCC filed a notice of appeal to ~~proceed. Briefing will be completed by mid-August~~the Indiana Court of Appeals on December 3, 2021. Duke Energy Indiana cannot predict the outcome of this matter.

~~Piedmont~~

~~2020 Tennessee Rate Case~~

On July 2, 2020, Piedmont filed an application with the TPUC, its first general rate case in Tennessee in nine years, for a rate increase for retail customers of approximately $30 million, which represents an approximate 15% increase in annual revenues. The rate increase is driven by significant infrastructure upgrade investments since Piedmont's previous rate case. Approximately half of the plant additions being added to rate base are categories of capital investment not covered under the IMR mechanism, which was approved in 2013. Piedmont amended its requested increase to approximately $26 million in December 2020. As authorized under Tennessee law, Piedmont implemented interim rates on January 2, 2021, at the level requested in its adjusted request. A settlement reached with the Tennessee Consumer Advocate in mid-January was filed with the TPUC on February 2, 2021. The settlement results in an increase of revenues of approximately $16 million and a ROE of 9.8%. On May 6, 2021, the TPUC issued an order approving the settlement. Revised customer rates became effective January 2, 2021. Piedmont refunded customers the difference between bills previously rendered under interim rates and such bills if rendered under approved rates, plus interest, in April 2021.

~~2021 North Carolina Rate Case~~

On March 22, 2021, Piedmont filed an application with the NCUC for a rate increase for retail customers of approximately $109 million, which represents an approximate 10% increase in retail revenues. The rate increase is driven by customer growth and significant infrastructure upgrade investments (plant additions) since the last general rate case. Approximately 30% of the plant additions being rolled into rate base are categories of plant investment that are covered under the IMR mechanism, which was originally approved as part of the 2013 North Carolina Rate Case. A hearing date has not yet been established. Piedmont cannot predict the outcome of this matter.

5348


FINANCIAL STATEMENTS			REGULATORY MATTERS

Piedmont

2022 South Carolina Rate Case

On April 1, 2022, Piedmont filed an application with the PSCSC for a rate increase for retail customers of approximately $7 million, which represents an approximate 3.4% increase in retail revenues. The rate increase is driven by customer growth and infrastructure upgrade investments (plant additions) since Piedmont’s last proceeding in 2021 under South Carolina’s Rate Stabilization Act. In addition, Piedmont agreed with the South Carolina Office of Regulatory Staff in 2019 to file a general rate case no later than April 1, 2022, to conduct a more comprehensive review of rates including the allocation of costs to residential, commercial and industrial customers. The PSCSC has scheduled an evidentiary hearing for the week of August 15, 2022. Piedmont cannot predict the outcome of this matter.

OTHER REGULATORY MATTERS

~~Atlantic Coast Pipeline, LLC~~

Atlantic Coast Pipeline (ACP pipeline) was planned to be an approximately 600-mile interstate natural gas pipeline running from West Virginia to North Carolina. Duke Energy indirectly owns a 47% interest, which is accounted for as an equity method investment through its Gas Utilities and Infrastructure segment.

As a result of the uncertainty created by various legal rulings, the potential impact on the cost and schedule for the project, the ongoing legal challenges and the risk of additional legal challenges and delays through the construction period and Dominion’s decision to sell substantially all of its gas transmission and storage segment assets, Duke Energy's Board of Directors and management decided that it was not prudent to continue to invest in the project. On July 5, 2020, Duke Energy and Dominion announced the cancellation of the ACP pipeline project.

As part of the pretax charges to earnings of approximately $2.1 billion recorded in June 2020, within Equity in (losses) earnings of unconsolidated affiliates on the Duke Energy Condensed Consolidated Statements of Operations, Duke Energy established liabilities related to the cancellation of the ACP pipeline project. In February 2021, Duke Energy paid approximately $855 million to fund ACP's outstanding debt, relieving Duke Energy of its guarantee. At March 31, 2021, there is $38 million and $48 million within Other Current Liabilities and Other Noncurrent Liabilities, respectively, in the Gas Utilities and Infrastructure segment. The liabilities represent Duke Energy's obligation of approximately $86 million to satisfy remaining ARO requirements to restore construction sites.

~~See Notes 1 and 11 for additional information regarding this transaction.~~

Potential Coal Plant Retirements

The Subsidiary Registrants periodically file ~~integrated resource plans~~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 ~~integrated resource plans (IRPs)~~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, ~~2021,~~2022, and exclude capitalized asset retirement costs.

Remaining Net
Capacity Book Value
(in MW) (in millions)
Duke Energy Carolinas
Allen Steam Station Units 1-2(a)
334 $ 21
Allen Steam Station Units 4-5(b)
526 388
Cliffside Unit 5(b)
546 343
Duke Energy Progress
Mayo Unit 1(b)
746 660
Roxboro Units 3-4(b)
1,409 478
Duke Energy Florida
Crystal River Units 4-5(c)
1,430 1,683
Duke Energy Indiana
Gallagher Units 2 and 4(d)
280 91
Gibson Units 1-5(e)
2,845 1,834
Cayuga Units 1-2(e)
1,005 755
Total Duke Energy 9,121 $ 6,253


~~FINANCIAL STATEMENTS~~			~~REGULATORY MATTERS~~








		Remaining Net
	Capacity	Book Value
	(in MW)	(in millions)
Duke Energy Carolinas
Allen Steam Station Units 1(a)	167	$	12
Allen Steam Station Units 5(b)	259	265
Cliffside Unit 5(b)	546	358
Duke Energy Progress
Mayo Unit 1(b)	713	621
Roxboro Units 3-4(b)	1,409	450
Duke Energy Florida
Crystal River Units 4-5(c)	1,442	1,636
Duke Energy Indiana
Gibson Units 1-5(d)	2,845	2,076
Cayuga Units 1-2(d)	1,005	676
Total Duke Energy	8,386	$	6,094

(a)As part of the 2015 resolution of a lawsuit involving alleged New Source Review violations, Duke Energy Carolinas must retire Allen Steam Station ~~Units~~Unit 1 ~~through 3~~ by December 31, 2024. The long-term energy options considered in the IRP could result in retirement of ~~these units~~this unit earlier than ~~their~~its current estimated useful ~~lives. Unit 3 with a capacity of 270 MW and a net book value of $26 million at December 31, 2020, was retired in March 2021.~~live.

(b)These units ~~are~~were included in the IRP filed by Duke Energy Carolinas and Duke Energy Progress in North Carolina and South Carolina on September 1, 2020. The long-term energy options considered in the IRP could result in retirement of these units earlier than their current estimated useful lives. In 2019, Duke Energy Carolinas and Duke Energy Progress filed North Carolina rate cases that included depreciation studies that accelerate end-of-life dates for these plants. NCUC issued orders in the 2019 rate cases of Duke Energy Carolinas and Duke Energy Progress on March 31, 2021, and April 16, 2021, respectively, in which the proposals to shorten the remaining depreciable lives of these units were denied, while indicating the IRP proceeding was the appropriate proceeding for the review of generating plant retirements.

(c)On January 14, 2021, Duke Energy Florida filed ~~a settlement~~the 2021 Settlement agreement with the FPSC, which proposed depreciation rates reflecting retirement dates for Duke Energy Florida's last 2 coal-fired generating facilities, Crystal River Units 4-5, eight years ahead of schedule in 2034 rather than in 2042. The ~~settlement was~~FPSC approved by the ~~FPSC~~2021 Settlement on May 4, 2021.

(d)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. In February 2021, upon approval by MISO of a new retirement date, Duke Energy Indiana determined it would modify the retirement date to June 1, 2021.

~~(e)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, included proposed depreciation rates reflecting retirement dates from 2026 to 2038. The depreciation rates reflecting these updated retirement dates were approved by the IURC as part of the rate case order issued on June 29, 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.


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.


(in millions)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
Reserves for Environmental Remediation	Reserves for Environmental Remediation					Reserves for Environmental Remediation
Duke Energy	Duke Energy	$	74	$	75	Duke Energy	$	87	$	88
Duke Energy Carolinas	Duke Energy Carolinas	18		19		Duke Energy Carolinas	19		19
Progress Energy	Progress Energy	18		19		Progress Energy	23		23
Duke Energy Progress	Duke Energy Progress	6		6		Duke Energy Progress	11		11
Duke Energy Florida	Duke Energy Florida	12		12		Duke Energy Florida	11		11
Duke Energy Ohio	Duke Energy Ohio	21		22		Duke Energy Ohio	33		34
Duke Energy Indiana	Duke Energy Indiana	5		6		Duke Energy Indiana	4		4
Piedmont	Piedmont	11		10		Piedmont	8		9

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~~material.

LITIGATION

Duke Energy

Michael Johnson et al. v. Duke Energy Corporation et al.

On September 23, 2020, plaintiff Michael Johnson, a former Duke Energy employee and participant in the ~~table below.~~Duke Energy Retirement Savings Plan (Plan) brought suit on his own behalf and on behalf of other participants and beneficiaries similarly situated against Duke Energy Corporation, the Duke Energy Benefits Committee, and other unnamed individual defendants. The complaint, which was subsequently amended to add a current participant as a plaintiff on November 23, 2020, alleges that the defendants breached their fiduciary duties with respect to certain fees associated with the Plan in violation of the Employee Retirement Income Security Act of 1974 and seeks certification of a class of all individuals who were participants or beneficiaries of the Plan at any time on or after September 23, 2014. The defendants filed a motion to dismiss the plaintiffs’ amended complaint on December 18, 2020. On January 31, 2022, the court denied the defendants' motion to dismiss. On February 28, 2022, Duke Energy responded to the amended complaint. Discovery commenced and the parties exchanged preliminary disclosures. After review of these disclosures, the parties filed a joint stipulation of dismissal with prejudice on April 28, 2022. If approved by the Court, this matter will be fully resolved. Duke Energy cannot predict the outcome of this matter.


~~(in millions)~~
~~Duke Energy~~	$	20
~~Duke Energy Carolinas~~	12



~~Duke Energy Ohio~~	4

Texas Storm Uri Tort Litigation

Several Duke Energy renewables project companies, located in the ERCOT market, were named in lawsuits arising out of Texas Storm Uri in mid-February 2021. Duke Energy Corporation, which had originally been named in several suits, was dismissed from the lawsuits. The lawsuits against the Duke Energy renewables project companies seek recovery for property damages, personal injury and for wrongful death allegedly caused by the power outages, which the plaintiffs claim was the result of collective failures of generators, transmission and distribution operators, retail energy providers and others, including ERCOT. The cases have been consolidated into a Texas state court multidistrict litigation (MDL) proceeding for discovery and pre-litigation purposes. NaN MDL cases have been designated for motions to dismiss while all other cases are stayed. Duke Energy renewables projects are named as defendants in 3 of these 5 cases. The parties' briefing on omnibus motions to dismiss should be completed by July 2022 and will focus on lack of duty, tariff defenses and sovereign immunity. Decisions on these motions will be applicable to all of the stayed cases. Duke Energy cannot predict the outcomes of these matters.

5550


FINANCIAL STATEMENTS			COMMITMENTS AND CONTINGENCIES

~~LITIGATION~~

~~Duke Energy~~

~~Texas Storm Uri Tort Litigation~~

Duke Energy and several Duke Energy renewables project companies have been named in multiple lawsuits arising out of Texas Storm Uri in mid-February 2021, and particularly, in the deregulated market managed by the Electric Reliability Council of Texas.. Currently, 15 state court actions have been filed in counties across Texas and 1 case is pending in federal court in Texas. These lawsuits, filed by individuals, seek recovery for property damages, personal injury and for wrongful death allegedly incurred by the plaintiffs as a result of power losses, which the plaintiffs claim was the result of the defendants' failure to take appropriate precautions. Certain defendants have moved to transfer all related cases including those naming Duke Energy entities into a Texas state court multi-district litigation proceeding for coordination before a single judge. No ruling has yet been issued on this motion. Duke Energy cannot predict the outcomes of these state and federal litigation matters.Carolinas

Ruben Villano, et al. v. Duke Energy Carolinas, LLC

On June 16, 2021, a group of 9 individuals went over a low head dam adjacent to the Dan River Steam Station in Eden, North Carolina, while water tubing. Emergency personnel rescued 4 people and ~~Duke Energy Progress~~

~~Coal Ash Insurance Coverage Litigation~~

~~In March 2017,~~5 others were confirmed deceased. On August 11, 2021, Duke Energy Carolinas ~~and Duke Energy Progress~~was served with the complaint filed ~~a civil action~~ in Durham County Superior Court on behalf of 4 survivors, which was later amended to include all the ~~North Carolina Business Court against various insurance providers.~~decedents along with the survivors, except for one minor. 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 U.S. Environmental Protection Agency CCR rule at 15 coal-fired plants in North Carolina and South Carolina. Fact discovery has been completed. The parties' fully briefed and argued motions relating to key legal matters are pending before the court for rulings. Trial remains scheduled for January 24, 2022.alleges that Duke Energy Carolinas knew that the river was used for recreational purposes and that Duke Energy ~~Progress~~did not adequately warn about the dam, and that Duke Energy Carolinas created a dangerous and hidden hazard on the Dan River in building and maintaining the low head dam. On September 30, 2021, Duke Energy Carolinas filed its motion to dismiss and motion for transfer of venue from Durham County to Rockingham County, both of which were denied on November 15, 2021. On November 15, 2021, Duke Energy Carolinas was also served with Plaintiffs Second Amended Complaint, which added the final minor plaintiff and consolidated all the actions into 1 lawsuit. Duke Energy Carolinas has filed its Answer and Affirmative Defenses to the Second Amended Complaint. Mediation is scheduled for December 2022. Discovery has commenced and is scheduled to be completed on or before February 28, 2023. The case is scheduled to be trial-ready by April 24, 2023. Duke Energy Carolinas cannot predict the outcome of this matter.

~~Duke Energy Carolinas~~

NTE Carolinas II, LLC Litigation

In November 2017, Duke Energy Carolinas entered into a standard FERC large generator interconnection agreement (LGIA) with NTE Carolinas II, LLC (NTE), a company that proposed to build a combined-cycle natural gas plant in Rockingham County, North Carolina. On September 6, 2019, Duke Energy Carolinas filed a lawsuit in Mecklenburg County Superior Court against NTE for breach of contract, alleging that NTE's failure to pay benchmark payments for Duke Energy Carolinas' transmission system upgrades required under the interconnection agreement constituted a termination of the interconnection agreement. Duke Energy Carolinas is seeking a monetary judgment against NTE because NTE failed to make multiple milestone payments. The lawsuit was moved to federal court in North Carolina. NTE filed a motion to dismiss Duke Energy Carolinas’ complaint and brought counterclaims alleging anti-competitive conduct and violations of state and federal statutes. Duke Energy Carolinas filed a motion to dismiss NTE's counterclaims.

On May 21, 2020, in response to a NTE petition challenging Duke Energy Carolinas' termination of the LGIA, FERC issued a ruling ~~(i)~~ that 1) it has exclusive jurisdiction to determine whether a transmission provider may terminate a ~~LGIA, (ii)~~LGIA; 2) FERC approval is required to terminate a conforming LGIA if objected to by the interconnection ~~customer,~~customer; and ~~(iii)~~3) Duke Energy may not announce the termination of a conforming LGIA unless FERC has approved the termination. FERC's Office of Enforcement also initiated an investigation of Duke Energy Carolinas into matters pertaining to the LGIA. Duke Energy Carolinas is cooperating with the Office of Enforcement but cannot predict the outcome of this investigation.

On August 17, 2020, the court denied both NTE’s and Duke Energy Carolinas’ ~~Motion~~motions to ~~Dismiss.~~dismiss. In October 2021, NTE filed a Second Amended Counterclaim and Complaint, and in January 2022, NTE filed a Third Amended Counterclaim and Complaint. Duke Energy Carolinas has responded to these pleadings. On December 6, 2021, Duke Energy Carolinas filed an Amended Complaint. On March 1, 2022, the parties participated in mediation, which ended in an impasse. On April 4, 2022, Duke Energy Carolinas filed a motion for summary judgment seeking a ruling in its favor as to some of its affirmative claims against NTE and to all of NTE’s counterclaims. Duke Energy Carolinas' motion will be fully briefed on May 10, 2022. The ~~parties are in active discovery and trial~~case is scheduled ~~for June 20,~~to be trial-ready by August 1, 2022. Duke Energy Carolinas cannot predict the outcome of this matter.

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, 2021, there were 126 asserted claims for non-malignant cases with cumulative relief sought of up to $31 million, and 47 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 ~~$564~~$495 million at March 31, ~~2021,~~2022, and ~~$572~~$501 million at December 31, ~~2020.~~2021. 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 ~~2040~~2041 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 ~~2040~~2041 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 $714 million in excess of the self-insured retention. Receivables for insurance recoveries were ~~$704~~$644 million at March 31, ~~2021,~~2022, and $644 million at December 31, ~~2020.~~2021. These amounts are classified in Other within Other Noncurrent Assets and Receivables within Current Assets on the Condensed Consolidated Balance Sheets. Any future payments up to the policy limit will be reimbursed by the third-party insurance carrier. 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.


~~FINANCIAL STATEMENTS~~			~~COMMITMENTS AND CONTINGENCIES~~

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~~$12 million for Duke Energy and Duke Energy Carolinas as of March 31, ~~2021,~~2022, and December 31, ~~2020.~~2021. The insurance receivable is 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.

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~~DOE 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 $200 million for Duke Energy Progress and Duke Energy Florida, respectively. ~~Discovery is ongoing~~


FINANCIAL STATEMENTS			COMMITMENTS AND CONTINGENCIES

On March 30, 2022, the DOE and ~~a trial is expected to occur in 2021.~~

Duke Energy ~~Florida~~

~~Power Purchase Dispute Arbitration~~

Progress executed a settlement agreement, pursuant to which Duke Energy ~~Florida,~~Progress will receive damages for costs incurred between 2014 and 2018, and will be able to submit future costs on ~~behalf of its customers, entered into~~ a ~~PPA for the purchase of firm capacity and energy from a qualifying facility under the Public Utilities Regulatory Policies Act of 1978.~~defined schedule. In April 2022, Duke Energy ~~Florida determined~~Progress received $87 million in proceeds that related to damages incurred in 2014 through 2018.

On May 2, 2022, the ~~qualifying facility did not perform in accordance with the PPA,~~DOE and Duke Energy Florida ~~terminated the PPA. The qualifying facility counterparty filed~~executed a ~~confidential American Arbitration Association (AAA) arbitration demand, challenging the termination of the PPA and seeking damages.~~

~~The final arbitration hearing occurred during the week of December 7, 2020. An arbitral award was issued in March 2021, upholding~~settlement agreement, pursuant to which Duke Energy ~~Florida's positions on all issues~~Florida will receive approximately $180 million for costs incurred between 2014 and ~~awarding the company termination costs.~~2018, and will be able to submit costs incurred in 2019 and 2020 pursuant to an audit process.

Duke Energy Indiana

Coal Ash Basin Closure Plan Appeal

On January 27, 2020, Hoosier Environmental Council (HEC) filed a Petition for Administrative Review with the Indiana Office of Environmental Adjudication challenging the Indiana Department of Environmental Management’s (IDEM's) December 10, 2019, partial approval of Duke Energy Indiana’s ash pond closure ~~plan. On March 11, 2020,~~plan at Duke ~~Energy Indiana filed a Motion to Dismiss. On May 5, 2020, the court denied the motion.~~Energy's Gallagher power station. After hearing oral arguments in early April 2021 on Duke Energy Indiana's and HEC's competing Motions for Summary Judgment, on May 4, 2021, the administrative court rejected all of HEC’s claims and issued a ruling in favor of Duke Energy Indiana. ~~HEC has until~~On June 3, 2021, HEC filed an appeal in Superior Court to seek judicial review of the order. DukeOn June 25, 2021, Duke Energy Indiana filed its response to the Petition to Review. On August 30, 2021, HEC served Duke Energy Indiana with its Brief in Support of Petition for Judicial Review. On October 29, 2021, Duke Energy Indiana and IDEM filed their response briefs. On December 13, 2021, HEC filed and served its Reply Brief.

On January 11, 2022, Duke Energy Indiana received a compliance obligation letter from the EPA notifying the company that the two basins at issue in the litigation are subject to requirements of the CCR Rule. The letter does not provide a deadline for compliance. Duke Energy Indiana is evaluating the EPA letter, its potential impacts on the litigation and the extent to which this letter could apply to CCR surface impoundments at its other Indiana sites.

Following the January 11, 2022 EPA notice of compliance letter, the parties filed a joint motion to stay the litigation for 45 days, which was approved by the court. As a result, the oral argument scheduled for February 1, 2022, was postponed. Duke Energy Indiana and HEC engaged in settlement discussions, but the parties were unable to reach resolution. On April 21, 2022, HEC filed a Motion to Lift Stay and Motion for Judicial Notice. HEC also requested that the court hold a hearing within 45 days and also take judicial notice of the EPA's January 11, 2022 letter. On April 22, 2022, Duke Energy Indiana sent IDEM a letter withdrawing the closure plans for the Gallagher North Ash Pond and Primary Pond Ash Fill. After acknowledgment by IDEM of withdrawal of these closure plans, Duke Energy Indiana filed a Motion to Dismiss the litigation as moot on April 28, 2022, and IDEM filed a separate brief on May 2, 2022, in support of this motion. Briefing is ongoing. 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, 2021 December 31, 2020
Reserves for Legal Matters
Duke Energy $ 65 $ 68
Duke Energy Carolinas 3 2
Progress Energy 57 61
Duke Energy Progress 11 13
Duke Energy Florida 26 28
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.


~~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.


FINANCIAL STATEMENTS			DEBT AND CREDIT FACILITIES

5. DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

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


					Three Months Ended March 31, 2021																				Three Months Ended March 31, 2022
							Duke		Duke		Duke		Duke		Duke		Duke										Duke		Duke
		Maturity	Interest		Duke		Energy		Energy		Energy		Energy		Energy		Energy					Maturity	Interest		Duke		Energy		Energy
Issuance Date	Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Progress		Florida		Ohio		Indiana		Piedmont		Issuance Date	Date	Rate		Energy		Carolinas		Progress
Unsecured Debt
March 2021(a)		Mar 2031	2.500	%	$	350	$	0	$	—	$	—	$	—	$	—	$	—	$	350

First Mortgage Bonds																					First Mortgage Bonds
March 2022(a)																					March 2022(a)	March 2032	2.850	%	$	500	$	500	$	—
March 2022(a)																					March 2022(a)	March 2052	3.550	%	650		650		—
March 2022(a)																					March 2022(a)	April 2032	3.400	%	500		—		500
March 2022(a)																					March 2022(a)	April 2052	4.000	%	400		—		400

Total issuances	Total issuances				$	350	$	0	$	0	$	0	$	0	$	0	$	0	$	350	Total issuances				$	2,050	$	1,150	$	900

(a)~~Debt issued to repay at maturity $160 million senior unsecured notes due June 2021, pay down short-term debt and for general corporate purposes.~~

In March 2021, Duke Energy Carolinas priced $1 billion of First Mortgage Bonds. The issuance and sale of securities settled in April 2021, in 2 separate tranches. The first tranche was issued for $550 million at a fixed interest rate of 2.55% and mature in April 2031. The second tranche was issued for $450 million at a fixed interest rate of 3.45% and mature in April 2051. Proceeds ~~from the issuance~~ will be used to ~~repay at maturity $500 million of 3.90% First Mortgage Bonds due June 2021, pay down intercompany short-term debt and for general company purposes.~~finance or refinance, in whole or in part, existing or new eligible projects under the sustainable financing framework.

