Piedmont Natural Gas (PNY) 10-Q 2024 Q3 Quarterly report

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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 September 30, 2024

OR

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

For the transition period from _________to_________

Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Zip Code and Telephone Number	IRS Employer Identification No.
1-32853	DUKE ENERGY CORPORATION	20-2777218

(a Delaware corporation)

525 South Tryon Street

Charlotte, North Carolina 28202

800-488-3853

1-4928 DUKE ENERGY CAROLINAS, LLC 56-0205520

(a North Carolina limited liability company)

525 South Tryon Street

Charlotte, North Carolina 28202

800-488-3853

1-15929 PROGRESS ENERGY, INC. 56-2155481

(a North Carolina corporation)

411 Fayetteville Street

Raleigh, North Carolina 27601

800-488-3853

1-3382 DUKE ENERGY PROGRESS, LLC 56-0165465

(a North Carolina limited liability company)

411 Fayetteville Street

Raleigh, North Carolina 27601

800-488-3853

1-3274 DUKE ENERGY FLORIDA, LLC 59-0247770

(a Florida limited liability company)

299 First Avenue North

St. Petersburg, Florida 33701

800-488-3853

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

(an Ohio corporation)

139 East Fourth Street

Cincinnati, Ohio 45202

800-488-3853

1-3543 DUKE ENERGY INDIANA, LLC 35-0594457

(an Indiana limited liability company)

1000 East Main Street

Plainfield, Indiana 46168

800-488-3853

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

(a North Carolina corporation)

525 South Tryon Street

Charlotte, North Carolina 28202

800-488-3853

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    5.625% 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

Duke Energy    3.10% Senior Notes due 2028    DUK 28A    New York Stock Exchange LLC        

Duke Energy    3.85% Senior Notes due 2034    DUK 34    New York Stock Exchange LLC

Duke Energy    3.75% Senior Notes due 2031    DUK 31A    New York Stock Exchange LLC

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

Duke Energy Corporation (Duke Energy)	Yes	☒	No	☐	Duke Energy Florida, LLC (Duke Energy Florida)	Yes	☒	No	☐
Duke Energy Carolinas, LLC (Duke Energy Carolinas)	Yes	☒	No	☐	Duke Energy Ohio, Inc. (Duke Energy Ohio)	Yes	☒	No	☐
Progress Energy, Inc. (Progress Energy)	Yes	☒	No	☐	Duke Energy Indiana, LLC (Duke Energy Indiana)	Yes	☒	No	☐
Duke Energy Progress, LLC (Duke Energy Progress)	Yes	☒	No	☐	Piedmont Natural Gas Company, Inc. (Piedmont)	Yes	☒	No	☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Duke Energy	Yes	☒	No	☐	Duke Energy Florida	Yes	☒	No	☐
Duke Energy Carolinas	Yes	☒	No	☐	Duke Energy Ohio	Yes	☒	No	☐
Progress Energy	Yes	☒	No	☐	Duke Energy Indiana	Yes	☒	No	☐
Duke Energy Progress	Yes	☒	No	☐	Piedmont	Yes	☒	No	☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Duke Energy	Large Accelerated Filer	☒	Accelerated filer	☐	Non-accelerated Filer	☐	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Carolinas	Large Accelerated Filer	☐	Accelerated filer	☐	Non-accelerated Filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Progress Energy	Large Accelerated Filer	☐	Accelerated filer	☐	Non-accelerated Filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Progress	Large Accelerated Filer	☐	Accelerated filer	☐	Non-accelerated Filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Florida	Large Accelerated Filer	☐	Accelerated filer	☐	Non-accelerated Filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Ohio	Large Accelerated Filer	☐	Accelerated filer	☐	Non-accelerated Filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Duke Energy Indiana	Large Accelerated Filer	☐	Accelerated filer	☐	Non-accelerated Filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Piedmont	Large Accelerated Filer	☐	Accelerated filer	☐	Non-accelerated Filer	☒	Smaller reporting company	☐	Emerging growth company	☐

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Duke Energy	Yes	☐	No	☒	Duke Energy Florida	Yes	☐	No	☒
Duke Energy Carolinas	Yes	☐	No	☒	Duke Energy Ohio	Yes	☐	No	☒
Progress Energy	Yes	☐	No	☒	Duke Energy Indiana	Yes	☐	No	☒
Duke Energy Progress	Yes	☐	No	☒	Piedmont	Yes	☐	No	☒

Number of shares of common stock outstanding at October 31, 2024:

Registrant	Description	Shares
Duke Energy	Common stock, $0.001 par value	772,482,405
Duke Energy Carolinas	All of the registrant's limited liability company member interests are directly owned by Duke Energy.	N/A
Progress Energy	All of the registrant's common stock is directly owned by Duke Energy.	100
Duke Energy Progress	All of the registrant's limited liability company member interests are indirectly owned by Duke Energy.	N/A
Duke Energy Florida	All of the registrant's limited liability company member interests are indirectly owned by Duke Energy.	N/A
Duke Energy Ohio	All of the registrant's common stock is indirectly owned by Duke Energy.	89,663,086
Duke Energy Indiana	All of the registrant's limited liability company member interests are owned by a Duke Energy subsidiary that is 80.1% indirectly owned by Duke Energy.	N/A
Piedmont	All of the registrant's common stock is directly owned by Duke Energy.	100

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	15
	Progress Energy, Inc. Financial Statements	19
	Duke Energy Progress, LLC Financial Statements	23
	Duke Energy Florida, LLC Financial Statements	27
	Duke Energy Ohio, Inc. Financial Statements	31
	Duke Energy Indiana, LLC Financial Statements	35
	Piedmont Natural Gas Company, Inc. Financial Statements	39
	Combined Notes to Condensed Consolidated Financial Statements
	Note 1 – Organization and Basis of Presentation	43
	Note 2 – Dispositions	45
	Note 3 – Business Segments	47
	Note 4 – Regulatory Matters	49
	Note 5 – Commitments and Contingencies	56
	Note 6 – Debt and Credit Facilities	59
	Note 7 – Asset Retirement Obligations	61
	Note 8 – Goodwill	62
	Note 9 – Related Party Transactions	63
	Note 10 – Derivatives and Hedging	64
	Note 11 – Investments in Debt and Equity Securities	70
	Note 12 – Fair Value Measurements	74
	Note 13 – Variable Interest Entities	79
	Note 14 – Revenue	82
	Note 15 – Stockholders' Equity	88
	Note 16 – Employee Benefit Plans	90
	Note 17 – Income Taxes	91
	Note 18 – Subsequent Events	92
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	93
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	112
Item 4.	Controls and Procedures	112
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	113
Item 1A.	Risk Factors	113
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	115
Item 5.	Other Information	115
Item 6.	Exhibits	116
	Signatures	119

GLOSSARY OF TERMS

Glossary of Terms 

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

Term or Acronym	Definition
2015 CCR Rule	A 2015 EPA rule establishing national regulations to provide a comprehensive set of requirements for the management and disposal of CCR from coal-fired power plants
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.
2024 CCR Rule	The EPA's Legacy CCR Surface Impoundments rule issued in April 2024, which significantly expands the scope of the 2015 CCR Rule
AFUDC	Allowance for funds used during construction
ARM	Annual Review Mechanism
ARO	Asset Retirement Obligation
Bison	Bison Insurance Company Limited
Brookfield	Brookfield Renewable Partners L.P.
CCR	Coal Combustion Residuals
CEP	Capital Expenditure Program
CPCN	Certificate of Public Convenience and Necessity
the Company	Duke Energy Corporation and its subsidiaries
Commercial Renewables Disposal Groups	Commercial Renewables business segment, excluding the offshore wind contract for Carolina Long Bay, separated into the utility-scale solar and wind group, the distributed generation group and the remaining assets
COVID-19	Coronavirus Disease 2019
CRC	Cinergy Receivables Company, LLC
Crystal River Unit 3	Crystal River Unit 3 Nuclear Plant
DEFR	Duke Energy Florida Receivables, LLC
DEPR	Duke Energy Progress Receivables, LLC
DERF	Duke Energy Receivables Finance Company, LLC
DOE	U.S. 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 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	United States Environmental Protection Agency
EPS	Earnings (Loss) Per Share
ERCOT	Electric Reliability Council of Texas
ETR	Effective tax rate
EU&I	Electric Utilities and Infrastructure
Exchange Act	Securities Exchange Act of 1934
FERC	Federal Energy Regulatory Commission
FPSC	Florida Public Service Commission

GLOSSARY OF TERMS

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
GHG	Greenhouse Gas
GU&I	Gas Utilities and Infrastructure
GWh	Gigawatt-hours
HB 951	The Energy Solutions for North Carolina, or House Bill 951, passed in October 2021
IMR	Integrity Management Rider
IRA	Inflation Reduction Act
IRS	Internal Revenue Service
IURC	Indiana Utility Regulatory Commission
JDA	Joint Dispatch Agreement
KPSC	Kentucky Public Service Commission
LLC	Limited Liability Company
MW	Megawatt
MWh	Megawatt-hour
NCUC	North Carolina Utilities Commission
NMC	National Methanol Company
NPNS	Normal purchase/normal sale
OPEB	Other Post-Retirement Benefit Obligations
the Parent	Duke Energy Corporation holding company
Piedmont	Piedmont Natural Gas Company, Inc.
Progress Energy	Progress Energy, Inc.
PSCSC	Public Service Commission of South Carolina
PTC	Production Tax Credit
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
TPUC	Tennessee Public Utility Commission
U.S.	United States
VIE	Variable Interest Entity

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 ability to implement our business strategy, including our carbon emission reduction goals;

◦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 timely 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;

◦The impact of extraordinary external events, such as the pandemic health event resulting from COVID-19, and their collateral consequences, including the disruption of global supply chains or the economic activity in our service territories;

◦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, storm damage, reduced customer usage due to cost pressures from inflation or fuel costs, 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, 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, financial position, and cash flows, 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 and costs related thereto;

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

◦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 or other attack, war, vandalism, cybersecurity threats, data security breaches, operational events, information technology failures or other catastrophic events, such as severe storms, 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;

FORWARD-LOOKING STATEMENTS

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

◦Changes in rules for regional transmission organizations, including changes in rate designs and new and evolving capacity markets, and risks related to obligations created by the default of other participants;

◦The ability to control operation and maintenance costs;

◦The level of creditworthiness of counterparties to transactions;

◦The ability to obtain adequate insurance at acceptable costs and recover on claims made;

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

◦The ability of subsidiaries to pay dividends or distributions to Duke Energy Corporation holding company (the Parent);

◦The performance of projects undertaken by our businesses and the success of efforts to invest in and develop new opportunities;

◦The effect of accounting and reporting pronouncements issued periodically by accounting standard-setting bodies and the SEC;

◦The impact of United States tax legislation to our financial condition, results of operations or cash flows and our credit ratings;

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

◦Asset or business acquisitions and dispositions may not yield the anticipated benefits; and

◦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.

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.

FINANCIAL STATEMENTS

ITEM 1. FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Operations

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions, except per share amounts)	2024		2023		2024		2023
Operating Revenues
Regulated electric	$	7,775	$	7,640	$	21,253	$	20,140
Regulated natural gas	298		284		1,511		1,497
Nonregulated electric and other	81		70		233		211
Total operating revenues	8,154		7,994		22,997		21,848
Operating Expenses
Fuel used in electric generation and purchased power	2,644		2,571		7,207		6,987
Cost of natural gas	70		57		380		434
Operation, maintenance and other	1,409		1,428		4,108		4,113
Depreciation and amortization	1,516		1,353		4,312		3,913
Property and other taxes	383		394		1,162		1,136
Impairment of assets and other charges	(5)		88		39		96
Total operating expenses	6,017		5,891		17,208		16,679
Gains on Sales of Other Assets and Other, net	7		8		25		46
Operating Income	2,144		2,111		5,814		5,215
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	15		45		53		85
Other income and expenses, net	166		133		502		431
Total other income and expenses	181		178		555		516
Interest Expense	872		774		2,513		2,221
Income From Continuing Operations Before Income Taxes	1,453		1,515		3,856		3,510
Income Tax Expense From Continuing Operations	163		42		481		316
Income From Continuing Operations	1,290		1,473		3,375		3,194
Income (Loss) From Discontinued Operations, net of tax	25		(152)		12		(1,316)
Net Income	1,315		1,321		3,387		1,878
Less: Net Income Attributable to Noncontrolling Interests	34		69		68		42
Net Income Attributable to Duke Energy Corporation	1,281		1,252		3,319		1,836
Less: Preferred Dividends	39		39		92		92
Less: Preferred Redemption Costs	16		$	—	$	16	$	—
Net Income Available to Duke Energy Corporation Common Stockholders	$	1,226	$	1,213	$	3,211	$	1,744
Earnings Per Share – Basic and Diluted
Income from continuing operations available to Duke Energy Corporation common stockholders
Basic and Diluted	$	1.57	$	1.83	$	4.16	$	3.94
Income (loss) from discontinued operations attributable to Duke Energy Corporation common stockholders
Basic and Diluted	$	0.03	$	(0.24)	$	0.01	$	(1.67)
Net income available to Duke Energy Corporation common stockholders
Basic and Diluted	$	1.60	$	1.59	$	4.17	$	2.27
Weighted Average Shares Outstanding
Basic	772		771		772		771
Diluted	773		771		772		771

See Notes to Condensed Consolidated Financial Statements

9

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Comprehensive Income

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Net Income	$	1,315	$	1,321	$	3,387	$	1,878
Other Comprehensive Income (Loss), net of tax(a)
Pension and OPEB adjustments	1		(1)		17		(1)
Net unrealized (losses) gains on cash flow hedges	(57)		200		60		206
Reclassification into earnings from cash flow hedges	(2)		24		(3)		28
Net unrealized (losses) gains on fair value hedges	(3)		15		(24)		30
Unrealized gains (losses) on available-for-sale securities	7		(6)		4		(2)
Other Comprehensive (Loss) Income, net of tax	(54)		232		54		261
Comprehensive Income	1,261		1,553		3,441		2,139
Less: Comprehensive Income Attributable to Noncontrolling Interests	34		69		68		42
Comprehensive Income Attributable to Duke Energy	1,227		1,484		3,373		2,097
Less: Preferred Dividends	39		39		92		92
Less: Preferred Redemption Costs	16		—		16		—
Comprehensive Income Available to Duke Energy Corporation Common Stockholders	$	1,172	$	1,445	$	3,265	$	2,005

(a)Net of income tax benefit of approximately $16 million and income tax expense of $69 million for the three months ended September 30, 2024, and 2023, respectively and approximately $16 million and $78 million of income tax expense for the nine months ended September 30, 2024, and 2023, respectively.

See Notes to Condensed Consolidated Financial Statements

10

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2024		December 31, 2023
ASSETS
Current Assets
Cash and cash equivalents	$	376	$	253
Receivables (net of allowance for doubtful accounts of $127 at 2024 and $55 at 2023)	2,161		1,112
Receivables of VIEs (net of allowance for doubtful accounts of $91 at 2024 and $150 at 2023)	1,971		3,019
Receivable from sales of Commercial Renewables Disposal Groups	545		—
Inventory (includes $477 at 2024 and $462 at 2023 related to VIEs)	4,338		4,292
Regulatory assets (includes $119 at 2024 and $110 at 2023 related to VIEs)	2,300		3,648
Assets held for sale	4		14
Other (includes $76 at 2024 and $90 at 2023 related to VIEs)	447		431
Total current assets	12,142		12,769
Property, Plant and Equipment
Cost	179,542		171,353
Accumulated depreciation and amortization	(58,146)		(56,038)
Net property, plant and equipment	121,396		115,315
Other Noncurrent Assets
Goodwill	19,303		19,303
Regulatory assets (includes $1,716 at 2024 and $1,642 at 2023 related to VIEs)	13,778		13,618
Nuclear decommissioning trust funds	11,511		10,143
Operating lease right-of-use assets, net	1,146		1,092
Investments in equity method unconsolidated affiliates	477		492
Assets held for sale	81		197
Other	3,732		3,964
Total other noncurrent assets	50,028		48,809
Total Assets	$	183,566	$	176,893
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable (includes $212 at 2024 and $188 at 2023 related to VIEs)	$	3,953	$	4,228
Notes payable and commercial paper	3,947		4,288
Taxes accrued	1,016		816
Interest accrued	809		745
Current maturities of long-term debt (includes $1,012 at 2024 and $428 at 2023 related to VIEs)	3,597		2,800
Asset retirement obligations	639		596
Regulatory liabilities	1,267		1,369
Liabilities associated with assets held for sale	77		122
Other	2,122		2,319
Total current liabilities	17,427		17,283
Long-Term Debt (includes $1,842 at 2024 and $3,000 at 2023 related to VIEs)	76,524		72,452
Other Noncurrent Liabilities
Deferred income taxes	10,859		10,556
Asset retirement obligations	9,511		8,560
Regulatory liabilities	14,926		14,039
Operating lease liabilities	956		917
Accrued pension and other post-retirement benefit costs	432		485
Investment tax credits	866		864
Liabilities associated with assets held for sale	85		157
Other (includes $33 at 2024 and $35 at 2023 related to VIEs)	1,731		1,393
Total other noncurrent liabilities	39,366		36,971
Commitments and Contingencies
Equity
Preferred stock, Series A, $0.001 par value, 40 million depositary shares authorized and outstanding at 2024 and 2023	973		973
Preferred stock, Series B, $0.001 par value, 1 million shares authorized; 0 and 1 million shares outstanding at 2024 and 2023	—		989
Common stock, $0.001 par value, 2 billion shares authorized; 772 million and 771 million shares outstanding at 2024 and 2023	1		1
Additional paid-in capital	45,060		44,920
Retained earnings	3,052		2,235
Accumulated other comprehensive income (loss)	47		(6)
Total Duke Energy Corporation stockholders' equity	49,133		49,112
Noncontrolling interests	1,116		1,075
Total equity	50,249		50,187
Total Liabilities and Equity	$	183,566	$	176,893

See Notes to Condensed Consolidated Financial Statements

11

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	3,387	$	1,878
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	4,792		4,538
Equity component of AFUDC	(173)		(146)
Losses on sales of Commercial Renewables Disposal Groups	22		1,603
Gains on sales of other assets	(25)		(46)
Impairment of assets and other charges	39		96
Deferred income taxes	369		(29)
Equity in earnings of unconsolidated affiliates	(53)		(70)
Contributions to qualified pension plans	(100)		(100)
Payments for asset retirement obligations	(417)		(423)
Provision for rate refunds	(28)		(59)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	35		29
Receivables	(22)		481
Inventory	(36)		(531)
Other current assets	742		40
Increase (decrease) in
Accounts payable	90		(972)
Taxes accrued	202		277
Other current liabilities	(248)		(116)
Other assets	154		491
Other liabilities	221		368
Net cash provided by operating activities	8,951		7,309
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(9,191)		(9,310)
Contributions to equity method investments	(8)		(30)
Purchases of debt and equity securities	(3,380)		(2,811)
Proceeds from sales and maturities of debt and equity securities	3,450		2,848
Net proceeds from the sales of other assets	1		130
Other	(723)		(578)
Net cash used in investing activities	(9,851)		(9,751)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	7,760		8,704
Issuance of common stock	26		—
Redemption of preferred stock	(1,000)		—
Payments for the redemption of long-term debt	(2,833)		(3,097)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	552		575
Payments for the redemption of short-term debt with original maturities greater than 90 days	(1,025)		(110)
Notes payable and commercial paper	(42)		(1,404)
Contributions from noncontrolling interests	47		278
Dividends paid	(2,411)		(2,438)
Other	(84)		(95)
Net cash provided by financing activities	990		2,413
Net increase (decrease) in cash, cash equivalents and restricted cash	90		(29)
Cash, cash equivalents and restricted cash at beginning of period	357		603
Cash, cash equivalents and restricted cash at end of period	$	447	$	574
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	1,604	$	1,528

See Notes to Condensed Consolidated Financial Statements

12

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Three Months Ended September 30, 2023 and 2024
										Accumulated Other Comprehensive
										Income (Loss)
										Net		Net Unrealized				Total
										Gains		(Losses) Gains				Duke Energy
			Common			Additional				(Losses)		on Available-		Pension and		Corporation		Non-
	Preferred		Stock	Common		Paid-in		Retained		on		for-Sale-		OPEB		Stockholders'		controlling		Total
(in millions)	Stock		Shares	Stock		Capital		Earnings		Hedges(b)		Securities		Adjustments		Equity		Interests		Equity
Balance at June 30, 2023	$	1,962	771	$	1	$	44,866	$	1,615	$	(4)	$	(19)	$	(88)	$	48,333	$	2,738	$	51,071
Net income(d)	—		—	—		—		1,213		—		—		—		1,213		69		1,282
Other comprehensive income (loss)	—		—	—		—		—		239		(6)		(1)		232		—		232
Common stock issuances, including dividend reinvestment and employee benefits	—		—	—		22		—		—		—		—		22		—		22
Common stock dividends	—		—	—		—		(793)		—		—		—		(793)		—		(793)
Contribution from noncontrolling interests, net of transaction costs	—		—	—		—		—		—		—		—		—		30		30
Distributions to noncontrolling interest in subsidiaries	—		—	—		—		—		—		—		—		—		(20)		(20)
Other	—		—	—		(2)		1		—		—		—		(1)		3		2
Balance at September 30, 2023	$	1,962	771	$	1	$	44,886	$	2,036	$	235	$	(25)	$	(89)	$	49,006	$	2,820	$	51,826
Balance at June 30, 2024	$	1,962	772	$	1	$	45,007	$	2,635	$	193	$	(18)	$	(73)	$	49,707	$	1,099	$	50,806
Net income(d)	—		—	—		—		1,226		—		—		—		1,226		34		1,260
Other comprehensive income (loss)	—		—	—		—		—		(62)		7		1		(54)		—		(54)
Common stock issuances, including dividend reinvestment and employee benefits	—		—	—		53		—		—		—		—		53		—		53
Preferred stock, Series B, redemption	(989)		—	—		—		—		—		—		—		(989)		—		(989)
Common stock dividends	—		—	—		—		(806)		—		—		—		(806)		—		(806)
Distributions to noncontrolling interest in subsidiaries	—		—	—		—		—		—		—		—		—		(18)		(18)
Other	—		—	—				(3)		—		—		(1)		(4)		1		(3)
Balance at September 30, 2024	$	973	772	$	1	$	45,060	$	3,052	$	131	$	(11)	$	(73)	$	49,133	$	1,116	$	50,249

See Notes to Condensed Consolidated Financial Statements

13

FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Nine Months Ended September 30, 2023 and 2024
										Accumulated Other Comprehensive
										Income (Loss)
										Net		Net Unrealized				Total
										Gains		Gains (Losses)				Duke Energy
			Common			Additional				(Losses)		on Available-		Pension and		Corporation		Non-
	Preferred		Stock	Common		Paid-in		Retained		on		for-Sale-		OPEB		Stockholders'		controlling		Total
(in millions)	Stock		Shares	Stock		Capital		Earnings		Hedges(b)		Securities		Adjustments		Equity		Interests		Equity
Balance at December 31, 2022	$	1,962	770	$	1	$	44,862	$	2,637	$	(29)	$	(23)	$	(88)	$	49,322	$	2,531	$	51,853
Net income(d)	—		—	—		—		1,744		—		—		—		1,744		42		1,786
Other comprehensive income (loss)	—		—	—		—		—		264		(2)		(1)		261		—		261
Common stock issuances, including dividend reinvestment and employee benefits	—		1	—		43		—		—		—		—		43		—		43
Common stock dividends	—		—	—		—		(2,346)		—		—		—		(2,346)		—		(2,346)
Sale of noncontrolling interest	—		—	—		(13)		—		—		—		—		(13)		10		(3)
Contributions from noncontrolling interests, net of transaction costs(a)	—		—	—		—		—		—		—		—		—		278		278
Distributions to noncontrolling interest in subsidiaries	—		—	—		—		—		—		—		—		—		(45)		(45)
Other	—		—	—		(6)		1		—		—		—		(5)		4		(1)
Balance at September 30, 2023	$	1,962	771	$	1	$	44,886	$	2,036	$	235	$	(25)	$	(89)	$	49,006	$	2,820	$	51,826
Balance at December 31, 2023	$	1,962	771	$	1	$	44,920	$	2,235	$	98	$	(15)	$	(89)	$	49,112	$	1,075	$	50,187
Net income(d)	—		—	—		—		3,211		—		—		—		3,211		68		3,279
Other comprehensive income	—		—	—		—		—		33		4		17		54		—		54
Common stock issuances, including dividend reinvestment and employee benefits	—		1	—		139		—		—		—		—		139		—		139
Preferred stock, Series B, redemption	(989)		—	—		—		—		—		—		—		(989)		—		(989)
Common stock dividends	—		—	—		—		(2,392)		—		—		—		(2,392)		—		(2,392)
Sale of Commercial Renewables Disposal Groups(c)	—		—	—				—		—		—		—		—		(51)		(51)
Contributions from noncontrolling interests, net of transaction costs	—		—	—		—		—		—		—		—		—		47		47
Distributions to noncontrolling interest in subsidiaries	—		—	—		—		—		—		—		—		—		(23)		(23)
Other	—		—	—		1		(2)		—		—		(1)		(2)				(2)
Balance at September 30, 2024	$	973	772	$	1	$	45,060	$	3,052	$	131	$	(11)	$	(73)	$	49,133	$	1,116	$	50,249

(a)Relates primarily to tax equity financing activity in the Commercial Renewables Disposal Groups.

(b)See Duke Energy Condensed Consolidated Statements of Comprehensive Income for detailed activity related to Cash Flow and Fair Value hedges.

(c)See Note 2 for additional information.

(d)Net income available to Duke Energy Corporation Common Stockholders reflects preferred dividends and, for 2024, the $16 million preferred stock redemption costs.

See Notes to Condensed Consolidated Financial Statements

14

FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Operating Revenues	$	2,707	$	2,393	$	7,411	$	6,155
Operating Expenses
Fuel used in electric generation and purchased power	922		690		2,531		1,823
Operation, maintenance and other	463		424		1,358		1,285
Depreciation and amortization	472		407		1,306		1,186
Property and other taxes	88		90		271		276
Impairment of assets and other charges	(2)		64		32		70
Total operating expenses	1,943		1,675		5,498		4,640
Gains on Sales of Other Assets and Other, net	—		—		1		26
Operating Income	764		718		1,914		1,541
Other Income and Expenses, net	58		63		181		181
Interest Expense	189		172		537		504
Income Before Income Taxes	633		609		1,558		1,218
Income Tax Expense	49		30		153		97
Net Income and Comprehensive Income	$	584	$	579	$	1,405	$	1,121

See Notes to Condensed Consolidated Financial Statements

15

FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2024		December 31, 2023
ASSETS
Current Assets
Cash and cash equivalents	$	13	$	9
Receivables (net of allowance for doubtful accounts of $17 at 2024 and $11 at 2023)	250		265
Receivables of VIEs (net of allowance for doubtful accounts of $53 at 2024 and $45 at 2023)	1,149		991
Receivables from affiliated companies	202		203
Notes receivable from affiliated companies	177		—
Inventory	1,482		1,484
Regulatory assets (includes $12 at 2024 and 2023 related to VIEs)	927		1,564
Other (includes $6 at 2024 and $9 at 2023 related to VIEs)	48		31
Total current assets	4,248		4,547
Property, Plant and Equipment
Cost	58,465		56,670
Accumulated depreciation and amortization	(20,026)		(19,896)
Net property, plant and equipment	38,439		36,774
Other Noncurrent Assets
Regulatory assets (includes $188 at 2024 and $196 at 2023 related to VIEs)	3,867		3,916
Nuclear decommissioning trust funds	6,505		5,686
Operating lease right-of-use assets, net	85		78
Other	1,165		1,109
Total other noncurrent assets	11,622		10,789
Total Assets	$	54,309	$	52,110
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	1,302	$	1,183
Accounts payable to affiliated companies	230		195
Notes payable to affiliated companies	—		668
Taxes accrued	386		281
Interest accrued	158		179
Current maturities of long-term debt (includes $510 at 2024 and $10 at 2023 related to VIEs)	520		19
Asset retirement obligations	253		224
Regulatory liabilities	576		587
Other	589		702
Total current liabilities	4,014		4,038
Long-Term Debt (includes $198 at 2024 and $708 at 2023 related to VIEs)	16,212		15,693
Long-Term Debt Payable to Affiliated Companies	300		300
Other Noncurrent Liabilities
Deferred income taxes	4,084		4,379
Asset retirement obligations	3,727		3,789
Regulatory liabilities	6,586		5,990
Operating lease liabilities	75		75
Accrued pension and other post-retirement benefit costs	45		57
Investment tax credits	302		301
Other (includes $20 at 2024 and $17 at 2023 related to VIEs)	652		581
Total other noncurrent liabilities	15,471		15,172
Commitments and Contingencies
Equity
Member's equity	18,318		16,913
Accumulated other comprehensive loss	(6)		(6)
Total equity	18,312		16,907
Total Liabilities and Equity	$	54,309	$	52,110

See Notes to Condensed Consolidated Financial Statements

16

FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,405	$	1,121
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	1,504		1,380
Equity component of AFUDC	(85)		(69)
Gains on sales of other assets	—		(26)
Impairment of assets and other charges	32		70
Deferred income taxes	(105)		(7)
Contributions to qualified pension plans	(26)		(26)
Payments for asset retirement obligations	(131)		(145)
Provision for rate refunds	(7)		(35)
(Increase) decrease in
Receivables	(136)		(4)
Receivables from affiliated companies	1		225
Inventory	2		(257)
Other current assets	(3)		(439)
Increase (decrease) in
Accounts payable	149		(523)
Accounts payable to affiliated companies	35		12
Taxes accrued	105		121
Other current liabilities	(226)		(48)
Other assets	652		526
Other liabilities	(121)		105
Net cash provided by operating activities	3,045		1,981
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,923)		(2,646)
Purchases of debt and equity securities	(1,712)		(1,594)
Proceeds from sales and maturities of debt and equity securities	1,712		1,594
Net proceeds from the sales of other assets	—		30
Notes receivable from affiliated companies	(177)		—
Other	(289)		(215)
Net cash used in investing activities	(3,389)		(2,831)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,031		2,764
Payments for the redemption of long-term debt	(17)		(1,040)
Notes payable to affiliated companies	(668)		(902)
Other	(1)		(1)
Net cash provided by financing activities	345		821
Net increase (decrease) in cash, cash equivalents and restricted cash	1		(29)
Cash, cash equivalents and restricted cash at beginning of period	19		53
Cash, cash equivalents and restricted cash at end of period	$	20	$	24
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	611	$	534

See Notes to Condensed Consolidated Financial Statements

17

FINANCIAL STATEMENTS

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Three Months Ended September 30, 2023 and 2024
			Accumulated Other
			Comprehensive
			Loss
	Member's		Net Losses on		Total
(in millions)	Equity		Cash Flow Hedges		Equity
Balance at June 30, 2023	$	15,990	$	(6)	$	15,984
Net income	579		—		579
Other	(3)		—		(3)
Balance at September 30, 2023	$	16,566	$	(6)	$	16,560
Balance at June 30, 2024	$	17,714	$	(6)	$	17,708
Net income	584		—		584
Other	20		—		20
Balance at September 30, 2024	$	18,318	$	(6)	$	18,312
	Nine Months Ended September 30, 2023 and 2024
			Accumulated Other
			Comprehensive
			Loss
	Member's		Net Losses on		Total
(in millions)	Equity		Cash Flow Hedges		Equity
Balance at December 31, 2022	$	15,448	$	(6)	$	15,442
Net income	1,121		—		1,121
Other	(3)		—		(3)
Balance at September 30, 2023	$	16,566	$	(6)	$	16,560
Balance at December 31, 2023	$	16,913	$	(6)	$	16,907
Net income	1,405				1,405
Balance at September 30, 2024	$	18,318	$	(6)	$	18,312

See Notes to Condensed Consolidated Financial Statements

18

FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Operating Revenues	$	3,860	$	4,055	$	10,445	$	10,315
Operating Expenses
Fuel used in electric generation and purchased power	1,384		1,535		3,729		3,902
Operation, maintenance and other	653		711		1,869		1,963
Depreciation and amortization	640		563		1,795		1,609
Property and other taxes	170		205		494		546
Impairment of assets and other charges	(3)		24		6		29
Total operating expenses	2,844		3,038		7,893		8,049
Gains on Sales of Other Assets and Other, net	7		8		20		20
Operating Income	1,023		1,025		2,572		2,286
Other Income and Expenses, net	56		49		178		146
Interest Expense	271		241		796		706
Income Before Income Taxes	808		833		1,954		1,726
Income Tax Expense	130		131		320		280
Net Income	$	678	$	702	$	1,634	$	1,446
Other Comprehensive Income, net of tax
Unrealized gains on available-for-sale securities	1		—		1		2
Other Comprehensive Income, net of tax	1		—		1		2
Comprehensive Income	$	679	$	702	$	1,635	$	1,448

