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Duke Energy
DUK
#227
Rank
$99.28 B
Marketcap
๐Ÿ‡บ๐Ÿ‡ธ United States
Country
$127.67
Share price
2.10%
Change (1 day)
12.70%
Change (1 year)
๐Ÿ›ข Oil&Gas๐Ÿ”‹ Electricity๐Ÿšฐ Utility companies โšก Energy
Categories
  1. Duke Energy
  2. Quarterly Reports (10-Q)
  3. Financial Year FY2021 Q3

Duke Energy - 10-Q quarterly report FY2021 Q3


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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, 2021
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 numberRegistrant, State of Incorporation or Organization,
Address of Principal Executive Offices and Telephone Number		IRS Employer Identification Number
duk-20210930_g1.jpg
1-32853
DUKE ENERGY CORPORATION
20-2777218
(a Delaware corporation)
526 South Church Street
Charlotte, North Carolina 28202-1803
704-382-3853
1-4928
DUKE ENERGY CAROLINAS, LLC
56-0205520
(a North Carolina limited liability company)
526 South Church Street
Charlotte, North Carolina 28202-1803
704-382-3853
1-15929
PROGRESS ENERGY, INC.
56-2155481
(a North Carolina corporation)
410 South Wilmington Street
Raleigh, North Carolina 27601-1748
704-382-3853
1-3382
DUKE ENERGY PROGRESS, LLC
56-0165465
(a North Carolina limited liability company)
410 South Wilmington Street
Raleigh, North Carolina 27601-1748
704-382-3853
1-3274
DUKE ENERGY FLORIDA, LLC
59-0247770
(a Florida limited liability company)
299 First Avenue North
St. Petersburg, Florida 33701
704-382-3853
1-1232
DUKE ENERGY OHIO, INC.
31-0240030
(an Ohio corporation)
139 East Fourth Street
Cincinnati, Ohio 45202
704-382-3853
1-3543
DUKE ENERGY INDIANA, LLC
35-0594457
(an Indiana limited liability company)
1000 East Main Street
Plainfield, Indiana 46168
704-382-3853
1-6196
PIEDMONT NATURAL GAS COMPANY, INC.
56-0556998
(a North Carolina corporation)
4720 Piedmont Row Drive
Charlotte, North Carolina 28210
704-364-3120




SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
Name of each exchange on
Registrant    Title of each class    Trading symbols        which registered
Duke Energy    Common Stock, $0.001 par value    DUK    New York Stock Exchange LLC

Duke Energy    5.625% Junior Subordinated Debentures due    DUKB    New York Stock Exchange LLC
September 15, 2078
Duke Energy    Depositary Shares, each representing a 1/1,000th    DUK PR A    New York Stock Exchange LLC
interest in a share of 5.75% Series A Cumulative
Redeemable Perpetual Preferred Stock, par value
$0.001 per share
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Duke Energy Corporation (Duke Energy)Yes☒No☐Duke Energy Florida, LLC (Duke Energy Florida)Yes☒No☐
Duke Energy Carolinas, LLC (Duke Energy Carolinas)Yes☒No☐Duke Energy Ohio, Inc. (Duke Energy Ohio)Yes☒No☐
Progress Energy, Inc. (Progress Energy)Yes☒No☐Duke Energy Indiana, LLC (Duke Energy Indiana)Yes☒No☐
Duke Energy Progress, LLC (Duke Energy Progress)Yes☒No☐Piedmont Natural Gas Company, Inc. (Piedmont)Yes☒No☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Duke EnergyYes☒No☐Duke Energy FloridaYes☒No☐
Duke Energy CarolinasYes☒No☐Duke Energy OhioYes☒No☐
Progress EnergyYes☒No☐Duke Energy IndianaYes☒No☐
Duke Energy ProgressYes☒No☐PiedmontYes☒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 EnergyLarge Accelerated Filer☒Accelerated filer☐Non-accelerated Filer☐Smaller reporting company☐Emerging growth company☐
Duke Energy CarolinasLarge Accelerated Filer☐Accelerated filer☐Non-accelerated Filer☒Smaller reporting company☐Emerging growth company☐
Progress EnergyLarge Accelerated Filer☐Accelerated filer☐Non-accelerated Filer☒Smaller reporting company☐Emerging growth company☐
Duke Energy ProgressLarge Accelerated Filer☐Accelerated filer☐Non-accelerated Filer☒Smaller reporting company☐Emerging growth company☐
Duke Energy FloridaLarge Accelerated Filer☐Accelerated filer☐Non-accelerated Filer☒Smaller reporting company☐Emerging growth company☐
Duke Energy OhioLarge Accelerated Filer☐Accelerated filer☐Non-accelerated Filer☒Smaller reporting company☐Emerging growth company☐
Duke Energy IndianaLarge Accelerated Filer☐Accelerated filer☐Non-accelerated Filer☒Smaller reporting company☐Emerging growth company☐
PiedmontLarge 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 EnergyYes
☐
No☒Duke Energy FloridaYes
☐
No☒
Duke Energy CarolinasYes
☐
No☒Duke Energy OhioYes
☐
No☒
Progress EnergyYes
☐
No☒Duke Energy IndianaYes
☐
No☒
Duke Energy ProgressYes
☐
No☒PiedmontYes
☐
No☒
Number of shares of common stock outstanding at October 31, 2021:
RegistrantDescriptionShares
Duke EnergyCommon stock, $0.001 par value769,343,372