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)	(in millions)	Maturity Date	Interest Rate			March 31, 2021		(in millions)	Maturity Date	Interest Rate		March 31, 2022
Unsecured Debt	Unsecured Debt							Unsecured Debt
Duke Energy (Parent)		May 2021	0.698	%	(a)	500
Piedmont		June 2021	4.240	%		160
Duke Energy (Parent)		September 2021	3.550	%		500
Duke Energy (Parent)		September 2021	1.800	%		750
Duke Energy Florida		November 2021	0.441	%	(a)	200
Duke Energy Progress		February 2022	0.369	%	(a)	700
Progress Energy								Progress Energy	April 2022	3.150	%	$	450
Duke Energy (Parent)	Duke Energy (Parent)	March 2022	3.227	%		300		Duke Energy (Parent)	August 2022	3.050	%	500
Duke Energy (Parent)	Duke Energy (Parent)	March 2022	0.827	%	(a)	300		Duke Energy (Parent)	August 2022	2.400	%	500

First Mortgage Bonds	First Mortgage Bonds							First Mortgage Bonds
Duke Energy Carolinas	Duke Energy Carolinas	June 2021	3.900	%		500		Duke Energy Carolinas	May 2022	3.350	%	350
Duke Energy Florida		August 2021	3.100	%		300
Duke Energy Progress	Duke Energy Progress	September 2021	3.000	%		500		Duke Energy Progress	May 2022	2.800	%	500
Duke Energy Progress		September 2021	8.625	%		100
Duke Energy Indiana		January 2022	8.850	%		53
Other(b)						723
Duke Energy Carolinas								Duke Energy Carolinas	March 2023	2.500	%	500
Duke Energy Carolinas								Duke Energy Carolinas	March 2023	3.050	%	500
Other(a)								Other(a)				584
Current maturities of long-term debt	Current maturities of long-term debt					$	5,586	Current maturities of long-term debt				$	3,884

(a) ~~Debt has a floating interest rate.~~

~~(b)~~ Includes finance lease obligations, amortizing debt, tax-exempt bonds with mandatory put options and small bullet maturities.

AVAILABLE CREDIT FACILITIES

Master Credit Facility

In March ~~2021,~~2022, Duke Energy amended its existing ~~$8 billion~~ Master Credit Facility to increase the amount of the facility from $8 billion to $9 billion and to extend the termination date to March ~~2026.~~2027. 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.

5853


FINANCIAL STATEMENTS			DEBT AND CREDIT FACILITIES

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


		March 31, 2021																	March 31, 2022
				Duke		Duke		Duke		Duke		Duke		Duke							Duke		Duke		Duke		Duke		Duke		Duke
		Duke		Energy		Energy		Energy		Energy		Energy		Energy					Duke		Energy		Energy		Energy		Energy		Energy		Energy
(in millions)	(in millions)	Energy		(Parent)		Carolinas		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		(Parent)		Carolinas		Progress		Florida		Ohio		Indiana		Piedmont
Facility size(a)	Facility size(a)	$	8,000	$	2,650	$	1,475	$	1,250	$	700	$	625	$	600	$	700	Facility size(a)	$	9,000	$	3,300	$	1,225	$	1,400	$	900	$	775	$	600	$	800
Reduction to backstop issuances	Reduction to backstop issuances																	Reduction to backstop issuances
Commercial paper(b)	Commercial paper(b)	(3,466)		(1,781)		(741)		(292)		(243)		(259)		(150)		—		Commercial paper(b)	(2,819)		(1,715)		(300)		(150)		(236)		(86)		(150)		(182)
Outstanding letters of credit	Outstanding letters of credit	(31)		(25)		(4)		(2)		—		—		—		—		Outstanding letters of credit	(38)		(25)		(4)		(2)		(7)		—		—		—
Tax-exempt bonds	Tax-exempt bonds	(81)		—		—		—		—		—		(81)		—		Tax-exempt bonds	(81)		—		—		—		—		—		(81)		—

Available capacity under the Master Credit Facility	Available capacity under the Master Credit Facility	$	4,422	$	844	$	730	$	956	$	457	$	366	$	369	$	700	Available capacity under the Master Credit Facility	$	6,062	$	1,560	$	921	$	1,248	$	657	$	689	$	369	$	618

(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, 2021
(in millions) Facility size Amount drawn
Duke Energy (Parent) Three-Year Revolving Credit Facility(a)
$ 1,000 $ 500

~~(a)During March 2021,~~ Duke Energy ~~extended the~~(Parent) Term Loan Facility

On March 9, 2022, Duke Energy (Parent) entered into a Term Loan Credit Agreement (Credit Agreement) with commitments totaling $1.4 billion maturing March 9, 2024. The maturity date of the Credit Agreement may be extended for up to two years by request of Duke Energy (Parent), upon satisfaction of certain conditions contained in the Credit Agreement. Borrowings under the facility were used to repay amounts drawn under the Three-Year Revolving Credit Facility ~~from May~~and for general corporate purposes, including repayment of a portion of Duke Energy's outstanding commercial paper. The balance is classified as Long-Term Debt on Duke Energy's Condensed Consolidated Balance Sheets. The Three-Year Revolving Credit Facility was terminated in March 2022.

Intercompany Credit Agreements

In March 2022, Progress Energy closed a revolving credit agreement with Duke Energy (Parent), which allowed up to ~~May 2024.~~$2.5 billion in intercompany borrowings.

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, ~~2021,~~2022, and December 31, ~~2020.~~2021.


		Electric Utilities		Gas Utilities		Commercial					Electric Utilities		Gas Utilities		Commercial
(in millions)	(in millions)	and Infrastructure		and Infrastructure		Renewables		Total		(in millions)	and Infrastructure		and Infrastructure		Renewables		Total

Goodwill balance	Goodwill balance	$	17,379	$	1,924	$	122	$	19,425	Goodwill balance	$	17,379	$	1,924	$	122	$	19,425
Accumulated impairment charges	Accumulated impairment charges	0		0		(122)		(122)		Accumulated impairment charges	—		—		(122)		(122)
Goodwill, adjusted for accumulated impairment charges	Goodwill, adjusted for accumulated impairment charges	$	17,379	$	1,924	$	0	$	19,303	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, ~~2021,~~2022, and December 31, ~~2020.~~2021.

Progress Energy

Progress Energy's Goodwill is included in the Electric Utilities and Infrastructure segment and there are 0no accumulated impairment charges.

Piedmont

Piedmont's Goodwill is included in the Gas Utilities and Infrastructure segment and there are 0no accumulated impairment charges.

5954


FINANCIAL STATEMENTS			RELATED PARTY TRANSACTIONS

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,					Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		(in millions)		2022		2021
Duke Energy Carolinas	Duke Energy Carolinas					Duke Energy Carolinas
Corporate governance and shared service expenses(a)	Corporate governance and shared service expenses(a)	$	203	$	134	Corporate governance and shared service expenses(a)		$	206	$	203
Indemnification coverages(b)	Indemnification coverages(b)	6		5		Indemnification coverages(b)		7		6
Joint Dispatch Agreement (JDA) revenue(c)	Joint Dispatch Agreement (JDA) revenue(c)	13		7		Joint Dispatch Agreement (JDA) revenue(c)		26		13
JDA expense(c)	JDA expense(c)	40		24		JDA expense(c)		94		40
Intercompany natural gas purchases(d)	Intercompany natural gas purchases(d)	14		6		Intercompany natural gas purchases(d)		13		14
Progress Energy	Progress Energy					Progress Energy
Corporate governance and shared service expenses(a)	Corporate governance and shared service expenses(a)	$	181	$	146	Corporate governance and shared service expenses(a)		$	196	$	181
Indemnification coverages(b)	Indemnification coverages(b)	10		9		Indemnification coverages(b)		11		10
JDA revenue(c)	JDA revenue(c)	40		24		JDA revenue(c)		94		40
JDA expense(c)	JDA expense(c)	13		7		JDA expense(c)		26		13
Intercompany natural gas purchases(d)	Intercompany natural gas purchases(d)	19		19		Intercompany natural gas purchases(d)		19		19
Duke Energy Progress	Duke Energy Progress					Duke Energy Progress
Corporate governance and shared service expenses(a)	Corporate governance and shared service expenses(a)	$	105	$	75	Corporate governance and shared service expenses(a)		$	119	$	105
Indemnification coverages(b)	Indemnification coverages(b)	5		4		Indemnification coverages(b)		5		5
JDA revenue(c)	JDA revenue(c)	40		24		JDA revenue(c)		94		40
JDA expense(c)	JDA expense(c)	13		7		JDA expense(c)		26		13
Intercompany natural gas purchases(d)	Intercompany natural gas purchases(d)	19		19		Intercompany natural gas purchases(d)		19		19
Duke Energy Florida	Duke Energy Florida					Duke Energy Florida
Corporate governance and shared service expenses(a)	Corporate governance and shared service expenses(a)	$	76	$	71	Corporate governance and shared service expenses(a)		$	77	$	76
Indemnification coverages(b)	Indemnification coverages(b)	5		5		Indemnification coverages(b)		6		5
Duke Energy Ohio	Duke Energy Ohio					Duke Energy Ohio
Corporate governance and shared service expenses(a)	Corporate governance and shared service expenses(a)	$	79	$	84	Corporate governance and shared service expenses(a)		$	82	$	79
Indemnification coverages(b)	Indemnification coverages(b)	1		1		Indemnification coverages(b)		1		1
Duke Energy Indiana	Duke Energy Indiana					Duke Energy Indiana
Corporate governance and shared service expenses(a)	Corporate governance and shared service expenses(a)	$	113	$	106	Corporate governance and shared service expenses(a)		$	124	$	113
Indemnification coverages(b)	Indemnification coverages(b)	2		2		Indemnification coverages(b)		2		2
Piedmont	Piedmont					Piedmont
Corporate governance and shared service expenses(a)	Corporate governance and shared service expenses(a)	$	33	$	34	Corporate governance and shared service expenses(a)		$	35	$	33
Indemnification coverages(b)	Indemnification coverages(b)	1		1		Indemnification coverages(b)		1		1
Intercompany natural gas sales(d)	Intercompany natural gas sales(d)	33		25		Intercompany natural gas sales(d)		32		33
Natural gas storage and transportation costs(e)	Natural gas storage and transportation costs(e)	6		6		Natural gas storage and transportation costs(e)		6		6

(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.

6055


FINANCIAL STATEMENTS			RELATED PARTY TRANSACTIONS

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
		Energy		Progress		Energy											Energy		Progress		Energy
(in millions)	(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
March 31, 2021
March 31, 2022																March 31, 2022
Intercompany income tax receivable	Intercompany income tax receivable	$	—	$	84	$	—	$	46	$	—	$	—	$	—	Intercompany income tax receivable	$	20	$	49	$	—	$	9	$	5	$	—	$	—
Intercompany income tax payable	Intercompany income tax payable	31		—		12		—		2		36		39		Intercompany income tax payable	—		—		15		—		—		44		45

December 31, 2020
December 31, 2021																December 31, 2021
Intercompany income tax receivable	Intercompany income tax receivable	$	—	$	—	$	—	$	—	$	—	$	9	$	10	Intercompany income tax receivable	$	—	$	—	$	—	$	40	$	19	$	—	$	—
Intercompany income tax payable	Intercompany income tax payable	31		33		46		35		2		—		—		Intercompany income tax payable	62		—		84		—		—		10		27

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.

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 loss for the three months ended March 31, ~~2021,~~2022, and ~~2020,~~2021, 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 segment 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.

6156


FINANCIAL STATEMENTS			DERIVATIVES AND HEDGING

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

March 31, 2021
Duke Duke Duke Duke
Duke Energy Progress Energy Energy Energy
(in millions) Energy Carolinas Energy Progress Florida Ohio
Cash flow hedges $ 1,630 $ — $ — $ — $ — $ —
Undesignated contracts 1,731 400 1,250 750 500 27
Total notional amount(a)
$ 3,361 $ 400 $ 1,250 $ 750 $ 500 $ 27


	March 31, 2022
			Duke		Duke		Duke
	Duke		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Indiana		Ohio
Cash flow hedges	$	2,913	$	—	$	—	$	—
Undesignated contracts	577		250		300		27
Total notional amount(a)	$	3,490	$	250	$	300	$	27


		December 31, 2020													December 31, 2021
				Duke				Duke		Duke		Duke					Duke				Duke		Duke		Duke
		Duke		Energy		Progress		Energy		Energy		Energy			Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		(in millions)	Energy		Carolinas		Energy		Progress		Indiana		Ohio
Cash flow hedges	Cash flow hedges	$	632	$	—	$	—	$	—	$	—	$	—	Cash flow hedges	$	2,415	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	Undesignated contracts	1,177		400		750		750		—		27		Undesignated contracts	1,177		350		500		500		300		27
Total notional amount(a)	Total notional amount(a)	$	1,809	$	400	$	750	$	750	$	—	$	27	Total notional amount(a)	$	3,592	$	350	$	500	$	500	$	300	$	27

(a)Duke Energy includes amounts related to consolidated VIEs of ~~$631~~$663 million ~~in cash flow hedges~~ and ~~$54 million in undesignated contracts as of March 31, 2021, and $632~~$665 million in cash flow hedges as of March 31, 2022 and December 31, ~~2020.~~2021, respectively.

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 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. To manage risk associated with commodity prices, the Duke Energy Registrants may enter into long-term power purchase or sales contracts and long-term natural gas supply agreements.

Cash Flow Hedges

For derivatives designated as hedging the exposure to variable cash flows of a future transaction, referred to as a cash flow hedge, 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. Gains and losses reclassified out of accumulated other comprehensive loss for the three months ended March 31, ~~2021,~~2022, and ~~2020,~~2021, were not material. Duke Energy’s commodity derivatives designated as hedges include long-term electricity sales in the Commercial Renewables segment.

Undesignated Contracts

For the Subsidiary Registrants, bulk power electricity 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, 2021						March 31, 2022
			Duke		Duke	Duke	Duke					Duke		Duke	Duke	Duke
		Duke	Energy	Progress	Energy	Energy	Energy				Duke	Energy	Progress	Energy	Energy	Energy
		Energy	Carolinas	Energy	Progress	Ohio	Indiana		Piedmont		Energy	Carolinas	Energy	Progress	Ohio	Indiana	Piedmont
Electricity (GWh)(a)	Electricity (GWh)(a)	16,259	—	—	—	1,325	4,214		—	Electricity (GWh)(a)	16,176	—	—	—	791	4,501	—
Natural gas (millions of dekatherms)	Natural gas (millions of dekatherms)	675	151	158	158	—	2		364	Natural gas (millions of dekatherms)	860	284	243	243	—	7	326

6257


FINANCIAL STATEMENTS			DERIVATIVES AND HEDGING


		December 31, 2020						December 31, 2021
			Duke		Duke	Duke	Duke					Duke		Duke	Duke	Duke
		Duke	Energy	Progress	Energy	Energy	Energy				Duke	Energy	Progress	Energy	Energy	Energy
		Energy	Carolinas	Energy	Progress	Ohio	Indiana		Piedmont		Energy	Carolinas	Energy	Progress	Ohio	Indiana	Piedmont
Electricity (GWh)(a)	Electricity (GWh)(a)	35,409	—	—	—	2,559	10,802		—	Electricity (GWh)(a)	22,344	—	—	—	1,681	10,688	—
Natural gas (millions of dekatherms)	Natural gas (millions of dekatherms)	678	145	158	158	—	2		373	Natural gas (millions of dekatherms)	823	264	215	215	—	8	336

(a)Duke Energy includes ~~10,720~~9,763 GWh and ~~22,048~~9,975 GWh related to cash flow hedges as of March 31, ~~2021,~~2022, and December 31, ~~2020,~~2021, respectively.

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, 2021
Duke Duke Duke Duke Duke
Duke Energy Progress Energy Energy Energy Energy
(in millions) Energy Carolinas Energy Progress Florida Ohio Indiana Piedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current $ 32 $ 17 $ 12 $ 12 $ — $ — $ 2 $ 1
Noncurrent 14 7 7 7 — — — —
Total Derivative Assets – Commodity Contracts $ 46 $ 24 $ 19 $ 19 $ — $ — $ 2 $ 1
Interest Rate Contracts
Designated as Hedging Instruments
Current $ 31 $ — $ — $ — $ — $ — $ — $ —
Not Designated as Hedging Instruments
Current $ 129 $ 38 $ 84 $ 81 $ 3 $ — $ — $ —
Total Derivative Assets – Interest Rate Contracts $ 160 $ 38 $ 84 $ 81 $ 3 $ — $ — $ —
Total Derivative Assets $ 206 $ 62 $ 103 $ 100 $ 3 $ — $ 2 $ 1


Derivative Liabilities		March 31, 2021
Derivative Assets																		Derivative Assets	March 31, 2022
				Duke				Duke		Duke		Duke		Duke							Duke				Duke		Duke		Duke		Duke
		Duke		Energy		Progress		Energy		Energy		Energy		Energy					Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts	Commodity Contracts																	Commodity Contracts
Designated as Hedging Instruments
Current		$	19	$	—	$	—	$	—	$	—	$	—	$	—	—
Noncurrent		109		—		—		—		—		—		—		—

Not Designated as Hedging Instruments	Not Designated as Hedging Instruments																	Not Designated as Hedging Instruments
Current	Current	$	19	$	—	$	—	$	—	$	—	$	—	$	—	$	19	Current	$	673	$	335	$	295	$	255	$	40	$	—	$	28	$	7
Noncurrent	Noncurrent	154		—		25		9		—		—		—		129		Noncurrent	280		151		130		130		—		—		—		—
Total Derivative Liabilities – Commodity Contracts		$	301	$	—	$	25	$	9	$	—	$	—	$	—	$	148
Total Derivative Assets – Commodity Contracts																		Total Derivative Assets – Commodity Contracts	$	953	$	486	$	425	$	385	$	40	$	—	$	28	$	7
Interest Rate Contracts	Interest Rate Contracts																	Interest Rate Contracts
Designated as Hedging Instruments	Designated as Hedging Instruments																	Designated as Hedging Instruments
Current	Current	$	15	$	—	$	—	$	—	$	—	$	—	$	—	$	—	Current	$	94	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	Noncurrent	25		—		—		—		—		—		—		—		Noncurrent	37		—		—		—		—		—		—		—
Not Designated as Hedging Instruments	Not Designated as Hedging Instruments																	Not Designated as Hedging Instruments
Current		4		—		3		—		3		1		—		—

Noncurrent	Noncurrent	4		—		—		—		—		4		—		—		Noncurrent	24		7		—		—		—		—		17		—
Total Derivative Liabilities – Interest Rate Contracts		$	48	$	—	$	3	$	—	$	3	$	5	$	—	$	—
Total Derivative Assets – Interest Rate Contracts																		Total Derivative Assets – Interest Rate Contracts	$	155	$	7	$	—	$	—	$	—	$	—	$	17	$	—

Total Derivative Liabilities		$	349	$	—	$	28	$	9	$	3	$	5	$	—	$	148
Total Derivative Assets																		Total Derivative Assets	$	1,108	$	493	$	425	$	385	$	40	$	—	$	45	$	7

6358


FINANCIAL STATEMENTS			DERIVATIVES AND HEDGING


Derivative Assets		December 31, 2020
Derivative Liabilities																		Derivative Liabilities	March 31, 2022
				Duke				Duke		Duke		Duke		Duke							Duke				Duke		Duke		Duke		Duke
		Duke		Energy		Progress		Energy		Energy		Energy		Energy					Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts	Commodity Contracts																	Commodity Contracts

Designated as Hedging Instruments																		Designated as Hedging Instruments
Current																		Current	$	49	$	—	$	—	$	—	$	—	$	—	$	—	—
Noncurrent																		Noncurrent	160		—		—		—		—		—		—		—
Not Designated as Hedging Instruments	Not Designated as Hedging Instruments																	Not Designated as Hedging Instruments
Current	Current	$	30	$	14	$	9	$	9	$	—	$	1	$	6	$	1	Current	61		36		—		—		—		—		—		24
Noncurrent	Noncurrent	13		6		6		6		—		—		—		—		Noncurrent	149		1		—		—		—		—		—		149
Total Derivative Assets – Commodity Contracts		$	43	$	20	$	15	$	15	$	—	$	1	$	6	$	1
Total Derivative Liabilities – Commodity Contracts																		Total Derivative Liabilities – Commodity Contracts	$	419	$	37	$	—	$	—	$	—	$	—	$	—	$	173
Interest Rate Contracts	Interest Rate Contracts																	Interest Rate Contracts

Designated as Hedging Instruments																		Designated as Hedging Instruments
Current																		Current	$	4	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent																		Noncurrent	7		—		—		—		—		—		—		—
Not Designated as Hedging Instruments	Not Designated as Hedging Instruments																	Not Designated as Hedging Instruments
Current	Current	$	18	$	—	$	18	$	18	$	—	$	—	$	—	$	—	Current	1		—		—		—		—		1		—		—

Total Derivative Assets – Interest Rate Contracts		$	18	$	—	$	18	$	18	$	—	$	—	$	—	$	—
Noncurrent																		Noncurrent	2		—		—		—		—		2		—		—
Total Derivative Liabilities – Interest Rate Contracts																		Total Derivative Liabilities – Interest Rate Contracts	$	14	$	—	$	—	$	—	$	—	$	3	$	—	$	—

Total Derivative Assets		$	61	$	20	$	33	$	33	$	—	$	1	$	6	$	1
Total Derivative Liabilities																		Total Derivative Liabilities	$	433	$	37	$	—	$	—	$	—	$	3	$	—	$	173


Derivative Liabilities		December 31, 2020
Derivative Assets																		Derivative Assets	December 31, 2021
				Duke				Duke		Duke		Duke		Duke							Duke				Duke		Duke		Duke		Duke
		Duke		Energy		Progress		Energy		Energy		Energy		Energy					Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts	Commodity Contracts																	Commodity Contracts
Designated as Hedging Instruments
Current		$	14	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent		70		—		—		—		—		—		—		—

Not Designated as Hedging Instruments	Not Designated as Hedging Instruments																	Not Designated as Hedging Instruments
Current	Current	$	30	$	13	$	2	$	2	$	—	$	—	$	1	$	15	Current	$	199	$	99	$	72	$	72	$	—	$	2	$	23	$	3
Noncurrent	Noncurrent	137		3		27		12		—		—		—		107		Noncurrent	113		63		50		50		—		—		—		—
Total Derivative Liabilities – Commodity Contracts		$	251	$	16	$	29	$	14	$	—	$	—	$	1	$	122
Total Derivative Assets – Commodity Contracts																		Total Derivative Assets – Commodity Contracts	$	312	$	162	$	122	$	122	$	—	$	2	$	23	$	3
Interest Rate Contracts	Interest Rate Contracts																	Interest Rate Contracts
Designated as Hedging Instruments	Designated as Hedging Instruments																	Designated as Hedging Instruments
Current	Current	$	15	$	—	$	—	$	—	$	—	$	—	$	—	$	—	Current	$	3	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	Noncurrent	48		—		—		—		—		—		—		—		Noncurrent	3		—		—		—		—		—		—		—
Not Designated as Hedging Instruments	Not Designated as Hedging Instruments																	Not Designated as Hedging Instruments
Current	Current	5		4		—		—		—		1		—		—		Current	2		—		2		2		—		—		—		—
Noncurrent		5		—		—		—		—		5		—		—
Total Derivative Liabilities – Interest Rate Contracts		$	73	$	4	$	—	$	—	$	—	$	6	$	—	$	—

Total Derivative Assets – Interest Rate Contracts																		Total Derivative Assets – Interest Rate Contracts	$	8	$	—	$	2	$	2	$	—	$	—	$	—	$	—

Total Derivative Liabilities		$	324	$	20	$	29	$	14	$	—	$	6	$	1	$	122
Total Derivative Assets																		Total Derivative Assets	$	320	$	162	$	124	$	124	$	—	$	2	$	23	$	3

6459


FINANCIAL STATEMENTS			DERIVATIVES AND HEDGING


Derivative Liabilities	December 31, 2021
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Commodity Contracts
Designated as Hedging Instruments
Current	$	27	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	117		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	72		18		19		5		14		—		13		21
Noncurrent	132		9		5		5		—		—		—		118
Total Derivative Liabilities – Commodity Contracts	$	348	$	27	$	24	$	10	$	14	$	—	$	13	$	139
Interest Rate Contracts
Designated as Hedging Instruments
Current	$	75	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Noncurrent	21		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	10		8		—		—		—		1		—		—
Noncurrent	18		—		—		—		—		4		14		—
Total Derivative Liabilities – Interest Rate Contracts	$	124	$	8	$	—	$	—	$	—	$	5	$	14	$	—