See Notes to Condensed Consolidated Financial Statements

19

FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2024		December 31, 2023
ASSETS
Current Assets
Cash and cash equivalents	$	82	$	59
Receivables (net of allowance for doubtful accounts of $41 at 2024 and $18 at 2023)	939		225
Receivables of VIEs (net of allowance for doubtful accounts of $38 at 2024 and $56 at 2023)	822		1,365
Receivables from affiliated companies	12		90
Inventory (includes $477 at 2024 and $462 at 2023 related to VIEs)	2,006		1,901
Regulatory assets (includes $107 at 2024 and $98 at 2023 related to VIEs)	952		1,661
Other (includes $46 at 2024 and $68 at 2023 related to VIEs)	103		134
Total current assets	4,916		5,435
Property, Plant and Equipment
Cost	71,653		67,644
Accumulated depreciation and amortization	(23,450)		(22,300)
Net property, plant and equipment	48,203		45,344
Other Noncurrent Assets
Goodwill	3,655		3,655
Regulatory assets (includes $1,528 at 2024 and $1,446 at 2023 related to VIEs)	6,560		6,430
Nuclear decommissioning trust funds	5,005		4,457
Operating lease right-of-use assets, net	643		617
Other	1,269		1,156
Total other noncurrent assets	17,132		16,315
Total Assets	$	70,251	$	67,094
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable (includes $199 at 2024 and $188 at 2023 related to VIEs)	$	1,386	$	1,374
Accounts payable to affiliated companies	551		464
Notes payable to affiliated companies	805		1,043
Taxes accrued	435		259
Interest accrued	242		224
Current maturities of long-term debt (includes $502 at 2024 and $418 at 2023 related to VIEs)	1,418		661
Asset retirement obligations	227		245
Regulatory liabilities	377		418
Other	801		860
Total current liabilities	6,242		5,548
Long-Term Debt (includes $1,581 at 2024 and $1,910 at 2023 related to VIEs)	22,646		22,948
Long-Term Debt Payable to Affiliated Companies	150		150
Other Noncurrent Liabilities
Deferred income taxes	5,221		5,197
Asset retirement obligations	4,496		3,900
Regulatory liabilities	5,478		5,083
Operating lease liabilities	570		544
Accrued pension and other post-retirement benefit costs	251		266
Investment tax credits	372		371
Other (includes $13 at 2024 and $19 at 2023 related to VIEs)	455		227
Total other noncurrent liabilities	16,843		15,588
Commitments and Contingencies
Equity
Common Stock, $0.01 par value, 100 shares authorized and outstanding at 2024 and 2023	—		—
Additional paid-in capital	11,830		11,830
Retained earnings	12,549		11,040
Accumulated other comprehensive loss	(9)		(10)
Total equity	24,370		22,860
Total Liabilities and Equity	$	70,251	$	67,094

See Notes to Condensed Consolidated Financial Statements

20

FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,634	$	1,446
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	2,081		2,021
Equity component of AFUDC	(54)		(49)
Impairment of assets and other charges	6		29
Deferred income taxes	(19)		(38)
Contributions to qualified pension plans	(23)		(22)
Payments for asset retirement obligations	(221)		(212)
Provision for rate refunds	(1)		(24)
(Increase) decrease in
Receivables	(185)		(198)
Receivables from affiliated companies	78		2
Inventory	(95)		(224)
Other current assets	841		399
Increase (decrease) in
Accounts payable	194		(177)
Accounts payable to affiliated companies	87		(206)
Taxes accrued	179		357
Other current liabilities	12		4
Other assets	(504)		183
Other liabilities	127		(10)
Net cash provided by operating activities	4,137		3,281
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(3,891)		(3,607)
Purchases of debt and equity securities	(1,561)		(1,108)
Proceeds from sales and maturities of debt and equity securities	1,644		1,151
Other	(351)		(239)
Net cash used in investing activities	(4,159)		(3,803)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	849		1,272
Payments for the redemption of long-term debt	(460)		(440)
Notes payable to affiliated companies	(238)		140
Dividends to parent	(125)		(500)
Other	(1)		(1)
Net cash provided by financing activities	25		471
Net increase (decrease) in cash, cash equivalents and restricted cash	3		(51)
Cash, cash equivalents and restricted cash at beginning of period	135		184
Cash, cash equivalents and restricted cash at end of period	$	138	$	133
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	628	$	558

See Notes to Condensed Consolidated Financial Statements

21

FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Three Months Ended September 30, 2023 and 2024
					Accumulated Other Comprehensive Loss
					Net		Net Unrealized
	Additional				Losses on		Gains (Losses) on		Pension and
	Paid-in		Retained		Cash Flow		Available-for-		OPEB		Total
(in millions)	Capital		Earnings		Hedges		Sale Securities		Adjustments		Equity
Balance at June 30, 2023	$	11,830	$	10,329	$	(1)	$	(6)	$	(2)	$	22,150
Net income	—		702		—		—		—		702
Dividends to parent	—		(500)		—		—		—		(500)
Other	—		(1)		—		—		—		(1)
Balance at September 30, 2023	$	11,830	$	10,530	$	(1)	$	(6)	$	(2)	$	22,351
Balance at June 30, 2024	$	11,849	$	11,996	$	(1)	$	(5)	$	(4)	$	23,835
Net income	—		678		—		—		—		678
Other comprehensive income	—		—		—		1		—		1
Dividends to parent	—		(125)		—		—		—		(125)
Other	(19)		—		—		—		—		(19)
Balance at September 30, 2024	$	11,830	$	12,549	$	(1)	$	(4)	$	(4)	$	24,370
	Nine Months Ended September 30, 2023 and 2024
					Accumulated Other Comprehensive Loss
					Net		Net Unrealized
	Additional				Losses on		Gains (Losses) on		Pension and
	Paid-in		Retained		Cash Flow		Available-for-		OPEB		Total
	Capital		Earnings		Hedges		Sale Securities		Adjustments		Equity
Balance at December 31, 2022	$	11,832	$	9,585	$	(1)	$	(8)	$	(2)	$	21,406
Net income	—		1,446		—		—		—		1,446
Other comprehensive income	—		—		—		2		—		2
Dividends to parent	—		(500)		—		—		—		(500)
Other	(2)		(1)		—		—		—		(3)
Balance at September 30, 2023	$	11,830	$	10,530	$	(1)	$	(6)	$	(2)	$	22,351
Balance at December 31, 2023	$	11,830	$	11,040	$	(1)	$	(5)	$	(4)	$	22,860
Net income	—		1,634		—		—		—		1,634
Other comprehensive income	—		—		—		1		—		1
Dividends to parent	—		(125)		—		—		—		(125)
Balance at September 30, 2024	$	11,830	$	12,549	$	(1)	$	(4)	$	(4)	$	24,370

See Notes to Condensed Consolidated Financial Statements

22

FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Operating Revenues	$	1,914	$	1,886	$	5,338	$	4,844
Operating Expenses
Fuel used in electric generation and purchased power	679		651		1,896		1,685
Operation, maintenance and other	376		345		1,077		1,051
Depreciation and amortization	354		324		999		935
Property and other taxes	43		48		144		143
Impairment of assets and other charges	(3)		24		6		31
Total operating expenses	1,449		1,392		4,122		3,845
Gains on Sales of Other Assets and Other, net	1		1		2		2
Operating Income	466		495		1,218		1,001
Other Income and Expenses, net	34		31		107		92
Interest Expense	127		109		370		315
Income Before Income Taxes	373		417		955		778
Income Tax Expense	48		49		135		101
Net Income and Comprehensive Income	$	325	$	368	$	820	$	677

See Notes to Condensed Consolidated Financial Statements

23

FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2024		December 31, 2023
ASSETS
Current Assets
Cash and cash equivalents	$	46	$	18
Receivables (net of allowance for doubtful accounts of $10 at 2024 and $8 at 2023)	178		139
Receivables of VIEs (net of allowance for doubtful accounts of $38 at 2024 and $36 at 2023)	822		833
Receivables from affiliated companies	14		16
Inventory	1,320		1,227
Regulatory assets (includes $47 at 2024 and $39 at 2023 related to VIEs)	691		942
Other (includes $27 at 2024 and $31 at 2023 related to VIEs)	62		72
Total current assets	3,133		3,247
Property, Plant and Equipment
Cost	41,720		39,283
Accumulated depreciation and amortization	(15,947)		(15,227)
Net property, plant and equipment	25,773		24,056
Other Noncurrent Assets
Regulatory assets (includes $774 at 2024 and $643 at 2023 related to VIEs)	4,489		4,546
Nuclear decommissioning trust funds	4,657		4,075
Operating lease right-of-use assets, net	353		318
Other	719		682
Total other noncurrent assets	10,218		9,621
Total Assets	$	39,124	$	36,924
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	502	$	634
Accounts payable to affiliated companies	322		332
Notes payable to affiliated companies	610		891
Taxes accrued	193		176
Interest accrued	86		114
Current maturities of long-term debt (includes $443 at 2024 and $34 at 2023 related to VIEs)	983		72
Asset retirement obligations	225		244
Regulatory liabilities	295		300
Other	442		481
Total current liabilities	3,658		3,244
Long-Term Debt (includes $809 at 2024 and $1,079 at 2023 related to VIEs)	11,190		11,492
Long-Term Debt Payable to Affiliated Companies	150		150
Other Noncurrent Liabilities
Deferred income taxes	2,552		2,560
Asset retirement obligations	4,293		3,626
Regulatory liabilities	4,778		4,375
Operating lease liabilities	337		293
Accrued pension and other post-retirement benefit costs	138		146
Investment tax credits	130		129
Other (includes $13 at 2024 and $12 at 2023 related to VIEs)	271		102
Total other noncurrent liabilities	12,499		11,231
Commitments and Contingencies
Equity
Member's Equity	11,627		10,807
Total Liabilities and Equity	$	39,124	$	36,924

See Notes to Condensed Consolidated Financial Statements

24

FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	820	$	677
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	1,144		1,077
Equity component of AFUDC	(44)		(38)
Impairment of assets and other charges	6		31
Deferred income taxes	(32)		(12)
Contributions to qualified pension plans	(14)		(13)
Payments for asset retirement obligations	(153)		(166)
Provision for rate refunds	(1)		(24)
(Increase) decrease in
Receivables	(15)		5
Receivables from affiliated companies	2		(7)
Inventory	(93)		(135)
Other current assets	288		(189)
Increase (decrease) in
Accounts payable	(74)		(38)
Accounts payable to affiliated companies	(10)		(256)
Taxes accrued	17		178
Other current liabilities	14		(25)
Other assets	(101)		175
Other liabilities	118		23
Net cash provided by operating activities	1,872		1,263
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,036)		(1,756)
Purchases of debt and equity securities	(1,452)		(973)
Proceeds from sales and maturities of debt and equity securities	1,451		969
Other	(130)		(114)
Net cash used in investing activities	(2,167)		(1,874)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	670		991
Payments for the redemption of long-term debt	(67)		(364)
Notes payable to affiliated companies	(281)		452
Distributions to parent	—		(500)
Other	—		(1)
Net cash provided by financing activities	322		578
Net increase (decrease) in cash, cash equivalents and restricted cash	27		(33)
Cash, cash equivalents and restricted cash at beginning of period	51		79
Cash, cash equivalents and restricted cash at end of period	$	78	$	46
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	256	$	206

See Notes to Condensed Consolidated Financial Statements

25

FINANCIAL STATEMENTS

DUKE ENERGY PROGRESS, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Three Months Ended
	September 30, 2023 and 2024
(in millions)	Member's Equity
Balance at June 30, 2023	$	10,618
Net income	368
Distributions to Parent	(500)
Balance at September 30, 2023	$	10,486
Balance at June 30, 2024	$	11,302
Net income	325
Balance at September 30, 2024	$	11,627
	Nine Months Ended
	September 30, 2023 and 2024
(in millions)	Member's Equity
Balance at December 31, 2022	$	10,309
Net income	677
Distributions to Parent	(500)
Balance at September 30, 2023	$	10,486
Balance at December 31, 2023	$	10,807
Net income	820
Balance at September 30, 2024	$	11,627

See Notes to Condensed Consolidated Financial Statements

26

FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Operating Revenues	$	1,940	$	2,164	$	5,092	$	5,456
Operating Expenses
Fuel used in electric generation and purchased power	705		885		1,833		2,218
Operation, maintenance and other	272		361		779		898
Depreciation and amortization	286		239		796		674
Property and other taxes	127		157		350		403
Impairment of assets and other charges	—		—		—		(1)
Total operating expenses	1,390		1,642		3,758		4,192
Gains on Sales of Other Assets and Other, net	1		—		2		1
Operating Income	551		522		1,336		1,265
Other Income and Expenses, net	21		19		67		56
Interest Expense	114		103		339		305
Income Before Income Taxes	458		438		1,064		1,016
Income Tax Expense	94		91		212		206
Net Income	$	364	$	347	$	852	$	810
Other Comprehensive Income, net of tax
Unrealized gains on available-for-sale securities	—		—		—		2
Other Comprehensive Income, net of tax	$	—	$	—	$	—	$	2
Comprehensive Income	$	364	$	347	$	852	$	812

See Notes to Condensed Consolidated Financial Statements

27

FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2024		December 31, 2023
ASSETS
Current Assets
Cash and cash equivalents	$	16	$	24
Receivables (net of allowance for doubtful accounts of $31 at 2024 and $11 at 2023)	760		83
Receivables of VIEs (net of allowance for doubtful accounts of $0 at 2024 and $20 at 2023)	—		532
Receivables from affiliated companies	2		238
Inventory (includes $477 at 2024 and $462 at 2023 related to VIEs)	686		674
Regulatory assets (includes $60 at 2024 and $59 at 2023 related to VIEs)	261		720
Other (includes $19 at 2024 and $37 at 2023 related to VIEs)	40		51
Total current assets	1,765		2,322
Property, Plant and Equipment
Cost	29,924		28,353
Accumulated depreciation and amortization	(7,496)		(7,067)
Net property, plant and equipment	22,428		21,286
Other Noncurrent Assets
Regulatory assets (includes $754 at 2024 and $803 at 2023 related to VIEs)	2,071		1,883
Nuclear decommissioning trust funds	349		382
Operating lease right-of-use assets, net	290		299
Other	497		429
Total other noncurrent assets	3,207		2,993
Total Assets	$	27,400	$	26,601
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable (includes $199 at 2024 and $188 at 2023 related to VIEs)	$	882	$	738
Accounts payable to affiliated companies	127		135
Notes payable to affiliated companies	195		152
Taxes accrued	238		185
Interest accrued	127		86
Current maturities of long-term debt (includes $59 at 2024 and $384 at 2023 related to VIEs)	436		589
Asset retirement obligations	2		1
Regulatory liabilities	82		118
Other	330		350
Total current liabilities	2,419		2,354
Long-Term Debt (includes $772 at 2024 and $831 at 2023 related to VIEs)	9,812		9,812
Other Noncurrent Liabilities
Deferred income taxes	2,765		2,733
Asset retirement obligations	203		274
Regulatory liabilities	700		708
Operating lease liabilities	234		251
Accrued pension and other post-retirement benefit costs	92		98
Investment tax credits	242		242
Other (includes $0 at 2024 and $6 at 2023 related to VIEs)	161		86
Total other noncurrent liabilities	4,397		4,392
Commitments and Contingencies
Equity
Member's equity	10,777		10,048
Accumulated other comprehensive loss	(5)		(5)
Total equity	10,772		10,043
Total Liabilities and Equity	$	27,400	$	26,601

See Notes to Condensed Consolidated Financial Statements

28

FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	852	$	810
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	936		943
Equity component of AFUDC	(11)		(10)
Impairment of assets and other charges	—		(1)
Deferred income taxes	13		(42)
Equity in (earnings) losses of unconsolidated affiliates	—		1
Contributions to qualified pension plans	(9)		(9)
Payments for asset retirement obligations	(68)		(46)
(Increase) decrease in
Receivables	(171)		(203)
Receivables from affiliated companies	236		(1)
Inventory	(2)		(89)
Other current assets	541		516
Increase (decrease) in
Accounts payable	266		(140)
Accounts payable to affiliated companies	(8)		(23)
Taxes accrued	56		289
Other current liabilities	(3)		23
Other assets	(391)		12
Other liabilities	27		(14)
Net cash provided by operating activities	2,264		2,016
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,855)		(1,851)
Purchases of debt and equity securities	(109)		(135)
Proceeds from sales and maturities of debt and equity securities	193		182
Other	(222)		(125)
Net cash used in investing activities	(1,993)		(1,929)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	179		281
Payments for the redemption of long-term debt	(393)		(76)
Notes payable to affiliated companies	43		(313)
Distributions to parent	(125)		—
Other	(1)		(1)
Net cash used in financing activities	(297)		(109)
Net decrease in cash, cash equivalents and restricted cash	(26)		(22)
Cash, cash equivalents and restricted cash at beginning of period	67		86
Cash, cash equivalents and restricted cash at end of period	$	41	$	64
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	372	$	352

See Notes to Condensed Consolidated Financial Statements

29

FINANCIAL STATEMENTS

DUKE ENERGY FLORIDA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Three Months Ended September 30, 2023 and 2024
			Accumulated
			Other
			Comprehensive
			Loss
			Net Unrealized
			Losses on
	Member's		Available-for-Sale		Total
(in millions)	Equity		Securities		Equity
Balance at June 30, 2023	$	9,494	$	(6)	$	9,488
Net income	347		—		347
Other	1		—		1
Balance at September 30, 2023	$	9,842	$	(6)	$	9,836
Balance at June 30, 2024	$	10,555	$	(5)	$	10,550
Net income	364		—		364
Distributions to parent	(125)		—		(125)
Other	(17)		—		(17)
Balance at September 30, 2024	$	10,777	$	(5)	$	10,772
	Nine Months Ended September 30, 2023 and 2024
			Accumulated
			Other
			Comprehensive
			Loss
			Net Unrealized
			Gains (Losses) on
	Member's		Available-for-Sale		Total
(in millions)	Equity		Securities		Equity
Balance at December 31, 2022	$	9,031	$	(8)	$	9,023
Net income	810		—		810
Other comprehensive income	—		2		2
Other	1		—		1
Balance at September 30, 2023	$	9,842	$	(6)	$	9,836
Balance at December 31, 2023	$	10,048	$	(5)	$	10,043
Net income	852		—		852
Distributions to parent	(125)		—		(125)
Other	2		—		2
Balance at September 30, 2024	$	10,777	$	(5)	$	10,772

See Notes to Condensed Consolidated Financial Statements

30

FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Operating Revenues
Regulated electric	$	497	$	472	$	1,431	$	1,411
Regulated natural gas	108		105		460		464
Total operating revenues	605		577		1,891		1,875
Operating Expenses
Fuel used in electric generation and purchased power	146		145		416		485
Cost of natural gas	18		6		100		118
Operation, maintenance and other	131		114		378		358
Depreciation and amortization	102		90		297		266
Property and other taxes	99		94		303		258
Total operating expenses	496		449		1,494		1,485
Operating Income	109		128		397		390
Other Income and Expenses, net	2		12		12		33
Interest Expense	52		46		144		125
Income Before Income Taxes	59		94		265		298
Income Tax Expense	7		14		42		47
Net Income and Comprehensive Income	$	52	$	80	$	223	$	251

See Notes to Condensed Consolidated Financial Statements

31

FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2024		December 31, 2023
ASSETS
Current Assets
Cash and cash equivalents	$	8	$	24
Receivables (net of allowance for doubtful accounts of $41 at 2024 and $9 at 2023)	401		112
Receivables from affiliated companies	11		239
Notes receivable from affiliated companies	33		—
Inventory	173		179
Regulatory assets	98		73
Other	43		134
Total current assets	767		761
Property, Plant and Equipment
Cost	13,784		13,210
Accumulated depreciation and amortization	(3,640)		(3,451)
Net property, plant and equipment	10,144		9,759
Other Noncurrent Assets
Goodwill	920		920
Regulatory assets	678		676
Operating lease right-of-use assets, net	8		16
Other	94		84
Total other noncurrent assets	1,700		1,696
Total Assets	$	12,611	$	12,216
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	285	$	338
Accounts payable to affiliated companies	62		71
Notes payable to affiliated companies	198		613
Taxes accrued	247		316
Interest accrued	55		35
Current maturities of long-term debt	150		—
Asset retirement obligations	7		6
Regulatory liabilities	59		56
Other	68		65
Total current liabilities	1,131		1,500
Long-Term Debt	3,989		3,493
Long-Term Debt Payable to Affiliated Companies	25		25
Other Noncurrent Liabilities
Deferred income taxes	1,324		1,272
Asset retirement obligations	130		130
Regulatory liabilities	475		497
Operating lease liabilities	8		16
Accrued pension and other post-retirement benefit costs	93		97
Other	94		86
Total other noncurrent liabilities	2,124		2,098
Commitments and Contingencies
Equity
Common Stock, $8.50 par value, 120 million shares authorized; 90 million shares outstanding at 2024 and 2023	762		762
Additional paid-in capital	3,119		3,100
Retained earnings	1,461		1,238
Total equity	5,342		5,100
Total Liabilities and Equity	$	12,611	$	12,216

See Notes to Condensed Consolidated Financial Statements

32

FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	223	$	251
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	300		269
Equity component of AFUDC	(4)		(7)
Deferred income taxes	30		7
Contributions to qualified pension plans	(5)		(5)
Payments for asset retirement obligations	(5)		(9)
(Increase) decrease in
Receivables	47		(23)
Receivables from affiliated companies	57		103
Inventory	6		(24)
Other current assets	57		103
Increase (decrease) in
Accounts payable	(32)		(69)
Accounts payable to affiliated companies	(9)		(1)
Taxes accrued	(69)		(70)
Other current liabilities	26		(29)
Other assets	44		(39)
Other liabilities	(43)		(8)
Net cash provided by operating activities	623		449
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(640)		(676)
Net proceeds from the sales of other assets	—		75
Notes receivable from affiliated companies	(199)		(11)
Other	(29)		(53)
Net cash used in investing activities	(868)		(665)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	645		749
Payments for the redemption of long-term debt	—		(300)
Notes payable to affiliated companies	(415)		(224)
Other	(1)		(5)
Net cash provided by financing activities	229		220
Net decrease (increase) in cash and cash equivalents	(16)		4
Cash and cash equivalents at beginning of period	24		16
Cash and cash equivalents at end of period	$	8	$	20
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	94	$	134

See Notes to Condensed Consolidated Financial Statements

33

FINANCIAL STATEMENTS

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Three Months Ended September 30, 2023 and 2024
			Additional
	Common		Paid-in		Retained		Total
(in millions)	Stock		Capital		Earnings		Equity
Balance at June 30, 2023	$	762	$	3,100	$	1,075	$	4,937
Net income	—		—		80		80
Balance at September 30, 2023	$	762	$	3,100	$	1,155	$	5,017
Balance at June 30, 2024	$	762	$	3,119	$	1,409	$	5,290
Net income	—		—		52		52
Balance at September 30, 2024	$	762	$	3,119	$	1,461	$	5,342
	Nine Months Ended September 30, 2023 and 2024
			Additional
	Common		Paid-in		Retained		Total
(in millions)	Stock		Capital		Earnings		Equity
Balance at December 31, 2022	$	762	$	3,100	$	904	$	4,766
Net income	—		—		251		251
Balance at September 30, 2023	$	762	$	3,100	$	1,155	$	5,017
Balance at December 31, 2023	$	762	$	3,100	$	1,238	$	5,100
Net income	—		—		223		223
Other	—		19		—		19
Balance at September 30, 2024	$	762	$	3,119	$	1,461	$	5,342

See Notes to Condensed Consolidated Financial Statements

34

FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Operating Revenues	$	836	$	851	$	2,342	$	2,606
Operating Expenses
Fuel used in electric generation and purchased power	267		283		761		980
Operation, maintenance and other	169		160		510		524
Depreciation and amortization	166		173		507		500
Property and other taxes	7		17		37		42
Total operating expenses	609		633		1,815		2,046
Operating Income	227		218		527		560
Other Income and Expenses, net	16		30		44		58
Interest Expense	58		53		173		157
Income Before Income Taxes	185		195		398		461
Income Tax Expense	29		36		65		82
Net Income	$	156	$	159	$	333	$	379
Other Comprehensive Loss, net of tax
Pension and OPEB adjustments	—		—		(1)		—
Comprehensive Income	$	156	$	159	$	332	$	379

See Notes to Condensed Consolidated Financial Statements

35

FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2024		December 31, 2023
ASSETS
Current Assets
Cash and cash equivalents	$	8	$	8
Receivables (net of allowance for doubtful accounts of $16 at 2024 and $5 at 2023)	416		156
Receivables from affiliated companies	5		197
Inventory	580		582
Regulatory assets	105		102
Other	77		98
Total current assets	1,191		1,143
Property, Plant and Equipment
Cost	19,897		18,900
Accumulated depreciation and amortization	(6,837)		(6,501)
Net property, plant and equipment	13,060		12,399
Other Noncurrent Assets
Regulatory assets	1,013		894
Operating lease right-of-use assets, net	42		50
Other	384		325
Total other noncurrent assets	1,439		1,269
Total Assets	$	15,690	$	14,811
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	261	$	300
Accounts payable to affiliated companies	61		176
Notes payable to affiliated companies	11		256
Taxes accrued	61		66
Interest accrued	74		54
Current maturities of long-term debt	4		4
Asset retirement obligations	152		120
Regulatory liabilities	165		209
Other	198		184
Total current liabilities	987		1,369
Long-Term Debt	4,647		4,348
Long-Term Debt Payable to Affiliated Companies	150		150
Other Noncurrent Liabilities
Deferred income taxes	1,571		1,436
Asset retirement obligations	1,126		689
Regulatory liabilities	1,411		1,459
Operating lease liabilities	38		46
Accrued pension and other post-retirement benefit costs	94		115
Investment tax credits	186		186
Other	15		—
Total other noncurrent liabilities	4,441		3,931
Commitments and Contingencies
Equity
Member's equity	5,465		5,012
Accumulated other comprehensive income	—		1
Total equity	5,465		5,013
Total Liabilities and Equity	$	15,690	$	14,811

See Notes to Condensed Consolidated Financial Statements

36

FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	333	$	379
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	510		503
Equity component of AFUDC	(13)		(7)
Deferred income taxes	87		15
Contributions to qualified pension plans	(8)		(8)
Payments for asset retirement obligations	(60)		(57)
Provision for rate refunds	(20)		—
(Increase) decrease in
Receivables	36		(23)
Receivables from affiliated companies	1		(12)
Inventory	2		(112)
Other current assets	36		209
Increase (decrease) in
Accounts payable	(29)		(86)
Accounts payable to affiliated companies	(74)		(32)
Taxes accrued	(5)		(4)
Other current liabilities	12		107
Other assets	(83)		(62)
Other liabilities	3		26
Net cash provided by operating activities	728		836
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(711)		(699)
Purchases of debt and equity securities	(31)		(53)
Proceeds from sales and maturities of debt and equity securities	22		42
Notes receivable from affiliated companies	(117)		156
Other	(24)		(50)
Net cash used in investing activities	(861)		(604)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	298		495
Payments for the redemption of long-term debt	—		(300)
Notes payable to affiliated companies	(245)		(234)
Capital contribution from parent	235		—
Distributions to parent	(154)		(209)
Other	(1)		(1)
Net cash provided by (used in) financing activities	133		(249)
Net increase (decrease) in cash and cash equivalents	—		(17)
Cash and cash equivalents at beginning of period	8		31
Cash and cash equivalents at end of period	$	8	$	14
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	104	$	94

See Notes to Condensed Consolidated Financial Statements

37

FINANCIAL STATEMENTS

DUKE ENERGY INDIANA, LLC

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Three Months Ended September 30, 2023 and 2024
			Accumulated Other
			Comprehensive Income
	Member's		Pension and		Total
(in millions)	Equity		OPEB Adjustments		Equity
Balance at June 30, 2023	$	4,826	$	1	$	4,827
Net income	159		—		159
Distributions to parent	(50)		—		(50)
Balance at September 30, 2023	$	4,935	$	1	$	4,936
Balance at June 30, 2024	$	5,401	$	—	$	5,401
Net income	156		—		156
Distributions to parent	(93)		—		(93)
Other	1		—		1
Balance at September 30, 2024	$	5,465	$	—	$	5,465
	Nine Months Ended September 30, 2023 and 2024
			Accumulated Other
			Comprehensive Income (Loss)
	Member's		Pension and		Total
(in millions)	Equity		OPEB Adjustments		Equity
Balance at December 31, 2022	$	4,702	$	1	$	4,703
Net income	379		—		379
Distributions to parent	(146)		—		(146)
Balance at September 30, 2023	$	4,935	$	1	$	4,936
Balance at December 31, 2023	$	5,012	$	1	$	5,013
Net income	333		—		333
Contributions from parent	235		—		235
Distributions to parent	(113)		—		(113)
Other	(2)		(1)		(3)
Balance at September 30, 2024	$	5,465	$	—	$	5,465

See Notes to Condensed Consolidated Financial Statements

38

FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Operating Revenues	$	219	$	208	$	1,139	$	1,119
Operating Expenses
Cost of natural gas	52		51		280		316
Operation, maintenance and other	87		77		267		248
Depreciation and amortization	65		59		191		175
Property and other taxes	16		16		47		46
Impairment of assets and other charges	—		—		—		(4)
Total operating expenses	220		203		785		781
Operating (Loss) Income	(1)		5		354		338
Other Income and Expenses, net	14		17		48		49
Interest Expense	47		41		135		120
(Loss) Income Before Income Taxes	(34)		(19)		267		267
Income Tax (Benefit) Expense	(10)		(5)		49		46
Net (Loss) Income and Comprehensive (Loss) Income	$	(24)	$	(14)	$	218	$	221

See Notes to Condensed Consolidated Financial Statements

39

FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)

(in millions)	September 30, 2024		December 31, 2023
ASSETS
Current Assets
Cash and cash equivalents	$	4	$	—
Receivables (net of allowance for doubtful accounts of $12 at 2024 and $11 at 2023)	126		311
Receivables from affiliated companies	12		10
Inventory	58		112
Regulatory assets	154		161
Other	80		7
Total current assets	434		601
Property, Plant and Equipment
Cost	12,619		11,908
Accumulated depreciation and amortization	(2,398)		(2,259)
Net property, plant and equipment	10,221		9,649
Other Noncurrent Assets
Goodwill	49		49
Regulatory assets	427		410
Operating lease right-of-use assets, net	4		4
Investments in equity method unconsolidated affiliates	78		78
Other	284		276
Total other noncurrent assets	842		817
Total Assets	$	11,497	$	11,067
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	196	$	315
Accounts payable to affiliated companies	64		54
Notes payable to affiliated companies	513		538
Taxes accrued	53		89
Interest accrued	50		39
Current maturities of long-term debt	150		40
Regulatory liabilities	91		98
Other	75		77
Total current liabilities	1,192		1,250
Long-Term Debt	3,853		3,628
Other Noncurrent Liabilities
Deferred income taxes	1,007		933
Asset retirement obligations	27		26
Regulatory liabilities	958		988
Operating lease liabilities	8		10
Accrued pension and other post-retirement benefit costs	6		8
Other	176		172
Total other noncurrent liabilities	2,182		2,137
Commitments and Contingencies
Equity
Common stock, no par value: 100 shares authorized and outstanding at 2024 and 2023	1,635		1,635
Retained earnings	2,634		2,416
Total Piedmont Natural Gas Company, Inc. stockholder's equity	4,269		4,051
Noncontrolling interests	1		1
Total equity	4,270		4,052
Total Liabilities and Equity	$	11,497	$	11,067

See Notes to Condensed Consolidated Financial Statements

40

FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Nine Months Ended
	September 30,
(in millions)	2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	218	$	221
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	193		177
Equity component of AFUDC	(17)		(15)
Impairment of assets and other charges	—		(4)
Deferred income taxes	54		52
Equity in earnings from unconsolidated affiliates	(6)		(6)
Contributions to qualified pension plans	(3)		(3)
(Increase) decrease in
Receivables	185		335
Receivables from affiliated companies	(2)		(1)
Inventory	54		83
Other current assets	(71)		(63)
Increase (decrease) in
Accounts payable	(39)		(78)
Accounts payable to affiliated companies	10		(3)
Taxes accrued	(36)		(30)
Other current liabilities	8		25
Other assets	(15)		(23)
Other liabilities	8		7
Net cash provided by operating activities	541		674
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(800)		(774)
Other	(44)		(32)
Net cash used in investing activities	(844)		(806)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	373		348
Payments for the redemption of long-term debt	(40)		—
Notes payable to affiliated companies	(26)		(216)
Net cash provided by financing activities	307		132
Net increase in cash and cash equivalents	4		—
Cash and cash equivalents at beginning of period	—		—
Cash and cash equivalents at end of period	$	4	$	—
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	143	$	149

See Notes to Condensed Consolidated Financial Statements

41

FINANCIAL STATEMENTS

PIEDMONT NATURAL GAS COMPANY, INC.

Condensed Consolidated Statements of Changes in Equity

(Unaudited)

	Three Months Ended September 30, 2023 and 2024
					Total
					Piedmont
					Natural Gas
	Common		Retained		Company, Inc.		Noncontrolling		Total
(in millions)	Stock		Earnings		Equity		Interests		Equity
Balance at June 30, 2023	$	1,635	$	2,272	$	3,907	$	1	$	3,908
Net loss	—		(14)		(14)		—		(14)
Balance at September 30, 2023	$	1,635	$	2,258	$	3,893	$	1	$	3,894
Balance at June 30, 2024	$	1,635	$	2,658	$	4,293	$	1	$	4,294
Net loss	—		(24)		(24)		—		(24)
Balance at September 30, 2024	$	1,635	$	2,634	$	4,269	$	1	$	4,270
	Nine Months Ended September 30, 2023 and 2024
					Total
					Piedmont
					Natural Gas
	Common		Retained		Company, Inc.		Noncontrolling		Total
(in millions)	Stock		Earnings		Equity		Interests		Equity
Balance at December 31, 2022	$	1,635	$	2,037	$	3,672	$	1	$	3,673
Net income	—		221		221		—		221
Balance at September 30, 2023	$	1,635	$	2,258	$	3,893	$	1	$	3,894
Balance at December 31, 2023	$	1,635	$	2,416	$	4,051	$	1	$	4,052
Net income	—		218		218		—		218
Balance at September 30, 2024	$	1,635	$	2,634	$	4,269	$	1	$	4,270

See Notes to Condensed Consolidated Financial Statements

42

FINANCIAL STATEMENTS ORGANIZATION AND BASIS OF PRESENTATION

Index to Combined Notes to Condensed Consolidated Financial Statements

The unaudited notes to the Condensed Consolidated Financial Statements that follow are a combined presentation. The following list indicates the registrants to which the footnotes apply.

Applicable Notes

Registrant

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

17

18

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 Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2023.

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 13 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.

Discontinued Operations

Duke Energy has elected to present cash flows of discontinued operations combined with cash flows of continuing operations. Unless otherwise noted, the notes to these condensed consolidated financial statements exclude amounts related to discontinued operations for all periods presented. For the nine months ended September 30, 2024, and 2023, the Income (Loss) From Discontinued Operations, net of tax on Duke Energy's Condensed Consolidated Statements of Operations includes amounts related to noncontrolling interests. A portion of Noncontrolling interests on Duke Energy's Condensed Consolidated Balance Sheets relates to discontinued operations for the periods presented. See Note 2 for discussion of discontinued operations related to the Commercial Renewables Disposal Groups.