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
PART I. FINANCIAL INFORMATION
9
15
19
23
27
31
35
Piedmont Natural Gas Company, Inc. Financial Statements
39
Note 1 – Organization and Basis of Presentation
43
Note 2 – Business Segments
45
Note 3 – Regulatory Matters
49
Note 4 – Commitments and Contingencies
59
Note 5 – Debt and Credit Facilities
62
Note 6 – Goodwill
63
Note 7 – Related Party Transactions
64
Note 8 – Derivatives and Hedging
65
Note 9 – Investments in Debt and Equity Securities
70
Note 10 – Fair Value Measurements
75
Note 11 – Variable Interest Entities
80
Note 12 – Revenue
83
Note 13 – Stockholders' Equity
89
Note 14 – Employee Benefit Plans
90
Note 15 – Income Taxes
91
Note 16 – Subsequent Events
92
93
110
111
PART II. OTHER INFORMATION
112
112
112
113
116


FORWARD-LOOKING STATEMENTS

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION
This document includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are based on management’s beliefs and assumptions and can often be identified by terms and phrases that include “anticipate,” “believe,” “intend,” “estimate,” “expect,” “continue,” “should,” “could,” “may,” “plan,” “project,” “predict,” “will,” “potential,” “forecast,” “target,” “guidance,” “outlook” or other similar terminology. Various factors may cause actual results to be materially different than the suggested outcomes within forward-looking statements; accordingly, there is no assurance that such results will be realized. These factors include, but are not limited to:
◦The impact of the COVID-19 pandemic;
◦State, federal and foreign legislative and regulatory initiatives, including costs of compliance with existing and future environmental requirements, including those related to climate change, as well as rulings that affect cost and investment recovery or have an impact on rate structures or market prices;
◦The extent and timing of costs and liabilities to comply with federal and state laws, regulations and legal requirements related to coal ash remediation, including amounts for required closure of certain ash impoundments, are uncertain and difficult to estimate;
◦The ability to recover eligible costs, including amounts associated with coal ash impoundment retirement obligations and costs related to significant weather events, and to earn an adequate return on investment through rate case proceedings and the regulatory process;
◦The costs of decommissioning nuclear facilities could prove to be more extensive than amounts estimated and all costs may not be fully recoverable through the regulatory process;
◦Costs and effects of legal and administrative proceedings, settlements, investigations and claims;
◦Industrial, commercial and residential growth or decline in service territories or customer bases resulting from sustained downturns of the economy and the economic health of our service territories or variations in customer usage patterns, including energy efficiency efforts and use of alternative energy sources, such as self-generation and distributed generation technologies;
◦Federal and state regulations, laws and other efforts designed to promote and expand the use of energy efficiency measures and distributed generation technologies, such as private solar and battery storage, in Duke Energy service territories could result in customers leaving the electric distribution system, excess generation resources as well as stranded costs;
◦Advancements in technology;
◦Additional competition in electric and natural gas markets and continued industry consolidation;
◦The influence of weather and other natural phenomena on operations, including the economic, operational and other effects of severe storms, hurricanes, droughts, earthquakes and tornadoes, including extreme weather associated with climate change;
◦Changing customer expectations and demands including heightened emphasis on environmental, social and governance concerns;
◦The ability to successfully operate electric generating facilities and deliver electricity to customers including direct or indirect effects to the company resulting from an incident that affects the U.S. electric grid or generating resources;
◦Operational interruptions to our natural gas distribution and transmission activities;
◦The availability of adequate interstate pipeline transportation capacity and natural gas supply;
◦The impact on facilities and business from a terrorist attack, cybersecurity threats, data security breaches, operational accidents, information technology failures or other catastrophic events, such as fires, explosions, pandemic health events or other similar occurrences;
◦The inherent risks associated with the operation of nuclear facilities, including environmental, health, safety, regulatory and financial risks, including the financial stability of third-party service providers;
◦The timing and extent of changes in commodity prices and interest rates and the ability to recover such costs through the regulatory process, where appropriate, and their impact on liquidity positions and the value of underlying assets;
◦The results of financing efforts, including the ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings, interest rate fluctuations, compliance with debt covenants and conditions and general market and economic conditions;
◦Credit ratings of the Duke Energy Registrants may be different from what is expected;
◦Declines in the market prices of equity and fixed-income securities and resultant cash funding requirements for defined benefit pension plans, other post-retirement benefit plans and nuclear decommissioning trust funds;
◦Construction and development risks associated with the completion of the Duke Energy Registrants’ capital investment projects, including risks related to financing, obtaining and complying with terms of permits, meeting construction budgets and schedules and satisfying operating and environmental performance standards, as well as the ability to recover costs from customers in a timely manner, or at all;
◦Changes in rules for regional transmission organizations, including changes in rate designs and new and evolving capacity markets, and risks related to obligations created by the default of other participants;
◦The ability to control operation and maintenance costs;
◦The level of creditworthiness of counterparties to transactions;
◦The ability to obtain adequate insurance at acceptable costs;
◦Employee workforce factors, including the potential inability to attract and retain key personnel;