Total Derivative Liabilities	$	472	$	35	$	24	$	10	$	14	$	5	$	27	$	139

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, 2021
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 $ 192 $ 55 $ 96 $ 93 $ 3 $ — $ 2 $ 1
Gross amounts offset — — — — — — — —
Net amounts presented in Current Assets: Other $ 192 $ 55 $ 96 $ 93 $ 3 $ — $ 2 $ 1
Noncurrent
Gross amounts recognized $ 14 $ 7 $ 7 $ 7 $ — $ — $ — $ —
Gross amounts offset (4) — (4) (4) — — — —
Net amounts presented in Other Noncurrent Assets: Other $ 10 $ 7 $ 3 $ 3 $ — $ — $ — $ —

Derivative Liabilities March 31, 2021
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 $ 57 $ — $ 3 $ — $ 3 $ 1 $ — $ 19
Gross amounts offset — — — — — — — —
Net amounts presented in Current Liabilities: Other $ 57 $ — $ 3 $ — $ 3 $ 1 $ — $ 19
Noncurrent
Gross amounts recognized $ 292 $ — $ 25 $ 9 $ — $ 4 $ — $ 129
Gross amounts offset (4) — (4) (4) — — — —
Net amounts presented in Other Noncurrent Liabilities: Other $ 288 $ — $ 21 $ 5 $ — $ 4 $ — $ 129


Derivative Assets	Derivative Assets	December 31, 2020																Derivative Assets	March 31, 2022
				Duke				Duke		Duke		Duke		Duke							Duke				Duke		Duke		Duke		Duke
		Duke		Energy		Progress		Energy		Energy		Energy		Energy					Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Current	Current																	Current
Gross amounts recognized	Gross amounts recognized	$	48	$	14	$	27	$	27	$	—	$	1	$	6	$	1	Gross amounts recognized	$	767	$	335	$	295	$	255	$	40	$	—	$	28	$	7
Gross amounts offset	Gross amounts offset	(3)		(2)		(2)		(2)		—		—		—		—		Gross amounts offset	(255)		(149)		(106)		(106)		—		—		—		—
Net amounts presented in Current Assets: Other	Net amounts presented in Current Assets: Other	$	45	$	12	$	25	$	25	$	—	$	1	$	6	$	1	Net amounts presented in Current Assets: Other	$	512	$	186	$	189	$	149	$	40	$	—	$	28	$	7
Noncurrent	Noncurrent																	Noncurrent
Gross amounts recognized	Gross amounts recognized	$	13	$	6	$	6	$	6	$	—	$	—	$	—	$	—	Gross amounts recognized	$	341	$	158	$	130	$	130	$	—	$	—	$	17	$	—
Gross amounts offset	Gross amounts offset	(5)		(1)		(4)		(4)		—		—		—		—		Gross amounts offset	(115)		(64)		(51)		(51)		—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	Net amounts presented in Other Noncurrent Assets: Other	$	8	$	5	$	2	$	2	$	—	$	—	$	—	$	—	Net amounts presented in Other Noncurrent Assets: Other	$	226	$	94	$	79	$	79	$	—	$	—	$	17	$	—

6560


FINANCIAL STATEMENTS			DERIVATIVES AND HEDGING


Derivative Liabilities	Derivative Liabilities	December 31, 2020																Derivative Liabilities	March 31, 2022
				Duke				Duke		Duke		Duke		Duke							Duke				Duke		Duke		Duke		Duke
		Duke		Energy		Progress		Energy		Energy		Energy		Energy					Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Current	Current																	Current
Gross amounts recognized	Gross amounts recognized	$	64	$	17	$	2	$	2	$	—	$	1	$	1	$	15	Gross amounts recognized	$	115	$	36	$	—	$	—	$	—	$	1	$	—	$	24
Gross amounts offset	Gross amounts offset	(3)		(2)		(2)		(2)		—		—		—		—		Gross amounts offset	—		—		—		—		—		—		—		—
Net amounts presented in Current Liabilities: Other	Net amounts presented in Current Liabilities: Other	$	61	$	15	$	—	$	—	$	—	$	1	$	1	$	15	Net amounts presented in Current Liabilities: Other	$	115	$	36	$	—	$	—	$	—	$	1	$	—	$	24
Noncurrent	Noncurrent																	Noncurrent
Gross amounts recognized	Gross amounts recognized	$	260	$	3	$	27	$	12	$	—	$	5	$	—	$	107	Gross amounts recognized	$	318	$	1	$	—	$	—	$	—	$	2	$	—	$	149
Gross amounts offset	Gross amounts offset	(5)		(1)		(4)		(4)		—		—		—		—		Gross amounts offset	—		—		—		—		—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	Net amounts presented in Other Noncurrent Liabilities: Other	$	255	$	2	$	23	$	8	$	—	$	5	$	—	$	107	Net amounts presented in Other Noncurrent Liabilities: Other	$	318	$	1	$	—	$	—	$	—	$	2	$	—	$	149


Derivative Assets	December 31, 2021
			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	$	204	$	99	$	74	$	74	$	—	$	2	$	23	$	3
Gross amounts offset	(25)		(16)		(9)		(9)		—		—		—		—
Net amounts presented in Current Assets: Other	$	179	$	83	$	65	$	65	$	—	$	2	$	23	$	3
Noncurrent
Gross amounts recognized	$	116	$	63	$	50	$	50	$	—	$	—	$	—	$	—
Gross amounts offset	(23)		(15)		(8)		(8)		—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	93	$	48	$	42	$	42	$	—	$	—	$	—	$	—


Derivative Liabilities	December 31, 2021
			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	$	184	$	26	$	19	$	5	$	14	$	1	$	13	$	21
Gross amounts offset	(11)		(6)		(5)		(5)		—		—		—		—
Net amounts presented in Current Liabilities: Other	$	173	$	20	$	14	$	—	$	14	$	1	$	13	$	21
Noncurrent
Gross amounts recognized	$	288	$	9	$	5	$	5	$	—	$	4	$	14	$	118
Gross amounts offset	(12)		(8)		(5)		(5)		—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	276	$	1	$	—	$	—	$	—	$	4	$	14	$	118

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.


FINANCIAL STATEMENTS			INVESTMENTS IN DEBT AND EQUITY SECURITIES

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 investment manager agreements and 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 a credit loss exists, the unrealized credit loss is included in earnings. There were no material credit losses as of March 31, ~~2021,~~2022, and December 31, ~~2020.~~2021.

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


~~FINANCIAL STATEMENTS~~			~~INVESTMENTS IN DEBT AND EQUITY SECURITIES~~

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, 2021						December 31, 2020							March 31, 2022						December 31, 2021
		Gross		Gross				Gross		Gross					Gross		Gross				Gross		Gross
		Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated			Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
		Holding		Holding		Fair		Holding		Holding		Fair			Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	(in millions)	Gains		Losses		Value		Gains		Losses		Value		(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF	NDTF													NDTF
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	$	193	$	—	$	—	$	177	Cash and cash equivalents	$	—	$	—	$	128	$	—	$	—	$	160
Equity securities	Equity securities	4,363		47		6,379		4,138		54		6,235		Equity securities	4,486		62		6,853		4,905		43		7,350
Corporate debt securities	Corporate debt securities	38		8		793		76		1		806		Corporate debt securities	9		43		786		39		6		829
Municipal bonds	Municipal bonds	13		1		299		22		—		370		Municipal bonds	2		16		321		14		1		314
U.S. government bonds	U.S. government bonds	31		18		1,559		51		—		1,361		U.S. government bonds	10		57		1,561		31		12		1,568

Other debt securities	Other debt securities	5		—		184		8		—		180		Other debt securities	—		7		177		3		1		180
Total NDTF Investments	Total NDTF Investments	$	4,450	$	74	$	9,407	$	4,295	$	55	$	9,129	Total NDTF Investments	$	4,507	$	185	$	9,826	$	4,992	$	63	$	10,401
Other Investments	Other Investments													Other Investments
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	$	222	$	—	$	—	$	127	Cash and cash equivalents	$	—	$	—	$	110	$	—	$	—	$	36
Equity securities	Equity securities	86		—		154		79		—		146		Equity securities	31		4		147		36		—		156
Corporate debt securities	Corporate debt securities	2		—		109		8		—		110		Corporate debt securities	—		7		124		2		1		119
Municipal bonds	Municipal bonds	3		1		77		5		—		86		Municipal bonds	1		2		83		3		1		80
U.S. government bonds	U.S. government bonds	—		1		55		—		—		42		U.S. government bonds	—		2		45		—		—		56
Other debt securities	Other debt securities	—		1		36		—		—		47		Other debt securities	—		2		36		—		1		45
Total Other Investments	Total Other Investments	$	91	$	3	$	653	$	92	$	—	$	558	Total Other Investments	$	32	$	17	$	545	$	41	$	3	$	492
Total Investments	Total Investments	$	4,541	$	77	$	10,060	$	4,387	$	55	$	9,687	Total Investments	$	4,539	$	202	$	10,371	$	5,033	$	66	$	10,893

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months endedMarch 31, ~~2021,~~2022, and ~~2020,~~2021, were as follows.


	Three Months Ended
(in millions)		March 31, 2022		March 31, 2021
FV-NI:
Realized gains		$	111	$	140
Realized losses		85		23
AFS:
Realized gains		4		18
Realized losses		23		13


FINANCIAL STATEMENTS			INVESTMENTS IN DEBT AND EQUITY SECURITIES

Three Months Ended
(in millions) March 31, 2021 March 31, 2020
FV-NI:
Realized gains $ 140 $ 23
Realized losses 23 65
AFS:
Realized gains 18 20
Realized losses 13 6

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, 2021						December 31, 2020							March 31, 2022						December 31, 2021
		Gross		Gross				Gross		Gross					Gross		Gross				Gross		Gross
		Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated			Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
		Holding		Holding		Fair		Holding		Holding		Fair			Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	(in millions)	Gains		Losses		Value		Gains		Losses		Value		(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF	NDTF													NDTF
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	$	63	$	—	$	—	$	30	Cash and cash equivalents	$	—	$	—	$	60	$	—	$	—	$	53
Equity securities	Equity securities	2,531		23		3,738		2,442		23		3,685		Equity securities	2,632		30		3,962		2,887		19		4,265
Corporate debt securities	Corporate debt securities	23		5		475		49		1		510		Corporate debt securities	6		30		503		24		4		506
Municipal bonds	Municipal bonds	—		—		22		6		—		91		Municipal bonds	—		5		52		2		—		48
U.S. government bonds	U.S. government bonds	16		9		669		25		—		475		U.S. government bonds	4		21		692		16		3		712
Other debt securities	Other debt securities	4		—		178		7		—		174		Other debt securities	—		7		172		3		1		175
Total NDTF Investments	Total NDTF Investments	$	2,574	$	37	$	5,145	$	2,529	$	24	$	4,965	Total NDTF Investments	$	2,642	$	93	$	5,441	$	2,932	$	27	$	5,759

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, 2022, and 2021, were as follows.


	Three Months Ended
(in millions)		March 31, 2022		March 31, 2021
FV-NI:
Realized gains		$	75	$	128
Realized losses		49		16
AFS:
Realized gains		3		13
Realized losses		16		9

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, 2022						December 31, 2021
	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	$	—	$	—	$	68	$	—	$	—	$	107
Equity securities	1,854		32		2,891		2,018		24		3,085
Corporate debt securities	3		13		283		15		2		323
Municipal bonds	2		11		269		12		1		266
U.S. government bonds	6		36		869		15		9		856

Other debt securities	—		—		5		—		—		5
Total NDTF Investments	$	1,865	$	92	$	4,385	$	2,060	$	36	$	4,642
Other Investments
Cash and cash equivalents	$	—	$	—	$	17	$	—	$	—	$	20

Municipal bonds	1		—		26		2		—		26
Total Other Investments	$	1	$	—	$	43	$	2	$	—	$	46
Total Investments	$	1,866	$	92	$	4,428	$	2,062	$	36	$	4,688

6763


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, ~~2021,~~2022, and ~~2020,~~2021, were as follows.

Three Months Ended
(in millions) March 31, 2021 March 31, 2020
FV-NI:
Realized gains $ 128 $ 9
Realized losses 16 45
AFS:
Realized gains 13 12
Realized losses 9 5

~~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, 2021 December 31, 2020
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 $ — $ — $ 130 $ — $ — $ 147
Equity securities 1,832 24 2,641 1,696 31 2,550
Corporate debt securities 15 3 318 27 — 296
Municipal bonds 13 1 277 16 — 279
U.S. government bonds 15 9 890 26 — 886
Other debt securities 1 — 6 1 — 6
Total NDTF Investments $ 1,876 $ 37 $ 4,262 $ 1,766 $ 31 $ 4,164
Other Investments
Cash and cash equivalents $ — $ — $ 107 $ — $ — $ 106
Municipal bonds 2 — 26 3 — 26
Total Other Investments $ 2 $ — $ 133 $ 3 $ — $ 132
Total Investments $ 1,878 $ 37 $ 4,395 $ 1,769 $ 31 $ 4,296

~~Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three months endedMarch 31, 2021, and 2020, were as follows.~~

Three Months Ended
(in millions) March 31, 2021 March 31, 2020
FV-NI:
Realized gains $ 12 $ 14
Realized losses 7 20
AFS:
Realized gains 4 5
Realized losses 3 1


~~FINANCIAL STATEMENTS~~			~~INVESTMENTS IN DEBT AND EQUITY SECURITIES~~


	Three Months Ended
(in millions)		March 31, 2022		March 31, 2021
FV-NI:
Realized gains		$	36	$	12
Realized losses		36		7
AFS:
Realized gains		1		4
Realized losses		6		3

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, 2021						December 31, 2020							March 31, 2022						December 31, 2021
		Gross		Gross				Gross		Gross					Gross		Gross				Gross		Gross
		Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated			Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
		Holding		Holding		Fair		Holding		Holding		Fair			Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	(in millions)	Gains		Losses		Value		Gains		Losses		Value		(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF	NDTF													NDTF
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	$	95	$	—	$	—	$	76	Cash and cash equivalents	$	—	$	—	$	58	$	—	$	—	$	94
Equity securities	Equity securities	1,746		24		2,547		1,617		31		2,459		Equity securities	1,757		32		2,782		1,915		23		2,970
Corporate debt securities	Corporate debt securities	15		3		291		27		—		296		Corporate debt securities	3		12		255		15		2		282
Municipal bonds	Municipal bonds	13		1		277		16		—		279		Municipal bonds	2		11		269		12		1		266
U.S. government bonds	U.S. government bonds	15		4		429		26		—		412		U.S. government bonds	6		19		502		15		3		472
Other debt securities	Other debt securities	1		—		6		1		—		6		Other debt securities	—		—		5		—		—		5
Total NDTF Investments	Total NDTF Investments	$	1,790	$	32	$	3,645	$	1,687	$	31	$	3,528	Total NDTF Investments	$	1,768	$	74	$	3,871	$	1,957	$	29	$	4,089
Other Investments	Other Investments													Other Investments
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	1	Cash and cash equivalents	$	—	$	—	$	14	$	—	$	—	$	16
Total Other Investments	Total Other Investments	$	—	$	—	$	1	$	—	$	—	$	1	Total Other Investments	$	—	$	—	$	14	$	—	$	—	$	16
Total Investments	Total Investments	$	1,790	$	32	$	3,646	$	1,687	$	31	$	3,529	Total Investments	$	1,768	$	74	$	3,885	$	1,957	$	29	$	4,105


	Three Months Ended
(in millions)		March 31, 2022		March 31, 2021
FV-NI:
Realized gains		$	36	$	12
Realized losses		35		7
AFS:
Realized gains		1		4
Realized losses		5		3


FINANCIAL STATEMENTS			INVESTMENTS IN DEBT AND EQUITY SECURITIES

Three Months Ended
(in millions) March 31, 2021 March 31, 2020
FV-NI:
Realized gains $ 12 $ 14
Realized losses 7 20
AFS:
Realized gains 4 5
Realized losses 3 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, 2021						December 31, 2020							March 31, 2022						December 31, 2021
		Gross		Gross				Gross		Gross					Gross		Gross				Gross		Gross
		Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated			Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
		Holding		Holding		Fair		Holding		Holding		Fair			Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	(in millions)	Gains		Losses		Value		Gains		Losses		Value		(in millions)	Gains		Losses		Value		Gains		Losses		Value
NDTF	NDTF													NDTF
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	$	35	$	—	$	—	$	71	Cash and cash equivalents	$	—	$	—	$	10	$	—	$	—	$	13
Equity securities	Equity securities	86		—		94		79		—		91		Equity securities	97		—		109		103		1		115
Corporate debt securities	Corporate debt securities	—		—		27		—		—		—		Corporate debt securities	—		1		28		—		—		41

U.S. government bonds	U.S. government bonds	—		5		461		—		—		474		U.S. government bonds	—		17		367		—		6		384

Total NDTF Investments(a)	Total NDTF Investments(a)	$	86	$	5	$	617	$	79	$	—	$	636	Total NDTF Investments(a)	$	97	$	18	$	514	$	103	$	7	$	553
Other Investments	Other Investments													Other Investments
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	1	Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	3

Municipal bonds	Municipal bonds	2		—		26		3		—		26		Municipal bonds	1		—		26		2		—		26
Total Other Investments	Total Other Investments	$	2	$	—	$	28	$	3	$	—	$	27	Total Other Investments	$	1	$	—	$	28	$	2	$	—	$	29
Total Investments	Total Investments	$	88	$	5	$	645	$	82	$	—	$	663	Total Investments	$	98	$	18	$	542	$	105	$	7	$	582

(a)During the three months ended March 31, ~~2021,~~2022, and the year ended December 31, ~~2020,~~2021, Duke Energy Florida received reimbursements from the NDTF for costs related to ongoing decommissioning activity of Crystal River Unit 3.


~~FINANCIAL STATEMENTS~~			~~INVESTMENTS IN DEBT AND EQUITY SECURITIES~~

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, 2021						December 31, 2020							March 31, 2022						December 31, 2021
		Gross		Gross				Gross		Gross					Gross		Gross				Gross		Gross
		Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated			Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
		Holding		Holding		Fair		Holding		Holding		Fair			Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	(in millions)	Gains		Losses		Value		Gains		Losses		Value		(in millions)	Gains		Losses		Value		Gains		Losses		Value
Investments	Investments													Investments
Cash and cash equivalents	Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	1	Cash and cash equivalents	$	—	$	—	$	1	$	—	$	—	$	—
Equity securities	Equity securities	62		—		102		58		—		97		Equity securities	4		4		91		6		—		97
Corporate debt securities	Corporate debt securities	—		—		4		—		—		3		Corporate debt securities	—		—		8		—		—		6
Municipal bonds	Municipal bonds	1		1		35		1		—		38		Municipal bonds	—		2		49		1		1		46
U.S. government bonds	U.S. government bonds	—		—		6		—		—		4		U.S. government bonds	—		—		6		—		—		12

Total Investments	Total Investments	$	63	$	1	$	147	$	59	$	—	$	143	Total Investments	$	4	$	6	$	155	$	7	$	1	$	161

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, ~~2021,~~2022, and ~~2020,~~2021, were immaterial.

DEBT SECURITY MATURITIES

The table below summarizes the maturity date for debt securities.


		March 31, 2021													March 31, 2022
				Duke				Duke		Duke		Duke					Duke				Duke		Duke		Duke
		Duke		Energy		Progress		Energy		Energy		Energy			Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana
Due in one year or less	Due in one year or less	$	152	$	7	$	116	$	18	$	98	$	5	Due in one year or less	$	162	$	7	$	139	$	32	$	107	$	8
Due after one through five years	Due after one through five years	1,013		375		579		267		312		18		Due after one through five years	969		367		528		270		258		24
Due after five through 10 years	Due after five through 10 years	693		310		289		217		72		9		Due after five through 10 years	536		235		228		212		16		6
Due after 10 years	Due after 10 years	1,254		652		533		501		32		13		Due after 10 years	1,466		810		557		517		40		25
Total	Total	$	3,112	$	1,344	$	1,517	$	1,003	$	514	$	45	Total	$	3,133	$	1,419	$	1,452	$	1,031	$	421	$	63


FINANCIAL STATEMENTS			FAIR VALUE MEASUREMENTS

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.


~~FINANCIAL STATEMENTS~~			~~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. Commodity derivatives with observable forward curves are classified as Level 2. If forward price curves are not observable for the full term of the contract and the unobservable period had more than an insignificant impact on the valuation, the commodity derivative is classified as Level 3. In isolation, increases (decreases) in natural gas forward prices result in favorable (unfavorable) fair value adjustments for natural gas purchase contracts; and increases (decreases) in electricity forward prices result in unfavorable (favorable) fair value adjustments for electricity sales contracts. Duke Energy regularly evaluates and validates pricing inputs used to estimate the fair value of natural gas commodity contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.

Interest rate derivatives

Most over-the-counter interest rate contract derivatives are valued using financial models that utilize observable inputs for similar instruments and are classified as Level 2. Inputs include forward interest rate curves, notional amounts, interest rates and credit quality of the counterparties.

Other fair value considerations

See Note 11 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, ~~2020,~~2021, for a discussion of the valuation of goodwill and intangible assets.