NONCONTROLLING INTEREST

Duke Energy maintains a controlling financial interest in certain less than wholly owned 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 Sheets. 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.

43

FINANCIAL STATEMENTS ORGANIZATION AND BASIS OF PRESENTATION

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 11 and 13 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.

	September 30, 2024										December 31, 2023
			Duke				Duke		Duke				Duke				Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Duke		Energy		Progress		Energy		Energy
	Energy		Carolinas		Energy		Progress		Florida		Energy		Carolinas		Energy		Progress		Florida
Current Assets
Cash and cash equivalents	$	376	$	13	$	82	$	46	$	16	$	253	$	9	$	59	$	18	$	24
Other	51		6		45		27		18		76		9		67		31		36
Other Noncurrent Assets
Other	18		1		11		5		7		16		1		9		2		7
Total cash, cash equivalents and restricted cash	$	445	$	20	$	138	$	78	$	41	$	345	$	19	$	135	$	51	$	67

INVENTORY

Provisions for inventory write-offs were not material at September 30, 2024, and December 31, 2023. The components of inventory are presented in the tables below.

	September 30, 2024
			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	$	3,229	$	1,076	$	1,580	$	1,052	$	528	$	141	$	381	$	12
Coal	810		360		232		161		71		21		197		—
Natural gas, oil and other fuel	299		46		194		107		87		11		2		46
Total inventory	$	4,338	$	1,482	$	2,006	$	1,320	$	686	$	173	$	580	$	58

	December 31, 2023
			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	$	3,086	$	1,075	$	1,465	$	963	$	502	$	139	$	361	$	12
Coal	842		364		231		154		77		28		219		—
Natural gas, oil and other fuel	364		45		205		110		95		12		2		100
Total inventory	$	4,292	$	1,484	$	1,901	$	1,227	$	674	$	179	$	582	$	112

OTHER NONCURRENT ASSETS

Duke Energy, through a nonregulated subsidiary, was the winner of the Carolina Long Bay offshore wind auction in May 2022 and recorded an asset of $150 million related to the arrangement in Other within Other noncurrent assets on the Consolidated Balance Sheets as of September 30, 2024, and December 31, 2023. The asset is recorded in the EU&I segment at historical cost and is subject to impairment testing should circumstances indicate the carrying value may not be recoverable.

ACCOUNTS PAYABLE

Duke Energy has a voluntary supply chain finance program (the “program”) that allows Duke Energy suppliers, at their sole discretion, to sell their receivables from Duke Energy to a global financial institution at a rate that leverages Duke Energy’s credit rating and which may result in favorable terms compared to the rate available to the supplier on their own credit rating. Suppliers participating in the program determine at their sole discretion, which invoices they will sell to the financial institution. Suppliers’ decisions on which invoices are sold do not impact Duke Energy’s payment terms, which are based on commercial terms negotiated between Duke Energy and the supplier regardless of program participation. The commercial terms negotiated between Duke Energy and its suppliers are consistent regardless of whether the supplier elects to participate in the program. Duke Energy does not issue any guarantees with respect to the program and does not participate in negotiations between suppliers and the financial institution. Duke Energy does not have an economic interest in the supplier’s decision to participate in the program and receives no interest, fees or other benefit from the financial institution based on supplier participation in the program.

44

FINANCIAL STATEMENTS ORGANIZATION AND BASIS OF PRESENTATION

The following table represents the changes in confirmed obligations outstanding for the nine months ended September 30, 2024, and 2023.

	Three Months Ended September 30, 2023 and 2024
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Confirmed obligations outstanding at June 30, 2023	$	40	$	5	$	14	$	12	$	2	$	2	$	—	$	19
Invoices confirmed during the period	47		2		11		2		9		4		—		30
Confirmed invoices paid during the period	(18)		(4)		(8)		(3)		(5)		—		—		(6)
Confirmed obligations outstanding at September 30, 2023	$	69	$	3	$	17	$	11	$	6	$	6	$	—	$	43
Confirmed obligations outstanding at June 30, 2024	$	28	$	—	$	—	$	—	$	—	$	—	$	—	$	28
Invoices confirmed during the period	26		—		1		—		1		—		—		25
Confirmed invoices paid during the period	(28)		—		—		—		—		—		—		(28)
Confirmed obligations outstanding at September 30, 2024	$	26	$	—	$	1	$	—	$	1	$	—	$	—	$	25
	Nine Months Ended September 30, 2023 and 2024
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Confirmed obligations outstanding at December 31, 2022	$	87	$	6	$	19	$	8	$	11	$	5	$	—	$	57
Invoices confirmed during the period	161		22		53		25		28		7		—		79
Confirmed invoices paid during the period	(179)		(25)		(55)		(22)		(33)		(6)		—		(93)
Confirmed obligations outstanding at September 30, 2023	$	69	$	3	$	17	$	11	$	6	$	6	$	—	$	43
Confirmed obligations outstanding at December 31, 2023	$	50	$	—	$	3	$	—	$	3	$	—	$	—	$	47
Invoices confirmed during the period	146		—		2		—		2		—		—		144
Confirmed invoices paid during the period	(170)		—		(4)		—		(4)		—		—		(166)
Confirmed obligations outstanding at September 30, 2024	$	26	$	—	$	1	$	—	$	1	$	—	$	—	$	25

NEW ACCOUNTING STANDARDS

No new accounting standards were adopted by the Duke Energy Registrants in 2024.

2. DISPOSITIONS

Sale of Commercial Renewables Segment

In 2023, Duke Energy completed the sale of substantially all the assets in the Commercial Renewables business segment. Duke Energy closed on the transaction with Brookfield on October 25, 2023, for proceeds of $1.1 billion, with approximately half of the proceeds received at closing and the remainder due 18 months after closing. The balance of the remaining proceeds to be received of $545 million is included in Receivable from sales of Commercial Renewables Disposal Groups, as of September 30, 2024, and $531 million is included in Other, within Other Noncurrent Assets, as of December 31, 2023, on Duke Energy's Consolidated Balance Sheets. The disposal process for the remaining assets is expected to be completed in 2024, with net proceeds from the dispositions not anticipated to be material.

Assets Held For Sale and Discontinued Operations

The Commercial Renewables Disposal Groups were classified as held for sale and as discontinued operations in the fourth quarter of 2022. No interest from corporate level debt was allocated to discontinued operations and no adjustments were made to the historical activity within the Consolidated Statements of Comprehensive Income, Consolidated Statements of Cash Flows or the Consolidated Statements of Changes in Equity. Unless otherwise noted, the notes to these consolidated financial statements exclude amounts related to discontinued operations for all periods presented.

45

FINANCIAL STATEMENTS DISPOSITIONS

The following table presents the carrying values of the major classes of Assets held for sale and Liabilities associated with assets held for sale included in Duke Energy's Consolidated Balance Sheets.

(in millions)	September 30, 2024		December 31, 2023
Current Assets Held for Sale
Other	$	4	$	14
Total current assets held for sale	4		14
Noncurrent Assets Held for Sale
Property, Plant and Equipment
Cost	101		247
Accumulated depreciation and amortization	(24)		(57)
Net property, plant and equipment	77		190
Operating lease right-of-use assets, net	4		4
Other	—		3
Total other noncurrent assets held for sale	4		7
Total Assets Held for Sale	$	85	$	211
Current Liabilities Associated with Assets Held for Sale
Accounts payable	$	19	$	9
Taxes accrued	1		3
Current maturities of long-term debt	43		5
Unrealized losses on commodity hedges	11		68
Other	3		37
Total current liabilities associated with assets held for sale	77		122
Noncurrent Liabilities Associated with Assets Held for Sale
Long-Term debt	—		39
Operating lease liabilities	5		5
Asset retirement obligations	5		8
Unrealized losses on commodity hedges	61		94
Other	14		11
Total other noncurrent liabilities associated with assets held for sale	85		157
Total Liabilities Associated with Assets Held for Sale	$	162	$	279

As of September 30, 2024, and December 31, 2023, the noncontrolling interest balance is $17 million and $66 million, respectively.

The following table presents the results of the Commercial Renewables Disposal Groups, which are included in Income (Loss) from Discontinued Operations, net of tax in Duke Energy's Consolidated Statements of Operations.

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in millions)	2024		2023		2024		2023
Operating revenues	$	2	$	103	$	9	$	293
Operation, maintenance and other	3		93		19		270
Property and other taxes	—		8		1		27
Other income and expenses, net	—		(2)		—		(9)
Interest expense	1		10		3		53
Loss on disposal	17		169		22		1,603
Loss before income taxes	(19)		(179)		(36)		(1,669)
Income tax benefit	(44)		(27)		(48)		(353)
Income (Loss) from discontinued operations	$	25	$	(152)	$	12	$	(1,316)
Add: Net (income) loss attributable to noncontrolling interest included in discontinued operations	(3)		(38)		(3)		33
Net income (loss) from discontinued operations attributable to Duke Energy Corporation	$	22	$	(190)	$	9	$	(1,283)

The Commercial Renewables Disposal Groups' assets held for sale amounts presented above reflect pretax impairments recorded against property, plant and equipment of approximately $131 million and $278 million as of September 30, 2024, and December 31, 2023, respectively. The carrying amounts for the remaining assets will be updated, if necessary, based on final disposition amounts.

46

FINANCIAL STATEMENTS DISPOSITIONS

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

	Nine Months Ended
	September 30,
(in millions)	2024		2023
Cash flows provided by (used in):
Operating activities	$	6	$	545
Investing activities	(13)		(597)

Other Sale-Related Matters

Duke Energy (Parent) and several Duke Energy renewables project companies, located in the ERCOT market, were named in several lawsuits arising out of Texas Storm Uri, which occurred in February 2021. The legal actions related to all but one of the project companies in this matter transferred to affiliates of Brookfield in conjunction with the transaction closing in October 2023. In May 2024, the remaining claim in the lawsuit was transferred to the buyer in connection with the sale of a portion of the remaining Commercial Renewables assets. See Note 5 for more information.

As part of the purchase and sale agreement for the distributed generation group, Duke Energy has agreed to retain certain guarantees, with expiration dates between 2029 through 2034, related to tax equity partners' assets and operations that will be disposed of via sale. Duke Energy has obtained certain guarantees from the buyers in regards to future performance obligations to assist in limiting Duke Energy's exposure under the retained guarantees. The fair value of the guarantees is immaterial as Duke Energy does not believe conditions are likely for performance under these guarantees.

3. BUSINESS SEGMENTS

Duke Energy

Duke Energy's segment structure includes the following two segments: EU&I and GU&I.

The EU&I segment primarily includes Duke Energy's regulated electric utilities in the Carolinas, Florida and the Midwest. EU&I also includes Duke Energy's electric transmission infrastructure investments and the offshore wind contract for Carolina Long Bay.

The GU&I segment includes Piedmont, Duke Energy's natural gas local distribution companies in Ohio and Kentucky and Duke Energy's natural gas storage, midstream pipeline and renewable natural gas investments.

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 NMC.

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

	Three Months Ended September 30, 2024
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations		Total
Unaffiliated revenues	$	7,833	$	309	$	8,142	$	12	$	—	$	8,154
Intersegment revenues	19		23		42		30		(72)		—
Total revenues	$	7,852	$	332	$	8,184	$	42	$	(72)	$	8,154
Segment income (loss)(a)(b)	$	1,451	$	(25)	$	1,426	$	(222)	$	—	$	1,204
Add: Noncontrolling interests											34
Add: Preferred dividends											39
Add: Preferred redemption costs											16
Discontinued operations											22
Net Income											$	1,315
Segment assets	$	161,471	$	17,852	$	179,323	$	4,243	$	—	$	183,566

47

FINANCIAL STATEMENTS BUSINESS SEGMENTS

	Three Months Ended September 30, 2023
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations		Total
Unaffiliated revenues	$	7,695	$	291	$	7,986	$	8	$	—	$	7,994
Intersegment revenues	20		22		42		25		(67)		—
Total revenues	$	7,715	$	313	$	8,028	$	33	$	(67)	$	7,994
Segment income (loss)(c)	$	1,447	$	15	$	1,462	$	(59)	$	—	$	1,403
Add: Noncontrolling interests											69
Add: Preferred dividends											39
Discontinued operations											(190)
Net Loss											$	1,321

(a)EU&I includes $17 million recorded within Operating Revenues on the Condensed Consolidated Statements of Operations and GU&I includes $1 million recorded within Operations, maintenance and other and $3 million recorded within Other income and expenses on the Condensed Consolidated Statements of Operations related to nonrecurring customer billing adjustments as a result of implementation of a new customer system.

(b)Other includes $16 million recorded as Preferred Redemption Costs on the Condensed Consolidated Statements of Operations related to the redemption of Series B Preferred Stock. Refer to Note 15 for further information.

(c)EU&I includes $95 million recorded within Impairment of assets and other charges and $16 million within Operations, maintenance and other on Duke Energy Carolinas' and Duke Energy Progress' Condensed Consolidated Statement of Operations related primarily to Duke Energy Carolinas' North Carolina rate case settlement and Duke Energy Progress' North Carolina rate case order.

	Nine Months Ended September 30, 2024
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations		Total
Unaffiliated revenues	$	21,420	$	1,547	$	22,967	$	30	$	—	$	22,997
Intersegment revenues	55		68		123		90		(213)		—
Total revenues	$	21,475	$	1,615	$	23,090	$	120	$	(213)	$	22,997
Segment income (loss)(a)(b)	$	3,562	$	265	$	3,827	$	(625)	$	—	$	3,202
Add: Noncontrolling interests											68
Add: Preferred dividends											92
Add: Preferred redemption costs											16
Discontinued operations											9
Net Income											$	3,387

	Nine Months Ended September 30, 2023
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations		Total
Unaffiliated revenues	$	20,308	$	1,516	$	21,824	$	24	$	—	$	21,848
Intersegment revenues	55		67		122		74		(196)		—
Total revenues	$	20,363	$	1,583	$	21,946	$	98	$	(196)	$	21,848
Segment income (loss)(c)	$	3,088	$	327	$	3,415	$	(388)	$	—	$	3,027
Add: Noncontrolling interests											42
Add: Preferred dividends											92
Discontinued operations											(1,283)
Net Income											$	1,878

(a)EU&I includes $42 million recorded within Impairment of assets and other charges, $2 million within Operations, maintenance and other, and an $11 million reduction recorded within Interest Expense on Duke Energy Carolinas' and Duke Energy Progress' Condensed Consolidated Statement of Operations, related to the Duke Energy Carolinas' South Carolina rate case order. Additionally, EU&I includes $17 million recorded within Operating Revenues on the Condensed Consolidated Statements of Operations and GU&I includes $1 million recorded within Operations, maintenance and other and $3 million recorded within Other income and expenses on the Condensed Consolidated Statements of Operations related to nonrecurring customer billing adjustments as a result of implementation of a new customer system.

(b)Other includes $16 million recorded as Preferred Redemption Costs on the Condensed Consolidated Statements of Operations related to the redemption of Series B Preferred Stock. Refer to Note 15 for further information.

48

FINANCIAL STATEMENTS BUSINESS SEGMENTS

(c)EU&I includes $95 million recorded within Impairment of assets and other charges and $16 million within Operations, maintenance and other on Duke Energy Carolinas' and Duke Energy Progress' Condensed Consolidated Statement of Operations related primarily to Duke Energy Carolinas' North Carolina rate case settlement and Duke Energy Progress' North Carolina rate case order.

Duke Energy Ohio

Duke Energy Ohio has two reportable segments, EU&I and GU&I. The remainder of Duke Energy Ohio's operations is presented as Other.

	Three Months Ended September 30, 2024
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Eliminations		Total
Total revenues	$	497	$	108	$	605	$	—	$	—	$	605
Segment income (loss)/Net income	$	57	$	(4)	$	53	$	(1)	$	—	$	52
Segment assets	$	8,096	$	4,456	$	12,552	$	13	$	46	$	12,611

	Three Months Ended September 30, 2023
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Total
Total revenues	$	472	$	105	$	577	$	—	$	577
Segment income (loss)/Net income	$	65	$	17	$	82	$	(2)	$	80

	Nine Months Ended September 30, 2024
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Total
Total revenues	$	1,431	$	460	$	1,891	$	—	$	1,891
Segment income (loss)/Net income	$	181	$	46	$	227	$	(4)	$	223

	Nine Months Ended September 30, 2023
	Electric		Gas		Total
	Utilities and		Utilities and		Reportable
(in millions)	Infrastructure		Infrastructure		Segments		Other		Total
Total revenues	$	1,411	$	464	$	1,875	$	—	$	1,875
Segment income (loss)/Net income	$	168	$	87	$	255	$	(4)	$	251

4. REGULATORY MATTERS

RATE-RELATED INFORMATION

The NCUC, PSCSC, FPSC, IURC, PUCO, TPUC and KPSC approve rates for retail electric and natural gas services within their states. The FERC approves rates for electric sales to wholesale customers served under cost-based rates (excluding Ohio and Indiana), as well as sales of transmission service. The FERC also regulates certification and siting of new interstate natural gas pipeline projects. For open regulatory matters, unless otherwise noted, the Subsidiary Registrants and Duke Energy Kentucky cannot predict the outcome or ultimate resolution of their respective matters.

As discussed further below, the Subsidiary Registrants were impacted by significant storms in 2024. Each Subsidiary Registrant is responsible for the restoration of service within its respective service territory and the recovery of related storm costs, including financing costs and, as applicable, the replenishment of storm-related reserves. The Subsidiary Registrants are considering all available avenues to recover storm-related costs, including insurance recovery and the securitization for certain costs, where applicable. Total storm restoration costs across the Subsidiary Registrants, including capital expenditures, for hurricanes Helene, Debby and Milton are estimated to be in the range of $2.4 billion to $2.9 billion and are expected to primarily impact the following registrants:

(in millions)	Cost Estimate Range(a)
Duke Energy Carolinas	$	950	-	$	1,150
Duke Energy Progress	350		-	450
Duke Energy Florida	1,100		-	1,300

(a)    These estimates do not include amounts for rebuilding certain damaged infrastructure, as estimates of such costs are not yet available, and will change as restoration work is completed and additional information is received on actual costs incurred. Duke Energy Florida was the only jurisdiction materially impacted by Hurricane Milton.

49

FINANCIAL STATEMENTS REGULATORY MATTERS

Hurricane Helene

In late September 2024, Hurricane Helene made landfall in Florida as a Category 4 storm and subsequently impacted all of Duke Energy's service territories as the storm moved inland, with the most severe damage occurring in the Duke Energy Florida territory and the Duke Energy Carolinas and Duke Energy Progress territories in North Carolina and South Carolina. Approximately 3.5 million customers were impacted across Duke Energy's system. As of September 30, 2024, Duke Energy's restoration costs incurred, including capital of $112 million, were approximately $582 million (primarily $261 million, $51 million and $251 million for Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively). Approximately $451 million of the operation and maintenance expenses are deferred in regulatory assets on the Condensed Consolidated Balance Sheets as of September 30, 2024 (primarily $177 million, $34 million and $236 million for Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively). Total storm restoration costs, including capital expenditures, for Duke Energy are currently estimated to be in the range of $1.5 billion to $1.9 billion (primarily $900 million to $1.1 billion for Duke Energy Carolinas, $300 million to $400 million for Duke Energy Progress and $300 million to $400 million for Duke Energy Florida). These estimates do not include amounts for rebuilding certain damaged infrastructure, as estimates of such costs are not yet available, and will change as restoration work is completed and additional information is received on actual costs incurred.

Hurricane Debby

In August 2024, Hurricane Debby made landfall in Florida as a Category 1 storm, impacting primarily the Duke Energy Florida territory as well as the Duke Energy Carolinas and Duke Energy Progress territories in North Carolina and South Carolina. Approximately 700,000 customers were impacted across Duke Energy's system. As of September 30, 2024, Duke Energy's restoration costs incurred, including capital expenditures of $11 million, were approximately $150 million (primarily $45 million, $45 million and $60 million for Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively). Approximately $90 million of the operation and maintenance expenses are deferred in regulatory assets on the Condensed Consolidated Balance Sheets as of September 30, 2024 (primarily $23 million, $13 million and $54 million for Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively). These estimates could change as additional information is received on actual costs incurred.

Duke Energy Carolinas and Duke Energy Progress

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 three contentions and claimed that Duke Energy Carolinas did not satisfy the National Environmental Policy Act (NEPA) of 1969, as amended, or the NRC’s NEPA-implementing regulations. Following Duke Energy Carolinas' answer and the Petitioners' reply, 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 Hearing Request proceeding.

On February 24, 2022, the NRC issued a decision in the SLR appeal related to Florida Power and Light's Turkey Point nuclear generating station in Florida. The NRC 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. Although 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 supplement to its environmental report providing information on environmental impacts during the SLR period prior to the rulemaking being completed. On November 7, 2022, Duke Energy Carolinas submitted a supplement to its environmental report addressing environmental impacts during the SLR period. On March 6, 2024, the NRC staff submitted the rulemaking, which included the updated GEIS, to the NRC. The NRC approved the publication of the final rule on May 16, 2024. The updated GEIS was finalized and published on August 1, 2024, and the final rule was issued on August 6, 2024.

On December 19, 2022, the NRC published a notice in the Federal Register that the NRC will conduct a limited scoping process to gather additional information necessary to prepare an environmental impact statement (EIS) to evaluate the environmental impacts at ONS during the SLR period. The NRC received comments from the EPA and the Petitioners and these comments identify 18 potential impacts that should be considered by the NRC in the EIS, which include, but are not limited to, climate change and flooding, environmental justice, severe accidents and external events. On February 8, 2024, the NRC issued the Oconee site-specific draft EIS. The NRC and EPA published the notice for the public to submit comments on the ONS site-specific draft EIS. On April 29, 2024, the Petitioners filed a Hearing Request. The request proposed three contentions and claimed that the ONS site-specific draft EIS is inadequate to satisfy the requirements of NEPA and the NRC’s NEPA-implementing regulations. Duke Energy Carolinas provided responses to the proposed contentions by May 31, 2024, as ordered by the ASLB. On June 24, 2024, the ASLB convened a pre-hearing conference to obtain information and ask questions concerning the admissibility of the Petitioners' contentions. On August 29, 2024, the ASLB issued a protective order to protect Sensitive Unclassified Non-Safeguards Information (SUNSI) that is identified as Critical Energy/Electrical Infrastructure Information. On October 18, 2024, the ASLB indicated that it plans to issue a decision on contention admissibility by December 18, 2024. The NRC's issuance of the final EIS is pending the ASLB's decision.

50

FINANCIAL STATEMENTS REGULATORY MATTERS

On December 19, 2022, the NRC issued the Safety Evaluation Report (SER) for the safety portion of the SLR application. The NRC determined Duke Energy Carolinas met the requirements of the applicable regulations and identified actions that have been taken or will be taken to manage the effects of aging and address time-limited analyses. Duke Energy Carolinas and the NRC met with the Advisory Committee on Reactor Safeguards (ACRS) on February 2, 2023, to discuss issues regarding the SER and SLR application. On February 25, 2023, the ACRS issued a report to the NRC on the safety aspects of the ONS SLR application, which concluded that the established programs and commitments made by Duke Energy Carolinas to manage age-related degradation provide confidence that ONS can be operated in accordance with its current licensing basis for the subsequent period of extended operation without undue risk to the health and safety of the public and the SLR application for ONS should be approved.

Although the NRC’s GEIS applicability decision has delayed 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, although Duke Energy Carolinas cannot guarantee the outcome of the license application process.

Duke Energy Carolinas and Duke Energy Progress intend to seek renewal of operating licenses and 20-year license extensions for all of their nuclear stations.

Duke Energy Carolinas

2023 North Carolina Rate Case

On January 19, 2023, Duke Energy Carolinas filed a performance-based regulation (PBR) application with the NCUC to request an increase in base rate retail revenues. The PBR application included a multiyear rate plan (MYRP) to recover projected capital investments during the three-year MYRP period. In addition to the MYRP, the PBR application included an Earnings Sharing Mechanism, Residential Decoupling Mechanism and Performance Incentive Mechanisms (PIMS) as required by HB 951. The application as originally filed requested an overall retail revenue increase of $501 million in Year 1, $172 million in Year 2 and $150 million in Year 3, for a combined total of $823 million, or 15.7%, by early 2026. The rate increase is driven primarily by transmission and distribution investments since the last rate case and projected in the MYRP, as well as investments in energy storage and solar assets included in the MYRP consistent with the Carolinas Carbon Plan (Carbon Plan).

On August 22, 2023, Duke Energy Carolinas filed with the NCUC a partial settlement with the Public Staff in connection with its PBR application. The partial settlement included, among other things, agreement on a substantial portion of the North Carolina retail rate base for the historic base case of approximately $19.5 billion and all of the capital projects and related costs to be included in the three-year MYRP, including $4.6 billion (North Carolina retail allocation) projected to go in service over the MYRP period. Additionally, the partial settlement included agreement, with certain adjustments, on depreciation rates, the recovery of grid improvement plan costs and PIMs, Tracking Metrics and the Residential Decoupling Mechanism under the PBR application. On August 28, 2023, Duke Energy Carolinas filed with the NCUC a second partial settlement with the Public Staff resolving additional issues, including the future treatment of nuclear production tax credits related to the Inflation Reduction Act, through a stand-alone rider that will provide the benefits to customers beginning January 1, 2025. As a result of the partial settlements, Duke Energy Carolinas recognized pretax charges of $59 million within Impairment of assets and other charges, which primarily related to certain COVID-19 deferred costs, and $8 million within Operations, maintenance and other, for the three and nine months ended September 30, 2023, on the Condensed Consolidated Statements of Operations.

On December 15, 2023, the NCUC issued an order approving Duke Energy Carolinas' PBR application, as modified by the partial settlements and the order, including an overall retail revenue increase of $436 million in Year 1, $174 million in Year 2 and $158 million in Year 3, for a combined total of $768 million. The order established an ROE of 10.1% based upon an equity ratio of 53% and approved, with certain adjustments, depreciation rates and the recovery of grid improvement plan costs and certain deferred COVID-related costs. Additionally, the Residential Decoupling Mechanism and PIMs were approved as requested under the PBR application and revised by the partial settlements. Duke Energy Carolinas implemented interim rates, subject to refund, on September 1, 2023. New revised Year 1 rates and the residential decoupling were implemented on January 15, 2024.

On February 13, 2024, a number of parties filed Notices of Appeal of the December 15, 2023, NCUC order. Notices of Appeal were filed by the Carolina Industrial Group for Fair Utility Rates (CIGFUR) III, a collection of various electric membership corporations (collectively, the EMCs), and the North Carolina Attorney General’s Office (the AGO). CIGFUR III and the EMCs appealed the interclass subsidy reduction percentage and the Transmission Cost Allocation stipulation. In addition, CIGFUR III appealed the NCUC’s elimination of the equal percentage fuel cost allocation methodology. The AGO appealed several issues including the authorized ROE and certain rate design and accounting matters. On March 1, 2024, Carolina Utility Customers Association, Inc. appealed several issues, including the authorized ROE and certain rate design and accounting matters. In July 2024, the Supreme Court of North Carolina consolidated the appeal with the parallel appeal of the NCUC's order regarding the Duke Energy Progress PBR application. The briefing is scheduled to be completed by December 31, 2024. Duke Energy Carolinas anticipates a decision to be issued by the third quarter of 2025.

2024 South Carolina Rate Case

On January 4, 2024, Duke Energy Carolinas filed a rate case with the PSCSC to request an increase in base rate retail revenues. On May 17, 2024, Duke Energy Carolinas and the Office of Regulatory Staff, as well as other consumer, environmental, and industrial intervening parties, filed an Agreement and Stipulation of Settlement resolving all issues in the base rate proceeding. The major components of the settlement include a $240 million annual customer rate increase, prior to a reduction from the accelerated return to customers of federal unprotected Property, Plant and Equipment related EDIT of $84 million annually over the first two years. The stipulation includes an ROE of 9.94% with an equity ratio of 51.21% and resolves recovery of the Company's continued investments in the grid, its new corporate headquarters and environmental compliance costs. The PSCSC held a hearing on May 20, 2024, to consider evidence supporting the stipulation. On July 3, 2024, the PSCSC issued its final order approving an increase in base rates and approving nearly all components of the Agreement and Stipulation of Settlement. The order revised recovery of certain environmental compliance costs, the only provision of the settlement agreement not fully approved by the PSCSC. As a result, Duke Energy Carolinas recognized pretax charges of $33 million within Impairment of assets and other charges, $2 million within Operations, maintenance and other, partially offset by an $11 million reduction in Interest expense, for the nine months ended September 30, 2024, on the Condensed Consolidated Statements of Operations. Based upon the order, after accelerating the EDIT giveback to customers, the net rate increase is $150 million annually for the first two years. Revised customer rates were effective August 1, 2024, and are based upon a South Carolina retail rate base of $7.4 billion.

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FINANCIAL STATEMENTS REGULATORY MATTERS

Marshall Combustion Turbines CPCN

On March 14, 2024, Duke Energy Carolinas filed with the NCUC an application to construct and operate two hydrogen-capable advanced-class simple-cycle combustion turbines (CTs) at the site of the existing Marshall Steam Station. The two new CTs – totaling approximately 850 MW – will enable the retirement of Marshall coal units 1 and 2 and provide incremental capacity to support system capacity needs and expanded flexibility to support integration of renewables. Pending regulatory approvals, construction is planned to start in 2026, and the CTs are targeted to be placed into service by the end of 2028. As part of the application, Duke Energy Carolinas noted that Construction Work in Progress for the proposed facility will accrue AFUDC and will not be in rate base, resulting in no impact on Duke Energy Carolinas' North Carolina retail revenue requirement during the construction period. The 2029 North Carolina retail revenue requirement for the proposed facility is estimated to be $104 million, representing an approximate average retail rate increase of 2.2% across all classes. The expert witness hearing concluded on August 6, 2024. An order is expected no later than December 31, 2024, in parallel with the NCUC’s order in the Carolinas Resource Plan proceeding.

Duke Energy Progress

2022 North Carolina Rate Case

On October 6, 2022, Duke Energy Progress filed a PBR application with the NCUC to request an increase in base rate retail revenues. The rate request before the NCUC included an MYRP to recover projected capital investments during the three-year MYRP period. In addition to the MYRP, the PBR application included an Earnings Sharing Mechanism, Residential Decoupling Mechanism and PIMs as required by HB 951. The overall retail revenue increase as originally filed would have been $326 million in Year 1, $151 million in Year 2 and $138 million in Year 3, for a combined total of $615 million, by late 2025. The rate increase is driven primarily by transmission and distribution investments since the last rate case and projected in the MYRP, as well as investments in energy storage and solar assets included in the MYRP consistent with the Carbon Plan.

On April 26, 2023, Duke Energy Progress filed with the NCUC a partial settlement with Public Staff, which included agreement on many aspects of Duke Energy Progress' three-year MYRP proposal. In May 2023, CIGFUR II joined this partial settlement and Public Staff and CIGFUR II filed a separate settlement reaching agreement on PIMs, Tracking Metrics and the Residential Decoupling Mechanism under the PBR application.

On August 18, 2023, the NCUC issued an order approving Duke Energy Progress' PBR application, as modified by the partial settlements and the order, including an overall retail revenue increase of $233 million in Year 1, $126 million in Year 2 and $135 million in Year 3, for a combined total of $494 million. Key aspects of the order include the approval of North Carolina retail rate base for the historic base case of approximately $12.2 billion and capital projects and related costs to be included in the three-year MYRP, including $3.5 billion (North Carolina retail allocation) projected to go in service over the MYRP period. The order established an ROE of 9.8% based upon an equity ratio of 53% and approved, with certain adjustments, depreciation rates and the recovery of grid improvement plan costs and certain deferred COVID-related costs. Additionally, the Residential Decoupling Mechanism and PIMs were approved as requested under the PBR application and revised by the partial settlements. As a result of the order, Duke Energy Progress recognized pretax charges of $28 million within Impairment of assets and other charges, which primarily related to certain COVID-19 deferred costs, and $8 million within Operations, maintenance and other, for the three and nine months ended September 30, 2023, on the Condensed Consolidated Statements of Operations. Duke Energy Progress implemented interim rates, subject to refund, on June 1, 2023, and implemented revised Year 1 rates and the residential decoupling on October 1, 2023.

On October 17, 2023, CIGFUR II and Haywood Electric Membership Corporation each filed a Notice of Appeal of the August 18, 2023 NCUC order. Both parties are appealing certain matters that do not impact the overall revenue requirement in the rate case. Specifically, they appealed the interclass subsidy reduction percentage, and CIGFUR II also appealed the Customer Assistance Program and the equal percentage fuel cost allocation methodology. On November 6, 2023, the AGO filed a Notice of Cross Appeal of the NCUC's determination regarding the exclusion of electric vehicle revenue from the residential decoupling mechanism. On November 9, 2023, Duke Energy Progress, the Public Staff, CIGFUR II, and a number of other parties reached a settlement pursuant to which CIGFUR II agreed not to pursue its appeal of the Customer Assistance Program. In July 2024, the Supreme Court of North Carolina consolidated the appeal with the parallel appeal of the NCUC's order regarding the Duke Energy Carolinas PBR application. The briefing is scheduled to be completed by December 31, 2024. Duke Energy Progress anticipates a decision to be issued by the third quarter of 2025.

2023 South Carolina Storm Securitization

On May 31, 2023, Duke Energy Progress filed a petition with the PSCSC requesting authorization for the financing of Duke Energy Progress' storm recovery costs through securitization due to storm recovery activities required as a result of the following storms: Pax, Ulysses, Matthew, Florence, Michael, Dorian, Izzy and Jasper. On September 8, 2023, Duke Energy Progress filed a comprehensive settlement agreement with all parties on all cost recovery issues raised in the storm securitization proceeding.

The evidentiary hearing occurred in early September 2023. On September 20, 2023, the PSCSC approved the comprehensive settlement agreement and on October 13, 2023, the PSCSC issued its financing order. The storm recovery bonds of $177 million were issued by Duke Energy Progress on April 25, 2024. Duke Energy Progress implemented storm recovery charges effective May 1, 2024. See Notes 6 and 13 for more information.