FORWARD-LOOKING STATEMENTS

◦The ability of subsidiaries to pay dividends or distributions to Duke Energy Corporation holding company (the Parent);
◦The performance of projects undertaken by our nonregulated businesses and the success of efforts to invest in and develop new opportunities;
◦The effect of accounting pronouncements issued periodically by accounting standard-setting bodies;
◦The impact of U.S. tax legislation to our financial condition, results of operations or cash flows and our credit ratings;
◦The impacts from potential impairments of goodwill or equity method investment carrying values;
◦Asset or business acquisitions and dispositions, including our ability to successfully consummate the second closing of the minority investment in Duke Energy Indiana, may not yield the anticipated benefits;
◦The actions of activist shareholders could disrupt our operations, impact our ability to execute on our business strategy, or cause fluctuations in the trading price of our common stock; and
◦The ability to implement our business strategy, including enhancing existing technology systems.
Additional risks and uncertainties are identified and discussed in the Duke Energy Registrants' reports filed with the SEC and available at the SEC's website at sec.gov. In light of these risks, uncertainties and assumptions, the events described in the forward-looking statements might not occur or might occur to a different extent or at a different time than described. Forward-looking statements speak only as of the date they are made and the Duke Energy Registrants expressly disclaim an obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

GLOSSARY OF TERMS

Glossary of Terms 
The following terms or acronyms used in this Form 10-Q are defined below:
Term or AcronymDefinition
2013 SettlementRevised and Restated Stipulation and Settlement Agreement approved in November 2013 among Duke Energy Florida, the Florida Office of Public Counsel and other customer representatives
2017 SettlementSecond Revised and Restated Settlement Agreement in 2017 among Duke Energy Florida, the Florida Office of Public Counsel and other customer representatives, which replaces and supplants the 2013 Settlement
2021 SettlementSettlement 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.
ACPAtlantic Coast Pipeline, LLC, a limited liability company owned by Dominion Energy, Inc. and Duke Energy
ACP pipelineThe approximately 600-mile canceled interstate natural gas pipeline
AFSAvailable for Sale
AFUDCAllowance for funds used during construction
AROAsset retirement obligations
BisonBison Insurance Company Limited
BoardDuke Energy Board of Directors
CCRCoal Combustion Residuals
Coal Ash ActNorth Carolina Coal Ash Management Act of 2014
the companyDuke Energy Corporation and its subsidiaries
COVID-19Coronavirus Disease 2019
CRCCinergy Receivables Company, LLC
Crystal River Unit 3Crystal River Unit 3 Nuclear Plant
DEFPFDuke Energy Florida Project Finance, LLC
DEFRDuke Energy Florida Receivables, LLC
DEPRDuke Energy Progress Receivables, LLC
DERFDuke Energy Receivables Finance Company, LLC
Duke EnergyDuke Energy Corporation (collectively with its subsidiaries)
Duke Energy OhioDuke Energy Ohio, Inc.
Duke Energy ProgressDuke Energy Progress, LLC
Duke Energy CarolinasDuke Energy Carolinas, LLC
Duke Energy FloridaDuke Energy Florida, LLC
Duke Energy IndianaDuke Energy Indiana, LLC
Duke Energy KentuckyDuke Energy Kentucky, Inc.
Duke Energy RegistrantsDuke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont
EDITExcess deferred income tax
ElliottElliott Investment Management, L.P.
EPSEarnings Per Share
ETREffective tax rate
Exchange ActSecurities Exchange Act of 1934
FERCFederal Energy Regulatory Commission
FPSCFlorida Public Service Commission
FTRFinancial transmission rights
GAAPGenerally accepted accounting principles in the U.S.