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, 2021											March 31, 2022
(in millions)	(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Not Categorized		(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Not Categorized
NDTF cash and cash equivalents	NDTF cash and cash equivalents	$	193	$	193	$	—	$	—	$	—	NDTF cash and cash equivalents	$	128	$	128	$	—	$	—	$	—
NDTF equity securities	NDTF equity securities	6,379		6,332		—		—		47		NDTF equity securities	6,853		6,806		—		—		47
NDTF debt securities	NDTF debt securities	2,835		1,019		1,816		—		—		NDTF debt securities	2,845		947		1,898		—		—
Other equity securities	Other equity securities	154		154		—		—		—		Other equity securities	147		147		—		—		—
Other debt securities	Other debt securities	277		49		228		—		—		Other debt securities	288		39		249		—		—
Other cash and cash equivalents	Other cash and cash equivalents	222		222		—		—		—		Other cash and cash equivalents	110		110		—		—		—

Derivative assets	Derivative assets	206		1		203		2		—		Derivative assets	1,108		27		1,071		10		—
Total assets	Total assets	10,266		7,970		2,247		2		47		Total assets	11,479		8,204		3,218		10		47

Derivative liabilities	Derivative liabilities	(349)		—		(221)		(128)		—		Derivative liabilities	(433)		—		(224)		(209)		—
Net assets (liabilities)	Net assets (liabilities)	$	9,917	$	7,970	$	2,026	$	(126)	$	47	Net assets (liabilities)	$	11,046	$	8,204	$	2,994	$	(199)	$	47


		December 31, 2020											December 31, 2021
(in millions)	(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Not Categorized		(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Not Categorized
NDTF cash and cash equivalents	NDTF cash and cash equivalents	$	177	$	177	$	—	$	—	$	—	NDTF cash and cash equivalents	$	160	$	160	$	—	$	—	$	—
NDTF equity securities	NDTF equity securities	6,235		6,189		—		—		46		NDTF equity securities	7,350		7,300		—		—		50
NDTF debt securities	NDTF debt securities	2,717		874		1,843		—		—		NDTF debt securities	2,891		967		1,924		—		—
Other equity securities	Other equity securities	146		146		—		—		—		Other equity securities	156		156		—		—		—
Other debt securities	Other debt securities	285		37		248		—		—		Other debt securities	300		45		255		—		—
Other cash and cash equivalents	Other cash and cash equivalents	127		127		—		—		—		Other cash and cash equivalents	36		36		—		—		—
Derivative assets	Derivative assets	61		1		53		7		—		Derivative assets	320		3		293		24		—
Total assets	Total assets	9,748		7,551		2,144		7		46		Total assets	11,213		8,667		2,472		24		50

Derivative liabilities	Derivative liabilities	(324)		—		(240)		(84)		—		Derivative liabilities	(472)		(13)		(314)		(145)		—
Net assets (liabilities)	Net assets (liabilities)	$	9,424	$	7,551	$	1,904	$	(77)	$	46	Net assets (liabilities)	$	10,741	$	8,654	$	2,158	$	(121)	$	50


~~FINANCIAL STATEMENTS~~			~~FAIR VALUE MEASUREMENTS~~

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


			Derivatives (net)							Derivatives (net)
		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)			2021		2020		(in millions)		2022		2021
Balance at beginning of period	Balance at beginning of period			$	(77)	$	(102)	Balance at beginning of period		$	(121)	$	(77)

Total pretax realized or unrealized losses included in comprehensive income	Total pretax realized or unrealized losses included in comprehensive income			(44)		—		Total pretax realized or unrealized losses included in comprehensive income		(68)		(44)
Purchases, sales, issuances and settlements:	Purchases, sales, issuances and settlements:							Purchases, sales, issuances and settlements:

Settlements	Settlements			(7)		(9)		Settlements		(3)		(7)

Total gains included on the Condensed Consolidated Balance Sheet				2		23
Total (losses) gains included on the Condensed Consolidated Balance Sheet								Total (losses) gains included on the Condensed Consolidated Balance Sheet		(7)		2
Balance at end of period	Balance at end of period			$	(126)	$	(88)	Balance at end of period		$	(199)	$	(126)


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, 2021								March 31, 2022
(in millions)	(in millions)	Total Fair Value		Level 1		Level 2		Not Categorized			(in millions)	Total Fair Value		Level 1		Level 2		Not Categorized
NDTF cash and cash equivalents	NDTF cash and cash equivalents	$	63	$	63	$	—	$	—		NDTF cash and cash equivalents	$	60	$	60	$	—	$	—
NDTF equity securities	NDTF equity securities	3,738		3,691		—		47			NDTF equity securities	3,962		3,915		—		47
NDTF debt securities	NDTF debt securities	1,344		369		975		—			NDTF debt securities	1,419		349		1,070		—

Derivative assets	Derivative assets	62		—		62		—			Derivative assets	493		—		493		—
Total assets	Total assets	5,207		4,123		1,037		47			Total assets	5,934		4,324		1,563		47

Derivative liabilities											Derivative liabilities	(37)		—		(37)		—
Net assets											Net assets	$	5,897	$	4,324	$	1,526	$	47


		December 31, 2020								December 31, 2021
(in millions)	(in millions)	Total Fair Value		Level 1		Level 2		Not Categorized			(in millions)	Total Fair Value		Level 1		Level 2		Not Categorized
NDTF cash and cash equivalents	NDTF cash and cash equivalents	$	30	$	30	$	—	$	—		NDTF cash and cash equivalents	$	53	$	53	$	—	$	—
NDTF equity securities	NDTF equity securities	3,685		3,639		—		46			NDTF equity securities	4,265		4,215		—		50
NDTF debt securities	NDTF debt securities	1,250		192		1,058		—			NDTF debt securities	1,441		339		1,102		—

Derivative assets	Derivative assets	20		—		20		—			Derivative assets	162		—		162		—
Total assets	Total assets	4,985		3,861		1,078		46			Total assets	5,921		4,607		1,264		50
Derivative liabilities	Derivative liabilities	(20)		—		(20)		—			Derivative liabilities	(35)		—		(35)		—
Net assets	Net assets	$	4,965	$	3,861	$	1,058	$	46		Net assets	$	5,886	$	4,607	$	1,229	$	50

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, 2021 December 31, 2020
(in millions) Total Fair Value Level 1 Level 2 Total Fair Value Level 1 Level 2
NDTF cash and cash equivalents $ 130 $ 130 $ — $ 147 $ 147 $ —
NDTF equity securities 2,641 2,641 — 2,550 2,550 —
NDTF debt securities 1,491 650 841 1,467 682 785
Other debt securities 26 — 26 26 — 26
Other cash and cash equivalents 107 107 — 106 106 —
Derivative assets 103 — 103 33 — 33
Total assets 4,498 3,528 970 4,329 3,485 844
Derivative liabilities (28) — (28) (29) — (29)
Net assets $ 4,470 $ 3,528 $ 942 $ 4,300 $ 3,485 $ 815


~~FINANCIAL STATEMENTS~~			~~FAIR VALUE MEASUREMENTS~~


	March 31, 2022						December 31, 2021
(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2
NDTF cash and cash equivalents	$	68	$	68	$	—	$	107	$	107	$	—
NDTF equity securities	2,891		2,891		—		3,085		3,085		—
NDTF debt securities	1,426		598		828		1,450		628		822
Other debt securities	26		—		26		26		—		26
Other cash and cash equivalents	17		17		—		20		20		—

Derivative assets	425		2		423		124		—		124
Total assets	4,853		3,576		1,277		4,812		3,840		972

Derivative liabilities	—		—		—		(24)		—		(24)
Net assets	$	4,853	$	3,576	$	1,277	$	4,788	$	3,840	$	948

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, 2021						December 31, 2020						March 31, 2022		December 31, 2021
(in millions)	(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2			(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2
NDTF cash and cash equivalents	NDTF cash and cash equivalents	$	95	$	95	$	—	$	76	$	76	$	—		NDTF cash and cash equivalents	$	58	$	58	$	—	$	94	$	94	$	—
NDTF equity securities	NDTF equity securities	2,547		2,547		—		2,459		2,459		—			NDTF equity securities	2,782		2,782		—		2,970		2,970		—
NDTF debt securities	NDTF debt securities	1,003		237		766		993		237		756			NDTF debt securities	1,031		279		752		1,025		289		736

Other cash and cash equivalents	Other cash and cash equivalents	1		1		—		1		1		—			Other cash and cash equivalents	14		14		—		16		16		—
Derivative assets	Derivative assets	100		—		100		33		—		33			Derivative assets	385		2		383		124		—		124
Total assets	Total assets	3,746		2,880		866		3,562		2,773		789			Total assets	4,270		3,135		1,135		4,229		3,369		860
Derivative liabilities	Derivative liabilities	(9)		—		(9)		(14)		—		(14)			Derivative liabilities	—		—		—		(10)		—		(10)
Net assets	Net assets	$	3,737	$	2,880	$	857	$	3,548	$	2,773	$	775		Net assets	$	4,270	$	3,135	$	1,135	$	4,219	$	3,369	$	850


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, 2021						December 31, 2020						March 31, 2022		December 31, 2021
(in millions)	(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2			(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2
NDTF cash and cash equivalents	NDTF cash and cash equivalents	$	35	$	35	$	—	$	71	$	71	$	—		NDTF cash and cash equivalents	$	10	$	10	$	—	$	13	$	13	$	—
NDTF equity securities	NDTF equity securities	94		94		—		91		91		—			NDTF equity securities	109		109		—		115		115		—
NDTF debt securities	NDTF debt securities	488		413		75		474		445		29			NDTF debt securities	395		319		76		425		339		86
Other debt securities	Other debt securities	26		—		26		26		—		26			Other debt securities	26		—		26		26		—		26
Other cash and cash equivalents	Other cash and cash equivalents	2		2		—		1		1		—			Other cash and cash equivalents	2		2		—		3		3		—

Derivative assets	Derivative assets	3		—		3		—		—		—			Derivative assets	40		—		40		—		—		—
Total assets	Total assets	648		544		104		663		608		55			Total assets	582		440		142		582		470		112

Derivative liabilities	Derivative liabilities	(3)		—		(3)		—		—		—			Derivative liabilities	—		—		—		(14)		—		(14)
Net assets	Net assets	$	645	$	544	$	101	$	663	$	608	$	55		Net assets	$	582	$	440	$	142	$	568	$	470	$	98

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, ~~2021,~~2022, and December 31, ~~2020~~.2021.

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, 2021 December 31, 2020
(in millions) Total Fair Value Level 1 Level 2 Level 3 Total Fair Value Level 1 Level 2 Level 3
Other equity securities $ 102 $ 102 $ — $ — $ 97 $ 97 $ — $ —
Other debt securities 45 — 45 — 45 — 45 —
Other cash and cash equivalents — — — — 1 1 — —
Derivative assets 2 — — 2 6 — — 6
Total assets $ 149 $ 102 $ 45 $ 2 $ 149 $ 98 $ 45 $ 6
Derivative liabilities — — — — (1) (1) — —
Net assets $ 149 $ 102 $ 45 $ 2 $ 148 $ 97 $ 45 $ 6


~~FINANCIAL STATEMENTS~~			~~FAIR VALUE MEASUREMENTS~~


	March 31, 2022								December 31, 2021
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Total Fair Value		Level 1		Level 2		Level 3
Other equity securities	$	91	$	91	$	—	$	—	$	97	$	97	$	—	$	—
Other debt securities	63		—		63		—		64		—		64		—
Other cash and cash equivalents	1		1		—		—		—		—		—		—
Derivative assets	45		18		17		10		23		1		—		22
Total assets	200		110		80		10		184		98		64		22
Derivative liabilities	—		—		—		—		(27)		(13)		(14)		—
Net assets	$	200	$	110	$	80	$	10	$	157	$	85	$	50	$	22

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)							Derivatives (net)
		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)			2021		2020		(in millions)		2022		2021
Balance at beginning of period	Balance at beginning of period			$	6	$	11	Balance at beginning of period		$	22	$	6

Purchases, sales, issuances and settlements:	Purchases, sales, issuances and settlements:							Purchases, sales, issuances and settlements:

Settlements	Settlements			(6)		(6)		Settlements		(6)		(6)

Total gains (losses) included on the Condensed Consolidated Balance Sheet				2		(3)
Total (losses) gains included on the Condensed Consolidated Balance Sheet								Total (losses) gains included on the Condensed Consolidated Balance Sheet		(6)		2
Balance at end of period	Balance at end of period			$	2	$	2	Balance at end of period		$	10	$	2

PIEDMONT

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


		March 31, 2021						December 31, 2020							March 31, 2022						December 31, 2021
(in millions)	(in millions)	Total Fair Value		Level 1		Level 2			Total Fair Value		Level 1		Level 2			(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2

Derivative assets	Derivative assets	$	1	$	1	$	—		$	1	$	1	$	—		Derivative assets	$	7	$	7	$	—	$	3	$	3	$	—

Derivative liabilities	Derivative liabilities	(148)		—		(148)			(122)		—		(122)			Derivative liabilities	(173)		—		(173)		(139)		—		(139)
Net (liabilities) assets	Net (liabilities) assets	$	(147)	$	1	$	(148)		$	(121)	$	1	$	(122)		Net (liabilities) assets	$	(166)	$	7	$	(173)	$	(136)	$	3	$	(139)

~~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) 2021 2020
Balance at beginning of period $ — $ (117)
Total gains and settlements — 26
Balance at end of period $ — $ (91)


FINANCIAL STATEMENTS			FAIR VALUE MEASUREMENTS

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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


		March 31, 2021												March 31, 2022
											Weighted												Weighted
		Fair Value									Average			Fair Value									Average
Investment Type	Investment Type	(in millions)		Valuation Technique	Unobservable Input	Range					Range		Investment Type	(in millions)		Valuation Technique	Unobservable Input	Range					Range
Duke Energy	Duke Energy												Duke Energy

Electricity contracts	Electricity contracts	$	(128)	RTO forward pricing	Forward electricity curves – price per MWh	$	15.55	-	$	134.48	$	34.80	Electricity contracts	$	(210)	RTO forward pricing	Forward electricity curves – price per MWh	$	20.33	-	$	187.82	$	46.51

Duke Energy Ohio													Duke Energy Ohio

FTRs													FTRs	1		RTO auction pricing	FTR price – per MWh	0.16		-	1.26		0.63

Duke Energy Indiana	Duke Energy Indiana												Duke Energy Indiana
FTRs	FTRs	2		RTO auction pricing	FTR price – per MWh	(1.02)		-	7.23		0.80		FTRs	10		RTO auction pricing	FTR price – per MWh	(0.46)		-	17.24		2.32

Duke Energy	Duke Energy												Duke Energy
Total Level 3 derivatives	Total Level 3 derivatives	$	(126)										Total Level 3 derivatives	$	(199)


~~FINANCIAL STATEMENTS~~			~~FAIR VALUE MEASUREMENTS~~


		December 31, 2020										December 31, 2021
										Weighted										Weighted
		Fair Value								Average		Fair Value								Average
Investment Type	Investment Type	(in millions)		Valuation Technique	Unobservable Input	Range				Range	Investment Type	(in millions)		Valuation Technique	Unobservable Input	Range				Range
Duke Energy	Duke Energy										Duke Energy

Electricity contracts	Electricity contracts	$	(84)	Discounted cash flow	Forward electricity curves – price per MWh	$	14.68	-	$151.84	$28.84	Electricity contracts	$	(145)	RTO forward pricing	Forward electricity curves – price per MWh	$	19.04	-	$139.11	$37.57

Duke Energy Ohio	Duke Energy Ohio										Duke Energy Ohio

FTRs	FTRs	1		RTO auction pricing	FTR price – per MWh	0.25		-	1.68	0.79	FTRs	2		RTO auction pricing	FTR price – per MWh	0.06		-	1.79	0.96

Duke Energy Indiana	Duke Energy Indiana										Duke Energy Indiana
FTRs	FTRs	6		RTO auction pricing	FTR price – per MWh	(2.40)		-	7.41	1.05	FTRs	22		RTO auction pricing	FTR price – per MWh	(1.18)		-	13.11	2.68

Duke Energy	Duke Energy										Duke Energy
Total Level 3 derivatives	Total Level 3 derivatives	$	(77)								Total Level 3 derivatives	$	(121)

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, 2021				December 31, 2020					March 31, 2022				December 31, 2021
(in millions)	(in millions)	Book Value		Fair Value		Book Value		Fair Value		(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy(a)	Duke Energy(a)	$	60,354	$	64,641	$	59,863	$	69,292	Duke Energy(a)	$	66,080	$	66,633	$	63,835	$	69,683
Duke Energy Carolinas	Duke Energy Carolinas	12,329		13,461		12,218		14,917		Duke Energy Carolinas	14,470		15,117		13,275		15,101
Progress Energy	Progress Energy	19,333		21,838		19,264		23,470		Progress Energy	21,657		22,669		20,823		23,751
Duke Energy Progress	Duke Energy Progress	9,356		10,131		9,258		10,862		Duke Energy Progress	11,114		11,260		10,249		11,252
Duke Energy Florida	Duke Energy Florida	7,884		9,018		7,915		9,756		Duke Energy Florida	8,451		8,911		8,482		9,772
Duke Energy Ohio	Duke Energy Ohio	3,090		3,397		3,089		3,650		Duke Energy Ohio	3,193		3,278		3,193		3,570
Duke Energy Indiana	Duke Energy Indiana	4,091		4,691		4,091		5,204		Duke Energy Indiana	4,270		4,554		4,323		5,067
Piedmont	Piedmont	3,127		3,412		2,780		3,306		Piedmont	2,969		2,984		2,968		3,278

(a)Book value of long-term debt includes ~~$1.3~~$1.2 billion and $1.25 billion at March 31, ~~2021,~~2022, and December 31, ~~2020,~~2021, respectively, of net 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, ~~2021,~~2022, and December 31, ~~2020,~~2021, 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.

~~NaN~~


FINANCIAL STATEMENTS			VARIABLE INTEREST ENTITIES

No financial support was provided to any of the consolidated VIEs during the three months ended March 31, ~~2021,~~2022, and the year ended December 31, ~~2020,~~2021, 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, which generally exclude receivables past due more than a predetermined number of days and reserves for expected past-due balances. The sole source of funds to satisfy the related debt obligations is cash collections from the receivables. Amounts borrowed under the credit facilities ~~for DERF and DEPR~~ are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt. ~~Amounts borrowed under the credit facilities for DEFR are reflected on the Condensed Consolidated Balance Sheets as Current maturities of 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.


~~FINANCIAL STATEMENTS~~			~~VARIABLE INTEREST ENTITIES~~

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, which generally exclude receivables past due more than a predetermined number of days and reserves for expected past-due balances. 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.

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 2023
Credit facility amount $ 350 $ 475 $ 350 $ 250
Amounts borrowed at March 31, 2021 350 430 350 250
Amounts borrowed at December 31, 2020 350 364 250 250
Restricted Receivables at March 31, 2021 472 613 422 323
Restricted Receivables at December 31, 2020 547 696 500 397


	Duke Energy
			Duke Energy		Duke Energy		Duke Energy
			Carolinas		Progress		Florida
(in millions)	CRC		DERF		DEPR		DEFR
Expiration date	February 2025		January 2025		April 2023		April 2023
Credit facility amount	$	350	$	475	$	350	$	250
Amounts borrowed at March 31, 2022	350		499		350		250
Amounts borrowed at December 31, 2021	350		475		350		250
Restricted Receivables at March 31, 2022	566		858		658		503
Restricted Receivables at December 31, 2021	587		844		574		427

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, 2021 December 31, 2020
Receivables of VIEs $ 4 $ 4
Regulatory Assets: Current 54 53
Current Assets: Other 14 39
Other Noncurrent Assets: Regulatory assets 927 937
Current Liabilities: Other 2 10
Current maturities of long-term debt 55 55
Long-Term Debt 972 1,002

7671


FINANCIAL STATEMENTS			VARIABLE INTEREST ENTITIES

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


(in millions)	March 31, 2022		December 31, 2021
Receivables of VIEs	$	5	$	5
Regulatory Assets: Current	54		54
Current Assets: Other	13		39
Other Noncurrent Assets: Regulatory assets	872		883
Current Liabilities: Other	2		9
Current maturities of long-term debt	56		56
Long-Term Debt	916		946

Storm Recovery Bonds – Duke Energy Carolinas NC Storm Funding and Duke Energy Progress NC Storm Funding

Duke Energy Carolinas NC Storm Funding, LLC. (DECNCSF) and Duke Energy Progress NC Storm Funding, LLC. (DEPNCSF) are bankruptcy remote, wholly owned special purpose subsidiaries of Duke Energy Carolinas and Duke Energy Progress, respectively. These entities were formed in 2021 for the sole purpose of issuing storm recovery bonds to finance certain of Duke Energy Carolinas’ and Duke Energy Progress’ unrecovered regulatory assets related to storm costs.

In November 2021, DECNCSF and DEPNCSF issued $237 million and $770 million of senior secured bonds, respectively and used the proceeds to acquire storm recovery property from Duke Energy Carolinas and Duke Energy Progress. The storm recovery property was created by state legislation and NCUC financing orders for the purpose of financing storm costs incurred in 2018 and 2019. The storm recovery property acquired includes the right to impose, bill, collect and adjust a non-bypassable charge from all Duke Energy Carolinas’ and Duke Energy Progress’ retail customers until the bonds are paid in full and all financing costs have been recovered. The storm recovery bonds are secured by the storm recovery property and cash collections from the storm recovery charges are the sole source of funds to satisfy the debt obligation. The bondholders have no recourse to Duke Energy Carolinas or Duke Energy Progress.

DECNCSF and DEPNCSF are considered VIEs primarily because the equity capitalization is insufficient to support their operations. Duke Energy Carolinas and Duke Energy Progress have the power to direct the significant activities of the VIEs as described above and therefore Duke Energy Carolinas and Duke Energy Progress are considered the primary beneficiaries and consolidate DECNCSF and DEPNCSF, respectively.

The following table summarizes the impact of these VIEs on Duke Energy Carolinas’ and Duke Energy Progress’ Consolidated Balance Sheets.


	March 31, 2022				December 31, 2021
	Duke Energy		Duke Energy		Duke Energy		Duke Energy
(in millions)	Carolinas		Progress		Carolinas		Progress
Regulatory Assets: Current	$	12	$	39	$	12	$	39
Current Assets: Other	4		14		—		—
Other Noncurrent Assets: Regulatory assets	217		711		220		720
Other Noncurrent Assets: Other	1		4		1		4

Current Liabilities: Other	2		6		—		—
Current maturities of long-term debt	10		32		5		15
Long-Term Debt	223		730		228		747

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)	(in millions)	March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021
Current Assets: Other	Current Assets: Other	$	319	$	257	Current Assets: Other	$	215	$	215
Property, Plant and Equipment: Cost	Property, Plant and Equipment: Cost	6,860		6,394		Property, Plant and Equipment: Cost	7,337		7,339
Accumulated depreciation and amortization	Accumulated depreciation and amortization	(1,297)		(1,242)		Accumulated depreciation and amortization	(1,534)		(1,474)
Other Noncurrent Assets: Other	Other Noncurrent Assets: Other	66		67		Other Noncurrent Assets: Other	70		62
Current maturities of long-term debt	Current maturities of long-term debt	167		167		Current maturities of long-term debt	297		167
Long-Term Debt	Long-Term Debt	1,584		1,569		Long-Term Debt	1,325		1,475
Other Noncurrent Liabilities: AROs	Other Noncurrent Liabilities: AROs	153		148		Other Noncurrent Liabilities: AROs	173		173
Other Noncurrent Liabilities: Other	Other Noncurrent Liabilities: Other	331		316		Other Noncurrent Liabilities: Other	360		319


FINANCIAL STATEMENTS			VARIABLE INTEREST ENTITIES

NON-CONSOLIDATED VIEs

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


		March 31, 2021								March 31, 2022
		Duke Energy				Duke		Duke		Duke Energy								Duke	Duke
		Pipeline		Commercial				Energy			Energy			Pipeline		Commercial					Energy		Energy
(in millions)	(in millions)	Investments		Renewables		Total		Ohio			Indiana		(in millions)	Investments		Renewables			Total		Ohio		Indiana
Receivables from affiliated companies	Receivables from affiliated companies	$	—	$	—	$	—	$	46		$	60	Receivables from affiliated companies	$	—	$	—		$	—	$	65	$	80
Other current assets		4		—		4		—			$	—

Investments in equity method unconsolidated affiliates	Investments in equity method unconsolidated affiliates	3		480		483		—			—		Investments in equity method unconsolidated affiliates	29		504			533		—		—
Deferred tax asset	Deferred tax asset	29		—		29		—			—		Deferred tax asset	61		—			61		—		—
Total assets	Total assets	$	36	$	480	$	516	$	46		$	60	Total assets	$	90	$	504		$	594	$	65	$	80

Other current liabilities	Other current liabilities	38		3		41		—			—		Other current liabilities	50		3			53		—		—

Other noncurrent liabilities	Other noncurrent liabilities	48		10		58		—			—		Other noncurrent liabilities	52		3			55		—		—
Total liabilities	Total liabilities	$	86	$	13	$	99	$	—		$	—	Total liabilities	$	102	$	6		$	108	$	—	$	—
Net (liabilities) assets	Net (liabilities) assets	$	(50)	$	467	$	417	$	46		$	60	Net (liabilities) assets	$	(12)	$	498		$	486	$	65	$	80


		December 31, 2020								December 31, 2021
		Duke Energy				Duke		Duke		Duke Energy								Duke	Duke
		Pipeline		Commercial				Energy			Energy			Pipeline		Commercial					Energy		Energy
(in millions)	(in millions)	Investments		Renewables		Total		Ohio			Indiana		(in millions)	Investments		Renewables			Total		Ohio		Indiana
Receivables from affiliated companies	Receivables from affiliated companies	$	—	$	—	$	—	$	83		$	110	Receivables from affiliated companies	$	—	$	—		$	—	$	79	$	97

Investments in equity method unconsolidated affiliates	Investments in equity method unconsolidated affiliates	—		530		530		—			—		Investments in equity method unconsolidated affiliates	15		508			523		—		—
Other noncurrent assets	Other noncurrent assets	31		—		31		—			—		Other noncurrent assets	61		—			61		—		—
Total assets	Total assets	$	31	$	530	$	561	$	83		$	110	Total assets	$	76	$	508		$	584	$	79	$	97

Other current liabilities	Other current liabilities	928		5		933		—			—		Other current liabilities	47		4			51		—		—

Other noncurrent liabilities	Other noncurrent liabilities	8		10		18		—			—		Other noncurrent liabilities	54		3			57		—		—
Total liabilities	Total liabilities	$	936	$	15	$	951	$	—		$	—	Total liabilities	$	101	$	7		$	108	$	—	$	—
Net assets (liabilities)		$	(905)	$	515	$	(390)	$	83		$	110
Net (liabilities) assets													Net (liabilities) assets	$	(25)	$	501		$	476	$	79	$	97

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 ~~future exit costs associated with the cancellation of the ACP pipeline and~~ certain renewable energy project entities guarantees for debt services and operations and maintenance, as discussed below.


~~FINANCIAL STATEMENTS~~			~~VARIABLE INTEREST ENTITIES~~

Pipeline Investments

Duke Energy has investments in various joint ventures to construct and operate pipeline projects. 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.

Duke Energy has a 47% ownership interest in ACP. In 2020, Duke Energy determined that it would no longer invest in the construction of the ACP pipeline. In February 2021, Duke Energy paid approximately $855 million to fund ACP's outstanding debt, relieving Duke Energy of its guarantee. See Notes 1 and 3 for further information regarding this transaction.