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FINANCIAL STATEMENTS REGULATORY MATTERS

Person County Combined Cycle CPCN

On March 28, 2024, Duke Energy Progress filed with the NCUC its application to construct and operate a 1,360-MW hydrogen-capable, advanced-class combined-cycle generating facility (CC) in Person County at the site of the existing Roxboro Plant. Subject to negotiation of final contractual terms, the new Roxboro CC will be co-owned with the North Carolina Electric Membership Corporation (NCEMC), with Duke Energy Progress owning approximately 1,135 MW and NCEMC owning the remaining 225 MW. Pending regulatory approvals, construction is planned to start in 2026, with the CC targeted to be placed in service by the end of 2028. The CC will allow for the retirement of Roxboro’s coal-fired units 1 and 4. As part of the application, Duke Energy Progress noted that the recovery of Construction Work in Progress during the construction period for the proposed facility may be pursued in a future rate case. The 2029 North Carolina retail revenue requirement for the proposed facility is estimated to be $98 million, representing an approximate average retail rate increase of 2.6% across all classes. The expert witness hearing concluded on August 8, 2024. An order is expected no later than December 31, 2024, in parallel with the NCUC’s order in the Carolinas Resource Plan proceeding.

Duke Energy Florida

2021 Settlement Agreement

On January 14, 2021, Duke Energy Florida filed a Settlement Agreement (the “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”).

Pursuant to the 2021 Settlement, the 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 also agreed to an ROE band of 8.85% to 10.85% with a midpoint of 9.85% based upon an equity ratio of 53%. 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%. On July 25, 2022, this provision was triggered. Duke Energy Florida filed a petition with the FPSC on August 12, 2022, to increase the ROE effective August 2022 with a base rate increase effective January 1, 2023. The FPSC approved this request on October 4, 2022. The 2021 Settlement Agreement also provided that Duke Energy Florida will be able to retain $173 million of the expected Department of Energy (DOE) award from its lawsuit to recover spent nuclear fuel to mitigate customer rates over the term of the 2021 Settlement. In return, Duke Energy Florida is permitted to recognize the $173 million into earnings through the approved settlement period. Duke Energy Florida settled the DOE lawsuit and received payment of approximately $180 million on June 15, 2022, of which the retail portion was approximately $154 million. The 2021 Settlement authorizes Duke Energy Florida to collect the difference between $173 million and the $154 million retail portion of the amount received through the capacity cost recovery clause. As of September 30, 2024, Duke Energy Florida has recognized $165 million (pretax) into earnings, including $8 million and $31 million recognized during the three months ended September 30, 2024, and 2023, respectively, and $24 million and $94 million recognized during the nine months ended September 30, 2024, and 2023, respectively. The remaining $8 million is expected to be recognized in the fourth quarter of 2024.

The 2021 Settlement also contained a provision to recover or flow back the effects of tax law changes. As a result of the IRA enacted on August 16, 2022, Duke Energy Florida is eligible for PTCs associated with solar facilities placed in service beginning in January 2022. Duke Energy Florida filed a petition with the FPSC on October 17, 2022, to reduce base rates effective January 1, 2023, by $56 million to flow back the expected 2023 PTCs and to flow back the expected 2022 PTCs via an adjustment to the capacity cost recovery clause. On December 14, 2022, the FPSC issued an order approving Duke Energy Florida's petition.

In addition to these terms, the 2021 Settlement 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 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 resolved remaining unrecovered storm costs for Hurricane Michael and Hurricane Dorian.

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

Clean Energy Connection

On July 1, 2020, Duke Energy Florida petitioned the FPSC for approval of a voluntary solar program consisting 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 and the projects are expected to be completed by the end of 2024. This investment is included in base rates offset by the revenue from the subscription fees and the credits will be included for recovery in the fuel cost recovery clause. The FPSC approved the program in January 2021.

On February 24, 2021, the League of United Latin American Citizens (LULAC) filed a notice of appeal of the FPSC’s order approving the Clean Energy Connection to the Supreme Court of Florida. The Supreme Court of Florida heard oral arguments in the appeal on February 9, 2022. On May 27, 2022, the Supreme Court of Florida issued an order remanding the case back to the FPSC so that the FPSC can amend its order to better address some of the arguments raised by LULAC. On September 23, 2022, the FPSC issued a revised order and submitted it on September 26, 2022, to the Supreme Court of Florida. The Supreme Court of Florida requested that the parties file supplemental briefs regarding the revised order, which were filed February 6, 2023. LULAC has filed a request for Oral Argument on the issues discussed in the supplemental briefs, but the court has yet to rule on that request. The FPSC approval order remains in effect pending the outcome of the appeal.

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FINANCIAL STATEMENTS REGULATORY MATTERS

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 evidentiary hearing began on August 2, 2022. On October 4, 2022, the FPSC voted to approve Duke Energy Florida’s plan with one modification to remove the transmission loop radially fed program, representing a reduction of approximately $80 million over the 10-year period starting in 2025. On December 9, 2022, the OPC filed a notice of appeal of this order to the Florida Supreme Court. The OPC's initial brief was filed on April 18, 2023. Duke Energy Florida filed its answer brief on July 17, 2023. The OPC's reply brief was filed on October 16, 2023. The Florida Supreme Court heard oral arguments on February 7, 2024 and the parties await the court's decision.

Hurricanes Ian and Idalia

On September 28, 2022, much of Duke Energy Florida’s service territory was impacted by Hurricane Ian, which caused significant damage resulting in more than 1.1 million outages. After depleting any existing storm reserves, which were approximately $107 million before Hurricane Ian, Duke Energy Florida is permitted to petition the FPSC for recovery of additional incremental operation and maintenance costs resulting from the storm and to replenish the retail customer storm reserve to approximately $132 million. Duke Energy Florida filed its petition for cost recovery of various storms, including Hurricane Ian, and replenishment of the storm reserve on January 23, 2023, seeking recovery of $442 million, for recovery over 12 months beginning with the first billing cycle in April 2023. On March 7, 2023, the FPSC approved this request for interim recovery, subject to refund, and ordered Duke Energy Florida to file documentation of the total actual storm costs, once known. Duke Energy Florida filed documentation evidencing its total actual storm costs of $431 million on September 29, 2023. The FPSC approved the prudence of these costs at a final hearing on May 21, 2024.

On August 30, 2023, Hurricane Idalia made landfall on Florida’s gulf coast, causing damage and impacting more than 200,000 customers across Duke Energy Florida's service territory. On October 16, 2023, Duke Energy Florida requested to combine the $92 million retail portion of the deferred estimated Hurricane Idalia costs with $74 million of costs projected to be collected after December 31, 2023, under the existing approved storm cost recovery and storm surcharge. This $74 million of costs relates primarily to the approved ongoing replenishment of the storm reserves. At its December 5, 2023 Agenda Conference, the FPSC approved recovery of the total $166 million over 12 months beginning with its first billing cycle in January 2024, replacing the previously approved storm cost recovery and storm surcharge, and ordered Duke Energy Florida to file documentation of the total actual Idalia-related storm costs, once known. Revised rates were effective January 1, 2024. Duke Energy Florida filed documentation evidencing its total Idalia actual storm costs of $98 million on September 23, 2024.

2024 Florida Rate Case

On April 2, 2024, Duke Energy Florida filed a formal request for new base rates with the FPSC. Duke Energy Florida proposed a three-year rate plan that would begin in January 2025, once its current base rate settlement agreement concludes at the end of 2024. Duke Energy Florida proposed multiyear rate increases that use the projected 12-month periods ending December 31, 2025, 2026, and 2027 as the test years, with adjusted rates to be effective with the first billing period of January 2025, 2026, and 2027, respectively.

On July 15, 2024, Duke Energy Florida filed a settlement agreement with the FPSC. The parties to the settlement include Duke Energy Florida, the Office of Public Counsel and other intervening parties. Pursuant to the settlement, the parties agreed to a base rate stay-out provision that expires year-end 2027; however, Duke Energy Florida is allowed an increase to its base rates in 2025 and 2026, as well as utilization of certain tax benefits in lieu of a revenue increase in 2027. Additionally, revenue increases related to solar investments will be recovered via the Solar Base Rate Adjustment mechanism. The parties also agreed to an ROE band of 9.3% to 11.3% with a midpoint of 10.3% with an equity ratio of 53%. The agreement provides for $203 million and $59 million in base rate increases in 2025 and 2026, respectively, as well as increases associated with investments in 12 new solar facilities as they come online, estimated at $12 million, $71 million and $58 million in 2025, 2026 and 2027, respectively. On August 21, 2024, the FPSC approved the settlement agreement without modification.

Hurricane Milton

In October 2024, Hurricane Milton made landfall in Florida as a Category 3 storm, impacting more than 1 million customers in the Duke Energy Florida territory. Total storm restoration costs, including capital expenditures, for Duke Energy Florida are currently estimated to be in the range of $700 million to $850 million. These estimates do not include amounts for rebuilding certain damaged infrastructure, as estimates of such costs are not yet available, and will change as restoration work is completed and additional information is received on actual costs incurred.

Duke Energy Florida has certain existing storm-reserve regulatory liability amounts which will be applied to recovery of the 2024 storm costs (including for Hurricanes Helene and Debby as discussed above) which totaled approximately $100 million as of September 30, 2024.

Duke Energy Ohio

Duke Energy Ohio Electric Base Rate Case

Duke Energy Ohio filed with the PUCO an electric distribution base rate case application on October 1, 2021, with supporting testimony filed on October 15, 2021, requesting an increase in electric distribution base rates of approximately $55 million. On September 19, 2022, Duke Energy Ohio filed a Stipulation and Recommendation with the PUCO, which includes an increase in overall electric distribution base rates of approximately $23 million with an equity ratio of 50.5% and an ROE of 9.5%. The stipulation is among all but one party to the proceeding. The PUCO issued an order on December 14, 2022, approving the Stipulation without material modification. Rates went into effect on January 3, 2023. The Ohio Consumers' Counsel filed an application for rehearing on January 13, 2023, arguing the Stipulation was unreasonable, discriminatory, and denied OCC due process. On March 20, 2024, the PUCO issued its Second Entry on Rehearing, denying OCC's rehearing application. The deadline for OCC to seek an appeal has expired and the matter is now closed.

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FINANCIAL STATEMENTS REGULATORY MATTERS

Duke Energy Ohio Natural Gas Base Rate Case

Duke Energy Ohio filed with the PUCO a natural gas base rate case application on June 30, 2022, with supporting testimony filed on July 14, 2022, requesting an increase in natural gas base rates of approximately $49 million. The drivers for this case are capital invested since Duke Energy Ohio's last natural gas base rate case in 2012. Duke Energy Ohio also sought to adjust the caps on its CEP rider. On April 28, 2023, Duke Energy Ohio filed a stipulation with all parties to the case except the OCC. In the stipulation, the parties agreed to approximately $32 million in revenue increases with an equity ratio of 52.32% and an ROE of 9.6%, and adjustments to the CEP Rider caps. The stipulation was opposed by the OCC at an evidentiary hearing that concluded on May 24, 2023. On November 1, 2023, PUCO issued an order approving the stipulation as filed. New rates went into effect November 1, 2023. On December 1, 2023, the OCC filed an application for rehearing. On December 13, 2023, the PUCO granted OCC's application for rehearing for further consideration of issues raised. As a result of a Supreme Court of Ohio decision regarding procedural issues related to applications for rehearing, PUCO denied OCC’s rehearing request. On October 25, 2024, the OCC filed its Notice of Appeal with the Ohio Supreme Court.

Duke Energy Ohio Electric Security Plan

On April 1, 2024, Duke Energy Ohio filed with the PUCO a request for an Electric Security Plan (ESP). The ESP application proposes a three-year term from June 1, 2025, through May 31, 2028, and includes continuation of market-based customer rates through competitive procurement processes for generation and continuation and expansion of existing rider mechanisms. Duke Energy Ohio is proposing a new rider mechanism relating to electric distribution infrastructure modernization programs, which may be enabled by and partially funded through federal or state funding opportunities, future battery storage projects, and two proposed electric vehicle programs. Additional proposed new rider mechanisms are related to solar for all investments for low-income and disadvantaged communities, low-income senior citizen bill assistance, and energy efficiency and demand-side management programs. At the request of Duke Energy Ohio, PUCO suspended the evidentiary hearing scheduled for November 13, 2024, in light of ongoing settlement discussions.

Duke Energy Kentucky Electric Base Rate Case

On December 1, 2022, Duke Energy Kentucky filed a rate case with the KPSC requesting an annualized increase in electric base rates of approximately $75 million. The request for rate increase was driven by capital investments to strengthen the electricity generation and delivery systems along with adjusted depreciation rates for the East Bend and Woodsdale Combustion Turbine (CT) generation stations. Duke Energy Kentucky also requested approval for new programs and tariff updates, including a voluntary community-based renewable subscription program and two electric vehicle charging programs. The KPSC issued an order on October 12, 2023, including a $48 million increase in base revenues, an ROE of 9.75% for electric base rates and 9.65% for electric riders and an equity ratio of 52.145%. New rates went into effect October 13, 2023. The Company's request to align the depreciation rates of East Bend with a 2035 retirement date was denied and the KPSC ordered depreciation rates with a 2041 retirement date for the unit. The KPSC did approve the request to align the depreciation rates of Woodsdale CT with a 2040 retirement date and denied the voluntary community-based renewable subscription program and the two electric vehicle charging programs.

On November 1, 2023, Duke Energy Kentucky filed for rehearing requesting certain matters be reconsidered by the KPSC. On November 21, 2023, KPSC granted in part and denied in part the Company's request for rehearing. On February 15, 2024, the KPSC issued a briefing schedule for the rehearing process. The briefing concluded on April 1, 2024, and the matter was submitted for decision on April 2, 2024. On July 1, 2024, the KPSC issued its final order on rehearing, ruling in Duke Energy Kentucky's favor on nearly all issues. However, the KPSC ordered Duke Energy Kentucky to refund alleged over collections since the KPSC's October 12, 2023, order. On July 10, 2024, the KPSC issued an order correcting the base fuel rate used to calculate new base rates in its July 1, 2024, order and its calculation of Duke Energy Kentucky's Street Lighting Rate. New rates were implemented in August 2024.

On December 14, 2023, Duke Energy Kentucky filed an appeal with the Franklin County Circuit Court on certain matters for which the KPSC denied rehearing, specifically as it relates to including decommissioning costs in depreciation rates for East Bend and Woodsdale. Duke Energy Kentucky filed its initial brief in June 2024. Appellee briefs were filed September 24, 2024, and Duke Energy Kentucky's reply brief is due November 8, 2024.

Duke Energy Indiana

Indiana Coal Ash Recovery

In Duke Energy Indiana’s 2019 rate case, the IURC opened a subdocket 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. On November 3, 2021, the IURC issued an order allowing recovery for post-2018 coal ash basin closure costs for the plans that have been approved by IDEM, as well as continuing deferral, with carrying costs, on the balance. The OUCC and the Duke Industrial Group appealed. The Indiana Court of Appeals issued its opinion on February 21, 2023, reversing the IURC's order to the extent that it allowed Duke Energy Indiana to recover federally mandated costs incurred prior to the IURC's November 3, 2021 order. In addition, the court found that any costs incurred pre-petition to determine federally mandated compliance options were not specifically authorized by the statute and should also be disallowed.

In the second quarter of 2023, Duke Energy Indiana filed its proposal to remove from rates certain costs incurred prior to the IURC's November 3, 2021 order date. On September 20, 2023, the IURC approved the Company's proposal to remove the costs from its rates and assessed simple interest of the refunds of 4.71%, beginning from when the costs were initially recovered from customers. Duke Energy Indiana seeks to recover the pre-order costs denied by the Indiana Court of Appeals and certain future coal ash closure costs as part of depreciation costs in the 2024 Indiana Rate Case.

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FINANCIAL STATEMENTS REGULATORY MATTERS

Duke Energy Indiana filed a new petition under the amended version of the federal mandate statute for additional post-2018 coal ash closure costs for the remaining basins not included in the Indiana coal ash recovery case from 2020. An evidentiary hearing was held on January 25, 2024. On May 8, 2024, the IURC issued a CPCN and approved these coal ash related compliance projects as federally mandated compliance projects. On June 7, 2024, the Citizens Action Coalition of Indiana (CAC) filed a motion to appeal the IURC order granting the coal ash CPCN proceeding and approving the coal ash related compliance projects. CAC filed its appellant's brief on October 4, 2024. Appellees' briefs are due December 9, 2024.

TDSIC 2.0

On November 23, 2021, Duke Energy Indiana filed for approval of the Transmission, Distribution, Storage Improvement Charge 2.0 investment plan for 2023-2028 (TDSIC 2.0). On June 15, 2022, the IURC approved, without modification, TDSIC 2.0, which includes approximately $2 billion in transmission and distribution investments selected to improve customer reliability, harden and improve resiliency of the grid, enable expansion of renewable and distributed energy projects and encourage economic development. In addition, the IURC set up a subdocket to consider a targeted economic development project, which the IURC approved on March 2, 2022. On July 15, 2022, the OUCC filed a notice of appeal to the Indiana Court of Appeals in Duke Energy Indiana’s TDSIC 2.0 proceeding. An appellant brief was filed on October 28, 2022, and Duke Energy Indiana filed its responsive brief on December 28, 2022. The Indiana Court of Appeals issued its opinion on March 9, 2023, affirming the IURC’s order in its entirety. The Duke Industrial Group filed a petition to transfer to the Indiana Supreme Court. The Indiana Supreme Court granted transfer and held an oral argument on September 28, 2023, and the parties await the court's decision.

2024 Indiana Rate Case

On April 4, 2024, Duke Energy Indiana filed an application with the IURC for a rate increase of $492 million, representing an overall average bill increase of approximately 16.2%, which, if approved, would be added to retail customer bills in two steps, approximately 11.7% in 2025 and approximately 4.5% in 2026. Duke Energy Indiana requested an ROE of 10.5% with an equity ratio of 53%. The rate increase is driven by $1.6 billion in investments made since the last general rate case filed in 2019 in order to reliably serve customers, improve resiliency of the system, and advance environmental sustainability. An evidentiary hearing was completed on September 5, 2024, with briefing continuing until October 31, 2024. An order is anticipated by January 2025 with new rates effective in March 2025.

Piedmont

2024 North Carolina Rate Case

On April 1, 2024, Piedmont filed an application with the NCUC for a rate increase for retail customers. On September 13, 2024, Piedmont, the Public Staff and other intervening parties filed an Agreement and Stipulation of Settlement with the NCUC resolving all issues in the general rate case. The major components of the settlement include an overall average effective increase in net annual retail revenues of $88 million in the first year and $10 million of additional revenue after the first year. The settlement includes an ROE of 9.8% with an equity ratio of 52.3% and the addition of a rider mechanism for recovery of all pipeline integrity management operations and maintenance expenses. The settlement is subject to the review and approval of the NCUC. The evidentiary hearing concluded on September 18, 2024, and Piedmont implemented revised interim rates, subject to refund, November 1, 2024. An order is anticipated by January 2025.

5. COMMITMENTS AND CONTINGENCIES

ENVIRONMENTAL

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

Remediation Activities

In addition to AROs recorded as a result of various environmental regulations, the Duke Energy Registrants are responsible for environmental remediation at various sites. These include certain properties that are part of ongoing operations and sites formerly owned or used by Duke Energy entities. These sites are in various stages of investigation, remediation and monitoring. Managed in conjunction with relevant federal, state and local agencies, remediation activities vary based on 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.

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FINANCIAL STATEMENTS COMMITMENTS AND CONTINGENCIES

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

(in millions)	September 30, 2024		December 31, 2023
Reserves for Environmental Remediation
Duke Energy	$	80	$	88
Duke Energy Carolinas	25		23
Progress Energy	19		19
Duke Energy Progress	9		9
Duke Energy Florida	10		10
Duke Energy Ohio	28		36
Duke Energy Indiana	2		2
Piedmont	7		7

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.

LITIGATION

For open litigation, unless otherwise noted, Duke Energy and the Subsidiary Registrants cannot predict the outcome or ultimate resolution of their respective matters.

Duke Energy

Texas Storm Uri Tort Litigation

Duke Energy (Parent), several Duke Energy renewables project companies, and others in the ERCOT market were named in multiple lawsuits arising out of Texas Storm Uri, which occurred in February 2021. These lawsuits seek recovery for property damage, personal injury and wrongful death allegedly caused by the power outages that plaintiffs claim were the collective failure of generators including Duke Energy entities, transmission and distribution operators (TDUs), retail energy providers, and all others, including ERCOT. The cases were consolidated into a Texas state court multidistrict litigation (MDL) proceeding for discovery and pre-trial motions. Five MDL cases were designated as lead cases in which motions to dismiss were filed and all other cases were stayed.

On January 28, 2023, the court denied certain motions including those by the generator defendants and TDUs and granted others. The generators and TDUs filed separate petitions for Writ of Mandamus to the Texas Court of Appeals seeking to overturn the denials. The TDUs' petition, filed first, was accepted and oral argument was held on October 23, 2023. In the cases against the generators, plaintiffs have dismissed the claims against Duke Energy (Parent). However, before Duke Energy (Parent) was dismissed from all cases, on December 14, 2023, without argument, the Court of Appeals accepted mandamus of the generator defendants’ appeal, which includes all Duke Energy entities, and directed the MDL court to dismiss all claims. Plaintiffs filed their Petition for Reconsideration on January 29, 2024, and the generator defendants responded on May 6, 2024. Regardless of the outcome of any motion for reconsideration or appeal, claims against Duke Energy (Parent) will remain dismissed. In October 2023, in conjunction with the closing of the sale of the utility-scale solar and wind group, all but one of the project company lawsuits transferred to Brookfield. In May 2024, the remaining claim in the lawsuit was transferred to the buyer in connection with the sale of a portion of the remaining Commercial Renewables assets. See Note 2 for more information related to the sale of the Commercial Renewables Disposal Groups.

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 sought 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. Both NTE's and Duke Energy Carolinas' motions to dismiss were subsequently denied by the court.

On May 21, 2020, in response to a NTE petition challenging Duke Energy Carolinas' termination of the LGIA, FERC issued a ruling that 1) it has exclusive jurisdiction to determine whether a transmission provider may terminate an LGIA; 2) FERC approval is required to terminate a conforming LGIA if objected to by the interconnection customer; and 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. On April 6, 2023, Duke Energy Carolinas received notice from the FERC Office of Enforcement that they have closed their non-public investigation with no further action recommended.

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FINANCIAL STATEMENTS COMMITMENTS AND CONTINGENCIES

Following completion of discovery, 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. On June 24, 2022, the court issued an order partially granting Duke Energy Carolinas' motion by dismissing NTE's counterclaims that Duke Energy Carolinas engaged in anti-competitive behavior in violation of state and federal statutes. On October 12, 2022, the parties executed a settlement agreement with respect to the remaining breach of contract claims in the litigation and a Stipulation of Dismissal was filed with the court on October 13, 2022. On November 11, 2022, NTE filed its Notice of Appeal to the U.S. Court of Appeals for the Fourth Circuit as to the district court's summary judgment ruling in Duke Energy Carolinas' favor on NTE's antitrust and unfair competition claims. Briefing on NTE's appeal was completed on June 30, 2023. Oral argument took place on May 7, 2024. On August 5, 2024, the U.S. Court of Appeals for the Fourth Circuit reversed the district court's grant of summary judgment and remanded the case back to the district court for further proceedings. On August 19, 2024, Duke Energy Carolinas filed a petition for rehearing, which is fully briefed and awaiting the court's decision.

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.

Duke Energy Carolinas has recognized asbestos-related reserves of $402 million at September 30, 2024, and $423 million at December 31, 2023. 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 on Duke Energy Carolinas' best estimate for current and future asbestos claims through 2044 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 2044 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. Receivables for insurance recoveries were $539 million at September 30, 2024, and $572 million at December 31, 2023. 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.

The reserve for credit losses for insurance receivables is $9 million as of September 30, 2024, and December 31, 2023, for both Duke Energy and Duke Energy Carolinas. 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 Indiana

Coal Ash Insurance Coverage Litigation

In June 2022, Duke Energy Indiana filed a civil action in Indiana Superior Court against various insurance companies seeking declaratory relief with respect to insurance coverage for coal combustion residuals-related expenses and liabilities covered by third-party liability insurance policies. The insurance policies cover the 1969-1972 and 1984-1985 periods and provide third-party liability insurance for claims and suits alleging property damage, bodily injury and personal injury (or a combination thereof). A trial date has not yet been set.

On June 30, 2023, Duke Energy Indiana and Associated Electric and Gas Insurance Services (AEGIS) reached a confidential settlement, the results of which were not material to Duke Energy, and as a result, AEGIS was dismissed from the litigation on July 13, 2023. Duke Energy Indiana has also reached confidential settlements with other various insurance companies, the results of which were not material. In June 2024, Duke Energy Indiana filed an amended complaint adding several additional insurance companies as defendants to the litigation and the court entered an order staying the litigation until January 22, 2025.

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. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Other Noncurrent Liabilities and Other within Current Liabilities.

OTHER COMMITMENTS AND CONTINGENCIES

General

As part of their normal business, the Duke Energy Registrants are party to various financial guarantees, performance guarantees and other contractual commitments to extend guarantees of credit and other assistance to various subsidiaries, investees and other third parties. These guarantees involve elements of performance and credit risk, which are not fully recognized on the Condensed Consolidated Balance Sheets and have uncapped maximum potential payments. However, the Duke Energy Registrants do not believe these guarantees will have a material effect on their results of operations, cash flows or financial position.

In addition, the Duke Energy Registrants enter into various fixed-price, noncancelable commitments to purchase or sell power or natural gas, take-or-pay arrangements, transportation, or throughput agreements and other contracts that may or may not be recognized on their respective Condensed Consolidated Balance Sheets. Some of these arrangements may be recognized at fair value on their respective Condensed Consolidated Balance Sheets if such contracts meet the definition of a derivative and the NPNS exception does not apply. In most cases, the Duke Energy Registrants’ purchase obligation contracts contain provisions for price adjustments, minimum purchase levels and other financial commitments.

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FINANCIAL STATEMENTS DEBT AND CREDIT FACILITIES

6. DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

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

				Nine Months Ended September 30, 2024
						Duke		Duke		Duke		Duke		Duke		Duke
	Maturity	Interest		Duke		Energy		Energy		Energy		Energy		Energy		Energy
Issuance Date	Date	Rate		Energy		(Parent)		Carolinas		Progress		Florida		Ohio		Indiana		Piedmont
Unsecured Debt
January 2024(a)	January 2027	4.850	%	$	600	$	600	$	—	$	—	$	—	$	—	$	—	$	—
January 2024(a)	January 2029	4.850	%	650		650		—		—		—		—		—		—
April 2024(e)	April 2031	5.648	%	815		815		—		—		—		—		—		—
June 2024(d)	June 2034	5.450	%	750		750		—		—		—		—		—		—
June 2024(d)	June 2054	5.800	%	750		750		—		—		—		—		—		—
June 2024(h)	July 2031	5.900	%	80		—		—		—		—		80		—		—
June 2024(h)	July 2034	6.000	%	95		—		—		—		—		95		—		—
June 2024(h)	July 2039	6.170	%	50		—		—		—		—		50		—		—
August 2024(d)	February 2035	5.100	%	375		—		—		—		—		—		—		375
August 2024(i)	September 2054	6.450	%	1,000		1,000		—		—		—		—		—		—
Secured Debt
April 2024(f)	March 2044	5.404	%	177		—		—		177		—		—		—		—
First Mortgage Bonds
January 2024(b)	January 2034	4.850	%	$	575	$	—	$	575	$	—	—		$	—	$	—	$	—
January 2024(b)	January 2054	5.400	%	425		—		425		—		—		—		—		—
March 2024(b)	March 2034	5.250	%	300		—		—		—		—		—		300		—
March 2024(c)	March 2034	5.100	%	500		—		—		500		—		—		—		—
March 2024(d)	March 2054	5.550	%	425		—		—		—		—		425		—		—
April 2024(g)	April 2074	5.008	%	173		—		—		—		173		—		—		—
Total issuances				$	7,740	$	4,565	$	1,000	$	677	$	173	$	650	$	300	$	375

(a)Proceeds were used to repay the remaining $1 billion outstanding on Duke Energy (Parent)'s variable rate Term Loan Facility due March 2024, pay down a portion of short-term debt and for general corporate purposes. Duke Energy (Parent)'s Term Loan Facility was terminated in March 2024 in conjunction with the payoff of remaining borrowings.

(b)Proceeds were used to pay down a portion of short-term debt and for general company purposes.

(c)Proceeds were used to fund eligible green energy projects, pay down a portion of short-term debt and for general company purposes.

(d)Proceeds were used to pay down a portion of short-term debt and for general corporate purposes.

(e)In April 2024, Duke Energy issued 750 million euros aggregate principal amount of 3.75% senior notes due April 2031. Duke Energy's obligations under its euro-denominated fixed-rate notes were effectively converted to fixed-rate U.S. dollars at issuance through cross-currency swaps, mitigating foreign currency exchange risk associated with the interest and principal payments. The $815 million equivalent in U.S. dollars were used to repay a portion of a $1 billion debt maturity due April 2024, pay down short-term debt and for general corporate purposes. See Note 10 for additional information.

(f)Proceeds were used to finance the South Carolina portion of restoration expenditures related to the following storms: Pax, Ulysses, Matthew, Florence, Michael, Dorian, Izzy and Jasper. See Notes 4 and 13 for more information.

(g)Debt has a floating interest rate. Proceeds were used to pay down a portion of the DEFR accounts receivable securitization facility due in April 2024, and for general company purposes. See Note 13 for more information.

(h)Debt issued by Duke Energy Kentucky with proceeds used to pay down a portion of short-term debt and for general corporate purposes.

(i)Duke Energy issued $1 billion of fixed-to-fixed reset rate junior subordinated debentures (the debentures) with proceeds used to redeem Duke Energy’s outstanding Series B Preferred Stock and for general corporate purposes. The debentures will bear interest at 6.45% until September 1, 2034, and thereafter the interest rate will reset every five years to the five-year U.S. Treasury rate plus a spread of 2.588%. The debentures have early redemption options and are callable on or after June 2034 for 100% of the principal plus accrued interest. See Note 15 for additional information.

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FINANCIAL STATEMENTS DEBT AND CREDIT FACILITIES

CURRENT MATURITIES OF LONG-TERM DEBT

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

(in millions)	Maturity Date	Interest Rate		September 30, 2024
Unsecured Debt
Duke Energy (Parent)	April 2025	3.364	%	$	420
Duke Energy (Parent)	April 2025	3.950	%	250
Duke Energy (Parent)	September 2025	0.900	%	650
Duke Energy Ohio	June 2025	6.900	%	150
Duke Energy Progress	August 2025	3.250	%	500
Piedmont	September 2025	3.600	%	150
Secured Debt
Duke Energy Carolinas(a)	January 2025	6.036	%	305
Duke Energy Carolinas(a)	January 2025	6.097	%	195
Duke Energy Progress(a)	April 2025	6.096	%	240
Duke Energy Progress(a)	April 2025	6.096	%	160
First Mortgage Bonds
Duke Energy Florida(a)(b)	October 2073	5.005	%	200
Duke Energy Florida(a)(b)	April 2074	5.008	%	173
Other(c)				204
Current maturities of long-term debt				$	3,597

(a)Debt has a floating interest rate.

(b)These first mortgage bonds are classified as Current maturities of long-term debt on the Consolidated Balance Sheets based on terms of the indentures, which could require repayment in less than 12 months if exercised by the bondholders.

(c)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 2024, Duke Energy extended the termination date of its existing $9 billion Master Credit Facility to March 2029. 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. An amendment in conjunction with the issuance of the Convertible Senior Notes due April 2026 clarifies that payments due as a result of a conversion of a convertible note would not constitute an event of default.

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

	September 30, 2024
			Duke		Duke		Duke		Duke		Duke		Duke
	Duke		Energy		Energy		Energy		Energy		Energy		Energy
(in millions)	Energy		(Parent)		Carolinas		Progress		Florida		Ohio		Indiana		Piedmont
Facility size(a)	$	9,000	$	2,275	$	1,400	$	1,500	$	875	$	1,050	$	950	$	950
Reduction to backstop issuances
Commercial paper(b)	(3,526)		(1,526)		(300)		(698)		(175)		(206)		(160)		(461)
Outstanding letters of credit	(24)		(12)		(4)		(1)		(7)		—		—		—
Tax-exempt bonds	(81)		—		—		—		—		—		(81)		—
Available capacity under the Master Credit Facility	$	5,369	$	737	$	1,096	$	801	$	693	$	844	$	709	$	489

(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.

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FINANCIAL STATEMENTS DEBT AND CREDIT FACILITIES

Duke Energy Term Loan Facility

On March 26, 2024, Duke Energy (Parent) entered into a 364-day term loan facility with commitments totaling $700 million. Any undrawn commitments could be drawn up until April 25, 2024, (30 days after the effective date of the agreement) or are otherwise ineligible to be drawn. On April 24, 2024, $500 million was drawn under the facility with borrowings used for general corporate purposes. Borrowings could be prepaid at any time throughout the term of the facility and the terms and conditions of the facility were generally consistent with those governing Duke Energy's Master Credit Facility. During the second quarter of 2024, Duke Energy (Parent) terminated the facility and repaid the $500 million in outstanding borrowings.

Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida Term Loan Facilities

In November 2024, Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida entered into term loan facilities intended to meet incremental financing needs resulting from expenditures for the restoration of service and rebuilding of infrastructure related to hurricanes Debby, Helene and Milton as described in Note 4. Duke Energy Carolinas and Duke Energy Progress entered into two-year term loan facilities with commitments totaling $700 million and $250 million, respectively. Duke Energy Florida entered into a 364-day term loan facility with commitments totaling $800 million. Amounts may be drawn for six months from the Duke Energy Carolinas and Duke Energy Progress term loan facilities and for four months from the Duke Energy Florida term loan facility. Borrowings from the term loan facilities can be prepaid at any time and may be used to fund system restoration expenses and for general corporate purposes. Additionally, the Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida term loan facilities may be increased by $300 million, $150 million and $400 million, respectively.

In November 2024, $50 million, $50 million and $100 million were drawn under the term loan facilities for Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively.

7. ASSET RETIREMENT OBLIGATIONS

The Duke Energy Registrants record AROs when there is a legal obligation to incur retirement costs associated with the retirement of a long-lived asset and the obligation can be reasonably estimated. Actual costs incurred could be materially different from current estimates that form the basis of the recorded AROs.

The following table presents the AROs recorded on the Condensed Consolidated Balance Sheets.

	September 30, 2024
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Decommissioning of nuclear power facilities	$	4,634	$	2,024	$	2,605	$	2,483	$	122	$	—	$	—	$	—
Closure of ash impoundments	5,240		1,899		2,019		2,001		18		72		1,249		—
Other	276		57		99		34		65		65		29		27
Total ARO	$	10,150	$	3,980	$	4,723	$	4,518	$	205	$	137	$	1,278	$	27
Less: Current portion	639		253		227		225		2		7		152		—
Total noncurrent ARO	$	9,511	$	3,727	$	4,496	$	4,293	$	203	$	130	$	1,126	$	27

ARO Liability Rollforward

In April 2024, the EPA issued the 2024 CCR Rule under the Resource Conservation and Recovery Act, which significantly expands the scope of the 2015 CCR Rule by establishing regulatory requirements for inactive surface impoundments at retired generating facilities and previously unregulated coal ash sources at regulated facilities.

The following table presents the change in liability associated with AROs for the Duke Energy Registrants.

			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Balance at December 31, 2023(a)	$	9,156	$	4,013	$	4,145	$	3,870	$	275	$	136	$	809	$	26
Accretion expense(b)	316		137		145		138		7		5		33		1
Liabilities settled(c)	(485)		(154)		(254)		(181)		(73)		(6)		(70)		—
Revisions in estimates of cash flows(d)	1,163		(16)		687		691		(4)		2		506		—
Balance at September 30, 2024	$	10,150	$	3,980	$	4,723	$	4,518	$	205	$	137	$	1,278	$	27

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

(b)For the nine months ended September 30, 2024, substantially all accretion expense relates to Duke Energy's regulated operations and has been deferred in accordance with regulatory accounting treatment.

(c)Primarily relates to ash impoundment closures and nuclear decommissioning.

(d)The revision amounts represent the change in discounted cash flows for estimated closure costs as evaluated on a site-by-site basis. The increases primarily relate to additional scope requirements to regulate the disposal of CCR in landfills and surface impoundments as a result of the 2024 CCR Rule, including an increase in groundwater monitoring wells.

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FINANCIAL STATEMENTS ASSET RETIREMENT OBLIGATIONS

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

8. GOODWILL

Duke Energy

Duke Energy's Goodwill balance of $19.3 billion is allocated $17.4 billion to EU&I and $1.9 billion to GU&I on Duke Energy's Condensed Consolidated Balance Sheets at September 30, 2024, and December 31, 2023. There are no accumulated impairment charges.

Duke Energy Ohio

Duke Energy Ohio's Goodwill balance of $920 million, allocated $596 million to EU&I and $324 million to GU&I, is presented net of accumulated impairment charges of $216 million on the Condensed Consolidated Balance Sheets at September 30, 2024, and December 31, 2023.

Progress Energy

Progress Energy's Goodwill is included in the EU&I segment and there are no accumulated impairment charges.

Piedmont

Piedmont's Goodwill is included in the GU&I segment and there are no accumulated impairment charges.

Impairment Testing

Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont are required to perform an annual goodwill impairment test as of the same date each year and, accordingly, perform their annual impairment testing of goodwill as of August 31. Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont update their test between annual tests if events or circumstances occur that would more likely than not reduce the fair value of a reporting unit below its carrying value. As the fair value for Duke Energy, Progress Energy, Duke Energy Ohio and Piedmont exceeded their respective carrying values at the date of the annual impairment analysis, no goodwill impairment charges were recorded in the third quarter of 2024.

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FINANCIAL STATEMENTS RELATED PARTY TRANSACTIONS

9. 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. Transactions with related parties included on the Condensed Consolidated Statements of Operations and Comprehensive Income are presented in the following table.

	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2024		2023		2024		2023
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	186	$	198	$	589	$	586
Indemnification coverages(b)	11		9		33		26
JDA revenue(c)	7		5		29		26
JDA expense(c)	48		58		141		121
Intercompany natural gas purchases(d)	5		5		14		14
Progress Energy
Corporate governance and shared service expenses(a)	$	165	$	172	$	524	$	522
Indemnification coverages(b)	13		11		42		35
JDA revenue(c)	48		58		141		121
JDA expense(c)	7		5		29		26
Intercompany natural gas purchases(d)	19		19		56		56
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	104	$	103	$	318	$	314
Indemnification coverages(b)	5		5		17		15
JDA revenue(c)	48		58		141		121
JDA expense(c)	7		5		29		26
Intercompany natural gas purchases(d)	19		19		56		56
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	61	$	69	$	206	$	208
Indemnification coverages(b)	8		6		25		20
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	74	$	73	$	228	$	222
Indemnification coverages(b)	2		1		5		4
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	98	$	92	$	283	$	275
Indemnification coverages(b)	2		2		7		6
Piedmont
Corporate governance and shared service expenses(a)	$	40	$	32	$	121	$	107
Indemnification coverages(b)	1		1		3		3
Intercompany natural gas sales(d)	24		24		70		70
Natural gas storage and transportation costs(e)	5		6		17		18

(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 and Impairment of assets and other charges on the Condensed Consolidated Statements of Operations and Comprehensive Income.

(b)The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.

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

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

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

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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 13, certain trade receivables were previously 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 were largely cash but included a subordinated note from CRC for a portion of the purchase price. In March 2024, Duke Energy repaid all outstanding CRC borrowings and terminated the related CRC credit facility.

Intercompany Income Taxes

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

	Duke				Duke		Duke		Duke		Duke
	Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
September 30, 2024
Intercompany income tax receivable	$	—	$	—	$	—	$	—	$	7	$	28	$	39
Intercompany income tax payable	115		96		53		38		—		—		—
December 31, 2023
Intercompany income tax receivable	$	—	$	—	$	—	$	—	$	91	$	53	$	—
Intercompany income tax payable	81		92		94		114		—		—		57

10. DERIVATIVES AND HEDGING

The Duke Energy Registrants use commodity, interest rate and foreign currency contracts to manage commodity price risk, interest rate risk and foreign currency exchange 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. Foreign currency derivatives are used to manage risk related to foreign currency exchange rates on certain issuances of debt.

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 or financing activities on the Condensed Consolidated Statements of Cash Flows consistent with the classification of the hedged transaction.

INTEREST RATE RISK

The Duke Energy Registrants are exposed to changes in interest rates as a result of their issuance or anticipated issuance of variable-rate and fixed-rate debt and commercial paper. Interest rate risk is managed by limiting variable-rate exposures to a percentage of total debt and by monitoring changes in interest rates. To manage risk associated with changes in interest rates, the Duke Energy Registrants may enter into interest rate swaps, U.S. Treasury lock agreements and other financial contracts. In anticipation of certain fixed-rate debt issuances, a series of forward-starting interest rate swaps or Treasury locks may be executed to lock in components of current market interest rates. These instruments are later terminated prior to or upon the issuance of the corresponding debt.

Cash Flow Hedges

For a derivative designated as hedging the exposure to variable cash flows of a future transaction, referred to as a cash flow hedge, the effective portion of the derivative's gain or loss is initially reported as a component of other comprehensive income and subsequently reclassified into earnings once the future transaction impacts earnings. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt. Gains and losses reclassified out of accumulated other comprehensive income (loss) for the three and nine months ended September 30, 2024, and 2023, were not material. Duke Energy's interest rate derivatives designated as hedges include 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.

64

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

The following tables show notional amounts of outstanding derivatives related to interest rate risk.

	September 30, 2024
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana		Ohio
Cash flow hedges	$	2,825	$	—	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	3,202		1,150		1,775		1,125		650		250		27
Total notional amount	$	6,027	$	1,150	$	1,775	$	1,125	$	650	$	250	$	27

	December 31, 2023
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana		Ohio
Cash flow hedges	$	2,300	$	—	$	—	$	—	$	—	$	—	$	—
Undesignated contracts	2,727		1,050		1,250		925		325		400		27
Total notional amount	$	5,027	$	1,050	$	1,250	$	925	$	325	$	400	$	27

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.

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.

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 cost volatility for customers.

Volumes

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

	September 30, 2024
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Ohio	Indiana	Piedmont
Electricity (GWh)	19,823	—	—	—	2,474	17,349	—
Natural gas (millions of dekatherms)	791	264	244	244	—	30	253

	December 31, 2023
		Duke		Duke	Duke	Duke
	Duke	Energy	Progress	Energy	Energy	Energy
	Energy	Carolinas	Energy	Progress	Ohio	Indiana	Piedmont
Electricity (GWh)	13,608	—	—	—	1,616	11,992	—
Natural gas (millions of dekatherms)	846	279	274	274	—	30	263

FOREIGN CURRENCY RISK

Duke Energy may enter into foreign currency derivatives to hedge exposure to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S. dollars.

65

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

Fair Value Hedges

Derivatives related to existing fixed-rate securities are accounted for as fair value hedges, where the derivatives’ fair value gains or losses and hedged items’ fair value gains or losses are both recorded directly to earnings on the same income statement line item, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Duke Energy has elected to exclude the cross-currency basis spread from the assessment of effectiveness in the fair value hedges of its foreign currency risk and record any difference between the change in the fair value of the excluded components and the amounts recognized in earnings as a component of other comprehensive income or loss.

The following table shows Duke Energy's outstanding derivatives related to foreign currency risk at September 30, 2024.

										Fair Value Gain (Loss)(a)
										(in millions)
	Pay Notional				Receive Notional		Receive		Hedge	Three Months Ended September 30,				Nine Months Ended September 30,
	(in millions)		Pay Rate		(in millions)		Rate		Maturity Date	2024		2023		2024		2023
Fair value hedges
	$	645	4.75	%	600	euros	3.10	%	June 2028	$	23	$	(20)	$	23	$	(10)
	537		5.31	%	500	euros	3.85	%	June 2034	19		(17)		19		(9)
	815		5.648	%	750	euros	3.75	%	April 2031	29		—		20		—
Total notional amount	$	1,997			1,850	euros				$	71	$	(37)	$	62	$	(19)

(a)    Amounts are recorded in Other Income and expenses, net on the Condensed Consolidated Statement of Operations, which offsets an equal translation adjustment of the foreign denominated debt. See the Condensed Consolidated Statements of Comprehensive Income for amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is recorded.

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

The following tables show the fair value and balance sheet location of derivative instruments. Although derivatives subject to master netting arrangements are netted on the Condensed Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.

Derivative Assets	September 30, 2024
			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	$	37	$	10	$	8	$	8	$	—	$	2	$	16	$	2
Noncurrent	33		14		19		19		—		—		—		—
Total Derivative Assets – Commodity Contracts	$	70	$	24	$	27	$	27	$	—	$	2	$	16	$	2
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	20		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Noncurrent	18		2		6		6		—		—		10		—
Total Derivative Assets – Interest Rate Contracts	$	38	$	2	$	6	$	6	$	—	$	—	$	10	$	—
Foreign Currency Contracts
Designated as Hedging Instruments
Noncurrent	54		—		—		—		—		—		—		—
Total Derivative Assets – Foreign Currency Contracts	$	54	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Assets	$	162	$	26	$	33	$	33	$	—	$	2	$	26	$	2

66

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

Derivative Liabilities	September 30, 2024
			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	$	170	$	93	$	56	$	56	$	—	$	—	$	4	$	17
Noncurrent	209		57		45		45		—		—		—		107
Total Derivative Liabilities – Commodity Contracts	$	379	$	150	$	101	$	101	$	—	$	—	$	4	$	124
Interest Rate Contracts
Designated as Hedging Instruments
Noncurrent	52		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	5		—		5		5		—		—		—		—
Noncurrent	95		36		59		34		26		1		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	152	$	36	$	64	$	39	$	26	$	1	$	—	$	—
Foreign Currency Contracts
Designated as Hedging Instruments
Current	30		—		—		—		—		—		—		—
Total Derivative Liabilities – Foreign Currency Contracts	$	30	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Liabilities	$	561	$	186	$	165	$	140	$	26	$	1	$	4	$	124

Derivative Assets	December 31, 2023
			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	$	25	$	1	$	3	$	1	$	2	$	1	$	18	$	1
Noncurrent	57		26		31		31		—		—		—		—
Total Derivative Assets – Commodity Contracts	$	82	$	27	$	34	$	32	$	2	$	1	$	18	$	1
Interest Rate Contracts
Designated as Hedging Instruments
Current	31		—		—		—		—		—		—		—
Noncurrent	17		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	5		5		—		—		—		—		—		—
Noncurrent	10		3		—		—		—		—		7		—
Total Derivative Assets – Interest Rate Contracts	$	63	$	8	$	—	$	—	$	—	$	—	$	7	$	—
Foreign Currency Contracts
Designated as Hedging Instruments
Noncurrent	44		—		—		—		—		—		—		—
Total Derivative Assets – Foreign Currency Contracts	$	44	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Assets	$	189	$	35	$	34	$	32	$	2	$	1	$	25	$	1

67

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

Derivative Liabilities	December 31, 2023
			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	$	354	$	177	$	138	$	138	$	—	$	—	$	18	$	20
Noncurrent	255		67		61		61		—		—		—		127
Total Derivative Liabilities – Commodity Contracts	$	609	$	244	$	199	$	199	$	—	$	—	$	18	$	147
Interest Rate Contracts
Designated as Hedging Instruments
Current	25		—		—		—		—		—		—		—
Noncurrent	26		—		—		—		—		—		—		—
Not Designated as Hedging Instruments
Current	13		2		11		11		—		—		—		—
Noncurrent	39		14		24		9		15		1		—		—
Total Derivative Liabilities – Interest Rate Contracts	$	103	$	16	$	35	$	20	$	15	$	1	$	—	$	—
Foreign Currency Contracts
Designated as Hedging Instruments
Current	17		—		—		—		—		—		—		—
Total Derivative Liabilities – Foreign Currency Contracts	$	17	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Derivative Liabilities	$	729	$	260	$	234	$	219	$	15	$	1	$	18	$	147

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 amounts shown are calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

Derivative Assets	September 30, 2024
			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	$	37	$	10	$	8	$	8	$	—	$	2	$	16	$	2
Offset	(15)		(8)		(7)		(7)		—		—		—		—
Net amounts presented in Current Assets: Other	$	22	$	2	$	1	$	1	$	—	$	2	$	16	$	2
Noncurrent
Gross amounts recognized	$	125	$	16	$	25	$	25	$	—	$	—	$	10	$	—
Offset	(26)		(10)		(16)		(16)		—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	99	$	6	$	9	$	9	$	—	$	—	$	10	$	—

68

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

Derivative Liabilities	September 30, 2024
			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	$	205	$	93	$	61	$	61	$	—	$	—	$	4	$	17
Offset	(15)		(8)		(7)		(7)		—		—		—		—
Cash collateral posted	(23)		(13)		(5)		(5)		—		—		(4)		—
Net amounts presented in Current Liabilities: Other	$	167	$	72	$	49	$	49	$	—	$	—	$	—	$	17
Noncurrent
Gross amounts recognized	$	356	$	93	$	104	$	79	$	26	$	1	$	—	$	107
Offset	(26)		(10)		(16)		(16)		—		—		—		—
Cash collateral posted	(30)		(22)		(9)		(9)		—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	300	$	61	$	79	$	54	$	26	$	1	$	—	$	107

Derivative Assets	December 31, 2023
			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	$	61	$	6	$	3	$	1	$	2	$	1	$	18	$	1
Offset	(2)		(1)		(1)		(1)		—		—		—		—
Net amounts presented in Current Assets: Other	$	59	$	5	$	2	$	—	$	2	$	1	$	18	$	1
Noncurrent
Gross amounts recognized	$	128	$	29	$	31	$	31	$	—	$	—	$	7	$	—
Offset	(37)		(14)		(22)		(22)		—		—		—		—
Net amounts presented in Other Noncurrent Assets: Other	$	91	$	15	$	9	$	9	$	—	$	—	$	7	$	—

Derivative Liabilities	December 31, 2023
			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	$	409	$	179	$	149	$	149	$	—	$	—	$	18	$	20
Offset	(2)		(1)		(1)		(1)		—		—		—		—
Cash collateral posted	(96)		(48)		(30)		(30)		—		—		(18)		—
Net amounts presented in Current Liabilities: Other	$	311	$	130	$	118	$	118	$	—	$	—	$	—	$	20
Noncurrent
Gross amounts recognized	$	320	$	81	$	85	$	70	$	15	$	1	$	—	$	127
Offset	(37)		(14)		(22)		(22)		—		—		—		—
Cash collateral posted	(66)		(38)		(28)		(28)		—		—		—		—
Net amounts presented in Other Noncurrent Liabilities: Other	$	217	$	29	$	35	$	20	$	15	$	1	$	—	$	127

69

FINANCIAL STATEMENTS DERIVATIVES AND HEDGING

OBJECTIVE CREDIT CONTINGENT FEATURES

Certain derivative contracts contain objective credit contingent features. These features include the requirement to post cash collateral or letters of credit if specific events occur, such as a credit rating downgrade below investment grade. The following tables show information with respect to derivative contracts that are in a net liability position and contain objective credit risk-related payment provisions.

	September 30, 2024
			Duke				Duke
	Duke		Energy		Progress		Energy
(in millions)	Energy		Carolinas		Energy		Progress
Aggregate fair value of derivatives in a net liability position	$	198	$	103	$	95	$	95
Fair value of collateral already posted	48		34		14		14
Additional cash collateral or letters of credit in the event credit risk-related contingent features were triggered	$	150	$	69	$	81	$	81

	December 31, 2023
			Duke				Duke
	Duke		Energy		Progress		Energy
(in millions)	Energy		Carolinas		Energy		Progress
Aggregate fair value of derivatives in a net liability position	$	342	$	175	$	166	$	166
Fair value of collateral already posted	144		86		58		58
Additional cash collateral or letters of credit in the event credit risk-related contingent features were triggered	$	198	$	89	$	108	$	108

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

11. INVESTMENTS IN DEBT AND EQUITY SECURITIES

Duke Energy’s investments in debt and equity securities are primarily comprised of investments held in (i) the nuclear decommissioning trust funds (NDTF) at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, (ii) 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 Available for Sale (AFS) and investments in equity securities as fair value through net income (FV-NI).

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

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

Investment Trusts

The investments within the Investment Trusts are managed by independent investment managers with discretion to buy, sell and invest pursuant to the guidelines 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 September 30, 2024, and December 31, 2023.

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

70

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.

	September 30, 2024						December 31, 2023
	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	$	—	$	—	$	151	$	—	$	—	$	133
Equity securities	6,005		11		8,224		4,942		22		7,278
Corporate debt securities	20		29		721		12		43		632
Municipal bonds	5		10		342		6		16		347
U.S. government bonds	37		46		1,824		24		65		1,575
Other debt securities	3		7		248		1		13		178
Total NDTF Investments	$	6,070	$	103	$	11,510	$	4,985	$	159	$	10,143
Other Investments
Cash and cash equivalents	$	—	$	—	$	68	$	—	$	—	$	31
Equity securities	62		—		188		33		—		158
Corporate debt securities	—		3		92		—		6		82
Municipal bonds	1		1		89		1		2		77
U.S. government bonds	—		2		55		—		2		65
Other debt securities	—		2		48		—		2		47
Total Other Investments	$	63	$	8	$	540	$	34	$	12	$	460
Total Investments	$	6,133	$	111	$	12,050	$	5,019	$	171	$	10,603

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months ended September 30, 2024, and 2023, were as follows.

	Three Months Ended				Nine Months Ended
(in millions)	September 30, 2024		September 30, 2023		September 30, 2024		September 30, 2023
FV-NI:
Realized gains	$	61	$	61	$	256	$	107
Realized losses	19		35		64		117
AFS:
Realized gains	10		16		22		37
Realized losses	8		45		44		104

DUKE ENERGY CAROLINAS

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

	September 30, 2024						December 31, 2023
	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	$	—	$	—	$	69	$	—	$	—	$	51
Equity securities	3,476		8		4,729		2,886		14		4,196
Corporate debt securities	9		25		458		4		35		390
Municipal bonds	—		3		42		—		4		50
U.S. government bonds	19		25		976		13		33		826
Other debt securities	3		7		231		1		13		172
Total NDTF Investments	$	3,507	$	68	$	6,505	$	2,904	$	99	$	5,685

71

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 and nine months ended September 30, 2024, and 2023, were as follows.

	Three Months Ended				Nine Months Ended
(in millions)	September 30, 2024		September 30, 2023		September 30, 2024		September 30, 2023
FV-NI:
Realized gains	$	38	$	43	$	163	$	70
Realized losses	9		17		30		64
AFS:
Realized gains	6		12		11		21
Realized losses	5		26		22		54

PROGRESS ENERGY

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

	September 30, 2024						December 31, 2023
	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	$	—	$	—	$	82	$	—	$	—	$	82
Equity securities	2,529		3		3,495		2,056		8		3,082
Corporate debt securities	11		4		263		8		8		242
Municipal bonds	5		7		300		6		12		297
U.S. government bonds	18		21		848		11		32		749
Other debt securities	—		—		17		—		—		6
Total NDTF Investments	$	2,563	$	35	$	5,005	$	2,081	$	60	$	4,458
Other Investments
Cash and cash equivalents	$	—	$	—	$	21	$	—	$	—	$	18
Municipal bonds	—		—		24		—		1		23
Total Other Investments	$	—	$	—	$	45	$	—	$	1	$	41
Total Investments	$	2,563	$	35	$	5,050	$	2,081	$	61	$	4,499

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months ended September 30, 2024, and 2023, were as follows.

	Three Months Ended				Nine Months Ended
(in millions)	September 30, 2024		September 30, 2023		September 30, 2024		September 30, 2023
FV-NI:
Realized gains	$	23	$	18	$	93	$	37
Realized losses	10		18		34		53
AFS:
Realized gains	4		4		11		16
Realized losses	3		19		22		50

72

FINANCIAL STATEMENTS INVESTMENTS IN DEBT AND EQUITY SECURITIES

DUKE ENERGY PROGRESS

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

	September 30, 2024						December 31, 2023
	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	$	—	$	—	$	61	$	—	$	—	$	55
Equity securities	2,407		3		3,361		1,956		8		2,970
Corporate debt securities	10		4		252		7		8		229
Municipal bonds	5		7		300		6		12		297
U.S. government bonds	17		13		666		10		18		518
Other debt securities	—		—		16		—		—		6
Total NDTF Investments	$	2,439	$	27	$	4,656	$	1,979	$	46	$	4,075
Other Investments
Cash and cash equivalents	$	—	$	—	$	16	$	—	$	—	$	14
Total Other Investments	$	—	$	—	$	16	$	—	$	—	$	14
Total Investments	$	2,439	$	27	$	4,672	$	1,979	$	46	$	4,089

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months ended September 30, 2024, and 2023, were as follows.

	Three Months Ended				Nine Months Ended
(in millions)	September 30, 2024		September 30, 2023		September 30, 2024		September 30, 2023
FV-NI:
Realized gains	$	23	$	15	$	93	$	34
Realized losses	10		18		34		52
AFS:
Realized gains	4		4		11		15
Realized losses	3		18		21		47

DUKE ENERGY FLORIDA

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

	September 30, 2024						December 31, 2023
	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	$	—	$	—	$	21	$	—	$	—	$	27
Equity securities	122		—		134		100		—		112
Corporate debt securities	1		—		11		1		—		13
U.S. government bonds	1		8		182		1		14		231
Other debt securities	—		—		1		—		—		—
Total NDTF Investments(a)	$	124	$	8	$	349	$	102	$	14	$	383
Other Investments
Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	3
Municipal bonds	—		—		24		—		1		23
Total Other Investments	$	—	$	—	$	26	$	—	$	1	$	26
Total Investments	$	124	$	8	$	375	$	102	$	15	$	409

(a)During the nine months ended September 30, 2024, and the year ended December 31, 2023, Duke Energy Florida received reimbursements from the NDTF for costs related to ongoing decommissioning activity of Crystal River Unit 3.

73

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 and nine months ended September 30, 2024, and 2023, were immaterial.

DUKE ENERGY INDIANA

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

	September 30, 2024						December 31, 2023
	Gross		Gross				Gross		Gross
	Unrealized		Unrealized		Estimated		Unrealized		Unrealized		Estimated
	Holding		Holding		Fair		Holding		Holding		Fair
(in millions)	Gains		Losses		Value		Gains		Losses		Value
Investments
Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	1
Equity securities	22		—		117		4		—		98
Corporate debt securities	—		—		7		—		—		8
Municipal bonds	1		1		52		1		1		46
U.S. government bonds	—		—		7		—		—		10
Total Investments	$	23	$	1	$	185	$	5	$	1	$	163

Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months ended September 30, 2024, and 2023, were immaterial.

DEBT SECURITY MATURITIES

The table below summarizes the maturity date for debt securities.

	September 30, 2024
			Duke				Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Indiana
Due in one year or less	$	92	$	9	$	68	$	10	$	58	$	7
Due after one through five years	862		347		431		326		105		20
Due after five through 10 years	712		426		234		220		14		13
Due after 10 years	1,753		925		719		678		41		26
Total	$	3,419	$	1,707	$	1,452	$	1,234	$	218	$	66

12. 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 the 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 per share practical expedient. The net asset value 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.

74

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 certain 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.

Foreign currency derivatives

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

Other fair value considerations

See Note 12 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2023, for a discussion of the valuation of goodwill and intangible assets. Also, see Note 8 for further information on the annual impairment test as of August 31, 2024.

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 10. See Note 11 for additional information related to investments by major security type for the Duke Energy Registrants.

	September 30, 2024
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Not Categorized
NDTF cash and cash equivalents	$	151	$	151	$	—	$	—	$	—
NDTF equity securities	8,224		8,195		—		—		29
NDTF debt securities	3,135		1,012		2,123		—		—
Other equity securities	188		188		—		—		—
Other debt securities	284		48		236		—		—
Other cash and cash equivalents	68		68		—		—		—
Derivative assets	162		2		143		17		—
Total assets	12,212		9,664		2,502		17		29
Derivative liabilities	(561)		(34)		(527)		—		—
Net assets	$	11,651	$	9,630	$	1,975	$	17	$	29

	December 31, 2023
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Not Categorized
NDTF cash and cash equivalents	$	133	$	133	$	—	$	—	$	—
NDTF equity securities	7,278		7,241		—		—		37
NDTF debt securities	2,732		829		1,903		—		—
Other equity securities	158		158		—		—		—
Other debt securities	271		55		216		—		—
Other cash and cash equivalents	31		31		—		—		—
Derivative assets	189		37		137		15		—
Total assets	10,792		8,484		2,256		15		37
Derivative liabilities	(729)		(60)		(669)		—		—
Net assets	$	10,063	$	8,424	$	1,587	$	15	$	37

75

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

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

	Derivatives (net)
	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2024		2023		2024		2023
Balance at beginning of period	$	35	$	41	$	15	$	34
Purchases, sales, issuances and settlements:
Purchases	—		3		29		50
Settlements	(13)		(18)		(36)		(76)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	(5)		4		9		22
Balance at end of period	$	17	$	30	$	17	$	30

DUKE ENERGY CAROLINAS

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

	September 30, 2024
(in millions)	Total Fair Value		Level 1		Level 2		Not Categorized
NDTF cash and cash equivalents	$	69	$	69	$	—	$	—
NDTF equity securities	4,729		4,700		—		29
NDTF debt securities	1,707		491		1,216		—
Derivative assets	26		—		26		—
Total assets	6,531		5,260		1,242		29
Derivative liabilities	(186)		—		(186)		—
Net assets	$	6,345	$	5,260	$	1,056	$	29

	December 31, 2023
(in millions)	Total Fair Value		Level 1		Level 2		Not Categorized
NDTF cash and cash equivalents	$	51	$	51	$	—	$	—
NDTF equity securities	4,196		4,159		—		37
NDTF debt securities	1,438		375		1,063		—
Derivative assets	35		—		35		—
Total assets	5,720		4,585		1,098		37
Derivative liabilities	(260)		—		(260)		—
Net assets	$	5,460	$	4,585	$	838	$	37

PROGRESS ENERGY

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

	September 30, 2024						December 31, 2023
(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2
NDTF cash and cash equivalents	$	82	$	82	$	—	$	82	$	82	$	—
NDTF equity securities	3,495		3,495		—		3,082		3,082		—
NDTF debt securities	1,428		521		907		1,294		454		840
Other debt securities	24		—		24		23		—		23
Other cash and cash equivalents	21		21		—		18		18		—
Derivative assets	33		—		33		34		—		34
Total assets	5,083		4,119		964		4,533		3,636		897
Derivative liabilities	(165)		—		(165)		(234)		—		(234)
Net assets	$	4,918	$	4,119	$	799	$	4,299	$	3,636	$	663

76

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

DUKE ENERGY PROGRESS

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

	September 30, 2024						December 31, 2023
(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2
NDTF cash and cash equivalents	$	61	$	61	$	—	$	55	$	55	$	—
NDTF equity securities	3,361		3,361		—		2,970		2,970		—
NDTF debt securities	1,234		375		859		1,050		266		784
Other cash and cash equivalents	16		16		—		14		14		—
Derivative assets	33		—		33		32		—		32
Total assets	4,705		3,813		892		4,121		3,305		816
Derivative liabilities	(140)		—		(140)		(219)		—		(219)
Net assets	$	4,565	$	3,813	$	752	$	3,902	$	3,305	$	597

DUKE ENERGY FLORIDA

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

	September 30, 2024						December 31, 2023
(in millions)	Total Fair Value		Level 1		Level 2		Total Fair Value		Level 1		Level 2
NDTF cash and cash equivalents	$	21	$	21	$	—	$	27	$	27	$	—
NDTF equity securities	134		134		—		112		112		—
NDTF debt securities	194		146		48		244		188		56
Other debt securities	24		—		24		23		—		23
Other cash and cash equivalents	2		2		—		3		3		—
Derivative assets	—		—		—		2		—		2
Total assets	375		303		72		411		330		81
Derivative liabilities	(26)		—		(26)		(15)		—		(15)
Net assets	$	349	$	303	$	46	$	396	$	330	$	66

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 September 30, 2024, and December 31, 2023.

DUKE ENERGY INDIANA

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

	September 30, 2024								December 31, 2023
(in millions)	Total Fair Value		Level 1		Level 2		Level 3		Total Fair Value		Level 1		Level 2		Level 3
Other equity securities	$	117	$	117	$	—	$	—	$	98	$	98	$	—	$	—
Other debt securities	66		—		66		—		64		—		64		—
Other cash and cash equivalents	2		2		—		—		1		1		—		—
Derivative assets	26		—		11		15		25		5		7		13
Total assets	211		119		77		15		188		104		71		13
Derivative liabilities	(4)		(4)		—		—		(18)		(18)		—		—
Net assets	$	207	$	115	$	77	$	15	$	170	$	86	$	71	$	13

77

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

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

	Derivatives (net)
	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2024		2023		2024		2023
Balance at beginning of period	$	33	$	37	$	13	$	29
Purchases, sales, issuances and settlements:
Purchases	—		—		27		42
Settlements	(13)		(14)		(33)		(70)
Total (losses) gains included on the Condensed Consolidated Balance Sheet	(5)		4		8		26
Balance at end of period	$	15	$	27	$	15	$	27

PIEDMONT

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

	September 30, 2024						December 31, 2023
(in millions)	Total Fair Value		Level 1		Level 2			Total Fair Value		Level 1		Level 2
Derivative assets	$	2	$	2	$	—		$	1	$	1	$	—
Derivative liabilities	(124)		—		(124)			(147)		—		(147)
Net (liabilities) assets	$	(122)	$	2	$	(124)		$	(146)	$	1	$	(147)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

	September 30, 2024
										Weighted
	Fair Value									Average
Investment Type	(in millions)		Valuation Technique	Unobservable Input	Range					Range
Duke Energy Ohio
FTRs	$	2	RTO auction pricing	FTR price – per MWh	$	—	-	$	1.35	$	0.56
Duke Energy Indiana
FTRs	15		RTO auction pricing	FTR price – per MWh	(0.76)		-	12.83		1.19
Duke Energy
Total Level 3 derivatives	$	17

	December 31, 2023
										Weighted
	Fair Value									Average
Investment Type	(in millions)		Valuation Technique	Unobservable Input	Range					Range
Duke Energy Ohio
FTRs	$	2	RTO auction pricing	FTR price – per MWh	$	0.36	-	$	2.11	$	0.71
Duke Energy Indiana
FTRs	13		RTO auction pricing	FTR price – per MWh	(1.05)		-	9.64		1.26
Duke Energy
Total Level 3 derivatives	$	15

78

FINANCIAL STATEMENTS FAIR VALUE MEASUREMENTS

OTHER FAIR VALUE DISCLOSURES

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

	September 30, 2024				December 31, 2023
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy(a)	$	80,121	$	76,285	$	75,252	$	69,790
Duke Energy Carolinas	17,032		16,342		16,012		15,077
Progress Energy	24,214		23,422		23,759		22,553
Duke Energy Progress	12,323		11,430		11,714		10,595
Duke Energy Florida	10,248		10,124		10,401		10,123
Duke Energy Ohio	4,164		4,087		3,518		3,310
Duke Energy Indiana	4,801		4,605		4,502		4,230
Piedmont	4,003		3,754		3,668		3,336

(a)Book value of long-term debt includes $1.0 billion at September 30, 2024 and December 31, 2023, of net unamortized debt discount and premium 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 September 30, 2024, and December 31, 2023, 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.

13. VARIABLE INTEREST ENTITIES

CONSOLIDATED VIEs

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

No financial support was provided to any of the consolidated VIEs during the nine months ended September 30, 2024, and the year ended December 31, 2023, 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 DERF, DEPR and DEFR credit facilities 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.