Commercial Renewables

Duke Energy has investments in various renewable energy project entities. ~~Some~~Duke Energy has a 50% ownership in a VIE, which owns a portfolio of ~~these entities are VIEs due to~~wind projects. This entity is a VIE as a result of Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. Duke Energy does not consolidate ~~these VIEs~~this VIE because power to direct and control key activities is shared jointly by Duke Energy and the other ~~owners.~~owner. Duke Energy also has equity ownership in an entity, which owns a portfolio of fuel cell projects. Duke Energy does not consolidate the fuel cell portfolio as it does not have the power to direct the activities that most significantly impact the economic performance of the entity.

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. ~~Duke Energy cannot predict the outcome in this matter. See Note 3 for additional information.~~

CRC

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


FINANCIAL STATEMENTS			VARIABLE INTEREST ENTITIES

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					Duke Energy Ohio				Duke Energy Indiana
(in millions)	(in millions)	March 31, 2021		December 31, 2020		March 31, 2021		December 31, 2020		(in millions)	March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021
Receivables sold	Receivables sold	$	241	$	270	$	285	$	344	Receivables sold	$	263	$	269	$	305	$	328
Less: Retained interests	Less: Retained interests	46		83		60		110		Less: Retained interests	65		79		80		97
Net receivables sold	Net receivables sold	$	195	$	187	$	225	$	234	Net receivables sold	$	198	$	190	$	225	$	231

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


			Duke Energy Ohio					Duke Energy Indiana						Duke Energy Ohio					Duke Energy Indiana
		Three Months Ended					Three Months Ended			Three Months Ended					Three Months Ended
		March 31,					March 31,			March 31,					March 31,
(in millions)	(in millions)		2021		2020			2021			2020		(in millions)		2022		2021			2022		2021
Sales	Sales												Sales
Receivables sold	Receivables sold		$	561	$	537		$	698		$	647	Receivables sold		$	663	$	561		$	782	$	698
Loss recognized on sale	Loss recognized on sale		3		4			3			4		Loss recognized on sale		3		3			4		3
Cash flows	Cash flows												Cash flows
Cash proceeds from receivables sold	Cash proceeds from receivables sold		$	596	$	559		$	746		$	672	Cash proceeds from receivables sold		$	674	$	596		$	795	$	746

Collection fees received													Collection fees received		—		—			—		—
Return received on retained interests	Return received on retained interests		1		2			2			2		Return received on retained interests		1		1			2		2

Cash flows from sales of receivables are reflected within Cash Flows From Operating Activities and Cash Flows from Investing 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.


~~FINANCIAL STATEMENTS~~			~~REVENUE~~

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															Remaining Performance Obligations
(in millions)	(in millions)	2021		2022		2023		2024		2025		Thereafter		Total		(in millions)	2022		2023		2024		2025		2026		Thereafter		Total

Progress Energy	Progress Energy	$	71	$	107	$	44	$	45	$	7	$	51	$	325	Progress Energy	$	80	$	53	$	45	$	7	$	7	$	43	$	235
Duke Energy Progress	Duke Energy Progress	6		8		8		8		—		—		30		Duke Energy Progress	6		8		8		—		—		—		22
Duke Energy Florida	Duke Energy Florida	65		99		36		37		7		51		295		Duke Energy Florida	74		45		37		7		7		43		213

Duke Energy Indiana	Duke Energy Indiana	2		—		7		12		12		24		57		Duke Energy Indiana	2		11		16		17		15		12		73

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

Gas Utilities and Infrastructure

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


FINANCIAL STATEMENTS			REVENUE

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															Remaining Performance Obligations
(in millions)	(in millions)	2021		2022		2023		2024		2025		Thereafter		Total		(in millions)	2022		2023		2024		2025		2026		Thereafter		Total

Piedmont	Piedmont	$	50	$	67	$	64	$	61	$	60	$	335	$	637	Piedmont	$	48	$	64	$	61	$	60	$	50	$	286	$	569

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~~Some 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.


~~FINANCIAL STATEMENTS~~			~~REVENUE~~

Disaggregated Revenues

Disaggregated revenues are presented as follows:


		Three Months Ended March 31, 2021																	Three Months Ended March 31, 2022
				Duke				Duke													Duke				Duke
(in millions)	(in millions)	Duke		Energy		Progress		Energy										(in millions)	Duke		Energy		Progress		Energy
By market or type of customer	By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure	Electric Utilities and Infrastructure																	Electric Utilities and Infrastructure
Residential	Residential	$	2,462	$	793	$	1,162	$	560	$	602	$	195	$	313	$	—	Residential	$	2,767	$	831	$	1,368	$	624	$	744	$	211	$	354	$	—
General	General	1,419		502		624		306		318		104		189		—		General	1,604		544		726		325		401		116		218		—
Industrial	Industrial	662		256		207		145		62		31		167		—		Industrial	772		276		270		194		76		35		192		—
Wholesale	Wholesale	504		114		326		292		34		13		50		—		Wholesale	626		113		411		349		62		23		79		—
Other revenues	Other revenues	226		74		160		83		77		22		18		—		Other revenues	202		111		211		139		72		21		(36)		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,273	$	1,739	$	2,479	$	1,386	$	1,093	$	365	$	737	$	—	Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,971	$	1,875	$	2,986	$	1,631	$	1,355	$	406	$	807	$	—

Gas Utilities and Infrastructure	Gas Utilities and Infrastructure																	Gas Utilities and Infrastructure
Residential	Residential	$	460	$	—	$	—	$	—	$	—	$	110	$	—	$	351	Residential	$	572	$	—	$	—	$	—	$	—	$	149	$	—	$	423
Commercial	Commercial	204		—		—		—		—		48		—		156		Commercial	269		—		—		—		—		64		—		204
Industrial	Industrial	50		—		—		—		—		7		—		43		Industrial	57		—		—		—		—		7		—		50
Power Generation	Power Generation	—		—		—		—		—		—		—		22		Power Generation	—		—		—		—		—		—		—		24
Other revenues	Other revenues	47		—		—		—		—		5		—		26		Other revenues	115		—		—		—		—		6		—		93
Total Gas Utilities and Infrastructure revenue from contracts with customers	Total Gas Utilities and Infrastructure revenue from contracts with customers	$	761	$	—	$	—	$	—	$	—	$	170	$	—	$	598	Total Gas Utilities and Infrastructure revenue from contracts with customers	$	1,013	$	—	$	—	$	—	$	—	$	226	$	—	$	794

Commercial Renewables	Commercial Renewables																	Commercial Renewables
Revenue from contracts with customers	Revenue from contracts with customers	$	54	$	—	$	—	$	—	$	—	$	—	$	—	$	—	Revenue from contracts with customers	$	51	$	—	$	—	$	—	$	—	$	—	$	—	$	—

Other	Other																	Other
Revenue from contracts with customers	Revenue from contracts with customers	$	6	$	—	$	—	$	—	$	—	$	—	$	—	$	—	Revenue from contracts with customers	$	7	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total revenue from contracts with customers	Total revenue from contracts with customers	$	6,094	$	1,739	$	2,479	$	1,386	$	1,093	$	535	$	737	$	598	Total revenue from contracts with customers	$	7,042	$	1,875	$	2,986	$	1,631	$	1,355	$	632	$	807	$	794

Other revenue sources(a)	Other revenue sources(a)	$	56	$	(23)	$	26	$	15	$	8	$	(3)	$	8	$	8	Other revenue sources(a)	$	90	$	13	$	6	$	1	$	—	$	6	$	15	$	11
Total revenues	Total revenues	$	6,150	$	1,716	$	2,505	$	1,401	$	1,101	$	532	$	745	$	606	Total revenues	$	7,132	$	1,888	$	2,992	$	1,632	$	1,355	$	638	$	822	$	805

(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.

8075


FINANCIAL STATEMENTS			REVENUE


		Three Months Ended March 31, 2020																	Three Months Ended March 31, 2021
				Duke				Duke													Duke				Duke
(in millions)	(in millions)	Duke		Energy		Progress		Energy										(in millions)	Duke		Energy		Progress		Energy
By market or type of customer	By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure	Electric Utilities and Infrastructure																	Electric Utilities and Infrastructure
Residential	Residential	$	2,261	$	756	$	1,064	$	502	$	562	$	176	$	265	$	—	Residential	$	2,462	$	793	$	1,162	$	560	$	602	$	195	$	313	$	—
General	General	1,492		549		648		319		329		114		181		—		General	1,419		502		624		306		318		104		189		—
Industrial	Industrial	693		269		216		154		62		35		175		—		Industrial	662		256		207		145		62		31		167		—
Wholesale	Wholesale	497		114		321		279		42		7		55		—		Wholesale	504		114		326		292		34		13		50		—
Other revenues	Other revenues	191		60		118		63		55		20		16		—		Other revenues	226		74		160		83		77		22		18		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,134	$	1,748	$	2,367	$	1,317	$	1,050	$	352	$	692	$	—	Total Electric Utilities and Infrastructure revenue from contracts with customers	$	5,273	$	1,739	$	2,479	$	1,386	$	1,093	$	365	$	737	$	—

Gas Utilities and Infrastructure	Gas Utilities and Infrastructure																	Gas Utilities and Infrastructure
Residential	Residential	$	362	$	—	$	—	$	—	$	—	$	97	$	—	$	264	Residential	$	460	$	—	$	—	$	—	$	—	$	110	$	—	$	351
Commercial	Commercial	169		—		—		—		—		43		—		126		Commercial	204		—		—		—		—		48		—		156
Industrial	Industrial	41		—		—		—		—		6		—		36		Industrial	50		—		—		—		—		7		—		43
Power Generation	Power Generation	—		—		—		—		—		—		—		11		Power Generation	—		—		—		—		—		—		—		22
Other revenues	Other revenues	30		—		—		—		—		6		—		24		Other revenues	47		—		—		—		—		5		—		26
Total Gas Utilities and Infrastructure revenue from contracts with customers	Total Gas Utilities and Infrastructure revenue from contracts with customers	$	602	$	—	$	—	$	—	$	—	$	152	$	—	$	461	Total Gas Utilities and Infrastructure revenue from contracts with customers	$	761	$	—	$	—	$	—	$	—	$	170	$	—	$	598

Commercial Renewables	Commercial Renewables																	Commercial Renewables
Revenue from contracts with customers	Revenue from contracts with customers	$	58	$	—	$	—	$	—	$	—	$	—	$	—	$	—	Revenue from contracts with customers	$	54	$	—	$	—	$	—	$	—	$	—	$	—	$	—

Other	Other																	Other
Revenue from contracts with customers	Revenue from contracts with customers	$	6	$	—	$	—	$	—	$	—	$	—	$	—	$	—	Revenue from contracts with customers	$	6	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total revenue from contracts with customers	Total revenue from contracts with customers	$	5,800	$	1,748	$	2,367	$	1,317	$	1,050	$	504	$	692	$	461	Total revenue from contracts with customers	$	6,094	$	1,739	$	2,479	$	1,386	$	1,093	$	535	$	737	$	598

Other revenue sources(a)	Other revenue sources(a)	$	149	$	—	$	55	$	21	$	30	$	(6)	$	—	$	51	Other revenue sources(a)	$	56	$	(23)	$	26	$	15	$	8	$	(3)	$	8	$	8
Total revenues	Total revenues	$	5,949	$	1,748	$	2,422	$	1,338	$	1,080	$	498	$	692	$	512	Total revenues	$	6,150	$	1,716	$	2,505	$	1,401	$	1,101	$	532	$	745	$	606

~~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.


		Three Months Ended March 31, 2020 and 2021																	Three Months Ended March 31, 2021 and 2022
				Duke				Duke													Duke				Duke
		Duke		Energy		Progress		Energy											Duke		Energy		Progress		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(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 December 31, 2020																		Balance at December 31, 2020	$	146	$	23	$	37	$	23	$	14	$	4	$	3	$	12

Balance at March 31, 2020		$	89	$	11	$	20	$	9	$	11	$	5	$	3	$	9

Balance at December 31, 2020		$	146	$	23	$	37	$	23	$	14	$	4	$	3	$	12
Write-Offs	Write-Offs	(21)		(8)		(10)		(5)		(5)		—		—		(1)		Write-Offs	(21)		(8)		(10)		(5)		(5)		—		—		(1)
Credit Loss Expense	Credit Loss Expense	17		10		7		2		5		—		—		3		Credit Loss Expense	17		10		7		2		5		—		—		3
Other Adjustments	Other Adjustments	5		9		3		3		1		—		—		—		Other Adjustments	5		9		3		3		1		—		—		—
Balance at March 31, 2021	Balance at March 31, 2021	$	147	$	34	$	37	$	23	$	15	$	4	$	3	$	14	Balance at March 31, 2021	$	147	$	34	$	37	$	23	$	15	$	4	$	3	$	14

Balance at December 31, 2021																		Balance at December 31, 2021	$	122	$	42	$	36	$	21	$	16	$	4	$	3	$	15
Write-Offs																		Write-Offs	(23)		(9)		(10)		(2)		(8)		—		—		(1)
Credit Loss Expense																		Credit Loss Expense	24		5		12		4		8		—		—		3
Other Adjustments																		Other Adjustments	17		14		13		8		5		—		—		—
Balance at March 31, 2022																		Balance at March 31, 2022	$	140	$	52	$	51	$	31	$	21	$	4	$	3	$	17

8176


FINANCIAL STATEMENTS			REVENUE

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 periodically for trade and other 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, 2021																	March 31, 2022
				Duke				Duke													Duke				Duke
		Duke		Energy		Progress		Energy											Duke		Energy		Progress		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Unbilled Revenue(a)(b)	Unbilled Revenue(a)(b)	$	758	$	293	$	183	$	90	$	93	$	4	$	16	$	44	Unbilled Revenue(a)(b)	$	945	$	339	$	270	$	161	$	109	$	7	$	44	$	64
0-30 days	0-30 days	1,656		337		633		357		275		55		35		185		0-30 days	2,133		518		944		558		386		40		26		215
30-60 days	30-60 days	181		62		46		31		15		8		3		21		30-60 days	288		75		111		64		47		8		4		23
60-90 days	60-90 days	46		15		11		6		5		3		1		6		60-90 days	102		33		40		22		18		2		3		7
90+ days	90+ days	120		31		26		4		22		28		11		7		90+ days	274		119		77		39		38		46		9		7
Deferred Payment Arrangements(c)	Deferred Payment Arrangements(c)	170		80		53		37		16		4		—		8		Deferred Payment Arrangements(c)	136		60		61		33		28		2		—		4
Trade and Other Receivables	Trade and Other Receivables	$	2,931	$	818	$	952	$	525	$	426	$	102	$	66	$	271	Trade and Other Receivables	$	3,878	$	1,144	$	1,503	$	877	$	626	$	105	$	86	$	320


		December 31, 2020																	December 31, 2021
				Duke				Duke													Duke				Duke
		Duke		Energy		Progress		Energy											Duke		Energy		Progress		Energy
(in millions)	(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont		(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Unbilled Revenue(a)(b)	Unbilled Revenue(a)(b)	$	969	$	328	$	283	$	167	$	116	$	2	$	16	$	86	Unbilled Revenue(a)(b)	$	964	$	316	$	266	$	193	$	73	$	4	$	27	$	106
0-30 days	0-30 days	1,789		445		707		398		307		60		26		149		0-30 days	2,104		595		800		405		393		42		51		202
30-60 days	30-60 days	185		80		54		25		29		8		3		8		30-60 days	212		77		72		44		28		4		13		12
60-90 days	60-90 days	22		1		10		4		6		2		1		3		60-90 days	88		37		41		21		20		1		1		2
90+ days	90+ days	119		16		32		9		23		30		12		9		90+ days	249		106		65		37		28		47		11		7
Deferred Payment Arrangements(c)	Deferred Payment Arrangements(c)	215		96		80		52		28		—		—		7		Deferred Payment Arrangements(c)	115		55		45		22		23		2		—		4
Trade and Other Receivables	Trade and Other Receivables	$	3,299	$	966	$	1,166	$	655	$	509	$	102	$	58	$	262	Trade and Other Receivables	$	3,732	$	1,186	$	1,289	$	722	$	565	$	100	$	103	$	333

(a)Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy or natural gas delivered but not yet billed and are included within Receivables and Receivables of VIEs on the Condensed Consolidated Balance Sheets.

(b)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 ~~$55~~$63 million and ~~$87~~$100 million for Duke Energy Ohio and Duke Energy Indiana, respectively, as of March 31, ~~2021,~~2022, and ~~$87~~$82 million and ~~$134~~$121 million for Duke Energy Ohio and Duke Energy Indiana, respectively, as of December 31, ~~2020.~~2021.

(c)Due to certain customer financial hardships created by the COVID-19 pandemic and resulting stay-at-home orders, Duke Energy permitted customers to defer payment of past-due amounts through an installment payment plan over a period of several months.

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 and accumulated preferred dividends, 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 and accumulated preferred dividends, 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 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.

8277


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,						Three Months Ended March 31,
(in millions, except per share amounts)	(in millions, except per share amounts)		2021		2020		(in millions, except per share amounts)		2022		2021
Net income available to Duke Energy common stockholders	Net income available to Duke Energy common stockholders		$	953	$	899	Net income available to Duke Energy common stockholders		$	818	$	953
Accumulated preferred stock dividends adjustment	Accumulated preferred stock dividends adjustment		12		13		Accumulated preferred stock dividends adjustment		12		12
Less: Impact of participating securities	Less: Impact of participating securities		1		1		Less: Impact of participating securities		1		1
Income from continuing operations available to Duke Energy common stockholders	Income from continuing operations available to Duke Energy common stockholders		$	964	$	911	Income from continuing operations available to Duke Energy common stockholders		$	829	$	964

Weighted average common shares outstanding – basic			769		734
Equity forwards			0		2
Weighted average common shares outstanding – diluted			769		736
Weighted average common shares outstanding – basic and diluted							Weighted average common shares outstanding – basic and diluted		770		769

EPS available to Duke Energy common stockholders	EPS available to Duke Energy common stockholders						EPS available to Duke Energy common stockholders
Basic and diluted	Basic and diluted		$	1.25	$	1.24	Basic and diluted		$	1.08	$	1.25

Potentially dilutive items excluded from the calculation(a)	Potentially dilutive items excluded from the calculation(a)		2		2		Potentially dilutive items excluded from the calculation(a)		2		2
Dividends declared per common share	Dividends declared per common share		$	0.965	$	0.945	Dividends declared per common share		$	0.985	$	0.965
Dividends declared on Series A preferred stock per depositary share(b)	Dividends declared on Series A preferred stock per depositary share(b)		$	0.359	$	0.359	Dividends declared on Series A preferred stock per depositary share(b)		$	0.359	$	0.359
Dividends declared on Series B preferred stock per share(c)	Dividends declared on Series B preferred stock per share(c)		$	24.375	$	24.917	Dividends declared on Series B preferred stock per share(c)		$	24.375	$	24.375

(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.

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.

QUALIFIED PENSION PLANS

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


	Three Months Ended March 31, 2022
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Service cost	$	40	$	12	$	12	$	7	$	4	$	1	$	2	$	1
Interest cost on projected benefit obligation	58		14		18		8		10		3		5		2
Expected return on plan assets	(140)		(38)		(46)		(22)		(24)		(5)		(9)		(6)
Amortization of actuarial loss	24		5		6		3		3		1		2		2
Amortization of prior service credit	(5)		(1)		—		—		—		—		—		(2)
Amortization of settlement charges	2		1		1		—		—		—		—		—
Net periodic pension costs	$	(21)	$	(7)	$	(9)	$	(4)	$	(7)	$	—	$	—	$	(3)


	Three Months Ended March 31, 2021
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Service cost	$	44	$	14	$	13	$	7	$	5	$	1	$	2	$	1
Interest cost on projected benefit obligation	55		13		17		7		10		3		5		2
Expected return on plan assets	(139)		(35)		(47)		(21)		(26)		(7)		(10)		(5)
Amortization of actuarial loss	33		7		10		5		5		2		3		2
Amortization of prior service credit	(7)		(2)		(1)		—		—		—		—		(1)
Amortization of settlement charges	2		1		1		—		—		—		—		—
Net periodic pension costs	$	(12)	$	(2)	$	(7)	$	(2)	$	(6)	$	(1)	$	—	$	(1)

8378


FINANCIAL STATEMENTS			EMPLOYEE BENEFIT 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)

NON-QUALIFIED PENSION PLANS

Net periodic pension costs for non-qualified pension plans were not material for the three months ended March 31, ~~2021,~~2022, and ~~2020.~~2021.

OTHER POST-RETIREMENT BENEFIT PLANS

Net periodic costs for OPEB plans were not material for the three months ended March 31, ~~2021,~~2022, and ~~2020.~~2021.

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						Three Months Ended
		March 31,						March 31,
			2021		2020				2022		2021
Duke Energy	Duke Energy		8.2	%	13.3	%	Duke Energy		(1.7)	%	8.2	%
Duke Energy Carolinas	Duke Energy Carolinas		6.9	%	16.1	%	Duke Energy Carolinas		7.4	%	6.9	%
Progress Energy	Progress Energy		12.9	%	17.5	%	Progress Energy		15.9	%	12.9	%
Duke Energy Progress	Duke Energy Progress		8.3	%	17.1	%	Duke Energy Progress		14.0	%	8.3	%
Duke Energy Florida	Duke Energy Florida		19.3	%	20.0	%	Duke Energy Florida		20.1	%	19.3	%
Duke Energy Ohio	Duke Energy Ohio		13.3	%	17.7	%	Duke Energy Ohio		(266.7)	%	13.3	%
Duke Energy Indiana	Duke Energy Indiana		17.6	%	20.8	%	Duke Energy Indiana		31.9	%	17.6	%
Piedmont	Piedmont		11.4	%	10.1	%	Piedmont		13.4	%	11.4	%

The decrease in the ETR for Duke Energy for the three months ended March 31, ~~2021,~~2022, was primarily due to an increase in the amortization of excess deferred ~~taxes.~~taxes related to the Duke Energy Ohio MGP Settlement.

The ~~decrease in the ETR for Duke Energy Carolinas for the three months ended March 31, 2021, was primarily due to an~~ increase ~~in the amortization of excess deferred taxes.~~

~~The decrease~~ in the ETR for Progress Energy for the three months ended March 31, ~~2021,~~2022, was primarily due to ~~an increase~~a decrease in the amortization of excess deferred taxes.

The ~~decrease~~increase in the ETR for Duke Energy Progress for the three months ended March 31, ~~2021,~~2022, was primarily due to ~~an increase~~a decrease in the amortization of excess deferred taxes.

The decrease in the ETR for Duke Energy Ohio for the three months ended March 31, ~~2021,~~2022, was primarily due to an increase in the amortization of excess deferred ~~taxes.~~taxes related to the MGP Settlement.

The ~~decrease~~increase in the ETR for Duke Energy Indiana for the three months ended March 31, ~~2021,~~2022, was primarily due to anthe coal ash impairment based on the Indiana Supreme Court Opinion.

The increase in the ETR for Piedmont for the three months ended March 31, 2022, was primarily due to a decrease in the amortization of excess deferred taxes.

16. SUBSEQUENT EVENTS

For information on subsequent events related to regulatory matters, and commitments and contingencies, ~~and debt and credit facilities,~~ see Notes 3 4 and 5.4.

8479


MD&A			DUKE ENERGY

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, ~~2021,~~2022, and with Duke Energy’s Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2021.

Executive Overview

Advancing Our Clean Energy Transformation

During the first quarter, we continued to ~~move past the challenges from 2020 while executing~~execute on our clean energy transformation. In March of 2021, we expanded the company’s senior management team and realigned roles and responsibilities to further accelerate our clean energy transition. This realignment will accelerate the execution of our strategy, clarify important roles in our clean energy transformation, ~~and position our company to grow –~~delivering strong, sustainable value for ~~our~~shareholders, customers, communities ~~employees~~ and ~~investors.~~employees.

~~To further our~~•We’re targeting energy generated from coal to represent less than 5% by 2030 and a full exit by 2035, subject to regulatory approvals. We’ve made strong progress ~~toward achieving net-zero~~in reducing carbon emissions ~~we will transform~~from electricity generation (a 44% reduction from 2005) and have committed to do more (at least 50% reduction by 2030 and net-zero by 2050).