In April 2024, Duke Energy Florida repaid all outstanding DEFR borrowings totaling $325 million and terminated the related DEFR credit facility. Additionally, Duke Energy Florida's related restricted receivables outstanding at DEFR at the time of termination totaled $459 million and were transferred back to Duke Energy Florida to be collected and reported as Receivables on the Condensed Consolidated Balance Sheets.

Receivables Financing – CRC

CRC is a bankruptcy remote, special purpose entity indirectly owned by Duke Energy. On a revolving basis, CRC bought certain accounts receivable arising from the sale of electricity, natural gas and related services from Duke Energy Ohio and Duke Energy Indiana. CRC then borrowed amounts under a credit facility to buy the receivables from Duke Energy Ohio and Duke Energy Indiana. Borrowing availability from the credit facility was limited to the amount of qualified receivables sold to CRC, which generally excluded receivables past due more than a predetermined number of days and reserved for expected past-due balances. The sole source of funds to satisfy the related debt obligation was cash collections from the receivables.

The proceeds Duke Energy Ohio and Duke Energy Indiana received from the sale of receivables to CRC were approximately 75% cash and 25% in the form of a subordinated note from CRC. The subordinated note was a retained interest in the receivables sold. Depending on collection experience, additional equity infusions to CRC would be required by Duke Energy to maintain a minimum equity balance of $3 million.

79

FINANCIAL STATEMENTS VARIABLE INTEREST ENTITIES

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

In March 2024, Duke Energy repaid all outstanding CRC borrowings totaling $350 million and terminated the related CRC credit facility. Additionally, Duke Energy's related restricted receivables outstanding at CRC at the time of termination totaled $682 million, consisting of $316 million and $366 million of restricted receivables that were transferred back to Duke Energy Indiana and Duke Energy Ohio, respectively, to be collected and reported as Receivables on the Condensed Consolidated Balance Sheets.

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	(a)	January 2025		April 2025		(b)
Credit facility amount	(a)	$	500	$	400	(b)
Amounts borrowed at September 30, 2024	—	500		400		—
Amounts borrowed at December 31, 2023	312	500		400		325
Restricted Receivables at September 30, 2024	—	1,149		822		—
Restricted Receivables at December 31, 2023	663	991		833		532

(a)    In March 2024, Duke Energy repaid all outstanding CRC borrowings and terminated the related $350 million CRC credit facility.

(b)    In April 2024, Duke Energy Florida repaid all outstanding DEFR borrowings and terminated the related $325 million DEFR credit facility.

Nuclear Asset-Recovery Bonds

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

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

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

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

(in millions)	September 30, 2024	December 31, 2023
Regulatory Assets: Current	60	59
Current Assets: Other	18	37
Other Noncurrent Assets: Regulatory assets	754	803
Current Liabilities: Other	2	8
Current maturities of long-term debt	59	59
Long-Term Debt	772	831

Storm Recovery Bonds

Duke Energy Carolinas NC Storm Funding, LLC (DECNCSF), Duke Energy Progress NC Storm Funding, LLC (DEPNCSF) and Duke Energy Progress SC Storm Funding, LLC (DEPSCSF) are bankruptcy remote, wholly owned special purpose subsidiaries of Duke Energy Carolinas and Duke Energy Progress. DECNCSF and DEPNCSF were formed in 2021 while DEPSCSF was formed in 2024, all 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 incurred in North Carolina and South Carolina.

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. In April 2024, DEPSCSF issued $177 million of senior secured bonds and used the proceeds to acquire storm recovery property from Duke Energy Progress. The storm recovery property was created by state legislation and a PSCSC financing order for the purpose of financing storm costs incurred from 2014 through 2022.

80

FINANCIAL STATEMENTS VARIABLE INTEREST ENTITIES

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’ North Carolina and South Carolina 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. These entities are considered VIEs primarily because their 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. Duke Energy Carolinas consolidates DECNCSF and Duke Energy Progress consolidates DEPNCSF and DEPSCSF.

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

	September 30, 2024						December 31, 2023
	Duke Energy		Duke Energy				Duke Energy		Duke Energy
	Carolinas		Progress				Carolinas		Progress
(in millions)	DECNCSF		DEPNCSF		DEPSCSF		DECNCSF		DEPNCSF
Regulatory Assets: Current	$	12	$	39	$	8	$	12	$	39
Current Assets: Other	6		19		8		9		31
Other Noncurrent Assets: Regulatory assets	188		617		157		196		643
Other Noncurrent Assets: Other	1		4		1		1		2
Current Liabilities: Other	1		4		4		10		34
Current Maturities of Long-Term Debt	10		34		9		3		8
Long-Term Debt	198		646		163		208		680

Procurement Company – Duke Energy Florida

Duke Energy Florida Purchasing Company, LLC (DEF ProCo) is a wholly owned special purpose subsidiary of Duke Energy Florida. DEF ProCo was formed in 2023 as the primary procurement agent for equipment, materials and supplies for Duke Energy Florida. DEF ProCo interacts with third-party suppliers on Duke Energy Florida’s behalf with credit and risk support provided by Duke Energy Florida. DEF ProCo is a qualified reseller under Florida tax law and conveys acquired assets to Duke Energy Florida through leases on each acquired asset.

This entity is considered a VIE primarily because the equity capitalization is insufficient to support their operations. Duke Energy Florida has the power to direct the significant activities of this VIE as described above and therefore Duke Energy Florida is considered the primary beneficiary and consolidates the procurement company.

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

(in millions)	September 30, 2024		December 31, 2023
Inventory	$	477	$	462
Accounts Payable	199		188

NON-CONSOLIDATED VIEs

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

	September 30, 2024
	Duke Energy		Duke		Duke
	Natural Gas		Energy		Energy
(in millions)	Investments		Ohio		Indiana
Receivables from affiliated companies	$	—	$	—	$	—
Investments in equity method unconsolidated affiliates	55		—		—
Other noncurrent assets	30		—		—
Total assets	$	85	$	—	$	—
Other current liabilities	4		—		—
Other noncurrent liabilities	1		—		—
Total liabilities	$	5	$	—	$	—
Net assets	$	80	$	—	$	—

81

FINANCIAL STATEMENTS VARIABLE INTEREST ENTITIES

	December 31, 2023
	Duke Energy		Duke		Duke
	Natural Gas		Energy		Energy
(in millions)	Investments		Ohio		Indiana
Receivables from affiliated companies	$	—	$	150	$	208
Investments in equity method unconsolidated affiliates	67		—		—
Other noncurrent assets	43		—		—
Total assets	$	110	$	150	$	208
Other current liabilities	4		—		—
Other noncurrent liabilities	5		—		—
Total liabilities	$	9	$	—	$	—
Net assets	$	101	$	150	$	208

The Duke Energy Registrants are not aware of any situations where the maximum exposure to loss significantly exceeds the carrying values shown above.

Natural Gas Investments

Duke Energy has investments in various joint ventures including pipeline and renewable natural gas 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.

CRC

Amounts included in Receivables from affiliated companies in the above table for Duke Energy Ohio and Duke Energy Indiana reflect their retained interest in receivables sold to CRC as of December 31, 2023. The subordinated notes held by Duke Energy Ohio and Duke Energy Indiana are stated at fair value as of December 31, 2023.

The following table shows the gross and net receivables sold. See discussion under Consolidated VIEs for additional information related to CRC's termination in March 2024.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	September 30, 2024		December 31, 2023		September 30, 2024		December 31, 2023
Receivables sold	$	—	$	361	$	—	$	351
Less: Retained interests	—		150		—		208
Net receivables sold	$	—	$	211	$	—	$	143

The following table shows sales and cash flows related to receivables sold and reflects CRC activity prior to its termination in March 2024.

		Duke Energy Ohio					Duke Energy Indiana
	Nine Months Ended					Nine Months Ended
	September 30,					September 30,
(in millions)		2024		2023				2024		2023
Sales
Receivables sold		$	474	$	1,973			$	473	$	2,646
Loss recognized on sale		7		25				6		15
Cash flows
Cash proceeds from receivables sold		$	478	$	2,024			$	523	$	2,465
Collection fees received		—		1				—		1
Return received on retained interests		4		15				4		9

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.

14. REVENUE

Duke Energy earns substantially all of its revenues through its reportable segments, EU&I and GU&I.

Electric Utilities and Infrastructure

EU&I 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.

82

FINANCIAL STATEMENTS REVENUE

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

	Remaining Performance Obligations
(in millions)	2024		2025		2026		2027		2028		Thereafter		Total
Duke Energy Carolinas	$	3	$	12	$	12	$	12	$	12	$	—	$	51
Progress Energy	18		30		7		7		7		29		98
Duke Energy Progress	2		—		—		—		—		—		2
Duke Energy Florida	16		30		7		7		7		29		96
Duke Energy Indiana	4		17		17		15		5		—		58

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

GU&I 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.

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

	Remaining Performance Obligations
(in millions)	2024		2025		2026		2027		2028		Thereafter		Total
Piedmont	$	16	$	60	$	51	$	49	$	46	$	195	$	417

Other

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

83

FINANCIAL STATEMENTS REVENUE

Disaggregated Revenues

Disaggregated revenues are presented as follows:

	Three Months Ended September 30, 2024
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	3,738	$	1,173	$	1,973	$	811	$	1,162	$	275	$	316	$	—
General	2,287		859		1,035		485		550		152		243		—
Industrial	924		416		275		196		79		39		193		—
Wholesale	620		158		394		350		44		15		53		—
Other revenues	237		71		166		88		78		24		23		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	7,806	$	2,677	$	3,843	$	1,930	$	1,913	$	505	$	828	$	—
Gas Utilities and Infrastructure
Residential	$	157	$	—	$	—	$	—	$	—	$	74	$	—	$	83
Commercial	91		—		—		—		—		23		—		68
Industrial	36		—		—		—		—		6		—		30
Power Generation	—		—		—		—		—		—		—		8
Other revenues	25		—		—		—		—		5		—		20
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	309	$	—	$	—	$	—	$	—	$	108	$	—	$	209
Other
Revenue from contracts with customers	$	12	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total revenue from contracts with customers	$	8,127	$	2,677	$	3,843	$	1,930	$	1,913	$	613	$	828	$	209
Other revenue sources(a)	$	27	$	30	$	17	$	(16)	$	27	$	(8)	$	8	$	10
Total revenues	$	8,154	$	2,707	$	3,860	$	1,914	$	1,940	$	605	$	836	$	219

84

FINANCIAL STATEMENTS REVENUE

	Three Months Ended September 30, 2023
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	3,602	$	988	$	2,043	$	756	$	1,287	$	268	$	303	$	—
General	2,229		779		1,089		467		622		135		224		—
Industrial	912		395		298		203		95		28		190		—
Wholesale	647		141		422		364		58		12		71		—
Other revenues	285		75		175		100		75		24		56		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	7,675	$	2,378	$	4,027	$	1,890	$	2,137	$	467	$	844	$	—
Gas Utilities and Infrastructure
Residential	$	152	$	—	$	—	$	—	$	—	$	73	$	—	$	80
Commercial	88		—		—		—		—		24		—		65
Industrial	26		—		—		—		—		4		—		23
Power Generation	—		—		—		—		—		—		—		23
Other revenues	28		—		—		—		—		4		—		8
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	294	$	—	$	—	$	—	$	—	$	105	$	—	$	199
Other
Revenue from contracts with customers	$	8	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total revenue from contracts with customers	$	7,977	$	2,378	$	4,027	$	1,890	$	2,137	$	572	$	844	$	199
Other revenue sources(a)	$	17	$	15	$	28	$	(4)	$	27	$	5	$	7	$	9
Total revenues	$	7,994	$	2,393	$	4,055	$	1,886	$	2,164	$	577	$	851	$	208

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

85

FINANCIAL STATEMENTS REVENUE

	Nine Months Ended September 30, 2024
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	9,945	$	3,190	$	5,115	$	2,214	$	2,901	$	768	$	872	$	—
General	6,234		2,331		2,834		1,334		1,500		448		624		—
Industrial	2,615		1,130		808		556		252		110		566		—
Wholesale	1,698		423		1,086		974		112		39		150		—
Other revenues	783		269		502		257		245		64		96		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	21,275	$	7,343	$	10,345	$	5,335	$	5,010	$	1,429	$	2,308	$	—
Gas Utilities and Infrastructure
Residential	$	859	$	—	$	—	$	—	$	—	$	307	$	—	$	552
Commercial	434		—		—		—		—		111		—		323
Industrial	115		—		—		—		—		23		—		92
Power Generation	—		—		—		—		—		—		—		24
Other revenues	97		—		—		—		—		19		—		78
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	1,505	$	—	$	—	$	—	$	—	$	460	$	—	$	1,069
Other
Revenue from contracts with customers	$	30	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Revenue from contracts with customers	$	22,810	$	7,343	$	10,345	$	5,335	$	5,010	$	1,889	$	2,308	$	1,069
Other revenue sources(a)	$	187	$	68	$	100	$	3	$	82	$	2	$	34	$	70
Total revenues	$	22,997	$	7,411	$	10,445	$	5,338	$	5,092	$	1,891	$	2,342	$	1,139

86

FINANCIAL STATEMENTS REVENUE

	Nine Months Ended September 30, 2023
			Duke				Duke		Duke		Duke		Duke
(in millions)	Duke		Energy		Progress		Energy		Energy		Energy		Energy
By market or type of customer	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Electric Utilities and Infrastructure
Residential	$	9,193	$	2,527	$	5,019	$	1,902	$	3,117	$	710	$	937	$	—
General	5,936		1,974		2,844		1,194		1,650		411		706		—
Industrial	2,630		1,011		844		560		284		155		618		—
Wholesale	1,695		402		1,064		942		122		33		195		—
Other revenues	618		202		440		238		202		73		103		—
Total Electric Utilities and Infrastructure revenue from contracts with customers	$	20,072	$	6,116	$	10,211	$	4,836	$	5,375	$	1,382	$	2,559	$	—
Gas Utilities and Infrastructure
Residential	$	838	$	—	$	—	$	—	$	—	$	317	$	—	$	522
Commercial	421		—		—		—		—		113		—		309
Industrial	103		—		—		—		—		19		—		84
Power Generation	—		—		—		—		—		—		—		69
Other revenues	93		—		—		—		—		15		—		32
Total Gas Utilities and Infrastructure revenue from contracts with customers	$	1,455	$	—	$	—	$	—	$	—	$	464	$	—	$	1,016
Other
Revenue from contracts with customers	$	24	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Total Revenue from contracts with customers	$	21,551	$	6,116	$	10,211	$	4,836	$	5,375	$	1,846	$	2,559	$	1,016
Other revenue sources(a)	$	297	$	39	$	104	$	8	$	81	$	29	$	47	$	103
Total revenues	$	21,848	$	6,155	$	10,315	$	4,844	$	5,456	$	1,875	$	2,606	$	1,119

(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.

87

FINANCIAL STATEMENTS REVENUE

The following table presents the reserve for credit losses for trade and other receivables.

	Three Months Ended September 30, 2023 and 2024
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Balance at June 30, 2023	$	199	$	57	$	73	$	43	$	30	$	8	$	4	$	13
Write-Offs	(36)		(14)		(20)		(11)		(8)		—		—		(5)
Credit Loss Expense	23		5		15		2		13		—		1		2
Other Adjustments	17		8		9		10		(1)		—		—		—
Balance at September 30, 2023	$	203	$	56	$	77	$	44	$	34	$	8	$	5	$	10
Balance at June 30, 2024	$	207	$	65	$	73	$	47	$	26	$	42	$	16	$	11
Write-Offs	(29)		(13)		(16)		(10)		(6)		—		—		—
Credit Loss Expense	34		15		18		7		11		—		—		1
Other Adjustments	6		3		4		4		—		(1)		—		—
Balance at September 30, 2024	$	218	$	70	$	79	$	48	$	31	$	41	$	16	$	12
	Nine Months Ended September 30, 2023 and 2024
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Balance at December 31, 2022	$	216	$	68	$	81	$	44	$	36	$	6	$	4	$	14
Write-Offs	(121)		(54)		(60)		(30)		(28)		—		—		(11)
Credit Loss Expense	62		18		33		7		26		2		1		7
Other Adjustments	46		24		23		23		—		—		—		—
Balance at September 30, 2023	$	203	$	56	$	77	$	44	$	34	$	8	$	5	$	10
Balance at December 31, 2023	$	205	$	56	$	74	$	44	$	31	$	9	$	5	$	11
Write-Offs	(97)		(41)		(49)		(29)		(20)		—		—		(4)
Credit Loss Expense	79		32		38		17		21		2		2		5
Other Adjustments	31		23		16		16		(1)		30		9		—
Balance at September 30, 2024	$	218	$	70	$	79	$	48	$	31	$	41	$	16	$	12

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.

15. 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 or convertible debt, were exercised or settled. Duke Energy applies the if-converted method for calculating any potential dilutive effect of the conversion of the outstanding convertible notes on diluted EPS, if applicable. 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.

88

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 September 30,				Nine Months Ended September 30,
(in millions, except per share amounts)	2024		2023		2024		2023
Net Income available to Duke Energy common stockholders	$	1,226	$	1,213	$	3,211	$	1,744
Less: Income (Loss) from discontinued operations attributable to Duke Energy common stockholders	22		(190)		9		(1,283)
Accumulated preferred stock dividends adjustment	14		12		14		12
Less: Impact of participating securities	2		2		4		4
Income from continuing operations available to Duke Energy common stockholders	$	1,216	$	1,413	$	3,212	$	3,035
Income (Loss) from discontinued operations, net of tax	$	25	$	(152)	$	12	$	(1,316)
Add: (Income) Loss attributable to NCI	(3)		(38)		(3)		33
Income (Loss) from discontinued operations attributable to Duke Energy common stockholders	$	22	$	(190)	$	9	$	(1,283)
Weighted average common shares outstanding – basic	772		771		772		771
Equity forwards	1		—		—		—
Weighted average common shares outstanding – diluted	773		771		772		771
EPS from continuing operations available to Duke Energy common stockholders
Basic and diluted(a)	$	1.57	$	1.83	$	4.16	$	3.94
Income (Loss) Per Share from discontinued operations attributable to Duke Energy common stockholders
Basic and diluted(a)	$	0.03	$	(0.24)	$	0.01	$	(1.67)
Potentially dilutive items excluded from the calculation(b)	2		2		2		2
Dividends declared per common share	$	1.045	$	1.025	$	3.095	$	3.035
Dividends declared on Series A preferred stock per depositary share(c)	$	0.359	$	0.359	$	1.078	$	1.078
Dividends declared on Series B preferred stock per share(d)	$	24.375	$	24.375	$	48.750	$	48.750

(a)For the periods presented subsequent to issuance in April 2023, the convertible notes were excluded from the calculations of diluted EPS because the effect was antidilutive.

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

(c)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.

(d)4.875% Series B Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock dividends were payable semiannually in arrears on the 16th day of March and September. The preferred stock was redeemed on September 16, 2024.

Common Stock

In November 2022, Duke Energy filed a prospectus supplement and executed an Equity Distribution Agreement (EDA) under which it may sell up to $1.5 billion of its common stock through an at-the-market (ATM) offering program, including an equity forward sales component. Under the terms of the EDA, Duke Energy may issue and sell shares of common stock through September 2025.

The following table shows ATM equity issuances pursuant to forward contracts executed during the nine months ended September 30, 2024.

Tranche	Shares Priced	Initial Forward Price
1	802,371	$	92.77
2	729,674	$	101.10
3	737,280	$	100.99
4	662,266	$	111.45
Total	2,931,591

The equity forwards require Duke Energy to either physically settle the transactions by issuing shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreements or net settle in whole or in part through the delivery or receipt of cash or shares. The settlement alternatives are at Duke Energy's election. No amounts have or will be recorded in Duke Energy's Condensed Consolidated Financial Statements with respect to the ATM offering until settlement of the equity forwards occurs, which is expected by December 31, 2024. The initial forward sale prices will be subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the relevant forward sale agreements. Until settlement of the equity forwards, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method.

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FINANCIAL STATEMENTS STOCKHOLDERS' EQUITY

Preferred Stock

On September 16, 2024, Duke Energy redeemed all 1 million outstanding shares of Series B Preferred Stock for a redemption price of $1,000 per share or $1 billion in total. Following the redemption, dividends ceased to accrue on the shares of Series B Preferred Stock, shares of the Series B Preferred Stock were no longer deemed outstanding and all rights of the holders of such shares of Series B Preferred Stock terminated. In conjunction with the redemption, Duke Energy recorded $16 million in preferred stock redemption costs, calculated as the difference of $11 million between the carrying value on the redemption date of the Series B Preferred Stock and the total amount of consideration paid to redeem, and including the recognition of an excise tax liability under the IRA of $5 million. The preferred stock redemption costs were recorded as a reduction to Retained earnings on Duke Energy Corporations' Condensed Consolidated Balance Sheets during the three months ended September 30, 2024.

16. 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.

The following table includes information related to the Duke Energy Registrants' contributions to its qualified defined benefit pension plans.

	Nine Months Ended September 30, 2024 and 2023
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Contributions made:
2024	$	100	$	26	$	23	$	14	$	9	$	5	$	8	$	3
2023	$	100	$	26	$	22	$	13	$	9	$	5	$	8	$	3

Duke Energy uses a December 31 measurement date for its qualified non-contributory defined benefit retirement plan assets and obligations. However, because Duke Energy believes it is probable in 2024 that total lump-sum benefit payments for one of its defined benefit retirement plans will exceed the settlement threshold, which is defined as the sum of the service cost and interest cost on projected benefit obligation components of net periodic pension costs, Duke Energy remeasured the plan's assets and plan's projected benefit obligation as of September 30, 2024. The discount rate used for the September 30, 2024 remeasurement was 5.0% and the cash balance interest crediting rate was 4.0%. The interest rate for lump sum and annuity conversions was updated to reflect current market conditions. All other assumptions used for the September 30, 2024, remeasurement were consistent with the measurement as of December 31, 2023.

As a result of the remeasurement, Duke Energy recognized a remeasurement loss of $11 million, of which $10 million was recorded in Regulatory Assets within Other Noncurrent Assets and $1 million was recorded in Accumulated Other Comprehensive Loss within the Condensed Consolidated Balance Sheets as of September 30, 2024. The remeasurement loss, which represents a decrease in funded status of the plan, reflects an increase of $117 million in the fair value of the plan's assets and an increase of $128 million in the plan's projected benefit obligation.

As the result of settlement accounting, Duke Energy recognized settlement charges of $72 million, of which $60 million was recorded to Regulatory Assets within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets and $12 million was recorded to Other Income and Expenses, net, within the Condensed Consolidated Statement of Operations as of September 30, 2024.

QUALIFIED PENSION PLANS

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

	Three Months Ended September 30, 2024
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Service cost	$	28	$	9	$	8	$	5	$	3	$	1	$	1	$	1
Interest cost on projected benefit obligation	82		19		26		12		14		5		6		2
Expected return on plan assets	(154)		(41)		(55)		(25)		(29)		(6)		(10)		(5)
Amortization of actuarial loss	9		2		2		1		1		—		1		1
Amortization of prior service credit	(3)		—		—		—		—		—		—		(1)
Amortization of settlement charges	17		5		7		6		—		2		—		2
Net periodic pension costs	$	(21)	$	(6)	$	(12)	$	(1)	$	(11)	$	2	$	(2)	$	—

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FINANCIAL STATEMENTS EMPLOYEE BENEFIT PLANS

	Three Months Ended September 30, 2023
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Service cost	$	28	$	9	$	9	$	5	$	3	$	1	$	1	$	1
Interest cost on projected benefit obligation	86		21		26		12		14		4		6		2
Expected return on plan assets	(147)		(40)		(50)		(24)		(26)		(6)		(10)		(5)
Amortization of actuarial loss	2		—		1		—		1		—		1		—
Amortization of prior service credit	(3)		—		—		—		—		—		—		(1)
Amortization of settlement charges	5		3		1		1		—		—		—		1
Net periodic pension costs	$	(29)	$	(7)	$	(13)	$	(6)	$	(8)	$	(1)	$	(2)	$	(2)

	Nine Months Ended September 30, 2024
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Service cost	$	85	$	28	$	24	$	15	$	10	$	2	$	4	$	3
Interest cost on projected benefit obligation	247		59		78		36		42		13		19		7
Expected return on plan assets	(462)		(122)		(163)		(75)		(87)		(19)		(31)		(15)
Amortization of actuarial loss	25		6		7		4		3		1		3		2
Amortization of prior service credit	(10)		—		—		—		—		—		(1)		(5)
Amortization of settlement charges	26		9		9		8		1		2		1		4
Net periodic pension costs	$	(89)	$	(20)	$	(45)	$	(12)	$	(31)	$	(1)	$	(5)	$	(4)

	Nine Months Ended September 30, 2023
			Duke				Duke		Duke		Duke		Duke
	Duke		Energy		Progress		Energy		Energy		Energy		Energy
(in millions)	Energy		Carolinas		Energy		Progress		Florida		Ohio		Indiana		Piedmont
Service cost	$	87	$	28	$	25	$	15	$	10	$	2	$	4	$	3
Interest cost on projected benefit obligation	258		63		80		37		43		13		20		7
Expected return on plan assets	(441)		(120)		(149)		(70)		(78)		(18)		(30)		(15)
Amortization of actuarial loss	7		1		3		1		2		—		2		—
Amortization of prior service credit	(10)		—		—		—		—		—		(1)		(5)
Amortization of settlement charges	14		7		3		3		1		—		1		3
Net periodic pension costs	$	(85)	$	(21)	$	(38)	$	(14)	$	(22)	$	(3)	$	(4)	$	(7)

NON-QUALIFIED PENSION PLANS

Net periodic pension costs for non-qualified pension plans were not material for the three and nine months ended September 30, 2024, and 2023.

OTHER POST-RETIREMENT BENEFIT PLANS

Net periodic costs for OPEB plans were not material for the three and nine months ended September 30, 2024, and 2023.

17. INCOME TAXES

On August 16, 2022, the IRA was signed into law. Among other provisions, the IRA created a new, zero-emission nuclear power PTC available for taxpayers beginning January 1, 2024. Through September 30, 2024, Duke Energy Carolinas and Duke Energy Progress have recorded PTC deferred tax assets of approximately $325 million and $59 million, respectively. These amounts represent the estimated net realizable value of the PTCs, which were deferred to a regulatory liability. The Company will continue to assess its calculations and interpretations as new information and guidance becomes available.

The Subsidiary Registrants will work with the state utility commissions on the appropriate regulatory process to pass the net realizable value back to customers over time. See Note 4 for additional information on Duke Energy Carolinas' approval for a stand-alone rider starting January 1, 2025.

In October 2024, $174 million of tax credits were sold for proceeds approximating carrying value, including $150 million of nuclear power PTCs sold by Duke Energy Carolinas.

91

FINANCIAL STATEMENTS 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				Nine Months Ended
	September 30,				September 30,
	2024		2023		2024		2023
Duke Energy	11.2	%	2.8	%	12.5	%	9.0	%
Duke Energy Carolinas	7.7	%	4.9	%	9.8	%	8.0	%
Progress Energy	16.1	%	15.7	%	16.4	%	16.2	%
Duke Energy Progress	12.9	%	11.8	%	14.1	%	13.0	%
Duke Energy Florida	20.5	%	20.8	%	19.9	%	20.3	%
Duke Energy Ohio	11.9	%	14.9	%	15.8	%	15.8	%
Duke Energy Indiana	15.7	%	18.5	%	16.3	%	17.8	%
Piedmont	29.4	%	26.3	%	18.4	%	17.2	%

The increase in the ETR for Duke Energy for the three months ended September 30, 2024, was primarily due to benefits associated with tax efficiency efforts in the prior year and a decrease in the amortization of EDIT. In 2023, the Company evaluated the deductibility of certain items spanning periods open under federal statute, including items related to interest on company-owned life insurance. As a result of this analysis, the Company recorded a favorable adjustment in the prior year of approximately $120 million.

The increase in the ETR for Duke Energy for the nine months ended September 30, 2024, was primarily due to benefits associated with tax efficiency efforts in the prior year. In 2023, the Company evaluated the deductibility of certain items spanning periods open under federal statute, including items related to interest on company-owned life insurance. As a result of this analysis, the Company recorded a favorable adjustment in the prior year of approximately $120 million.

The increase in the ETR for Duke Energy Carolinas for the three months ended September 30, 2024, was primarily due to a decrease in the amortization of EDIT.

The increase in the ETR for Duke Energy Carolinas for the nine months ended September 30, 2024, was primarily due to the amortization of EDIT in relation to higher pretax income.

The increase in the ETR for Duke Energy Progress for the three months ended September 30, 2024, was primarily due to a decrease in the amortization of EDIT.

The increase in the ETR for Duke Energy Progress for the nine months ended September 30, 2024, was primarily due to the amortization of EDIT in relation to higher pretax income.

The decrease in the ETR for Duke Energy Ohio for the three months ending September 30, 2024, was primarily due to the amortization of EDIT in relation to pretax income.

The decrease in the ETR for Duke Energy Indiana for the three and nine months ended September 30, 2024, was primarily due to an increase in the amortization of EDIT.

The increase in the ETR for Piedmont for the three months ending September 30, 2024, was primarily due to the amortization of EDIT in relation to higher pretax losses.

The increase in the ETR for Piedmont for the nine months ending September 30, 2024, was primarily due a decrease in the amortization of EDIT.

18. SUBSEQUENT EVENTS

For information on subsequent events related to regulatory matters, debt and credit facilities and income taxes, see Notes 4, 6 and 17, respectively.

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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, and operates in the U.S. primarily through its subsidiaries, Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont. Duke Energy’s consolidated financial information includes the results of the Subsidiary Registrants, which along with Duke Energy are collectively referred to as the Duke Energy Registrants.

Management’s Discussion and Analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2024, and with Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2023.

Executive Overview

Operational Excellence, Safety and Reliability. The reliable and safe operation of our power generating facilities, electric distribution system and natural gas infrastructure in our communities continues to be foundational to serving our customers, our financial results, and our credibility with stakeholders. In recent months, we have responded to several unprecedented and catastrophic weather events across our service territories.

In August 2024, Hurricane Debby made landfall in Florida as a Category 1 storm, impacting the Duke Energy Florida territory as well as the Duke Energy Carolinas and Duke Energy Progress territories in North Carolina and South Carolina and causing approximately 700,000 customer outages. In late September 2024, Hurricane Helene made landfall in Florida as a Category 4 storm and subsequently impacted all of Duke Energy's service territories as the storm moved inland, with the most severe damage occurring in Florida and the Carolinas. Approximately 3.5 million customers were impacted by Hurricane Helene across Duke Energy's system, the largest number of companywide outages from a single event on our system ever reported. Then, in October 2024, Hurricane Milton made landfall in Florida as a Category 3 storm, causing severe damage across our Florida service territory as a result of high winds, rain and flooding and resulting in more than 1 million customer outages.

In such extreme circumstances, our immediate priority is, and always will be, executing the extensive storm preparation and response work to ensure the safe, timely, and efficient restoration of service to impacted customers as quickly as possible. Round-the-clock power restoration efforts continued following the historic damage inflicted by these storms with lineworkers, tree trimmers and removal experts, state department of transportation workers and countless others, working to repair and, in certain areas, completely rebuild, the critical electricity infrastructure that powers and supports the communities we serve. We've also seen the benefits of ongoing grid hardening investments, leveraging self-healing technologies and remote restoration capabilities to automate the rerouting of power, more effectively deploy resources, and reduce the frequency or duration of outages for many of our customers during severe weather events.

We will continue the important work of rebuilding our communities in the weeks and months ahead, including power infrastructure in the hardest-hit areas of our service territories. We also plan to work with our state commissions to appropriately track and recover storm costs under approved regulatory frameworks on a timely basis. We will also remain focused on balancing the bill impacts on our customers from such catastrophic events, including seeking insurance recovery and exploring the potential securitization of related costs in certain jurisdictions, as appropriate. For more information, see "Matters Impacting Future Results," "Liquidity and Capital Resources," and Notes 4 and 6 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and "Debt and Credit Facilities."

Advancing Our Clean Energy Transition. During the nine months ended September 30, 2024, we continued to execute on our clean energy transition, remaining focused on reliability and affordability while delivering increasingly clean energy and providing strong, sustainable value for shareholders, customers, communities and employees.

•In May 2024, we entered into memorandums of understanding with several large customers, which propose exploring new and innovative approaches to support carbon-free energy generation and serve future energy needs of large businesses in North Carolina and South Carolina through the use of new tariff structures. The proposed Accelerating Clean Energy (ACE) tariff framework includes new, voluntary pricing structures for large commercial and industrial customers, which enable their direct support of carbon-free energy generation investments including facilitating beneficial customer on-site generation and load flexibility programs. The proposed ACE tariffs would be subject to regulatory approvals and include protections for non-participating customers.

•In January 2024, we filed supplemental modeling and analysis with the NCUC and PSCSC related to our combined systemwide Carolinas Resource Plan filed in August 2023. These updates were necessary due to substantially increased load forecasts resulting from continued economic development successes in the Carolinas occurring since the systemwide integrated resource plan was prepared. In March 2024, we filed for: (i) CPCNs with the NCUC for new natural gas generation facilities at the sites of the current Marshall Steam Station and Roxboro Plant in the Carolinas; and (ii) a Certificate of Environmental Compatibility and Public Convenience and Necessity with the PSCSC for a new solar center and associated facilities in Chesterfield and Darlington counties, South Carolina. Our energy transition strategy continues to focus on delivering a path to cleaner energy in a manner that protects grid reliability and affordability, all while meeting the energy demands of the growing and economically vibrant communities that we serve.

•As we continue to strengthen our grid and bring clean energy resources online, our customers are important partners in our clean energy future. In January 2024, we received approval for PowerPairSM, a new incentive-based pilot program for installing home solar generation with battery energy storage in our Duke Energy Carolinas and Duke Energy Progress North Carolina service territories. Enrollment options for residential customers that participate in the pilot include a one-time incentive of up to $9,000 for the installation of a solar plus battery system. The program was launched in May 2024 and successfully enrolled more than 1,300 customers in its first three months, providing another impactful way for our customers to save energy and money, while exploring new solutions to help manage low carbon grids of the future.