•We continued to execute financings under our ~~fleet~~Sustainable Financing Framework, raising approximately $2 billion during the quarter under the structure, with proceeds being allocated to ~~shift away from coal~~eligible projects such as electric grid investments that support the deployment of renewables, new solar generation and expect our largest source of energy in our regulated utilities will come from renewable energy resources, representing about 40% of our capacity in 2050. During the next five years, we have plans for $600 million in new battery storage, ~~investment across our regulated~~storm hardening and electric vehicle infrastructure, as well as expenditures that enable opportunities for diverse and small businesses. We expect storage investment to accelerate over this decade and beyond – and presently project more than 13,000 MW's of energy storage on our system by 2050. Our generation transition relies upon modernizing and enhancing our energy grid. We continue to install smart meters – more than 8.5 million so far – providing customers with more information about their energy use while helping us improve outage detection and restoration. By the end of 2021, nearly all of our customers will be served by smart meters.

We developed innovative IRPs in the Carolinas, outlining comprehensive proposals and offering six potential pathways to meet key carbon reduction milestones over the next 15 years while balancing affordability for customers. We’ve been working with stakeholder groups to help shape North Carolina’s Clean Energy Plan, with a common goal of reaching net-zero carbon emissions in a way that best serves our customers and our state. This complements the efforts underway on regulatory reform, including the introduction of more efficient cost recovery mechanisms. We also continue to monitor legislative activity at the federal level and any potential impacts on our strategy and investments across the enterprise.

Regulatory Activity. During the first quarter of ~~2021,~~2022, we continued to ~~move~~monitor developments while moving our regulatory strategy forward. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

•In April 2022, the MGP Settlement was approved without modification by the PUCO. The MGP Settlement resolved certain issues related to MGP remediation costs and the Tax Act as it related to Duke Energy ~~Carolinas 2019 Rate Case Order~~Ohio’s natural gas operations.

•OnIn April 2022, Piedmont Natural Gas filed a request with the South Carolina Public Service Commission to recover recent capital investments and update its operating costs and billing rates through a general rate case proceeding.

•In March ~~31, 2021,~~2022, the Indiana Supreme Court issued an opinion, which absent IURC preapproval of deferred accounting treatment determined DEI could not recover coal ash closure costs incurred between base rate cases. In connection with the rate case application filed in Indiana in 2019 by Duke Energy Indiana, the IURC issued an order in June 2020, which among other things provided for recovery of approximately $211 million of certain coal ash closure costs incurred by DEI prior to the IURC Order. The Court remanded the matter back to the IURC for proceedings consistent with the opinion. Duke Energy Indiana filed a request for rehearing with the Supreme Court on April 11, 2022.

•In February 2022, the NCUC adopted rules to govern the application and review process for the PBR authorized under HB 951. In April 2022, the NCUC adopted rules to govern the securitization of 50% of the North Carolina retail portion of the remaining net book value of retiring coal plants pursuant to HB 951. The rules are constructive and consistent with the policy objectives of HB 951. We remain engaged in next steps including developing an initial carbon reduction plan.

•In January 2022, the NCUC issued an order approving ~~without modification previous settlements reached by Duke Energy Carolinas,~~ the North Carolina Public Staff (the “Public Staff”) and other parties on March 25, 2020, and July 31, 2020, which resolved certain issues in Duke Energy Carolinas' base rate case proceeding originally filed withstipulation of partial settlement related to the ~~NCUC on September 31, 2019.~~

•~~The order approved without modification the Agreement and Stipulation of Partial Settlement filed with the NCUC on January 25,~~ 2021 which resolved all coal ash prudence and cost recovery issues through early 2030, including in Duke Energy Carolinas' 2019 base rate case proceeding, as well as the equitable sharing issue on remand from the Duke Energy Carolinas 2017 North Carolina rate case as a result of the December 11, 2020, North Carolina Supreme Court opinion.

•The order also approved a return on equity of 9.6% based upon a capital structure of 52% equity and 48% debt, deferral treatment for approximately $0.8 billion of grid improvement projects with a return, Unprotected Federal Excess Deferred Income Taxes flow back over a period of five years, and the reasonableness and prudence of $213 million of deferred storm costs which were removed from the rate case and for which Duke Energy Carolinas filed a petition seeking to securitize the costs in October 2020.

•The order denied Duke Energy Carolinas' proposal to shorten the remaining depreciable lives of certain coal-fired generating plants, indicating that Duke Energy Carolinas' IRP proceeding was the appropriate proceeding for the review of generating plant retirements.

~~Duke Energy Progress 2019 Rate Case Order~~

•On April 16, 2021, the NCUC issued an order approving without modification previous settlements reached by Duke Energy Progress, the Public Staff and other parties on June 2, 2020, and July 31, 2020, which resolved certain issues in Duke Energy Progress’ base rate case proceeding originally filed with the NCUC on October 30, 2019.

•The order approved without modification the Agreement and Stipulation of Partial Settlement filed with the NCUC on January 25, 2021, which resolved all coal ash prudence and cost recovery issues through early 2030, including in Duke Energy Progress’ 2019 base rate case proceeding, as well as the equitable sharing issue on remand from the Duke Energy Progress 2017 North Carolina rate case as a result of the December 11, 2020, North Carolina Supreme Court opinion.


~~MD&A~~			~~DUKE ENERGY~~

◦The order also approved a return on equity of 9.6% based upon a capital structure of 52% equity and 48% debt, deferral treatment for approximately $0.4 billion of grid improvement projects with a return, Unprotected Federal Excess Deferred Income Taxes flow back over a period of five years, and the reasonableness and prudence of $714 million of deferred storm costs, which were removed from the rate case and for which Duke Energy Progress filed a petition seeking to securitize the costs in October 2020.

◦The order denied Duke Energy Progress’ proposal to shorten the remaining depreciable lives of certain coal-fired generating plants, indicating that Duke Energy Progress’ IRP proceeding was the appropriate proceeding for the review of generating plant retirements.

Piedmont ~~2021~~ North Carolina Rate Case,

•~~On March 22, 2021, Piedmont filed an application with the NCUC for~~ which included a base rate increase ~~for retail customers~~ of ~~approximately $109~~$67 million, ~~which represents an approximate 10% increase in retail revenues. The rate increase is driven by customer growth~~subject to completion of the Robeson County LNG facility and ~~significant infrastructure upgrade investments (plant additions) since~~ the ~~last general rate case.~~Pender Onslow County expansion project.

Matters Impacting Future Results

The matters discussed herein could materially impact the future operating results, financial condition and cash flows of the Duke Energy Registrants and Business Segments.

Regulatory Matters

Coal Ash Costs

~~As a result~~Future spending of ~~the NCDEQ settlement on December 31, 2019, Duke Energy Carolinas and Duke Energy Progress agreed to excavate seven of the nine remaining~~ coal ash ~~basins~~costs, including amounts recorded for depreciation and liability accretion, is expected to continue to be deferred and recovered 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 off-site lined landfills.~~future rate cases or rider filings. The majority of spend is expected to occur over the next 15-20 years. ~~In January 2021, Duke Energy Carolinas and Duke Energy Progress reached a settlement agreement on recovery of coal ash costs as outlined in Note 3, "Regulatory Matters."~~


MD&A			MATTERS IMPACTING FUTURE RESULTS

~~The company agreed not to seek recovery of approximately $1 billion of deferred coal ash expenditures and Duke Energy Carolinas and Duke Ener~~gy Progress took a charge of approximately $500 million each in 2020. On March 31, 2021, and April 16, 2021, the NCUC approved the coal ash settlement for Duke Energy Carolinas and Duke Energy Progress, respectively.

In 2019, Duke Energy Carolinas and Duke Energy Progress received orders from the PSCSC 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. An order from regulatory or judicial authorities that rejects our proposed settlement or disallows recovery of costs related to closure of these ash basins could have an adverse impact.

Duke Energy Indiana has interpreted the CCR 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. In 2020, the Hoosier Environmental Council filed a petition challenging the Indiana Department of Environmental Management's (IDEM) partial approval of five of Duke Energy Indiana’s ash pond site closure plans at Gallagher Station. The petition does not challenge the other ~~thirteen~~ basin closures approved by IDEM at other Indiana stations. Interpretation of the requirements of the CCR rule is subject to further legal challenges and 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.

~~Rate Cases~~

In ~~March 2021, Piedmont filed a general rate case with the NCUC.The outcome of this rate case could have a material impact.~~

~~MGP~~

The PUCO has 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.January 2022, Duke Energy ~~Ohio has filed for~~Indiana received a ~~request for extension~~letter from the EPA regarding interpretation 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.

~~For additional information, see~~CCR rule. See Note 34 to the Condensed Consolidated Financial Statements, ~~“Regulatory Matters.”~~

~~Minority Interest Investment in Duke Energy Indiana~~

~~In January 2021, Duke Energy entered into a definitive agreement providing~~"Commitments and Contingencies" for a 19.9% minority interest investment in Duke Energy Indiana by an affiliate of GIC, Singapore's sovereign wealth fund. The transaction is subject to the satisfaction of certain customary conditions described in the investment agreement, including receipt of the approval of the FERC and completion of review by the Committee on Foreign Investments in the United States. Failure to obtain related approvals or satisfy the conditions in the investment agreement could result in the termination of the transaction and could result in an adverse impact.more information.

Commercial Renewables

Duke Energy continues to monitor recoverability of renewable merchant plants located in the ~~Electric Reliability Council of Texas~~ERCOT West market and in the PJM West market, due to ~~declining~~fluctuating market pricing and ~~declining~~ long-term forecasted energy ~~prices, primarily driven by lower forecasted natural gas~~ prices. Based on the most recent recoverability test, the carrying value approximated the aggregate estimated future undiscounted cash flows for the assets under review. A continued decline in energy market pricing or other factors unfavorably impacting the economics would likely result in a future impairment. Impairment of these assets could result in adverse impacts. For additional information, see Note 2 to the Condensed Consolidated Financial Statements, "Business Segments."


~~MD&A~~			~~MATTERS IMPACTING FUTURE RESULTS~~

In February 2021, a severe winter storm impacted certain Commercial Renewables assets in Texas. Extreme weather conditions limited the ability for these solar and wind facilities to generate and sell electricity into the ~~Electric Reliability Council of Texas~~ERCOT market. ~~Both~~ lost revenues and higher than expected purchased power costs have negatively impacted the operating results of these generating units. The financial impact of the storm is expected to have a material impact on the Commercial Renewables segment's 2021 operating results. In addition, Duke Energy has been named in multiple lawsuits arising out of this winter ~~storm, and particularly, the deregulated market managed by the Electric Reliability Council of Texas.~~storm. For more information, see ~~Notes 2 and~~Note 4 to the Condensed Consolidated Financial Statements, ~~"Business Segments" and~~ "Commitments and ~~Contingencies,~~Contingencies." ~~respectively.~~

~~COVID-19~~Supply Chain

Duke Energy cannot predict the extent to which the COVID-19 pandemic will impact its results of operations, financial position and cash flows in the future. Duke Energy will continue to actively monitor the impacts of COVID-19is monitoring supply chain disruptions, including the ~~economic slowdown caused by business closures~~cost and availability of key components of planned generating facilities, which could impact the timing of in-service or ~~by reduced operations~~economics of ~~businesses~~renewable projects and governmental agencies. The pandemic and resultant economic slowdown continues to cause an increase in certain costs, such as bad debt, and a reduction in the demand for energy. Duke Energy has mitigation plans in place to partially offset these impacts, and the ability to execute these plans is critical to preserving future financial results. The company is in the process of reviewing the long-term real estate strategy due to a potential change of in-office work policies after the COVID-19 pandemic. The plan may result in adverse impacts on operating results. The Company is also monitoring the impacts on future financial results and clean energy goals due to the availability of solar panels as a ~~reduction~~result of ~~physical work space, which could create accounting impacts in 2021. Accounting impacts may include reassessments~~the U.S. Department of ~~lease terms~~Commerce investigation into the potential circumvention of anti-dumping and ~~lease modifications, which could result in termination penalties, as well as, asset impairments on property, plant and equipment.~~

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, 2020, for discussion of risks associated wi~~th the Tax Act.~~countervailing duties by certain Chinese companies.

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 Corporation 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 (Loss) and GAAP Reported ~~EPS,~~Earnings (Loss) Per Share, respectively.

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

•Regulatory Matters represents the net impact of charges related to the 2022 Indiana Supreme Court ruling on coal ash.

•Gas Pipeline Investments represents additional exit obligations related to ACP.

•Severance represents the reversal of 2018 severance charges, which were deferred as a result of a partial settlement in the Duke Energy Carolinas and the Duke Energy Progress 2019 North Carolina rate cases.

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

GAAP reported EPS was ~~$1.25~~$1.08 for the first quarter of ~~2021~~2022 compared to ~~$1.24~~a $1.25 in the first quarter of ~~2020.~~2021. In addition to the drivers below, GAAP reported EPS ~~increased slightly~~decreased primarily due to ~~favorable weather and positive rate case impacts, offset by~~charges related to the ~~deferral of severance costs in the prior year, Texas Storm Uri impacts and share dilution from equity issuances.~~Indiana Supreme Court ruling on coal ash.

As discussed above, management also evaluates financial performance based on adjusted EPS. Duke Energy’s first quarter ~~2021~~2022 adjusted EPS was ~~$1.26~~$1.30 compared to ~~$1.14~~$1.26 for the first quarter of ~~2020.~~2021. The increase in adjusted EPS was primarily due to ~~better weather and positive rate case contributions,~~higher volumes, partially offset by ~~Texas Storm Uri impacts, the loss of ACP~~higher operation and ~~share dilution from equity issuances.~~maintenance expense, including storm costs, and lower returns on benefit trusts.


MD&A			DUKE ENERGY

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


		Three Months Ended March 31,									Three Months Ended March 31,
		2021				2020					2022				2021
(in millions, except per share amounts)	(in millions, except per share amounts)	Earnings		EPS		Earnings		EPS		(in millions, except per share amounts)	Earnings		EPS		Earnings		EPS

GAAP Reported Earnings/GAAP Reported EPS	GAAP Reported Earnings/GAAP Reported EPS	$	953	$	1.25	$	899	$	1.24	GAAP Reported Earnings/GAAP Reported EPS	$	818	$	1.08	$	953	$	1.25
Adjustments:	Adjustments:									Adjustments:

Gas Pipeline Investments(a)		5		0.01		—		—

Severance(b)		—		—		(75)		(0.10)

Regulatory Matters(a)										Regulatory Matters(a)	173		0.22		—		—
Gas Pipeline Investments(b)										Gas Pipeline Investments(b)	—		—		5		0.01
Adjusted Earnings/Adjusted EPS	Adjusted Earnings/Adjusted EPS	$	958	$	1.26	$	824	$	1.14	Adjusted Earnings/Adjusted EPS	$	991	$	1.30	$	958	$	1.26

(a)Net of tax benefit of $62 million and $22 million in noncontrolling interests.

(b)Net of tax benefit of $1 million.

~~(b) Net of tax expense of $23 million.~~


~~MD&A~~			~~SEGMENT RESULTS — ELECTRIC UTILITIES AND INFRASTRUCTURE~~

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,					Three Months Ended March 31,
(in millions)	(in millions)		2021		2020			Variance		(in millions)	2022		2021		Variance
Operating Revenues	Operating Revenues		$	5,281	$	5,183		$	98	Operating Revenues	$	6,002	$	5,281	$	721
Operating Expenses	Operating Expenses									Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power		1,462		1,467			(5)		Fuel used in electric generation and purchased power	1,837		1,462		375
Operation, maintenance and other	Operation, maintenance and other		1,282		1,325			(43)		Operation, maintenance and other	1,426		1,282		144
Depreciation and amortization	Depreciation and amortization		1,057		977			80		Depreciation and amortization	1,131		1,057		74
Property and other taxes	Property and other taxes		311		303			8		Property and other taxes	337		311		26
Impairment of assets and other charges	Impairment of assets and other charges		—		2			(2)		Impairment of assets and other charges	214		—		214
Total operating expenses	Total operating expenses		4,112		4,074			38		Total operating expenses	4,945		4,112		833
Gains on Sales of Other Assets and Other, net	Gains on Sales of Other Assets and Other, net		—		1			(1)		Gains on Sales of Other Assets and Other, net	2		—		2
Operating Income	Operating Income		1,169		1,110			59		Operating Income	1,059		1,169		(110)
Other Income and Expenses, net	Other Income and Expenses, net		104		85			19		Other Income and Expenses, net	114		104		10
Interest Expense	Interest Expense		340		339			1		Interest Expense	376		340		36
Income Before Income Taxes	Income Before Income Taxes		933		856			77		Income Before Income Taxes	797		933		(136)
Income Tax Expense	Income Tax Expense		113		151			(38)		Income Tax Expense	83		113		(30)
Add: Loss Attributable to Noncontrolling Interest										Add: Loss Attributable to Noncontrolling Interest	9		—		9
Segment Income	Segment Income		$	820	$	705		$	115	Segment Income	$	723	$	820	$	(97)

Duke Energy Carolinas GWh sales	Duke Energy Carolinas GWh sales		21,962		21,236			726		Duke Energy Carolinas GWh sales	22,549		21,962		587
Duke Energy Progress GWh sales	Duke Energy Progress GWh sales		16,537		15,670			867		Duke Energy Progress GWh sales	17,969		16,537		1,432
Duke Energy Florida GWh sales	Duke Energy Florida GWh sales		8,554		8,617			(63)		Duke Energy Florida GWh sales	9,902		8,554		1,348
Duke Energy Ohio GWh sales	Duke Energy Ohio GWh sales		6,004		5,823			181		Duke Energy Ohio GWh sales	5,997		6,004		(7)
Duke Energy Indiana GWh sales	Duke Energy Indiana GWh sales		7,726		7,606			120		Duke Energy Indiana GWh sales	7,950		7,726		224
Total Electric Utilities and Infrastructure GWh sales	Total Electric Utilities and Infrastructure GWh sales		60,783		58,952			1,831		Total Electric Utilities and Infrastructure GWh sales	64,367		60,783		3,584
Net proportional MW capacity in operation	Net proportional MW capacity in operation		50,026		49,561			465		Net proportional MW capacity in operation	49,340		50,026		(686)

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Electric Utilities and Infrastructure’s ~~higher~~lower segment income is due to ~~better weather compared to prior year, lower labor related expenses~~the Indiana Supreme Court ruling on recovery of certain coal ash costs and ~~rate case contributions in various jurisdictions.~~higher storm costs, partially offset by higher retail sales volumes. The following is a detailed discussion of the variance drivers by line item.

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

•~~a $92 million increase in retail sales, net of fuel revenues, due to better weather compared to prior year;~~

•~~a $33 million increase primarily due to higher base rate pricing from the Duke Energy Indiana retail rate case, partially offset by lower rider revenues;~~

•~~an $18 million increase in retail pricing due to base rate adjustments related to Duke Energy Florida annual increases from the 2017 Settlement Agreement and the solar base rate adjustment; and~~

•~~an $8 million increase in retail pricing primarily due to the Duke Energy Kentucky general rate case.~~

~~Partially offset by:~~

•~~a $24 million decrease in rider revenues at Duke Energy Carolinas primarily due to energy efficiency programs;~~

•~~a $15 million decrease in wholesale power revenues, net of fuel, at Duke Energy Florida primarily due to a restructured capacity contract which was converted to a seasonal contract; and~~

•~~an $8 million decrease in weather-normal retail sales volumes.~~

8882


MD&A			SEGMENT RESULTS — ELECTRIC UTILITIES AND INFRASTRUCTURE

Operating Revenues. The variance was driven primarily by:

•a $266 million increase in fuel revenues primarily due to higher fuel prices and retail sales volumes;

•a $243 million increase in weather-normal retail sales volumes;

•a $126 million increase in retail base rate pricing due to general rate cases in North Carolina, net of rider impacts as well as multiyear rate adjustments in Florida; and

•a $46 million increase in wholesale revenues primarily due to higher capacity volumes.

Partially offset by

•a $46 million decrease due to the Indiana Supreme Court ruling on recovery of certain coal ash costs.

Operating Expenses. The variance was driven primarily by:

•~~an $80~~a $375 million increase in fuel used in electric generation and purchased power due to higher fuel prices and volumes from customer demand;

•a $214 million increase in impairment of assets and other charges primarily due to the Indiana Supreme Court ruling on recovery of certain coal ash costs;

•a $144 million increase in operation, maintenance and other primarily driven by higher storm costs and higher outage and maintenance costs;

•a $74 million increase in depreciation and amortization primarily due to ~~accelerated depreciation~~higher plant in service and resolution of ~~retired coal units Crystal River 1 and 2, a change in depreciation rates from the Indiana, North Carolina and South Carolina retail~~prior year rate cases, partially offset by lower depreciation related to the extension of the lives of nuclear facilities; and

•a $26 million increase in property and ~~additional plant~~other taxes primarily due to higher payroll taxes due to CARES Act employee retention credits in ~~service.~~the prior year, increased property tax as well as higher revenue related taxes.

Interest Expense. The variance was primarily driven by interest expense on excess deferred tax liabilities.

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, 2022, and 2021, were 10.4% and 12.1%, respectively. The decrease in the ETR was primarily due to the amortization of excess deferred taxes in relation to lower pretax income.

Gas Utilities and Infrastructure


	Three Months Ended March 31,
(in millions)		2022		2021		Variance
Operating Revenues		$	1,032	$	775	$	257
Operating Expenses
Cost of natural gas		481		276		205
Operation, maintenance and other		182		102		80
Depreciation and amortization		79		68		11
Property and other taxes		41		35		6

Total operating expenses		783		481		302

Operating Income		249		294		(45)



Other Income and Expenses, Net		17		17		—
Interest Expense		40		33		7
Income Before Income Taxes		226		278		(52)
Income Tax (Benefit) Expense		(28)		33		(61)

Segment Income		$	254	$	245	$	9

Piedmont LDC throughput (dekatherms)		180,187,101		149,626,582		30,560,519
Duke Energy Midwest LDC throughput (Mcf)		37,246,072		37,109,003		137,069

Three Months Ended March 31, 2022, as compared to March 31, 2021

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


MD&A			SEGMENT RESULTS — GAS UTILITIES AND INFRASTRUCTURE

Operating Revenues.The variance was driven primarily by:

•a $205 million increase due to higher natural gas costs passed through to customers and increased off-system sales natural gas costs, partially offset by lower residential volumes;

•a $35 million increase due to base rate increases;

•a $7 million increase due to rider revenues related to Ohio Capital Expenditure Program (CEP); and

•a $6 million increase due to customer growth.

Partially offset by:

•a ~~$43~~$15 million decrease due to the MGP settlement.

Operating Expenses.The variance was driven primarily by:

•a $205 million increase in cost of natural gas due to higher natural gas costs passed through to customers and increased off-system sales natural gas costs, partially offset by lower residential volumes;

•an $80 million increase in operation, maintenance and other primarily ~~driven by lower labor related expenses, partially offset by higher storm costs.~~due to the MGP settlement; and

~~Other Income~~•an $11 million increase in depreciation and ~~Expenses, net.~~ ~~The variance was primarily~~amortization due to additional plant in service and lower ~~non-service pension costs and unrealized gains on the Duke Energy Florida nuclear decommissioning trust fund.~~CEP deferrals.

Income Tax ~~Expense.~~Benefit. The decrease in tax expense was primarily due to an increase in the amortization of excess deferred taxes ~~partially offset by an increase~~related to the Ohio MGP Settlement and a decrease in pretax income.The ETRs for the three months ended March 31, 2022, and 2021, were -12.4% and ~~2020, were 12.1% and 17.6%~~11.9%, respectively. The decrease in the ETR was primarily due to an increase in the amortization of excess deferred ~~taxes.~~taxes related to the Ohio MGP Settlement.