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MD&A DUKE ENERGY

Regulatory Activity. During the nine months ended September 30, 2024, we continued to move our regulatory strategy forward. See Note 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.

•In January 2024, Duke Energy Carolinas filed a South Carolina rate case, the first base rate case filed by Duke Energy Carolinas in the state since 2018 and reflecting the South Carolina retail allocation of significant investments, including approximately $1.5 billion of transmission and distribution assets. In May 2024, we reached a constructive comprehensive settlement with certain parties and in July 2024, the PSCSC issued an order approving the settlement and revising recovery of certain environmental compliance costs. New rates were effective August 1, 2024.

•In April 2024, we filed formal requests for new base rates across several jurisdictions including Duke Energy Florida, Duke Energy Indiana and Piedmont.

•Duke Energy Florida filed a three-year rate plan that will begin in January 2025, once its current base rate settlement agreement concludes at the end of 2024, and proposed approximately $4.9 billion in incremental investments to reduce outages, expand solar generation, and increase generation unit efficiency. In August 2024, the FPSC approved our constructive comprehensive settlement with certain parties, allowing us to continue making important investments to reduce outages, shorten response times, meet future energy demands, increase clean, solar generation and explore innovative technologies to generate cost savings for our customers.

•Duke Energy Indiana filed a general rate case with the IURC requesting an overall increase in revenues of $492 million. This is the first base rate case filed by Duke Energy Indiana since 2019 and reflects strategic investments to improve grid reliability and security, serve a growing customer base, and meet environmental regulations. These investments, which include approximately 345 miles of new power lines expected to be constructed through 2025, will support the more than 60,000 new customers anticipated since our last base rate case.

•Piedmont filed a general rate case with the NCUC, its first base rate case in North Carolina since 2021, reflecting significant investments to support ongoing service reliability, system growth, and compliance with federal pipeline safety regulations in addition to two energy reliability centers in eastern North Carolina. In September 2024, we reached a constructive comprehensive settlement with certain parties. Revised interim rates were effective November 1, 2024, subject to refund and pending NCUC approval of the settlement and a final order.

•Also, in April 2024, Duke Energy Progress issued $177 million of storm recovery bonds, our first issuance under South Carolina's 2022 securitization legislation, which provided the necessary framework for us to lower the bill impacts on our customers related to critical storm restoration activities.

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

In April 2024, the EPA issued the 2024 CCR Rule under the Resource Conservation and Recovery Act, which significantly expands the scope of the 2015 CCR Rule by establishing regulatory requirements for inactive surface impoundments at retired generating facilities and previously unregulated coal ash sources at regulated facilities. Duke Energy is participating in legal challenges to the 2024 CCR Rule.

Cost recovery for future expenditures is anticipated and will be pursued through the normal ratemaking process with federal and state utility commissions, which permit recovery of reasonable and prudently incurred costs associated with Duke Energy’s regulated operations. The majority of spend is expected to occur over the next 10 years. For more information, see "Other Matters" and Notes 4 and 7 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and "Asset Retirement Obligations."

Fuel Cost Recovery

As a result of rapidly rising commodity costs during 2022, including natural gas, fuel and purchased power prices in excess of amounts included in fuel-related revenues led to an increase in the under collection of fuel costs from customers in jurisdictions including those served by Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida. These amounts have been deferred in regulatory assets and impacted the cash flows of the registrants, including increased borrowings to temporarily finance related expenditures until recovery. Regulatory filings have been made and approved for recovery of all remaining uncollected 2022 fuel costs. Across all jurisdictions, Duke Energy is currently on pace to recover approximately $1.8 billion of deferred fuel costs in 2024 and we anticipate being in line with our historical average balance of deferred fuel costs by the end of this year.

Storm Cost Recovery

Beginning in the third quarter of 2024, a series of major storm events occurred that resulted in significant damage to utility infrastructure within our service territories and primarily impacted Duke Energy Carolinas', Duke Energy Progress' and Duke Energy Florida's electric utility operations. Hurricanes Debby, Helene and Milton caused widespread outages and included unprecedented damage to certain assets, including the hardest-hit areas on the western coast of Florida and certain regions in western North Carolina and upstate South Carolina. Appropriate storm cost recovery mechanisms are in place to track and recover incremental costs from such events. Funding restoration activities and, in some cases, the complete rebuild of critical infrastructure, for a series of sequential events of this magnitude has resulted in incremental financing needs until cost recovery occurs and may impact the near-term results of operations, financial position, or cash flows of the impacted registrants. For more information related to storm cost estimates, regulatory asset deferrals, and financing activities, see "Liquidity and Capital Resources" and Notes 4 and 6 to the Condensed Consolidated Financial Statements, "Regulatory Matters" and "Debt and Credit Facilities."

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MD&A MATTERS IMPACTING FUTURE RESULTS

EPA Regulations of GHG Emissions

In April 2024, the EPA issued a final rule under section 111 of the Clean Air Act (EPA Rule 111) regulating GHG emissions from existing coal-fired and new natural gas-fired power plants. Duke Energy is analyzing the potential impacts the rule could have on the Company, which could be material and may influence the timing, nature, and magnitude of future generation investments in our service territories. Cost recovery for future expenditures will be pursued through the normal ratemaking process with federal and state utility commissions, which permit recovery of reasonable and prudently incurred costs associated with Duke Energy’s regulated operations. Duke Energy is participating in legal challenges to the final rule. For more information, see "Other Matters."

Supply Chain

The Company continues to monitor the ongoing stability of markets for key materials and other developments, including public policy outcomes, that could disrupt or impact the Company's supply chain and, as a result, may impact Duke Energy's execution of its capital plan, future financial results or the achievement of its clean energy goals.

Goodwill

The Duke Energy Registrants performed their annual goodwill impairment tests as of August 31, 2024. As of this date, all of the Duke Energy Registrants' reporting units' estimated fair values materially exceeded the carrying values except for the GU&I reporting unit of Duke Energy Ohio. While no goodwill impairment charges were recorded in 2024, the potential for deteriorating economic conditions impacting GU&I's future cash flows or equity valuations of peer companies could impact the estimated fair value of GU&I, and goodwill impairment charges could be recorded in the future.

Other

Duke Energy continues to monitor general market conditions, including the potential for interest rate pressures on the Company's cost of capital, which may impact Duke Energy's execution of its capital plan, future financial results, or the achievement of its clean energy goals.

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, adjusted earnings and adjusted EPS, discussed below. Non-GAAP financial measures are numerical measures 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 basic 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 Basic 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 primarily represents impairment charges related to Duke Energy Carolinas' South Carolina rate case order in 2024 and the Duke Energy North Carolina rate case settlement and Duke Energy Progress' North Carolina rate case order in 2023.

•System Post-Implementation Costs represents the net impact of charges related to nonrecurring customer billing adjustments as a result of implementation of a new customer system.

•Preferred Redemption Costs represents charges related to the redemption of Series B Preferred Stock.

Discontinued operations primarily represents the operating results and impairments recognized related to the sale of Duke Energy's Commercial Renewables Disposal Groups.

Three Months Ended September 30, 2024, as compared to September 30, 2023

GAAP reported EPS was $1.60 for the three months ended September 30, 2024, compared to $1.59 for the three months ended September 30, 2023. In addition to the drivers below, GAAP reported EPS increased primarily due to higher impairments on the sale of the Commercial Renewables business in the prior year.

As discussed above, management also evaluates financial performance based on adjusted EPS. Duke Energy’s third quarter 2024 adjusted EPS was $1.62 compared to $1.94 for the third quarter of 2023. The decrease in adjusted EPS was primarily due to a higher effective tax rate, storm costs, interest expense, and depreciation expense on a growing asset base, partially offset by growth from rate increases and riders.

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MD&A DUKE ENERGY

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

	Three Months Ended September 30,
	2024				2023
(in millions, except per share amounts)	Earnings		EPS		Earnings		EPS
GAAP Reported Earnings/GAAP Reported Earnings Per Share	$	1,226	$	1.60	$	1,213	$	1.59
Adjustments:
Regulatory Matters(a)	—		—		84		0.11
System Post-Implementation Costs(b)	16		0.02		—		—
Preferred Redemption Costs(c)	16		0.02		—		—
Discontinued Operations(d)	(22)		(0.03)		190		0.24
Adjusted Earnings/Adjusted EPS	$	1,236	$	1.62	$	1,487	$	1.94

Note: Total EPS may not foot due to rounding.

(a)Net of $27 million tax benefit. $95 million recorded within Impairment of assets and other charges and $16 million recorded within Operations, maintenance and other.

(b)Net of $5 million tax benefit. $17 million recorded within Operating Revenues, $1 million recorded within Operations, maintenance and other and $3 million recorded within Other Income and expenses.

(c)Recorded within Preferred Redemption Costs.

(d)Recorded in Income (Loss) from Discontinued Operations, net of tax, and Net Income Attributable to Noncontrolling Interests.

Nine Months Ended September 30, 2024, as compared to September 30, 2023

GAAP Reported EPS was $4.17 for the nine months ended September 30, 2024, compared to $2.27 for the nine months ended September 30, 2023. In addition to the drivers below, GAAP reported EPS increased primarily due to higher impairments on the sale of the Commercial Renewables business in the prior year.

As discussed above, management also evaluates financial performance based on adjusted EPS. Duke Energy’s adjusted EPS was $4.24 for the nine months ended September 30, 2024, compared to $4.05 for the nine months ended September 30, 2023. The increase in adjusted EPS was primarily due to growth from rate increases and riders, higher sales volumes and favorable weather, partially offset by a higher effective tax rate, interest expense, and depreciation expense on a growing asset base.

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

	Nine Months Ended September 30,
	2024				2023
(in millions, except per share amounts)	Earnings		EPS		Earnings		EPS
GAAP Reported Earnings/GAAP Reported EPS	$	3,211	$	4.17	$	1,744	$	2.27
Adjustments:
Regulatory Matters(a)	25		0.03		84		0.11
System Post-Implementation Costs(b)	16		0.02		—		—
Preferred Redemption Costs(c)	16		0.02		—		—
Discontinued Operations(d)	(9)		(0.01)		1,283		1.67
Adjusted Earnings/Adjusted EPS	$	3,259	$	4.24	$	3,111	$	4.05

Note: Total EPS may not foot due to rounding.

(a)Net of $8 million tax benefit and $27 million tax benefit for the nine months ended September 30, 2024, and 2023, respectively. $42 million recorded within Impairment of assets and other charges, $2 million within Operations, maintenance and other, and an $11 million reduction recorded within Interest Expense for the nine months ended September 30, 2024. $95 million recorded within Impairment of assets and other charges and $16 million recorded within Operations, maintenance and other for the nine months ended September 30, 2023.

(b)Net of $5 million tax benefit. $17 million recorded within Operating Revenues, $1 million recorded within Operations, maintenance and other and $3 million recorded within Other Income and expenses.

(c)Recorded within Preferred Redemption Costs.

(d)Recorded in Income (Loss) from Discontinued Operations, net of tax, and Net Income Attributable to Noncontrolling Interests.

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: EU&I and GU&I. The remainder of Duke Energy’s operations is presented as Other. See Note 3 to the Condensed Consolidated Financial Statements, “Business Segments,” for additional information on Duke Energy’s segment structure.

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MD&A SEGMENT RESULTS — ELECTRIC UTILITIES AND INFRASTRUCTURE

Electric Utilities and Infrastructure

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2024		2023		Variance		2024		2023		Variance
Operating Revenues	$	7,852	$	7,715	$	137	$	21,475	$	20,363	$	1,112
Operating Expenses
Fuel used in electric generation and purchased power	2,664		2,591		73		7,266		7,045		221
Operation, maintenance and other	1,387		1,398		(11)		3,965		4,008		(43)
Depreciation and amortization	1,352		1,209		143		3,823		3,493		330
Property and other taxes	345		392		(47)		1,033		1,077		(44)
Impairment of assets and other charges	(5)		88		(93)		38		100		(62)
Total operating expenses	5,743		5,678		65		16,125		15,723		402
Gains on Sales of Other Assets and Other, net	2		2		—		9		30		(21)
Operating Income	2,111		2,039		72		5,359		4,670		689
Other Income and Expenses, net	129		131		(2)		401		388		13
Interest Expense	514		468		46		1,501		1,364		137
Income Before Income Taxes	1,726		1,702		24		4,259		3,694		565
Income Tax Expense	244		224		20		631		531		100
Less: Income Attributable to Noncontrolling Interest	31		31		—		66		75		(9)
Segment Income	$	1,451	$	1,447	$	4	$	3,562	$	3,088	$	474
Duke Energy Carolinas GWh sales	24,848		24,810		38		69,720		66,367		3,353
Duke Energy Progress GWh sales	19,107		19,704		(597)		52,439		50,503		1,936
Duke Energy Florida GWh sales	13,423		13,665		(242)		34,124		34,055		69
Duke Energy Ohio GWh sales	6,804		6,356		448		18,494		17,694		800
Duke Energy Indiana GWh sales	8,550		8,526		24		23,541		22,803		738
Total Electric Utilities and Infrastructure GWh sales	72,732		73,061		(329)		198,318		191,422		6,896
Net proportional MW capacity in operation							54,416		54,407		9

Three Months Ended September 30, 2024, as compared to September 30, 2023

EU&I’s results were driven by higher revenues from rate cases across multiple jurisdictions and higher weather-normal retail sales volumes, offset by higher depreciation. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

•a $152 million increase due to higher pricing from jurisdictional rate cases primarily at Duke Energy Carolinas and Duke Energy Progress and the 2021 Settlement at Duke Energy Florida;

•a $96 million increase in weather-normal retail sales volumes; and

•a $94 million increase in fuel revenues primarily due to net higher fuel cost recovery in the current year.

Partially offset by:

•a $92 million decrease in storm revenues at Duke Energy Florida;

•a $51 million decrease in rider revenues primarily due to a decrease in the return of EDIT to customers at Duke Energy Carolinas;

•a $32 million decrease in retail sales due to unfavorable weather compared to prior year, including the impacts of decoupling; and

•a $12 million decrease in franchise tax revenue primarily due to decreased revenues over prior year at Duke Energy Florida.

Operating Expenses. The variance was driven primarily by:

•a $143 million increase in depreciation and amortization primarily due to higher depreciable base and higher net amortizations driven by the North Carolina rate cases at Duke Energy Carolinas and Duke Energy Progress and lower amortization of the DOE settlement regulatory liability and higher depreciable base at Duke Energy Florida; and

•a $73 million increase in fuel used in electric generation and purchased power due to higher recovery of fuel expense at Duke Energy Carolinas and Duke Energy Progress, partially offset by lower deferred fuel amortization and lower fuel prices and volumes at Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana.

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MD&A SEGMENT RESULTS — ELECTRIC UTILITIES AND INFRASTRUCTURE

Partially offset by:

•a $93 million decrease in impairments of assets and other charges primarily related to the prior year rate case impacts at Duke Energy Carolinas and Duke Energy Progress;

•a $47 million decrease in property and other taxes due to lower property taxes and lower franchise and gross receipts tax driven by lower revenues at Duke Energy Florida; and

•an $11 million decrease in operation, maintenance and other primarily driven by lower storm amortization at Duke Energy Florida, lower storm and nuclear outage costs at Duke Energy Progress, partially offset by higher storm costs at Duke Energy Carolinas.

Interest Expense. The increase was primarily driven by higher outstanding debt balances and interest rates.

Income Tax Expense. The increase in tax expense was primarily due to an increase in pretax income and the decrease in the amortization of EDIT. The ETRs for the three months ended September 30, 2024, and 2023, were 14.1% and 13.2%, respectively. The increase in the ETR is primarily due to a decrease in the amortization of EDIT.

Nine Months Ended September 30, 2024, as compared to September 30, 2023

EU&I’s results were driven by higher revenues from rate cases across multiple jurisdictions, improved weather, and higher weather-normal retail sales volumes, partially offset by higher depreciation. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

•a $458 million increase due to higher pricing from jurisdictional rate cases primarily at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Kentucky and the 2021 Settlement at Duke Energy Florida;

•a $259 million increase in retail sales due to improved weather compared to prior year, including the impacts of decoupling;

•a $204 million increase in weather-normal retail sales volumes;

•a $195 million increase in fuel revenues primarily due to net higher fuel cost recovery in the current year;

•a $63 million increase in other revenues for customer programs at Duke Energy Florida; and

•a $50 million increase in rider revenues primarily for the Distribution Capital Investment Rider at Duke Energy Ohio.

Partially offset by:

•a $127 million decrease in storm revenues at Duke Energy Florida.

Operating Expenses. The variance was driven primarily by:

•a $330 million increase in depreciation and amortization primarily due to lower amortization of the DOE settlement regulatory liability and higher depreciable base at Duke Energy Florida and higher depreciable base and higher net amortizations driven by the North Carolina rate cases at Duke Energy Carolinas and Duke Energy Progress; and

•a $221 million increase in fuel used in electric generation and purchased power due to higher recovery of fuel expense at Duke Energy Carolinas and Duke Energy Progress, partially offset by lower deferred fuel amortization and lower fuel prices and volumes at Duke Energy Indiana, Duke Energy Florida and Duke Energy Ohio.

Partially offset by:

•a $62 million decrease in impairment of assets and other charges primarily related to the prior year North Carolina rate case impacts at Duke Energy Carolinas and Duke Energy Progress;

•a $44 million decrease in property and other taxes due to lower property taxes and lower franchise and gross receipts tax driven by lower revenues at Duke Energy Florida; and

•a $43 million decrease in operation, maintenance and other primarily driven by lower storm amortization at Duke Energy Florida and lower outage work at Duke Energy Indiana, partially offset by higher employee-related expenses, higher customer charge-offs and higher storm costs at Duke Energy Carolinas.

Gains on Sales of Other Assets and Other, net. The decrease was primarily due to the sale of the Mint Street parking deck in the prior year at Duke Energy Carolinas.

Interest Expense. The increase was primarily driven by higher outstanding debt balances and interest rates.

Income Tax Expense. The increase in tax expense was primarily due to an increase in pretax income. The ETRs for the nine months ended September 30, 2024, and 2023, were 14.8% and 14.4%, respectively.

98

MD&A SEGMENT RESULTS — GAS UTILITIES AND INFRASTRUCTURE

Gas Utilities and Infrastructure

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2024		2023		Variance		2024		2023		Variance
Operating Revenues	$	332	$	313	$	19	$	1,615	$	1,583	$	32
Operating Expenses
Cost of natural gas	70		57		13		380		434		(54)
Operation, maintenance and other	113		103		10		359		332		27
Depreciation and amortization	100		88		12		294		257		37
Property and other taxes	36		32		4		120		93		27
Impairment of assets and other charges	—		—		—		—		(4)		4
Total operating expenses	319		280		39		1,153		1,112		41
Losses on Sales of Other Assets and Other, net	—		—		—		—		(1)		1
Operating Income	13		33		(20)		462		470		(8)
Other Income and Expenses, net	15		39		(24)		49		86		(37)
Interest Expense	67		56		11		189		158		31
(Loss) Income Before Income Taxes	(39)		16		(55)		322		398		(76)
Income Tax (Benefit) Expense	(14)		1		(15)		57		71		(14)
Segment (Loss) Income	$	(25)	$	15	$	(40)	$	265	$	327	$	(62)
Piedmont LDC throughput (dekatherms)	162,163,516		143,224,608		18,938,908		453,695,306		426,926,457		26,768,849
Duke Energy Midwest LDC throughput (Mcf)	9,607,415		9,745,709		(138,294)		55,774,760		55,298,840		475,920

Three Months Ended September 30, 2024, as compared to September 30, 2023

GU&I’s results were impacted primarily by higher depreciation and amortization and interest expense, partially offset by higher margin growth. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

•a $5 million increase due to higher base rates, primarily from the Duke Energy Ohio rate case, partially offset by lower rider revenue at Duke Energy Ohio;

•a $4 million increase due to unregulated Renewable Natural Gas (RNG) revenue;

•a $4 million increase due to the North Carolina IMR; and

•a $4 million increase due to Tennessee ARM revenue.

Operating Expenses. The variance was driven primarily by:

•a $13 million increase in cost of natural gas due to higher volumes and higher rates passed through to customers;

•a $12 million increase in depreciation and amortization due to higher depreciable base; and

•a $10 million increase in operations, maintenance and other primarily due to higher employee-related costs, higher operating costs for new RNG projects and higher spend for outside services.

Other Income and Expenses, net. The decrease was primarily due to the revision in the prior year related to the Atlantic Coast Pipeline (ACP) ARO closure cost.

Interest Expense. The increase was primarily due to higher outstanding debt balances and interest rates.

Income Tax (Benefit) Expense. The increase in tax benefit was primarily due to a decrease in pretax income. The ETRs for the three months ended September 30, 2024, and 2023, were 35.9% and 6.3%, respectively. The increase in the ETR was primarily due to the amortization of EDIT in relation to pretax losses.

Nine Months Ended September 30, 2024, as compared to September 30, 2023

GU&I’s results were impacted primarily by higher depreciation and amortization, higher interest expense and higher property and other taxes, partially offset by higher margin growth. The following is a detailed discussion of the variance drivers by line item.

99

MD&A SEGMENT RESULTS — GAS UTILITIES AND INFRASTRUCTURE

Operating Revenues. The variance was driven primarily by:

•a $31 million increase due to higher base rates, primarily from the Duke Energy Ohio rate case, partially offset by lower rider revenue at Duke Energy Ohio;

•a $21 million increase due to Tennessee ARM revenue;

•a $16 million increase due to the North Carolina IMR;

•a $16 million increase due to unregulated RNG revenue; and

•a $10 million increase due to rate stabilization mechanisms in South Carolina.

Partially offset by:

•a $66 million decrease due to lower natural gas costs passed through to customers and lower rates, partially offset by higher volumes.

Operating Expenses. The variance was driven primarily by:

•a $37 million increase in depreciation and amortization due to higher depreciable base, higher depreciation for certain unregulated RNG projects and lower CEP deferrals;

•a $27 million increase in property and other taxes due to a higher base upon which property taxes are levied; and

•a $27 million increase in operations, maintenance and other primarily due to higher operating costs for new RNG projects, higher employee-related costs, higher IT project costs and higher spend for outside services.

Partially offset by:

•a $54 million decrease in cost of natural gas due to lower natural gas costs passed through to customers and lower rates, partially offset by higher volumes.

Other Income and Expenses, Net. The decrease was primarily due to the revision in the prior year related to the ACP ARO closure cost and lower revenue in the current year at SustainRNG.

Interest Expense. The increase was primarily due to higher outstanding debt balances and interest rates.

Income Tax (Benefit) Expense. The decrease in tax expense was primarily due to a decrease in pretax income. The ETRs for the nine months ended September 30, 2024, and 2023, were 17.7% and 17.8%, respectively.

Other

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2024		2023		Variance		2024		2023		Variance
Operating Revenues	$	42	$	33	$	9	$	120	$	98	$	22
Operating Expenses	31		4		27		157		53		104
Gains on Sales of Other Assets and Other, net	5		5		—		16		16		—
Operating Income (Loss)	16		34		(18)		(21)		61		(82)
Other Income and Expenses, net	72		47		25		218		168		50
Interest Expense	321		283		38		921		810		111
Loss Before Income Taxes	(233)		(202)		(31)		(724)		(581)		(143)
Income Tax Benefit	(66)		(182)		116		(207)		(285)		78
Less: Preferred Dividends	39		39		—		92		92		—
Less: Preferred Redemption Costs	16		—		16		16		—		16
Net Loss	$	(222)	$	(59)	$	(163)	$	(625)	$	(388)	$	(237)

Three Months Ended September 30, 2024, as compared to September 30, 2023

Other's results were impacted by a favorable prior year adjustment related to certain allowable tax deductions and higher interest expense driven by higher outstanding long-term debt balances and interest rates.

Operating Expenses. The increase was driven by franchise tax benefits recognized in the prior year.

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

Interest Expense. The increase was primarily due to higher outstanding long-term debt balances and interest rates.

100

MD&A SEGMENT RESULTS — GAS UTILITIES AND INFRASTRUCTURE

Income Tax Benefit. The decrease in the tax benefit was primarily due to the benefits associated with the tax efficiency efforts in the prior year. The ETRs for the three months ended September 30, 2024, and 2023, were 28.3% and 90.1%, respectively. The decrease in the ETR was primarily due to benefits associated with tax efficiency efforts in the prior year. In 2023, the Company evaluated the deductibility of certain items spanning periods open under federal statute, including items related to interest on company-owned life insurance. As a result of this analysis, the Company recorded a favorable adjustment in the prior year of approximately $120 million.

Preferred Redemption Costs. The increase was due to the redemption of the Company’s Series B Preferred Stock.

Nine Months Ended September 30, 2024, as compared to September 30, 2023

Other's results were impacted by higher interest expense driven by higher outstanding long-term debt balances and interest rates and decreases in the income tax benefit and franchise tax benefits.

Operating Revenues. The increase was primarily driven by favorable premiums related to captive insurance.

Operating Expenses. The increase was driven by franchise tax benefits recognized in the prior year, higher claim reserves related to captive insurance, contributions to the Duke Energy Foundation and increased expense on certain employee benefit obligations in the current year.

Other Income and Expenses, net. The variance was primarily due to higher return on investments that fund certain employee benefit obligations and higher yields on captive insurance investments.

Interest Expense. The increase was primarily due to higher outstanding long-term debt balances and interest rates.

Income Tax Benefit. The decrease in the tax benefit was primarily due to the benefits associated with tax efficiency efforts in the prior year, partially offset by an increase in pretax losses. The ETRs for the nine months ended September 30, 2024, and 2023, were 28.6% and 49.1%, respectively. The decrease in the ETR was primarily due to benefits associated with tax efficiency efforts in the prior year. In 2023, the Company evaluated the deductibility of certain items spanning periods open under federal statute, including items related to interest on company-owned life insurance. As a result of this analysis, the Company recorded a favorable adjustment in the prior year of approximately $120 million.

Preferred Redemption Costs. The increase was due to the redemption of the Company’s Series B Preferred Stock.

INCOME (LOSS) FROM DISCONTINUED OPERATIONS, NET OF TAX

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2024		2023		Variance		2024		2023		Variance
Income (Loss) From Discontinued Operations, net of tax	$	25	$	(152)	$	177	$	12	$	(1,316)	$	1,328

Three Months Ended September 30, 2024, as compared to September 30, 2023

The variance was primarily driven by impairments on the sale of the Commercial Renewables business recorded in the prior year.

Nine Months Ended September 30, 2024, as compared to September 30, 2023

The variance was primarily driven by impairments on the sale of the Commercial Renewables business recorded in the prior year.

DUKE ENERGY CAROLINAS

Results of Operations

	Nine Months Ended September 30,
(in millions)	2024		2023		Variance
Operating Revenues	$	7,411	$	6,155	$	1,256
Operating Expenses
Fuel used in electric generation and purchased power	2,531		1,823		708
Operation, maintenance and other	1,358		1,285		73
Depreciation and amortization	1,306		1,186		120
Property and other taxes	271		276		(5)
Impairment of assets and other charges	32		70		(38)
Total operating expenses	5,498		4,640		858
Gains on Sales of Other Assets and Other, net	1		26		(25)
Operating Income	1,914		1,541		373
Other Income and Expenses, net	181		181		—
Interest Expense	537		504		33
Income Before Income Taxes	1,558		1,218		340
Income Tax Expense	153		97		56
Net Income	$	1,405	$	1,121	$	284

101

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	2024
Residential sales	5.8	%
General service sales	4.0	%
Industrial sales	(0.2)	%
Wholesale power sales	14.1	%
Joint dispatch sales	2.3	%
Total sales	5.1	%
Average number of customers	2.2	%

Nine Months Ended September 30, 2024, as compared to September 30, 2023

Operating Revenues. The variance was driven primarily by:

•a $688 million increase in fuel revenues due to higher fuel rates and volumes;

•a $277 million increase due to higher pricing from the North Carolina and South Carolina rate cases;

•a $129 million increase in retail sales due to improved weather compared to prior year, including the impacts of decoupling;

•a $93 million increase in weather-normal retail sales volumes; and

•a $27 million increase in wholesale power revenues primarily due to higher contractual demand and sales.

Operating Expenses. The variance was driven primarily by:

•a $708 million increase in fuel used in electric generation and purchased power primarily due to the recovery of fuel expense, and higher volumes, partially offset by lower natural gas prices;

•a $120 million increase in depreciation and amortization primarily due to higher depreciable base and higher net amortizations driven by the North Carolina rate case; and

•a $73 million increase in operation, maintenance and other primarily due to higher employee-related expenses, higher customer charge-offs and higher storm costs.

Partially offset by:

•a $38 million decrease in impairment of assets and other charges primarily related to the prior year North Carolina rate case order and the current year South Carolina rate case order.

Gains on Sales of Other Assets and Other, net. The decrease was primarily due to the sale of the Mint Street parking deck in the prior year.

Interest Expense. The increase was primarily due to higher outstanding debt balances and interest rates.

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

102

MD&A PROGRESS ENERGY

PROGRESS ENERGY

Results of Operations

	Nine Months Ended September 30,
(in millions)	2024		2023		Variance
Operating Revenues	$	10,445	$	10,315	$	130
Operating Expenses
Fuel used in electric generation and purchased power	3,729		3,902		(173)
Operation, maintenance and other	1,869		1,963		(94)
Depreciation and amortization	1,795		1,609		186
Property and other taxes	494		546		(52)
Impairment of assets and other charges	6		29		(23)
Total operating expenses	7,893		8,049		(156)
Gains on Sales of Other Assets and Other, net	20		20		—
Operating Income	2,572		2,286		286
Other Income and Expenses, net	178		146		32
Interest Expense	796		706		90
Income Before Income Taxes	1,954		1,726		228
Income Tax Expense	320		280		40
Net Income	$	1,634	$	1,446	$	188

Nine Months Ended September 30, 2024, as compared to September 30, 2023

Operating Revenues. The variance was driven primarily by:

•a $150 million increase due to higher pricing from the North Carolina and South Carolina rate cases at Duke Energy Progress and the 2021 Settlement at Duke Energy Florida;

•a $99 million increase in weather-normal retail sales volumes at Duke Energy Progress;

•an $86 million increase in retail sales due to improved weather compared to prior year, including the impacts of decoupling, at Duke Energy Progress and Duke Energy Florida;

•a $63 million increase in Clean Energy Connection subscription revenues, higher residential fixed bill program revenues and higher transmission revenues at Duke Energy Florida;

•a $42 million increase in rider revenues primarily due to higher rates for the Storm Protection Plan at Duke Energy Florida; and

•a $12 million increase in wholesale revenues, net of fuel, due to higher sales volumes and capacity rates at Duke Energy Progress.

Partially offset by:

•a $159 million decrease in fuel and capacity revenues primarily due to lower fuel and capacity rates billed to retail customers at Duke Energy Florida, partially offset by an increase in fuel rates and volumes at Duke Energy Progress;

•a $127 million decrease in storm revenues at Duke Energy Florida; and

•a $25 million decrease in franchise tax revenue primarily due to decreased revenues over prior year at Duke Energy Florida.

Operating Expenses. The variance was driven primarily by:

•a $173 million decrease in fuel used in electric generation and purchased power primarily due to a decrease in purchased power costs driven by expiration of contracts in current year, lower fuel costs driven by lower natural gas prices and a decrease due to fuel cost recovery at Duke Energy Florida, partially offset by higher volumes and recovery of fuel expenses at Duke Energy Progress;

•a $94 million decrease in operation, maintenance and other primarily due to lower storm amortization at Duke Energy Florida;

•a $52 million decrease in property and other taxes primarily due to lower property taxes and lower franchise and gross receipts tax driven by lower revenues at Duke Energy Florida; and

•a $23 million decrease in impairment of assets and other charges due to prior year rate case impacts at Duke Energy Progress.

Partially offset by:

•a $186 million increase in depreciation and amortization due to lower amortization of the DOE settlement regulatory liability and higher depreciable base at Duke Energy Florida and higher net amortizations driven by the North Carolina rate case and higher depreciable base at Duke Energy Progress.

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MD&A PROGRESS ENERGY

Other Income and Expenses, net. The increase was primarily driven by miscellaneous income and AFUDC equity due to higher AFUDC base compared to prior year at Duke Energy Progress and other post-employment benefit activity at Duke Energy Florida.

Interest Expense. The increase was primarily due to higher outstanding debt balances and interest rates at Duke Energy Progress.

Income Tax Expense. The increase in tax expense was primarily due to an increase in pretax income, partially offset by an increase in PTCs.

DUKE ENERGY PROGRESS

Results of Operations

	Nine Months Ended September 30,
(in millions)	2024		2023		Variance
Operating Revenues	$	5,338	$	4,844	$	494
Operating Expenses
Fuel used in electric generation and purchased power	1,896		1,685		211
Operation, maintenance and other	1,077		1,051		26
Depreciation and amortization	999		935		64
Property and other taxes	144		143		1
Impairment of assets and other charges	6		31		(25)
Total operating expenses	4,122		3,845		277
Gains on Sales of Other Assets and Other, net	2		2		—
Operating Income	1,218		1,001		217
Other Income and Expenses, net	107		92		15
Interest Expense	370		315		55
Income Before Income Taxes	955		778		177
Income Tax Expense	135		101		34
Net Income	$	820	$	677	$	143

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

Increase (Decrease) over prior period	2024
Residential sales	4.4	%
General service sales	3.6	%
Industrial sales	(3.5)	%
Wholesale power sales	4.3	%
Joint dispatch sales	4.8	%
Total sales	3.8	%
Average number of customers	2.1	%

Nine Months Ended September 30, 2024, as compared to September 30, 2023

Operating Revenues. The variance was driven primarily by:

•a $227 million increase in fuel revenues due to higher fuel rates and volumes;

•a $99 million increase in weather-normal retail sales volumes;

•a $96 million increase due to higher pricing from the North Carolina and South Carolina rate cases;

•a $74 million increase in retail sales due to improved weather compared to prior year, including the impacts of decoupling; and

•a $12 million increase in wholesale revenues, net of fuel, due to higher sales volumes and capacity rates.