~~Gas Utilities and Infrastructure~~

Three Months Ended March 31,
(in millions) 2021 2020 Variance
Operating Revenues $ 775 $ 664 $ 111
Operating Expenses
Cost of natural gas 276 199 77
Operation, maintenance and other 102 110 (8)
Depreciation and amortization 68 66 2
Property and other taxes 35 30 5
Total operating expenses 481 405 76
Operating Income 294 259 35
Other Income and Expenses, net 17 49 (32)
Interest Expense 33 31 2
Income Before Income Taxes 278 277 1
Income Tax Expense 33 28 5
Segment Income $ 245 $ 249 $ (4)
Piedmont LDC throughput (dekatherms) 149,626,582 148,503,995 1,122,587
Duke Energy Midwest LDC throughput (Mcf) 37,109,003 33,785,834 3,323,169

~~Three Months Ended March 31, 2021, as compared to March 31, 2020~~

Gas Utilities and Infrastructure’s results were impacted primarily by the cancellation of the ACP pipeline offset by margin growth at Piedmont. The following is a detailed discussion of the variance drivers by line item.

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

•~~a $77 million increase due to higher natural gas costs passed through to customers, higher volumes and increased off-system sales natural gas costs;~~

•~~an $11 million increase due to Tennessee base rate case increases; and~~

•~~a $7 million increase due to North Carolina IMR.~~

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

•~~a $77 million increase in cost of natural gas primarily due to higher natural gas prices, higher volumes and increased off-system sales natural gas costs.~~

~~Other Income and Expenses, net.~~ ~~The variance was primarily driven by the cancellation of the ACP pipeline.~~

~~Income Tax Expense.~~ ~~The increase in the tax expense was primarily due to a decrease in AFUDC equity, partially offset by an increase in the amortization of excess deferred taxes~~. The ETRs for the three months ended March 31, 2021, and 2020 were 11.9% and 10.1%, respectively. The increase in the ETR was primarily due to a decrease in AFUDC equity, partially offset by an increase in the amortization of excess deferred taxes.


~~MD&A~~			~~SEGMENT RESULTS — COMMERCIAL RENEWABLES~~

Commercial Renewables


		Three Months Ended March 31,					Three Months Ended March 31,
(in millions)	(in millions)		2021		2020			Variance		(in millions)	2022		2021		Variance
Operating Revenues	Operating Revenues		$	119	$	129		$	(10)	Operating Revenues	$	121	$	119	$	2
Operating Expenses	Operating Expenses									Operating Expenses
Operation, maintenance and other	Operation, maintenance and other		72		69			3		Operation, maintenance and other	82		72		10
Depreciation and amortization	Depreciation and amortization		53		48			5		Depreciation and amortization	60		53		7
Property and other taxes	Property and other taxes		9		8			1		Property and other taxes	10		9		1

Total operating expenses	Total operating expenses		134		125			9		Total operating expenses	152		134		18

Operating Income			(15)		4			(19)
Losses on Sales of Other Assets and Other, net										Losses on Sales of Other Assets and Other, net	(1)		—		(1)
Operating Loss										Operating Loss	(32)		(15)		(17)
Other Income and Expenses, net	Other Income and Expenses, net		(25)		(1)			(24)		Other Income and Expenses, net	—		(25)		25
Interest Expense	Interest Expense		13		18			(5)		Interest Expense	18		13		5
Loss Before Income Taxes	Loss Before Income Taxes		(53)		(15)			(38)		Loss Before Income Taxes	(50)		(53)		3
Income Tax Benefit	Income Tax Benefit		(29)		(24)			(5)		Income Tax Benefit	(33)		(29)		(4)
Add: Loss Attributable to Noncontrolling Interests	Add: Loss Attributable to Noncontrolling Interests		51		48			3		Add: Loss Attributable to Noncontrolling Interests	28		51		(23)
Segment Income	Segment Income		$	27	$	57		$	(30)	Segment Income	$	11	$	27	$	(16)

Renewable plant production, GWh	Renewable plant production, GWh		2,588		2,437			151		Renewable plant production, GWh	2,988		2,588		400
Net proportional MW capacity in operation(a)	Net proportional MW capacity in operation(a)		4,294		3,502			792		Net proportional MW capacity in operation(a)	4,753		4,294		459

(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, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Commercial Renewables' results were unfavorable primarily ~~due to~~driven by fewer project investments financed by tax equity being placed into service in the current year and higher operating expenses for projects placed in service since the prior year, offset by the impacts for losses experienced in the prior year from Texas Storm ~~Uri resulting in a $35 million pre-tax loss.~~Uri.

Operating ~~Revenues.~~Expenses. The variance was primarily driven by a $13 million decrease for lower market prices in the current year impacting the wind portfolio and a $8 million decrease due to low wind resource and operating downtime. This was partially offset by an $8$14 million increase for ~~market sales in excess of market purchases during Texas Storm Uri~~higher operating expenses, depreciation, property tax expense, and ~~a $5 million increase due to growth of new projects.~~

~~Operating Expenses.~~ ~~The variance was primarily driven by a $7 million increase due to~~other development costs from the growth of new projects ~~placed in service~~ and a $2$4 million increase ~~associated with Texas Storm Uri.~~for higher operating expenses attributed to maintenance and other operating expenses.

Other Income and Expenses, net. The ~~variance~~increase was primarily ~~driven by a~~due to $29 million ~~loss~~of losses experienced in ~~equity earnings due to~~ the ~~impacts~~prior year from Texas Storm Uri ~~partially~~ offset by $4approximately $5 million ~~increase~~decrease in equity ~~earnings from the wind and distributed asset portfolios.~~earnings.

Interest Expense. The ~~decrease was~~increase is primarily ~~driven by~~due to a $4 million gain onrecorded in the prior year for an interest rate swap that ~~does~~did not qualify for hedge accounting.

~~Income Tax Benefit.~~ ~~The increase in the tax benefit was primarily driven by an increase in pretax losses, partially offset by a decrease in production tax credits generated.~~

~~Loss Attributable to Noncontrolling Interests.~~ ~~The increase was driven primarily by $15 million for the growth of new projects financed by tax equity, partially offset by a $12 million loss resulting from Texas Storm Uri.~~

~~Other~~

Three Months Ended March 31,
(in millions) 2021 2020 Variance
Operating Revenues $ 26 $ 23 $ 3
Operating Expenses 28 (89) 117
Operating (Loss) Income (2) 112 (114)
Other Income and Expenses, net 21 (33) 54
Interest Expense 151 171 (20)
Loss Before Income Taxes (132) (92) (40)
Income Tax Benefit (32) (19) (13)
Less: Preferred Dividends 39 39 —
Net Loss $ (139) $ (112) $ (27)

9084


MD&A			SEGMENT RESULTS — COMMERCIAL RENEWABLES

Income Tax Benefit. The increase in the tax benefit was primarily due to a decrease in taxes associated with tax equity investments.

Loss Attributable to Noncontrolling Interests. The variance was driven by a $23 million decrease for fewer projects placed in service financed with tax equity in the current year and a $12 million net decrease in losses allocated to tax equity members from existing tax equity structures offset by a $12 million increase for losses experienced in the prior year from Texas Storm Uri.

Other


	Three Months Ended March 31,
(in millions)		2022		2021		Variance
Operating Revenues		$	30	$	26	$	4






Operating Expenses		33		28		5
Gains on Sales of Other Assets and Other, net		1		—		1
Operating Loss		(2)		(2)		—
Other Income and Expenses, net		(6)		21		(27)
Interest Expense		159		151		8
Loss Before Income Taxes		(167)		(132)		(35)
Income Tax Benefit		(36)		(32)		(4)

Less: Preferred Dividends		39		39		—
Net Loss		$	(170)	$	(139)	$	(31)

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

The higher net loss was driven by ~~the prior year reversal of severance charges incurred in previous periods,~~lower return on investments and higher interest expense partially offset by higher ~~returns on investments that fund certain employee benefit obligations and lower interest rates. The following is a detailed discussion of~~equity earnings from the ~~variance drivers by line item.~~

~~Operating Expenses.~~ The increase was primarily due to the 2020 reversal of severance charges, incurred as a result of a 2018 corporate cost savings initiative, due to reaching settlement for regulatory recovery and higher expenses associated with certain employee benefit obligations.NMC investment.

Other Income and Expenses, net. The variance was primarily due to ~~higher returns~~lower return on investments that fund certain employee benefit ~~obligations.~~obligations partially offset by higher equity earnings from the NMC investment.

Interest Expense. The variance was primarily due to ~~lower interest rates on floating rate~~higher outstanding long-term debt.

Income Tax Benefit. The increase in the tax benefit was primarily ~~driven by~~due to an increase in pretax ~~losses.~~losses, partially offset by unfavorable tax impacts related to lower investment returns on certain employee benefit obligations. The ETRs for the three months ended March 31, 2022, and 2021, were 21.6% and ~~2020 were~~ 24.2% ~~and 20.7%~~, respectively. The ~~increase~~decrease in the ETR was primarily due to unfavorable tax impacts ~~in the prior year~~ related to lower investment returns on certain employee benefit obligations.

DUKE ENERGY CAROLINAS

Results of Operations


		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance
Operating Revenues	Operating Revenues	$	1,716	$	1,748	$	(32)	Operating Revenues	$	1,888	$	1,716	$	172
Operating Expenses	Operating Expenses							Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power	422		453		(31)		Fuel used in electric generation and purchased power	448		422		26
Operation, maintenance and other	Operation, maintenance and other	441		386		55		Operation, maintenance and other	512		441		71
Depreciation and amortization	Depreciation and amortization	359		343		16		Depreciation and amortization	379		359		20
Property and other taxes	Property and other taxes	83		81		2		Property and other taxes	93		83		10
Impairment of assets and other charges	Impairment of assets and other charges	—		2		(2)		Impairment of assets and other charges	3		—		3
Total operating expenses	Total operating expenses	1,305		1,265		40		Total operating expenses	1,435		1,305		130
Gains on Sales of Other Assets and Other, net		—		1		(1)

Operating Income	Operating Income	411		484		(73)		Operating Income	453		411		42
Other Income and Expenses, net	Other Income and Expenses, net	48		43		5		Other Income and Expenses, net	55		48		7
Interest Expense	Interest Expense	124		123		1		Interest Expense	141		124		17
Income Before Income Taxes	Income Before Income Taxes	335		404		(69)		Income Before Income Taxes	367		335		32
Income Tax Expense	Income Tax Expense	23		65		(42)		Income Tax Expense	27		23		4
Net Income	Net Income	$	312	$	339	$	(27)	Net Income	$	340	$	312	$	28


MD&A			DUKE ENERGY CAROLINAS

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	~~2021~~2022
Residential sales	~~13.5~~(3.6)	%
General service sales	~~(3.6)~~4.2	%
Industrial sales	~~(2.4)~~4.7	%
Wholesale power sales	~~15.0~~(4.6)	%
Joint dispatch sales	~~33.0~~(30.0)	%
Total sales	~~3.4~~2.7	%
Average number of customers	~~2.1~~2.0	%

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Operating Revenues. The variance was driven primarily by:

•a ~~$33~~$99 million ~~decrease~~increase in ~~fuel revenues due to lower prices and~~weather-normal retail sales volumes;

•a ~~$24~~$31 million ~~decrease~~increase in ~~rider~~fuel revenues ~~primarily~~ due to ~~energy efficiency programs;~~higher prices and volumes in the current year; and

•a ~~$14 million decrease in weather-normal retail sales volumes.~~

~~Partially offset by:~~

•~~a $50~~$20 million increase ~~in retail sales~~ due to ~~better weather compared~~higher pricing from the North Carolina retail rate case, net of a return of EDIT to ~~prior year.~~customers.


~~MD&A~~			~~DUKE ENERGY CAROLINAS~~

Operating Expenses. The variance was driven primarily by:

•a ~~$55~~$71 million increase in operation, maintenance and other expense primarily ~~driven by the deferral of 2018 severance costs~~ due to ~~the partial settlement agreement with the Public Staff of the NCUC related to the 2019 North Carolina retail rate case recorded in 2020;~~ ~~partially offset by lower nuclear~~higher storm restoration costs and higher outage and maintenance costs;~~and~~

•a ~~$16~~$26 million increase ~~in depreciation and amortization expense primarily due to additional plant in service and new depreciation rates associated with the North Carolina rate cases.~~

~~Partially offset by:~~

•~~a $31 million decrease~~ in fuel used in electric generation and purchased power primarily due to higher natural gas prices and changes in the generation mix, partially offset by the recovery of fuel expenses and lower ~~retail sales volumes.~~coal prices; and

•a $20 million increase in depreciation and amortization primarily due to an increase in assets placed into service, and new depreciation rates associated with the North Carolina rate case, partially offset by the extension of the lives of nuclear facilities.

Interest Expense. The variance was driven by interest expense on excess deferred tax liabilities.

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

PROGRESS ENERGY

Results of Operations


		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance
Operating Revenues	Operating Revenues	$	2,505	$	2,422	$	83	Operating Revenues	$	2,992	$	2,505	$	487
Operating Expenses	Operating Expenses							Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power	795		763		32		Fuel used in electric generation and purchased power	1,064		795		269
Operation, maintenance and other	Operation, maintenance and other	601		554		47		Operation, maintenance and other	645		601		44
Depreciation and amortization	Depreciation and amortization	485		452		33		Depreciation and amortization	536		485		51
Property and other taxes	Property and other taxes	142		135		7		Property and other taxes	152		142		10

Total operating expenses	Total operating expenses	2,023		1,904		119		Total operating expenses	2,397		2,023		374
Losses on Sales of Other Assets and Other, net		—		(1)		1
Gains on Sales of Other Assets and Other, net								Gains on Sales of Other Assets and Other, net	2		—		2
Operating Income	Operating Income	482		517		(35)		Operating Income	597		482		115
Other Income and Expenses, net	Other Income and Expenses, net	43		32		11		Other Income and Expenses, net	35		43		(8)
Interest Expense	Interest Expense	192		206		(14)		Interest Expense	211		192		19
Income Before Income Taxes	Income Before Income Taxes	333		343		(10)		Income Before Income Taxes	421		333		88
Income Tax Expense	Income Tax Expense	43		60		(17)		Income Tax Expense	67		43		24
Net Income	Net Income	290		283		7		Net Income	354		290		64

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Operating Revenues. The variance was driven primarily by:

•a ~~$33 million increase in retail sales, net of fuel revenues, due to better weather compared to prior year;~~

•~~a $21~~$237 million increase in fuel cost recovery driven by higher fuel prices and volumes in the current year;

•a ~~$19~~$124 million increase in ~~fuel and capacity revenues primarily due to recovery of the remaining value of retired coal units Crystal River 1 and 2; and~~

•~~an $18 million increase in~~weather-normal retail ~~pricing due to base rate adjustments related to annual increases from the 2017 Settlement Agreement and the solar base rate adjustment.~~

~~Partially offset by:~~

•~~a $15 million decrease in wholesale power revenues, net of fuel, primarily due to a restructured capacity contract, which was converted to a seasonal contract at Duke Energy Florida.~~

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

•a $47 million increase 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 with the Public Staff of the NCUC related to the 2019 North Carolina retail rate case recorded in 2020, as well as increased storm costs;

•~~a $33 million increase in depreciation and amortization primarily due to accelerated depreciation of retired coal units Crystal River 1 and 2, and increase in plant base; and~~

•~~a $32 million increase in fuel used in electric generation and purchased power primarily due to higher demand and changes in generation mix at Duke Energy Progress.~~

~~Other Income and Expenses, net.~~ ~~The increase is primarily due to unrealized gains on the nuclear decommissioning trust fund and pension plan assets at Duke Energy Florida.~~sales volumes;

9286


MD&A			PROGRESS ENERGY

•a $106 million increase in retail pricing due to the North Carolina rate case and base rate adjustments at Duke Energy Florida related to annual increases from the 2021 Settlement Agreement and the solar base rate adjustment; and

•a $32 million increase in wholesale revenues, net of fuel, due to higher capacity volumes.

Partially offset by:

•a $22 million decrease in capacity revenue primarily due to accelerated recovery of retired Crystal River coal units in 2021.

Operating Expenses. The variance was driven primarily by:

•a $269 million increase in fuel used in electric generation and purchased power primarily due to higher demand and higher natural gas prices;

•a $51 million increase in depreciation and amortization primarily due to increased rates at Duke Energy Florida and higher amortization of deferred coal ash and storm costs at Duke Energy Progress, partially offset by the extension of the lives at nuclear facilities at Duke Energy Progress; and

•a $44 million increase in operation, maintenance and other expense primarily due to higher storm costs at Duke Energy Progress.

Interest Expense. The variance was driven primarily by ~~lower intercompany~~ interest expense on excess deferred tax liabilities and ~~lower~~higher outstanding debt ~~outstanding~~ at ~~Progress~~Duke Energy ~~Inc.~~Progress.

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

DUKE ENERGY PROGRESS

Results of Operations


		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance
Operating Revenues	Operating Revenues	$	1,401	$	1,338	$	63	Operating Revenues	$	1,632	$	1,401	$	231
Operating Expenses	Operating Expenses							Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power	436		405		31		Fuel used in electric generation and purchased power	574		436		138
Operation, maintenance and other	Operation, maintenance and other	357		305		52		Operation, maintenance and other	391		357		34
Depreciation and amortization	Depreciation and amortization	285		287		(2)		Depreciation and amortization	306		285		21
Property and other taxes	Property and other taxes	49		47		2		Property and other taxes	49		49		—

Total operating expenses	Total operating expenses	1,127		1,044		83		Total operating expenses	1,320		1,127		193
Losses on Sales of Other Assets and Other, net		—		(1)		1
Gains on Sales of Other Assets and Other, net								Gains on Sales of Other Assets and Other, net	1		—		1
Operating Income	Operating Income	274		293		(19)		Operating Income	313		274		39
Other Income and Expenses, net	Other Income and Expenses, net	24		22		2		Other Income and Expenses, net	22		24		(2)
Interest Expense	Interest Expense	69		69		—		Interest Expense	85		69		16
Income Before Income Taxes	Income Before Income Taxes	229		246		(17)		Income Before Income Taxes	250		229		21
Income Tax Expense	Income Tax Expense	19		42		(23)		Income Tax Expense	35		19		16
Net Income	Net Income	$	210	$	204	$	6	Net Income	$	215	$	210	$	5


Increase (Decrease) over prior period	~~2021~~2022
Residential sales	~~18.7~~(4.5)	%
General service sales	~~(0.9)~~10.3	%
Industrial sales	~~(1.8)~~27.8	%
Wholesale power sales	~~10.2~~1.0	%
Joint dispatch sales	~~(7.6)~~51.4	%
Total sales	~~5.5~~8.7	%
Average number of customers	2.0	%

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Operating Revenues. The variance was driven primarily by:

•a ~~$42 million increase in retail sales due to better weather compared to prior year; and~~

•~~a $21~~$120 million increase in fuel cost recovery driven by higher fuel prices and volumes in the current ~~year.~~

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

•a ~~$52~~$56 million increase ~~in operation, maintenance and other expense primarily driven by the deferral of 2018 severance costs~~ due to higher pricing from the ~~partial settlement agreement with the Public Staff of the NCUC related to the 2019~~ North Carolina retail rate case, ~~recorded in 2020, as well as increased storm costs; and~~

•net of a ~~$31 million increase in fuel used in electric generation and purchased power primarily due~~return of EDIT to ~~higher demand and changes in generation mix.~~

~~Income Tax Expense.~~ ~~The decrease in tax expense was primarily due to an increase in the amortization of excess deferred taxes.~~customers;

9387


MD&A			DUKE ENERGY ~~FLORIDA~~PROGRESS

•a $33 million increase in weather-normal retail sales volumes in the current year; and

•a $16 million increase in wholesale revenues, net of fuel, due to higher capacity volumes.

Operating Expenses. The variance was driven primarily by:

•a $138 million increase in fuel used in electric generation and purchased power primarily due to higher natural gas prices and changes in the generation mix, partially offset by the recovery of fuel expenses and lower coal prices;

•a $34 million increase in operation, maintenance and other expense primarily due to higher storm costs; and

•a $21 million increase in depreciation and amortization due to higher amortization of deferred coal ash costs and amortization related to deferred storm costs, partially offset by lower depreciation related to the extension of the lives of nuclear facilities.

Interest Expense. The variance was driven primarily by interest expense on excess deferred tax liabilities and higher outstanding debt.

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

DUKE ENERGY FLORIDA

Results of Operations


		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance
Operating Revenues	Operating Revenues	$	1,101	$	1,080	$	21	Operating Revenues	$	1,355	$	1,101	$	254
Operating Expenses	Operating Expenses							Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power	359		358		1		Fuel used in electric generation and purchased power	490		359		131
Operation, maintenance and other	Operation, maintenance and other	242		245		(3)		Operation, maintenance and other	249		242		7
Depreciation and amortization	Depreciation and amortization	200		165		35		Depreciation and amortization	231		200		31
Property and other taxes	Property and other taxes	93		88		5		Property and other taxes	103		93		10

Total operating expenses	Total operating expenses	894		856		38		Total operating expenses	1,073		894		179

Gains on Sales of Other Assets and Other, net								Gains on Sales of Other Assets and Other, net	1		—		1
Operating Income	Operating Income	207		224		(17)		Operating Income	283		207		76
Other Income and Expenses, net	Other Income and Expenses, net	18		10		8		Other Income and Expenses, net	15		18		(3)
Interest Expense	Interest Expense	80		84		(4)		Interest Expense	84		80		4
Income Before Income Taxes	Income Before Income Taxes	145		150		(5)		Income Before Income Taxes	214		145		69
Income Tax Expense	Income Tax Expense	28		30		(2)		Income Tax Expense	43		28		15
Net Income	Net Income	$	117	$	120	$	(3)	Net Income	$	171	$	117	$	54

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	~~2021~~2022
Residential sales	~~10.5~~0.9	%
General service sales	~~(2.1)~~4.0	%
Industrial sales	~~5.6~~(0.9)	%
Wholesale and other	~~38.2~~77.4	%
Total sales	~~(0.7)~~15.8	%
Average number of customers	1.9	%

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Operating Revenues. The variance was driven primarily by:

•a ~~$19~~$117 million increase in fuel ~~and capacity revenues~~revenue primarily due to ~~recovery of the remaining value of retired coal units Crystal River 1~~higher retail sales volumes and 2;higher fuel rate in current year in response to an increase in natural gas prices;

•~~an $18~~a $91 million increase in weather-normal retail sales volumes;

•a $50 million increase in retail pricing due to base rate adjustments related to annual increases from the ~~2017~~2021 Settlement Agreement and the solar base rate adjustment;

•~~an $8 million increase in rider revenues primarily due to increased volumes;~~

•~~a $7 million increase in transmission revenues and customer equipment rentals:~~ and

•a $5$16 million increase ~~in weather-normal retail sales volumes.~~

~~Partially offset by:~~

•~~a $15 million decrease~~ in wholesale power revenues, net of fuel, primarily due to ~~a restructured~~higher capacity ~~contract which was converted to a seasonal contract;~~revenues and bulk power sales.

Partially offset by:

•a ~~$12~~$22 million decrease in ~~storm revenues due to full recovery of Hurricane Dorian costs in the prior year; and~~

•~~a $9 million decrease in retail sales, net of fuel revenues, due to unfavorable weather in the current year.~~

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

•~~a $35 million increase in depreciation and amortization~~capacity revenue primarily due to accelerated ~~depreciation~~recovery of the retired coal units Crystal River 1 and 2 ~~and an increase~~ in ~~plant base.~~

~~Other Income and Expense, net.~~ ~~The increase is primarily due to lower non-service pension costs and unrealized gains on the nuclear decommissioning trust fund.~~2021.

9488


MD&A			DUKE ENERGY ~~OHIO~~FLORIDA

Operating Expenses. The variance was driven primarily by:

•a $131 million increase in fuel used in electric generation and purchased power primarily due to higher natural gas prices;

•a $31 million increase in depreciation and amortization primarily due to an increase in depreciation rates starting in January 2022; and

•a $10 million increase in property and other taxes primarily due to an increase in gross receipts taxes.

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

DUKE ENERGY OHIO

Results of Operations


		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance
Operating Revenues	Operating Revenues							Operating Revenues
Regulated electric	Regulated electric	$	363	$	346	$	17	Regulated electric	$	412	$	363	$	49
Regulated natural gas	Regulated natural gas	169		152		17		Regulated natural gas	226		169		57

Total operating revenues	Total operating revenues	532		498		34		Total operating revenues	638		532		106
Operating Expenses	Operating Expenses							Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power	82		87		(5)		Fuel used in electric generation and purchased power	127		82		45

Cost of natural gas	Cost of natural gas	51		37		14		Cost of natural gas	107		51		56
Operation, maintenance and other	Operation, maintenance and other	108		123		(15)		Operation, maintenance and other	178		108		70
Depreciation and amortization	Depreciation and amortization	74		68		6		Depreciation and amortization	80		74		6
Property and other taxes	Property and other taxes	92		83		9		Property and other taxes	101		92		9

Total operating expenses	Total operating expenses	407		398		9		Total operating expenses	593		407		186

Operating Income	Operating Income	125		100		25		Operating Income	45		125		(80)
Other Income and Expenses, net	Other Income and Expenses, net	5		3		2		Other Income and Expenses, net	6		5		1
Interest Expense	Interest Expense	25		24		1		Interest Expense	30		25		5
Income Before Income Taxes	Income Before Income Taxes	105		79		26		Income Before Income Taxes	21		105		(84)
Income Tax Expense		14		14		—
Income Tax (Benefit) Expense								Income Tax (Benefit) Expense	(56)		14		(70)

Net Income	Net Income	$	91	$	65	$	26	Net Income	$	77	$	91	$	(14)

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			Electric		Natural Gas
Increase (Decrease) over prior year	Increase (Decrease) over prior year	2021				Increase (Decrease) over prior year	2022
Residential sales	Residential sales	13.0	%	13.6	%	Residential sales	(4.9)	%	1.5	%
General service sales	General service sales	(1.2)	%	12.0	%	General service sales	(1.0)	%	1.0	%
Industrial sales	Industrial sales	(2.2)	%	(0.8)	%	Industrial sales	(2.9)	%	(2.3)	%
Wholesale electric power sales	Wholesale electric power sales	115.8	%	n/a		Wholesale electric power sales	(19.0)	%	n/a
Other natural gas sales	Other natural gas sales	n/a		0.8	%	Other natural gas sales	n/a		(2.8)	%
Total sales	Total sales	3.1	%	9.8	%	Total sales	(0.1)	%	0.4	%
Average number of customers	Average number of customers	0.8	%	0.8	%	Average number of customers	1.0	%	0.8	%

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Operating Revenues. The variance was driven primarily by:

•a ~~$10~~$93 million increase in fuel related revenues primarily due to higher natural gas prices and increased volumes;

•~~an $8~~a $10 million increase in retail ~~pricing~~revenue riders, primarily due to the ~~Duke Energy~~Ohio Capital Expenditure Program (CEP), Distribution Capital Investment Rider (DCI), excise tax riders as a result of increased revenue and Kentucky ~~general rate case;~~Gas Weather Normalization rider, partially offset by decreases in Kentucky Environmental Surcharge Mechanism and the Ohio Tax Cuts and Jobs Act rider;

•a $7$9 million increase in weather-normal retail sales volumes;

•a $6 million increase in revenues ~~due~~related to ~~better weather compared to prior year;~~OVEC collections and OVEC sales into PJM; and

•a $7$5 million increase in PJM transmission revenues as a result of increased capital ~~spend;~~

•~~a $4 million increase in other revenues due to higher OVEC sales into PJM; and~~

•~~a $3 million increase in bulk power marketing sales.~~spend.

Partially offset by:

•a $7$15 million decrease ~~in retail revenue riders primarily~~ due to the suspension of the Ohio energy efficiency rider and a decrease in the Kentucky gas weather normalization rider, partially offset by an increase in the distribution capital investment rider due to an increase in capital spend.MGP settlement.

9589


MD&A			DUKE ENERGY OHIO

Operating Expenses. The variance was driven primarily by:

•a $9$101 million increase in fuel expense primarily driven by higher retail prices and increased volumes for natural ~~gas;~~gas and purchased power;

•a $70 million increase in operation, maintenance and other expense primarily due to the MGP settlement and higher storm costs;

•a $9 million increase in property and other taxes primarily due to increased plant in service, higher kilowatt and natural gas distribution taxes due to increased usage and a lower Network Integration Transmission Service tax deferral; and

•a $6 million increase in depreciation and amortization primarily driven by lower CEP deferrals and an increase in distribution ~~plant.~~plant in service.

~~. Partially offset by:~~

•Income Tax Benefit.~~a $15 million~~ The decrease in ~~operations, maintenance and other~~tax expense was primarily due ~~lower vegetation management costs, employee-related expenses, environmental reserves~~to an increase in the amortization of excess deferred taxes related to the MGP Settlement and ~~energy efficiency program costs~~a decrease in ~~Ohio.~~pretax income.

DUKE ENERGY INDIANA

Results of Operations


		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance
Operating Revenues	Operating Revenues	$	745	$	692	$	53	Operating Revenues	$	822	$	745	$	77
Operating Expenses	Operating Expenses							Operating Expenses
Fuel used in electric generation and purchased power	Fuel used in electric generation and purchased power	217		194		23		Fuel used in electric generation and purchased power	319		217		102
Operation, maintenance and other	Operation, maintenance and other	178		186		(8)		Operation, maintenance and other	192		178		14
Depreciation and amortization	Depreciation and amortization	152		132		20		Depreciation and amortization	156		152		4
Property and other taxes	Property and other taxes	21		22		(1)		Property and other taxes	25		21		4

Impairment of assets and other charges								Impairment of assets and other charges	211		—		211
Total operating expenses	Total operating expenses	568		534		34		Total operating expenses	903		568		335

Operating Income		177		158		19
Operating (Loss) Income								Operating (Loss) Income	(81)		177		(258)
Other Income and Expenses, net	Other Income and Expenses, net	9		10		(1)		Other Income and Expenses, net	10		9		1
Interest Expense	Interest Expense	50		43		7		Interest Expense	45		50		(5)
Income Before Income Taxes		136		125		11
Income Tax Expense		24		26		(2)
Net Income		$	112	$	99	$	13
(Loss) Income Before Income Taxes								(Loss) Income Before Income Taxes	(116)		136		(252)
Income Tax (Benefit) Expense								Income Tax (Benefit) Expense	(37)		24		(61)
Net (Loss) Income								Net (Loss) Income	$	(79)	$	112	$	(191)


Increase (Decrease) over prior year	~~2021~~2022
Residential sales	~~12.3~~(3.8)	%
General service sales	~~(0.2)~~0.3	%
Industrial sales	~~(2.6)~~(5.3)	%
Wholesale power sales	~~12.1~~11.9	%
Total sales	~~1.6~~2.9	%
Average number of customers	~~1.2~~1.3	%

Three Months Ended March 31, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Operating Revenues. The variance was driven primarily by:

•a ~~$33 million increase primarily due to higher base rate pricing from the Indiana retail rate case, net of lower rider revenues; and~~

•~~a $19~~$77 million increase in fuel revenues primarily due to higher fuel cost recovery driven by customer demand and fuel ~~prices.~~prices;

•a $16 million increase in weather-normal retail sales volumes driven by higher nonresidential customer demand;

•a $14 million increase in wholesale revenues primarily due to an increase in BPM sharing provision; and

•a $9 million increase in retail sales due to favorable weather in the current year.

Partially offset by:

•a $46 million decrease due to the Indiana Supreme Court ruling on recovery of certain coal ash costs.


MD&A			DUKE ENERGY INDIANA

Operating Expenses. The variance was driven primarily by:

•a ~~$23~~$211 million increase in impairment of assets and other charges primarily due to the Indiana Supreme Court ruling on recovery of certain coal ash costs;

•a $102 million increase in fuel used in electric generation and purchased power expense primarily due to higher ~~coal~~purchased power expense and higher natural gas costs; and

•a ~~$20~~$14 million increase ~~in depreciation and amortization primarily due to a change in depreciation rates from the Indiana retail rate case and additional plant in service.~~

~~Partially offset by:~~

•~~an $8 million decrease~~ in operation, maintenance and other primarily due to ~~lower outage~~higher storm costs and ~~other contractor spend.~~employee benefits.

~~Interest Expense.~~ Income Tax Benefit.The ~~variance~~decrease in tax expense was ~~driven by higher post-in-service carrying costs interest resulting~~primarily due to the change in pretax income from the coal ash impairment based on the Indiana ~~retail rate case, partially offset by higher fixed-rate debt outstanding in the prior year.~~Supreme Court Opinion.


~~MD&A~~			~~PIEDMONT~~

PIEDMONT

Results of Operations


		Three Months Ended March 31,							Three Months Ended March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance

Operating Revenues	Operating Revenues	$	606	$	512	$	94	Operating Revenues	$	805	$	606	$	199
Operating Expenses	Operating Expenses							Operating Expenses
Cost of natural gas	Cost of natural gas	225		162		63		Cost of natural gas	374		225		149
Operation, maintenance and other	Operation, maintenance and other	78		80		(2)		Operation, maintenance and other	95		78		17
Depreciation and amortization	Depreciation and amortization	48		45		3		Depreciation and amortization	54		48		6
Property and other taxes	Property and other taxes	14		12		2		Property and other taxes	16		14		2

Total operating expenses	Total operating expenses	365		299		66		Total operating expenses	539		365		174

Operating Income	Operating Income	241		213		28		Operating Income	266		241		25
Other Income and Expenses, net	Other Income and Expenses, net	17		12		5		Other Income and Expenses, net	13		17		(4)
Interest Expense	Interest Expense	29		27		2		Interest Expense	32		29		3
Income Before Income Taxes	Income Before Income Taxes	229		198		31		Income Before Income Taxes	247		229		18
Income Tax Expense	Income Tax Expense	26		20		6		Income Tax Expense	33		26		7
Net Income	Net Income	$	203	$	178	$	25	Net Income	$	214	$	203	$	11

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	~~2021~~2022
Residential deliveries	~~27.1~~(4.7)	%
Commercial deliveries	~~16.0~~2.9	%
Industrial deliveries	~~2.6~~1.1	%
Power generation deliveries	~~(12.8)~~45.8	%
For resale	~~40.9~~(3.9)	%
Total throughput deliveries	~~0.8~~20.4	%
Secondary market volumes	~~5.4~~18.8	%
Average number of customers	~~2.2~~1.6	%

The margin decoupling mechanism adjusts for variations in residential and commercial use per customer, including those due to weather and conservation. The weather normalization adjustment 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, ~~2021,~~2022, as compared to March 31, ~~2020~~2021

Operating Revenues. The variance was driven primarily by:

•a ~~$63~~$149 million increase due to higher natural gas costs passed through to customers ~~higher volumes~~ and ~~higher~~increased off-system sales natural gas ~~costs;~~costs, partially offset by lower residential volumes;

•~~an $11~~a $35 million increase due to ~~Tennessee~~ base rate ~~case~~ increases; and

•a $7$6 million increase due to ~~North Carolina IMR.~~customer growth.

Operating Expenses. The variance was driven primarily by:

•a ~~$63~~$149 million increase ~~in cost of natural gas~~ due to higher natural gas ~~prices, higher volumes~~costs passed through to customers and ~~higher~~increased off-system sales natural gas ~~costs.~~costs, partially offset by lower residential volumes.

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


MD&A			LIQUIDITY AND CAPITAL RESOURCES

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. Additionally, due to its existing tax attributes, Duke Energy does not expect to be a significant federal cash taxpayer until around 2030. Duke Energy’s Annual Report on Form 10-K for the year ended December 31, ~~2020,~~2021, included a summary and detailed discussion of projected primary sources and uses of cash for ~~2021~~2022 to ~~2023.~~


~~MD&A~~			~~LIQUIDITY AND CAPITAL RESOURCES~~

2024.

In January 2021, Duke Energy entered into a definitive agreement with an affiliate of GIC, for GIC to make a minority interest investment of 19.9% in Duke Energy Indiana. The investment will be completed following two closings for an aggregate investment amount of approximately $2 billion. The first closing is expected to be completed in the second quarter of 2021 and Duke Energy will issue 11.1% of the membership interests in exchange for 50% of the total investment amount. Duke Energy has the discretion to determine the timing of the second closing, but the closing will occur no later than January 2023. At the second closing, Duke Energy will issue additional membership interests, so GIC's minority interest ownership is 19.9% of Duke Energy Indiana, for the remaining 50% of the total investment amount. Proceeds from the minority interest investment are expected to address common equity needs through 2025 to partially fund Duke Energy's $59 billion capital and investment expenditure plan.

As of March 31, ~~2021,~~2022, Duke Energy had approximately ~~$379~~$853 million of cash on hand ~~$4.4~~and $6.1 billion available under its $8$9 billion Master Credit ~~Facility and $500 million available under the $1 billion Three-Year Revolving Credit~~ Facility. 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. Refer to Note 5 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities," for information regarding Duke Energy's debt issuances and maturities, and available credit facilities including the Master Credit Facility.

~~Credit Ratings~~

In March 2021, Moody's Investors Services, Inc. (Moody's) downgraded by one notch the long-term credit ratings for Duke Energy (Parent) and Duke Energy Carolinas. The downgrade reflects Duke Energy's balance sheet objectives. The downgrade for Duke Energy (Parent) and Duke Energy Carolinas also considers the impact for Duke Energy Carolinas and Duke Energy Progress as a result of the 2019 rate case orders and approval of the CCR Settlement Agreement. While these agreements are indicative of a regulatory environment that remains broadly supportive of utility credit quality, their financial terms resulted in current impairment charges and lowered the amount of future cash flow Duke Energy Carolinas and Duke Energy Progress will receive in conjunction with their coal ash remediation spending. As part of the credit rating action, Moody's affirmed Duke Energy's (Parent) short-term and commercial paper credit ratings and confirmed the credit ratings for Duke Energy Progress. Following a January 2021, credit rating downgrade of Duke Energy (Parent) and its subsidiaries, Standard & Poor's Rating Services continues to maintain a stable outlook on Duke Energy Corporation and its subsidiaries as of March 31, 2021.

Cash Flow Information

The following table summarizes Duke Energy’s cash flows.


		Three Months Ended					Three Months Ended
		March 31,					March 31,
(in millions)	(in millions)	2021		2020		(in millions)	2022		2021
Cash flows provided by (used in):	Cash flows provided by (used in):					Cash flows provided by (used in):
Operating activities	Operating activities	$	2,088	$	1,554	Operating activities	$	1,795	$	2,088
Investing activities	Investing activities	(3,137)		(3,022)		Investing activities	(2,699)		(3,137)
Financing activities	Financing activities	1,185		2,593		Financing activities	1,404		1,185

Net increase in cash, cash equivalents and restricted cash	Net increase in cash, cash equivalents and restricted cash	136		1,125		Net increase in cash, cash equivalents and restricted cash	500		136
Cash, cash equivalents and restricted cash at beginning of period	Cash, cash equivalents and restricted cash at beginning of period	556		573		Cash, cash equivalents and restricted cash at beginning of period	520		556
Cash, cash equivalents and restricted cash at end of period	Cash, cash equivalents and restricted cash at end of period	$	692	$	1,698	Cash, cash equivalents and restricted cash at end of period	$	1,020	$	692

OPERATING CASH FLOWS

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


		Three Months Ended							Three Months Ended
		March 31,							March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance
Net income	Net income	$	941	$	890	$	51	Net income	$	820	$	941	$	(121)
Non-cash adjustments to net income	Non-cash adjustments to net income	1,446		1,639		(193)		Non-cash adjustments to net income	1,582		1,446		136

Payments for asset retirement obligations	Payments for asset retirement obligations	(114)		(132)		18		Payments for asset retirement obligations	(119)		(114)		(5)

Working capital	Working capital	(185)		(843)		658		Working capital	(488)		(185)		(303)
Net cash provided by operating activities	Net cash provided by operating activities	$	2,088	$	1,554	$	534	Net cash provided by operating activities	$	1,795	$	2,088	$	(293)

The variance was primarily due to ~~decreases in coal stock balances, incentive payments and the~~ timing of ~~payments.~~accruals and payments in working capital accounts.

INVESTING CASH FLOWS

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


	Three Months Ended
	March 31,
(in millions)	2022		2021		Variance
Capital, investment and acquisition expenditures	$	(2,568)	$	(2,215)	$	(353)

Other investing items	(131)		(922)		791
Net cash used in investing activities	$	(2,699)	$	(3,137)	$	438

The variance relates primarily to payment made in 2021 to fund ACP's outstanding debt and lower overall investments in the Commercial Renewables segment, partially offset by increases in capital expenditures due to higher overall investments in the Electric Utilities and Infrastructure and Gas Utilities and Infrastructure segments.

9892


MD&A			LIQUIDITY AND CAPITAL RESOURCES

~~INVESTING CASH FLOWS~~

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

Three Months Ended
March 31,
(in millions) 2021 2020 Variance
Capital, investment and acquisition expenditures $ (2,215) $ (2,909) $ 694
Other investing items (922) (113) (809)
Net cash used in investing activities $ (3,137) $ (3,022) $ (115)

The variance relates primarily to payment made to fund ACP's outstanding debt, partially offset by decreases in capital expenditures due to lower overall investments in the Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables segments.

FINANCING CASH FLOWS

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


		Three Months Ended							Three Months Ended
		March 31,							March 31,
(in millions)	(in millions)	2021		2020		Variance		(in millions)	2022		2021		Variance
Issuances of long-term debt, net	Issuances of long-term debt, net	$	532	$	1,662	$	(1,130)	Issuances of long-term debt, net	$	2,291	$	532	$	1,759
Issuances of common stock	Issuances of common stock	5		40		(35)		Issuances of common stock	—		5		(5)

Notes payable, commercial paper and other short-term borrowings	Notes payable, commercial paper and other short-term borrowings	1,187		1,569		(382)		Notes payable, commercial paper and other short-term borrowings	(44)		1,187		(1,231)
Dividends paid	Dividends paid	(783)		(707)		(76)		Dividends paid	(799)		(783)		(16)
Contributions from noncontrolling interests	Contributions from noncontrolling interests	303		103		200		Contributions from noncontrolling interests	23		303		(280)

Other financing items	Other financing items	(59)		(74)		15		Other financing items	(67)		(59)		(8)
Net cash provided by financing activities	Net cash provided by financing activities	$	1,185	$	2,593	$	(1,408)	Net cash provided by financing activities	$	1,404	$	1,185	$	219

The variance was primarily due to:

•a ~~$1,130 million decrease~~$1.8 billion increase in net proceeds from ~~net~~ issuances of long-term debt, primarily due to ~~the~~ timing of issuances and redemptions of long-term ~~debt; and~~

•~~a $382 million decrease in net proceeds from issuances of notes payable and commercial paper.~~debt.

Partially offset by:

•a ~~$200~~$1.2 billion decrease in net borrowings from notes payable and commercial paper; and

•a $280 million ~~increase related to~~decrease in contributions from noncontrolling ~~interests for tax equity financing activity in the Commercial Renewables segment.~~interests.

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, 2021, there were no material changes to Duke Energy’s off-balance sheet arrangements. 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, 2020.

~~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, 2021, 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, 2020.

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, ~~2021,~~2022, there were no material changes to the Duke Energy Registrants' disclosures about market risk.

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.

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, ~~2021,~~2022, 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, ~~2021,~~2022, and have concluded no change has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

~~100~~93


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, ~~2020.~~2021.

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, ~~2020,~~2021, which could materially affect the Duke Energy Registrants’ financial condition or future results.

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

None.

~~101~~94


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

Exhibit

Duke

Energy

Progress

Energy

Number

Energy

Carolinas

Energy

Progress

Florida

Ohio

Indiana

Piedmont

4.1

One-Hundred and Sixth Supplemental Indenture, dated as of March 4, 2022 between the registrant and The Bank of New York Mellon Trust Company, N.A., as Trustee, and forms of global bonds representing the First and Refunding Mortgage Bonds, 2.85% Series due 2032 and First and Refunding Mortgage Bonds, 3.55% Series due 2052 (incorporated by reference to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on March 4, 2022, File No. 1-32853).

4.2

Eleventh Supplemental Indenture dated as of March 11, 2021 , between the regis trant and The Bank of New York Mellon Trust Company, N.A., as successor to Citibank, N.A. and form of global notes (incorporated by ~~reference~~refe rence to Exhibit 4.1 to ~~registrant’s Current~~registrant's Curren t Report on Form 8-K filed on March 11, ~~2021,~~2022 , File No. 1-6196).

~~4.2~~4.3

~~One Hundred and Fifth~~Ninety-second Supplemental Indenture, dated as of ~~April~~March 1, ~~2021 (incorporated~~2022, among the registrant , The Bank of New York Mellon (formerly Irving Trust Company) and Christie Leppert (successor to Frederick G. Herbst) and forms of global bonds (i ncorporated by reference to Exhibit 4.1 to ~~registrant’s~~registrant's Current Report on Form 8-K filed on ~~April~~March 1 ~~2021,~~7, 2022, File No. ~~1-0928)~~1-3382).

*10.1

~~Coal Combustion Residuals Settlement Agreement~~

*10.210.1

~~Investment Agreement by and among Cinergy Corp., Duke Energy Indiana HoldCo, LLC,~~ Duke Energy Corporation Executive Short-term Incentive Plan, as amended and ~~Epson Investment PTE. LTD.~~restated, effective February 23, 2022 (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on February 24, 2022, File No. 1-32853).


*10.3EXHIBITS

10.2

~~First Amendment to $1,000,000,000~~Amended and Restated Credit Agreement, dated as of ~~May 15, 2019,~~March 18, 2022, among ~~registrant,~~Duke Energy Corporation, Duke Energy Carolinas, LLC, Duke Energy Ohio, Inc., Duke Energy Indiana, LLC, Duke Energy Kentucky, Inc., Duke Energy Progress, LLC, Duke Energy Florida, LLC, and Piedmont Natural Gas Company, Inc., the Lenders party thereto, Wells Fargo Bank, National Association, as Administrative Agent and Swingline Lender and Wells Fargo Securities, LLC, as Joint Lead Arranger, Joint Bookrunner and Sustainability Structuring Agent. that increases the amount of the credit facility from $8B to $9B (incorporated by reference to Exhibit 10.1 to registrants' Current Report on Form 8-K filed on March 21, 2022, File Nos. 1-32853, 1-4928, 1-3382, 1-3274, 1-1232, 1-3543, 1-6196).

10.3

$1,400,000,000 Term Loan Credit Facility , dated as of March 9, 2022, among the registrant , as Borrower, certain Lenders from time to time parties thereto, and The Bank of Nova Scotia as Administrative Agent ~~PNC Bank, National Association, Sumitomo Mitsui Banking~~and Coordinating Lead Arranger (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on March 22, 2022, File No. 1-32853).

*10.4

Duke Energy Corporation ~~and TD Bank, N.A., as Co-Syndication Agents, and Bank of China, New York Branch, BNP Paribas, Santander Bank, N.A., and U.S. Bank, National Association, as Co-Documentation Agents.~~Restricted Stock Unit Award Agreement

*10.5

Duke Energy Corporation 2022 Director Compensation Program

*31.1.1

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.2

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.3

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.4

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.5

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.6

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.7

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.8

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.2.1

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

*31.2.2

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

*31.2.3

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

~~102~~96


EXHIBITS

*31.2.3

~~Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.~~

*31.2.4

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

*31.2.5

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

*31.2.6

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

*31.2.7

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

*31.2.8

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

*32.1.1

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.2

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.3

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.4

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.5

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.6

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.7

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.8

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.1

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.2

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.3

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.4

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.5

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.6

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.7

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

~~103~~97


EXHIBITS

*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.~~

*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.

*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).

*101.SCH

XBRL Taxonomy Extension Schema Document.

*101.CAL

XBRL Taxonomy Calculation Linkbase Document.

*101.LAB

XBRL Taxonomy Label Linkbase Document.

*101.PRE

XBRL Taxonomy Presentation Linkbase Document.

*101.DEF

XBRL Taxonomy Definition Linkbase Document.

*104

Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibit 101).

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.

~~104~~98


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 ~~10, 2021~~9, 2022	/s/ STEVEN K. YOUNG
		Steven K. Young Executive Vice President and Chief Financial Officer (Principal Financial Officer)

Date:	May ~~10, 2021~~9, 2022	/s/ ~~DWIGHT L. JACOBS~~CYNTHIA S. LEE
		~~Dwight L. Jacobs~~Cynthia S. Lee ~~Senior~~ Vice President, Chief Accounting Officer ~~Tax~~ and Controller (Principal Accounting Officer)

~~105~~99


	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


	March 31, 2021
(in millions)	Facility size		Amount drawn
Duke Energy (Parent) Three-Year Revolving Credit Facility(a)	$	1,000	$	500