Operating Expenses. The variance was driven primarily by:

•a $211 million increase in fuel used in electric generation and purchased power primarily due to the recovery of fuel expenses and higher volumes, partially offset by lower natural gas prices;

•a $64 million increase in depreciation and amortization primarily due to higher net amortizations driven by the North Carolina rate case and higher depreciable base; and

•a $26 million increase in operation, maintenance and other primarily due to higher storm costs and higher employee-related expenses, partially offset by lower project costs.

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MD&A DUKE ENERGY PROGRESS

Partially offset by:

•a $25 million decrease in impairment of assets and other charges primarily due to prior year rate case impacts.

Other Income and Expenses, net. The increase was driven primarily by miscellaneous income and AFUDC equity due to higher AFUDC base compared to prior year.

Interest Expense. The increase was driven primarily by higher outstanding debt balances and interest rates.

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

DUKE ENERGY FLORIDA

Results of Operations

	Nine Months Ended September 30,
(in millions)	2024		2023		Variance
Operating Revenues	$	5,092	$	5,456	$	(364)
Operating Expenses
Fuel used in electric generation and purchased power	1,833		2,218		(385)
Operation, maintenance and other	779		898		(119)
Depreciation and amortization	796		674		122
Property and other taxes	350		403		(53)
Impairment of assets and other charges	—		(1)		1
Total operating expenses	3,758		4,192		(434)
Gains on Sales of Other Assets and Other, net	2		1		1
Operating Income	1,336		1,265		71
Other Income and Expenses, net	67		56		11
Interest Expense	339		305		34
Income Before Income Taxes	1,064		1,016		48
Income Tax Expense	212		206		6
Net Income	$	852	$	810	$	42

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	2024
Residential sales	—	%
General service sales	0.7	%
Industrial sales	(1.1)	%
Wholesale power sales	(6.1)	%
Total sales	0.2	%
Average number of customers	2.2	%

Nine Months Ended September 30, 2024, as compared to September 30, 2023

Operating Revenues. The variance was driven primarily by:

•a $385 million decrease in fuel and capacity revenues primarily due to lower fuel and capacity rates;

•a $127 million decrease in storm revenues; and

•a $25 million decrease in franchise tax revenue primarily due to decreased revenues over prior year.

Partially offset by:

•a $63 million increase in higher transmission revenues, higher Clean Energy Connection subscription revenues and higher residential fixed bill program revenues;

•a $54 million increase due to higher pricing from the 2021 Settlement;

•a $42 million increase in rider revenues primarily due to higher rates for the Storm Protection Plan, Energy Conservation Cost Recovery and Environmental Cost Recovery; and

•a $12 million increase in retail sales due to improved weather compared to prior year.

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MD&A DUKE ENERGY FLORIDA

Operating Expenses. The variance was driven primarily by:

•a $385 million decrease in fuel used in electric generation and purchased power primarily due to lower purchased power costs driven by the expiration of contracts in the current year and lower fuel costs driven by lower natural gas prices and fuel cost recovery;

•a $119 million decrease in operation, maintenance and other primarily due to lower storm amortization; and

•a $53 million decrease in property and other taxes primarily due to lower property taxes and lower franchise and gross receipts tax driven by lower revenues.

Partially offset by:

•a $122 million increase in depreciation and amortization primarily due to lower amortization of the DOE settlement regulatory liability and higher depreciable base.

Other Income and Expenses, net. The increase was primarily driven by other post-employment benefit activity.

Interest Expense. The increase was primarily driven by lower interest credits on recovery clauses due to lower deferred balances, higher outstanding debt balances and interest rates, partially offset by lower intercompany interest income.

DUKE ENERGY OHIO

Results of Operations

	Nine Months Ended September 30,
(in millions)	2024		2023		Variance
Operating Revenues
Regulated electric	$	1,431	$	1,411	$	20
Regulated natural gas	460		464		(4)
Total operating revenues	1,891		1,875		16
Operating Expenses
Fuel used in electric generation and purchased power	416		485		(69)
Cost of natural gas	100		118		(18)
Operation, maintenance and other	378		358		20
Depreciation and amortization	297		266		31
Property and other taxes	303		258		45
Total operating expenses	1,494		1,485		9
Operating Income	397		390		7
Other Income and Expenses, net	12		33		(21)
Interest Expense	144		125		19
Income Before Income Taxes	265		298		(33)
Income Tax Expense	42		47		(5)
Net Income	$	223	$	251	$	(28)

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

	Electric		Natural Gas
Increase (Decrease) over prior year	2024		2024
Residential sales	4.8	%	(0.9)	%
General service sales	4.7	%	(0.8)	%
Industrial sales	(5.9)	%	18.7	%
Wholesale electric power sales	50.8	%	n/a
Other natural gas sales	n/a		(0.9)	%
Total sales	4.5	%	0.9	%
Average number of customers	1.1	%	0.9	%

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MD&A DUKE ENERGY OHIO

Nine Months Ended September 30, 2024, as compared to September 30, 2023

Operating Revenues. The variance was driven primarily by:

•a $35 million increase in retail revenue riders primarily due to the Distribution Capital Investment Rider, Distribution Storm Rider and Uncollectible Expense Rider, partially offset by a decrease in the Energy Efficiency Rider;

•a $31 million increase due to higher pricing from the Duke Energy Ohio natural gas rate case, net of decreases in the Ohio CEP rider and Accelerated Main Replacement Program Rider;

•a $31 million increase due to higher pricing from the Duke Energy Kentucky electric rate case;

•a $30 million increase in revenues related to higher Ohio Valley Electric Corporation (OVEC) rider collections and OVEC sales into PJM Interconnection, LLC;

•a $16 million increase due to improved weather compared to prior year; and

•a $14 million increase in transmission revenue.

Partially offset by:

•a $147 million decrease in fuel-related revenues primarily due to lower full-service retail sales volumes, as well as decreased natural gas costs.

Operating Expenses. The variance was driven primarily by:

•a $45 million increase in property and other taxes primarily due to a higher base upon which property taxes are levied, partially offset by lower franchise taxes;

•a $31 million increase in depreciation and amortization primarily driven by an increase in distribution plant in service and depreciation rates resulting from the Duke Energy Kentucky electric rate case implemented in 2023 and CEP deferrals in 2024; and

•a $20 million increase in operation, maintenance and other primarily due to higher employee-related expenses and storm costs.

Partially offset by:

•an $87 million decrease in fuel expense primarily driven by lower retail prices for natural gas and purchased power and a decrease in purchased power volumes.

Other Income and Expenses, net. The decrease was primarily driven by lower intercompany interest income.

Interest Expense. The increase was primarily driven by higher outstanding debt balances and interest rates.

DUKE ENERGY INDIANA

Results of Operations

	Nine Months Ended September 30,
(in millions)	2024		2023		Variance
Operating Revenues	$	2,342	$	2,606	$	(264)
Operating Expenses
Fuel used in electric generation and purchased power	761		980		(219)
Operation, maintenance and other	510		524		(14)
Depreciation and amortization	507		500		7
Property and other taxes	37		42		(5)
Total operating expenses	1,815		2,046		(231)
Operating Income	527		560		(33)
Other Income and Expenses, net	44		58		(14)
Interest Expense	173		157		16
Income Before Income Taxes	398		461		(63)
Income Tax Expense	65		82		(17)
Net Income	$	333	$	379	$	(46)

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MD&A DUKE ENERGY INDIANA

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	2024
Residential sales	4.5	%
General service sales	2.1	%
Industrial sales	(0.4)	%
Wholesale power sales	(1.9)	%
Total sales	3.2	%
Average number of customers	1.7	%

Nine Months Ended September 30, 2024, as compared to September 30, 2023

Operating Revenues. The variance was driven primarily by:

•a $233 million decrease in retail fuel revenues primarily due to lower fuel rates; and

•a $44 million decrease in wholesale revenues, including fuel, primarily due to the expiration of wholesale customer contracts.

Partially offset by:

•a $16 million increase in retail sales due to improved weather compared to prior year.

Operating Expenses. The variance was driven primarily by:

•a $219 million decrease in fuel used in electric generation and purchased power primarily due to lower deferred fuel amortization as well as lower purchased power expense and natural gas costs, partially offset by higher coal costs; and

•a $14 million decrease in operation, maintenance and other primarily due to lower outage costs.

Other Income and Expenses, net. The decrease was primarily due to lower intercompany interest income.

Interest Expense. The increase was primarily due to higher outstanding debt balances and interest rates.

Income Tax Expense. The decrease in tax expense was primarily due to a decrease in pretax income.

PIEDMONT

Results of Operations

	Nine Months Ended September 30,
(in millions)	2024		2023		Variance
Operating Revenues	$	1,139	$	1,119	$	20
Operating Expenses
Cost of natural gas	280		316		(36)
Operation, maintenance and other	267		248		19
Depreciation and amortization	191		175		16
Property and other taxes	47		46		1
Impairment of assets and other charges	—		(4)		4
Total operating expenses	785		781		4
Operating Income	354		338		16
Other Income and Expenses, net	48		49		(1)
Interest Expense	135		120		15
Income Before Income Taxes	267		267		—
Income Tax Expense	49		46		3
Net Income	$	218	$	221	$	(3)

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MD&A PIEDMONT

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

Increase (Decrease) over prior year	2024
Residential deliveries	12.0	%
Commercial deliveries	10.3	%
Industrial deliveries	0.6	%
Power generation deliveries	6.7	%
For resale	(0.1)	%
Total throughput deliveries	6.3	%
Secondary market volumes	(8.9)	%
Average number of customers	1.6	%

Nine Months Ended September 30, 2024, as compared to September 30, 2023

Operating Revenues. The variance was driven primarily by:

•a $21 million increase due to Tennessee ARM;

•a $16 million increase due to North Carolina IMR;

•a $10 million increase due to rate stabilization mechanisms in South Carolina; and

•a $9 million increase due to customer growth.

Partially offset by:

• a $36 million decrease due to lower natural gas costs passed through to customers and lower rates, partially offset by higher volumes.

Operating Expenses. The variance was driven primarily by:

• a $19 million increase in operations, maintenance and other primarily due to higher employee-related costs, outside services, and service company costs; and

•a $16 million increase in depreciation and amortization due to higher depreciable base.

Partially offset by:

•a $36 million decrease in cost of natural gas due to lower natural gas costs passed through to customers and lower rates, partially offset by higher volumes.

Interest Expense. The increase was primarily due to higher outstanding debt balances and interest rates.

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 and projected tax credits to be generated relating to the IRA, 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, 2023, included a summary and detailed discussion of projected primary sources and uses of cash for 2024 to 2026.

In 2024, Duke Energy executed several equity forward sales agreements as part of the ATM program. Settlement of the forward sales agreements is expected to occur by December 31, 2024. See Note 15 to the Condensed Consolidated Financial Statements, “Stockholders’ Equity” for further details. Also in 2024, Duke Energy Carolinas and Duke Energy Progress began recording nuclear PTC deferred tax assets related to the IRA and began monetizing the PTCs in the transferability markets established by the IRA beginning in October 2024. Duke Energy Carolinas and Duke Energy Progress will work with the state utility commissions on the appropriate regulatory process to pass the net realizable value back to customers over time. See Note 17 to the Condensed Consolidated Financial Statements, “Income Taxes,” for further information.

As of September 30, 2024, Duke Energy had $376 million of cash on hand and $5.4 billion available under its $9 billion Master 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.

During the second quarter of 2024, Moody’s Investors Service, Inc. (Moody's) maintained the credit ratings and affirmed the ratings outlook for all of the Duke Energy Registrants, including Duke Energy Ohio. Operations in Kentucky are conducted through Duke Energy Ohio's wholly owned subsidiary, Duke Energy Kentucky. Moody's revised Duke Energy Kentucky's ratings outlook to stable, citing the expectation that a credit supportive outcome in the utility's most recent electric rate case will support credit metrics appropriate for its Baa1 rating.

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MD&A LIQUIDITY AND CAPITAL RESOURCES

As discussed in Note 13 to the Condensed Consolidated Financial Statements, "Variable Interest Entities," Duke Energy terminated and repaid CRC in March 2024 and Duke Energy Florida terminated and repaid DEFR in April 2024. As a result of these repayments, CRC and DEFR have ceased operations and no longer acquire the receivables of Duke Energy’s subsidiaries. Duke Energy Carolinas and Duke Energy Progress continue to evaluate financing opportunities and anticipate termination and repayment of the borrowing facilities of DERF and DEPR prior to their scheduled termination dates in January 2025 and April 2025, respectively.

Beginning in the third quarter of 2024, a series of major storm events occurred that resulted in significant damage to utility infrastructure within our service territories and primarily impacted Duke Energy Carolinas', Duke Energy Progress' and Duke Energy Florida's electric utility operations. As discussed in Note 4, to the Condensed Consolidated Financial Statements, "Regulatory Matters," hurricanes Debby, Helene and Milton caused widespread outages and included unprecedented damage to certain assets, including the hardest-hit areas on the western coast of Florida and certain regions in western North Carolina and upstate South Carolina. Funding restoration activities and, in some cases, the complete rebuild of critical infrastructure, for a series of sequential events of this magnitude has resulted in incremental financing needs until cost recovery occurs. See "Matters Impacting Future Results" for further details and Note 6 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities," for information regarding Duke Energy's debt issuances and maturities, available credit facilities including the Master Credit Facility, and term loans executed in response to these major storm events.

See Note 2 to the Condensed Consolidated Financial Statements, "Dispositions," for the timing and use of proceeds from the sale of certain Commercial Renewables assets to affiliates of Brookfield.

Cash Flow Information

The following table summarizes Duke Energy’s cash flows.

	Nine Months Ended
	September 30,
(in millions)	2024		2023
Cash flows provided by (used in):
Operating activities	$	8,951	$	7,309
Investing activities	(9,851)		(9,751)
Financing activities	990		2,413
Net increase (decrease) in cash, cash equivalents and restricted cash	90		(29)
Cash, cash equivalents and restricted cash at beginning of period	357		603
Cash, cash equivalents and restricted cash at end of period	$	447	$	574

OPERATING CASH FLOWS

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

	Nine Months Ended
	September 30,
(in millions)	2024		2023		Variance
Net income	$	3,387	$	1,878	$	1,509
Non-cash adjustments to net income	4,943		5,887		(944)
Contributions to qualified pension plans	(100)		(100)		—
Payments for asset retirement obligations	(417)		(423)		6
Working capital	763		(792)		1,555
Other assets and Other liabilities	375		859		(484)
Net cash provided by operating activities	$	8,951	$	7,309	$	1,642

The variance is primarily driven by:

•a $1,071 million decrease in net working capital and other assets and liabilities amounts, primarily due to the recovery of deferred fuel costs and the timing of accruals and payments; and

•a $565 million increase in net income, after adjustment for non-cash items, primarily due to growth from rate increases and riders, higher sales volumes and favorable weather, partially offset by higher interest expense and a higher effective tax rate.

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MD&A LIQUIDITY AND CAPITAL RESOURCES

INVESTING CASH FLOWS

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

	Nine Months Ended
	September 30,
(in millions)	2024		2023		Variance
Capital, investment and acquisition expenditures	$	(9,199)	$	(9,340)	$	141
Other investing items	(652)		(411)		(241)
Net cash used in investing activities	$	(9,851)	$	(9,751)	$	(100)

The variance is primarily due to higher costs of removal in the current year and net proceeds received in the prior year related to the sale of certain assets, partially offset by lower capital expenditures in the current year due to the prior year sale of the Commercial Renewables business.

FINANCING CASH FLOWS

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

	Nine Months Ended
	September 30,
(in millions)	2024		2023		Variance
Issuances of long-term debt, net	$	4,927	$	5,607	$	(680)
Redemption of preferred stock	(1,000)		—		(1,000)
Notes payable, commercial paper and other short-term borrowings	(515)		(939)		424
Dividends paid	(2,411)		(2,438)		27
Contributions from noncontrolling interests	47		278		(231)
Other financing items	(58)		(95)		37
Net cash provided by financing activities	$	990	$	2,413	$	(1,423)

The variance is primarily due to:

•a $1 billion decrease due to the redemption of Series B preferred stock in the current year;

•a $680 million decrease in proceeds from net issuances of long-term debt, primarily due to timing of issuances and redemptions of long-term debt; and

•a $231 million decrease in contributions from noncontrolling interests, primarily due to the prior year sale of the Commercial Renewables business.

Partially offset by:

•a $424 million increase in net borrowings from notes payable and commercial paper.

OTHER MATTERS

Environmental Regulations

The Duke Energy Registrants are subject to federal, state and local regulations regarding air and water quality, hazardous and solid waste disposal, 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 4, "Regulatory Matters," in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2023, for more information regarding potential plant retirements and Note 4, "Regulatory Matters," to the Condensed Consolidated Financial Statements, for further information regarding regulatory filings related to the Duke Energy Registrants.

In April 2024, the EPA issued the 2024 CCR Rule under the Resource Conservation and Recovery Act, which significantly expands the scope of the 2015 CCR Rule by establishing regulatory requirements for inactive surface impoundments at retired generating facilities (Legacy CCR Surface Impoundments). The final rule also imposes a subset of the 2015 CCR Rule’s requirements, including groundwater monitoring, corrective action (where necessary), and in certain cases, closure, and post-closure care requirements, on previously unregulated coal ash sources at regulated facilities (CCR Management Units). CCR Management Units may include surface impoundments and landfills that closed prior to the effective date of the 2015 CCR Rule, inactive CCR landfills, and other areas where CCR is managed directly on the land at Duke Energy facilities. Duke Energy, as part of a group of similarly affected electric utilities, filed a petition to challenge the 2024 CCR Rule in the U.S. Court of Appeals for the District of Columbia Circuit on August 6, 2024. For more information, see Note 7 to the Condensed Consolidated Financial Statements, "Asset Retirement Obligations."

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MD&A OTHER MATTERS

In April 2024, the EPA issued a final rule under section 111 of the Clean Air Act (EPA Rule 111) regulating GHG emissions from existing coal-fired and new natural gas-fired power plants, referred to as electric generating units (EGUs). EPA Rule 111 requires existing coal-fired power plants expected to operate in 2039 and beyond to reduce GHG emissions by 90% through the use of carbon capture and sequestration starting in 2032, subject to certain modifications for coal plants that retire sooner and co-fire natural gas. EPA Rule 111 also establishes GHG emissions reduction standards for new natural gas-fired EGUs, subject to carve-outs for smaller peaking units that fill gaps that cannot be met with renewables or storage. The EPA did not finalize emission guidelines for GHG emissions from existing fossil fuel-fired stationary combustion turbines and intends to address these in a future rulemaking. Duke Energy is analyzing the potential impacts the rule could have on the Company, which could be material and may influence the timing, nature, and magnitude of future generation investments in our service territories. Duke Energy is participating in legal challenges to EPA Rule 111 as a member of Electric Generators for a Sensible Transition, a coalition of similarly affected utilities, and as a member of a utility trade group. The litigation is currently pending in the United States Court of Appeals for the D.C. Circuit.

Cost recovery for future expenditures is anticipated and will be pursued through the normal ratemaking process with federal and state utility commissions, which permit recovery of reasonable and prudently incurred costs associated with Duke Energy’s regulated operations.

Generation Mix Planning Process

In August 2023, Duke Energy Carolinas and Duke Energy Progress filed their 2023 systemwide Carolinas Resource Plan (the Plan) with the NCUC and PSCSC. The Plan provided a range of generation options, including three core portfolios, reflecting an “all of the above” approach to powering the energy needs of our growing region. In the Plan, Duke Energy Carolinas and Duke Energy Progress recommended Portfolio 3 as the most prudent path forward to comply with applicable state laws, providing a reliable and orderly energy transition that was proposed as the most reasonable, executable, and lowest-cost plan for the Carolinas. Portfolio 3 proposes a diverse and reliable set of generation and energy storage solutions and shrinks the challenges of growth and the transition from coal by expanding industry-leading energy efficiency and demand response options, laying out a path to reliably exit coal by 2035. Portfolio 3 also makes the most of existing system resources by extending the lives of Duke Energy’s nuclear plants and extending the license and doubling the peak hourly capacity of the Bad Creek pumped-hydro storage facility. Near-term actions consistent with Portfolio 3 were also proposed that will be executed between now and the end of 2026 to advance the orderly energy transition.

In November 2023, Duke Energy Carolinas and Duke Energy Progress provided notice to the NCUC and PSCSC of a substantially increased load forecast resulting from increased economic development in the Carolinas occurring since the systemwide Plan was prepared. The companies filed supplemental modeling and analysis with the NCUC and PSCSC in January 2024, demonstrating the need for additional resources beyond the set of resources identified by the companies in their initial plan.

In July 2024, Duke Energy Carolinas and Duke Energy Progress reached a broad settlement with the Public Staff of the NCUC, Walmart, and the Carolinas Clean Energy Business Association on the Plan, agreeing it is reasonable to use Portfolio 3 as the reference portfolio for planning purposes. Among other things, the settlement confirms a set of near-term activities, including development and procurement activities for solar, battery storage, onshore wind, and certain natural gas generation assets, as well as certain limited actions exploring initial development activities related to advanced nuclear, offshore wind, and to advance the potential for 1,834 MW of pumped storage hydro at the Bad Creek II facility by 2034. The NCUC conducted evidentiary hearings in July and August 2024 and issued an order accepting the settlement and providing further direction in November 2024. The order continues to emphasize the critical importance of reliability and maintaining affordability, while taking balanced actions to meet forecasted load growth.

The PSCSC held its hearings in September 2024 and in November 2024 voted to approve the Plan and directed Duke Energy Carolinas and Duke Energy Progress to work with the South Carolina Office of Regulatory Staff to provide alternative modeling around EPA Rule 111 compliance in a subsequent Carolinas Resource Plan filing.

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 Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2023.

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 September 30, 2024, and, based on 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 September 30, 2024, and have concluded no change has materially affected, or is reasonably likely to materially affect, internal controls over financial reporting.

112

OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The Duke Energy Registrants are, from time to time, parties to various lawsuits and regulatory proceedings in the ordinary course of their business. For information regarding legal proceedings, including regulatory and environmental matters, see Note 4, "Regulatory Matters," and Note 5, "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, 2023.

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 Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2023, which could materially affect the Duke Energy Registrants’ financial condition or future results. The information presented below updates, and should be read in conjunction with, the risk factors and information disclosed in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2023.

BUSINESS STRATEGY RISKS

Duke Energy’s future results could be adversely affected if it is unable to implement its business strategy including achieving its carbon emissions reduction goals.

Duke Energy’s results of operations depend, in significant part, on the extent to which it can implement its business strategy successfully. Duke Energy's clean energy transition, which includes achieving net-zero carbon emissions from electricity generation by 2050, modernizing the regulatory construct, transforming the customer experience, and digital transformation, is subject to business, policy, regulatory, technology, economic and competitive uncertainties and contingencies, many of which are beyond its control and may make those goals difficult to achieve.

Federal or state policies could be enacted that restrict the availability of, and increase the costs associated with the use of, fuels or generation technologies, such as natural gas or nuclear power, that enable Duke Energy to reduce its carbon emissions. For example, new EPA rules issued in April 2024 impose stringent GHG emission reduction standards, revised air toxic limits, and wastewater discharge limitations that may impact our carbon-reduction targets, and operational timeline and costs associated with certain new and existing generation. Supportive policies may be needed to facilitate the siting and cost recovery of transmission and distribution upgrades needed to accommodate the build out of large volumes of renewables and energy storage. Further, the approval of our state regulators will be necessary for the Company to continue to retire existing carbon emitting assets or make investments in new generating capacity. The Company may be constrained by the ability to procure resources or labor needed to build new generation at a reasonable price as well as to construct projects on time. In addition, new technologies that are not yet commercially available or are unproven at utility-scale will likely be needed, including carbon capture and sequestration and supporting infrastructure as well as new resources capable of following electric load over long durations such as advanced nuclear, hydrogen and long-duration storage. If these technologies are not developed or are not available at reasonable prices, or if we invest in early stage technologies that are then supplanted by technological breakthroughs, Duke Energy’s ability to achieve a net-zero target by 2050 at a cost-effective price could be at risk.

Achieving our carbon reduction goals will require continued operation of our existing carbon-free technologies including nuclear and renewables. The rapid transition to and expansion of certain low-carbon resources, such as renewables without cost-effective storage, may challenge our ability to meet customer expectations of reliability and affordability in a carbon constrained environment, particularly as demand increases. Our nuclear fleet is central to our ability to meet these objectives and customer expectations. We are continuing to seek to renew the operating licenses of the 11 reactors we operate at six nuclear stations for an additional 20 years, extending their operating lives to and beyond midcentury. Failure to receive approval from the NRC for the relicensing of any of these reactors could affect our ability to achieve a net-zero target by 2050.

As a consequence, Duke Energy may not be able to fully implement or realize the anticipated results of its energy transition strategy, which may have an adverse effect on its financial condition.

113

OTHER INFORMATION

REGULATORY, LEGISLATIVE AND LEGAL RISKS

The Duke Energy Registrants are subject to numerous environmental laws and regulations requiring significant capital expenditures that can increase the cost of operations, and which may impact or limit business plans, or cause exposure to environmental liabilities.

The Duke Energy Registrants are subject to numerous environmental laws and regulations affecting many aspects of their present and future operations, including CCRs, air emissions, water quality, wastewater discharges, solid waste and hazardous waste. For example, the new EPA rules issued in April 2024, among other things, impose stringent GHG emissions limitations on existing coal plants and new natural gas plants and more stringent air toxic limits on existing coal plants, increase limitations on wastewater discharge, and impose groundwater monitoring and corrective action requirements on previously unregulated coal ash sources at regulated facilities (CCR Management Units) and inactive surface impoundments at retired generating facilities (Legacy CCR Surface Impoundments). Potential legal challenges to such rules may not be successful, and adherence to these rules may increase the cost of compliance, impact generation resource mix and carbon-reduction targets, and negatively impact customer reliability and affordability due to such rules' imposition of stringent GHG emissions limitations and reliance on carbon capture technologies that are not yet adequately demonstrated at utility-scale. These and other environmental laws and regulations can result in increased capital, operating and other costs. These laws and regulations generally require the Duke Energy Registrants to obtain and comply with a wide variety of environmental licenses, permits, inspections and other approvals. Compliance with environmental laws and regulations can require significant expenditures, including expenditures for cleanup costs and damages arising from contaminated properties. Failure to comply with environmental regulations may result in the imposition of fines, penalties and injunctive measures affecting operating assets, as well as reputational damage. The steps the Duke Energy Registrants could be required to take to ensure their facilities are in compliance could be prohibitively expensive. As a result, the Duke Energy Registrants may be required to shut down or alter the operation of their facilities, which may cause the Duke Energy Registrants to incur losses. Further, the Duke Energy Registrants may not be successful in recovering capital and operating costs incurred to comply with new environmental regulations through existing regulatory rate structures and their contracts with customers. Also, the Duke Energy Registrants may not be able to obtain or maintain from time to time all required environmental regulatory approvals for their operating assets or development projects. Delays in obtaining any required environmental regulatory approvals, failure to obtain and comply with them or changes in environmental laws or regulations to more stringent compliance levels could, and are likely to, result in additional costs of operation for existing facilities or development of new facilities being prevented, delayed or subject to additional costs. The costs to comply with environmental laws and regulations could have a material effect on the Duke Energy Registrants’ results of operations, financial position or cash flows.

The EPA has issued or proposed federal regulations, including the new rules issued in April 2024, governing the management of cooling water intake structures, wastewater, CCR management units, air toxics emissions, and CO2 emissions. New state legislation in response to such regulations could impose carbon reduction goals that are more aggressive than the Company's plans. These regulations may require the Duke Energy Registrants to make additional capital expenditures and increase operating and maintenance costs.

OPERATIONAL RISKS

The reputation and financial condition of the Duke Energy Registrants could be negatively impacted due to their obligations to comply with federal and state regulations, laws, and other legal requirements that govern the operations, assessments, storage, closure, remediation, disposal and monitoring relating to CCR, the high costs and new rate impacts associated with implementing these new CCR-related requirements and the strategies and methods necessary to implement these requirements in compliance with these legal obligations.

As a result of electricity produced for decades at coal-fired power plants, the Duke Energy Registrants manage large amounts of CCR that are primarily stored in dry storage within landfills or combined with water in surface impoundments, all in compliance with applicable regulatory requirements. A CCR-related operational incident could have a material adverse impact on the reputation and results of operations, financial position and cash flows of the Duke Energy Registrants.

During 2015, EPA regulations were enacted related to the management of CCR from power plants. These regulations classify CCR as nonhazardous waste under the RCRA and apply to electric generating sites with new and existing landfills and, new and existing surface impoundments, and establish requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring, protection and remedial procedures and other operational and reporting procedures for the disposal and management of CCR. In addition to the federal regulations, CCR landfills and surface impoundments will continue to be regulated by existing state laws, regulations and permits, as well as additional legal requirements that may be imposed in the future, such as the settlement reached with the NCDEQ to excavate seven of the nine remaining coal ash basins in North Carolina, and partially excavate the remaining two, and the EPA's January 11, 2022, issuance of a letter interpreting the CCR Rule, including its applicability and closure provisions. Most recently, in April 2024, the EPA issued its final Legacy Surface Impoundment Rule, which significantly expands the scope of the 2015 CCR Rule to apply to legacy CCR surface impoundments (inactive impoundments at retired facilities) and CCR management units (previously unregulated coal ash sources at regulated facilities). These federal and state laws, regulations and other legal requirements may require or result in additional expenditures, including increased operating and maintenance costs, which could affect the results of operations, financial position and cash flows of the Duke Energy Registrants. The Duke Energy Registrants will continue to seek full cost recovery for expenditures through the normal ratemaking process with state and federal utility commissions, who permit recovery in rates of reasonable and prudently incurred costs associated with the Duke Energy Registrants’ regulated operations, and through other wholesale contracts with terms that contemplate recovery of such costs, although there is no guarantee of full cost recovery. In addition, the timing for and amount of recovery of such costs could have a material adverse impact on Duke Energy's cash flows.

The Duke Energy Registrants have recognized significant AROs related to these CCR-related requirements. Closure activities began in 2015 at the four sites specified as high priority by the Coal Ash Act and at the W.S. Lee Steam Station site in South Carolina in connection with other legal requirements. Excavation at these sites involves movement of CCR materials to off-site locations for use as structural fill, to appropriately engineered off-site or on-site lined landfills or conversion of the ash for beneficial use. Duke Energy has completed excavation of coal ash at the four high-priority North Carolina sites. At other sites, planning and closure methods have been studied and factored into the estimated retirement and management costs, and closure activities have commenced. As the closure and CCR management work progresses and final closure plans and corrective action measures are developed and approved at each site, the scope and complexity of work and the amount of CCR material could be greater than estimates and could, therefore, materially increase compliance expenditures and rate impacts.

114

OTHER INFORMATION

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

None.

ITEM 5. OTHER INFORMATION

Director and Officer Trading Arrangements

During the three months ended September 30, 2024, no director or officer of the Company adopted, terminated or modified a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement, as each term is defined in Item 408(a) of Regulation S-K.

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EXHIBITS

ITEM 6. EXHIBITS

Exhibits filed herein are designated by an asterisk (*). All exhibits not so designated are incorporated by reference to a prior filing, as indicated. Items constituting management contracts or compensatory plans or arrangements are designated by a double asterisk (**). The Company agrees to furnish upon request to the commission a copy of any omitted schedules or exhibits upon request on all items designated by a triple asterisk (***).

			Duke		Duke	Duke	Duke	Duke
Exhibit		Duke	Energy	Progress	Energy	Energy	Energy	Energy
Number		Energy	Carolinas	Energy	Progress	Florida	Ohio	Indiana	Piedmont
4.1	Fourteenth Supplemental Indenture, dated as of August 14, 2024, between the registrant 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 to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on August 14, 2024, File No. 1-6196).								X
4.2	Thirty-fourth Supplemental Indenture, dated as of August 22, 2024, between the registrant and The Bank of New York Mellon Trust Company, N.A., as Trustee, and form of global debenture included therein (incorporated by reference to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on August 22, 2024, File No. 1-32853).	X
*31.1.1	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.	X
*31.1.2	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.		X
*31.1.3	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.			X
*31.1.4	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.				X
*31.1.5	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.					X
*31.1.6	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.						X
*31.1.7	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.							X
*31.1.8	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.								X
*31.2.1	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.	X
*31.2.2	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.		X
*31.2.3	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.			X
*31.2.4	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.				X
*31.2.5	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.					X
*31.2.6	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.						X

116

EXHIBITS

*31.2.7	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.							X
*31.2.8	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.								X
*32.1.1	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.	X
*32.1.2	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.		X
*32.1.3	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.			X
*32.1.4	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.				X
*32.1.5	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.					X
*32.1.6	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.						X
*32.1.7	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.							X
*32.1.8	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.								X
*32.2.1	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.	X
*32.2.2	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.		X
*32.2.3	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.			X
*32.2.4	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.				X
*32.2.5	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.					X
*32.2.6	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.						X
*32.2.7	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.							X
*32.2.8	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.								X
*101.INS	XBRL Instance Document (this does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document).	X	X	X	X	X	X	X	X

117

EXHIBITS

*101.SCH	XBRL Taxonomy Extension Schema Document.	X	X	X	X	X	X	X	X
*101.CAL	XBRL Taxonomy Calculation Linkbase Document.	X	X	X	X	X	X	X	X
*101.LAB	XBRL Taxonomy Label Linkbase Document.	X	X	X	X	X	X	X	X
*101.PRE	XBRL Taxonomy Presentation Linkbase Document.	X	X	X	X	X	X	X	X
*101.DEF	XBRL Taxonomy Definition Linkbase Document.	X	X	X	X	X	X	X	X
*104	Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibit 101).	X	X	X	X	X	X	X	X

The total amount of securities of the registrant or its subsidiaries authorized under any instrument with respect to long-term debt not filed as an exhibit does not exceed 10% of the total assets of the registrant and its subsidiaries on a consolidated basis. The registrant agrees, upon request of the SEC, to furnish copies of any or all of such instruments to it.

118

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:	November 7, 2024	/s/ BRIAN D. SAVOY
		Brian D. Savoy Executive Vice President and Chief Financial Officer (Principal Financial Officer)
Date:	November 7, 2024	/s/ CYNTHIA S. LEE
		Cynthia S. Lee Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)

119