GLOSSARY OF TERMS

GAAP Reported EarningsNet Income Available to Duke Energy Corporation Common Stockholders
GAAP Reported EPSBasic Earnings Per Share Available to Duke Energy Corporation common stockholders
GICGIC Private Limited, Singapore's sovereign wealth fund and an experienced investor in U.S. infrastructure
GWhGigawatt-hours
IMRIntegrity Management Rider
IRSInternal Revenue Service
Investment TrustsNDTF investments and grantor trusts of Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana
IURCIndiana Utility Regulatory Commission
KPSCKentucky Public Service Commission
LLCLimited Liability Company
MGPManufactured gas plant
MWMegawatt
MWhMegawatt-hour
NCUCNorth Carolina Utilities Commission
NDTFNuclear decommissioning trust funds
NPNSNormal purchase/normal sale
OPEBOther Post-Retirement Benefit Obligations
OVECOhio Valley Electric Corporation
PiedmontPiedmont Natural Gas Company, Inc.
PJMPennsylvania-New Jersey-Maryland Interconnection
PPAPurchase Power Agreement
Progress EnergyProgress Energy, Inc.
PSCSCPublic Service Commission of South Carolina
PUCOPublic Utilities Commission of Ohio
RTORegional Transmission Organization
Subsidiary RegistrantsDuke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont
the Tax ActTax Cuts and Jobs Act
TPUCTennessee Public Utility Commission
U.S.United States
VIEVariable Interest Entity
WACCWeighted Average Cost of Capital


FINANCIAL STATEMENTS

ITEM 1. FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION
Condensed Consolidated Statements of Operations
(Unaudited)
Three Months EndedNine Months Ended
September 30,September 30,
(in millions, except per share amounts)2021202020212020
Operating Revenues
Regulated electric$6,495 $6,315 $16,972 $16,402 
Regulated natural gas263 214 1,314 1,115 
Nonregulated electric and other193 192 573 574 
Total operating revenues6,951 6,721 18,859 18,091 
Operating Expenses
Fuel used in electric generation and purchased power1,844 1,849 4,702 4,645 
Cost of natural gas75 41 430 299 
Operation, maintenance and other1,507 1,450 4,319 4,142 
Depreciation and amortization1,265 1,217 3,698 3,497 
Property and other taxes371 324 1,073 1,003 
Impairment of assets and other charges211 28 342 36 
Total operating expenses5,273 4,909 14,564 13,622 
Gains on Sales of Other Assets and Other, net9 2 11 10 
Operating Income1,687 1,814 4,306 4,479 
Other Income and Expenses
Equity in earnings (losses) of unconsolidated affiliates22 (80)14 (2,004)
Other income and expenses, net238 127 493 310 
Total other income and expenses260 47 507 (1,694)
Interest Expense581 522 1,688 1,627 
Income Before Income Taxes1,366 1,339 3,125 1,158 
Income Tax Expense (Benefit)90 105 210 (74)
Net Income1,276 1,234 2,915 1,232 
Add: Net Loss Attributable to Noncontrolling Interests129 70 247 208 
Net Income Attributable to Duke Energy Corporation1,405 1,304 3,162 1,440 
Less: Preferred Dividends39 39 92 93 
Net Income Available to Duke Energy Corporation Common Stockholders$1,366 $1,265 $3,070 $1,347 
Earnings Per Share – Basic and Diluted
Net income available to Duke Energy Corporation common stockholders
Basic and Diluted$1.79 $1.74 $4.00 $1.85 
Weighted Average Shares Outstanding
Basic and Diluted769 735 769 735 

See Notes to Condensed Consolidated Financial Statements
9
FINANCIAL STATEMENTS
DUKE ENERGY CORPORATION
Condensed Consolidated Statements of Comprehensive Income
(Unaudited)
Three Months EndedNine Months Ended
September 30,September 30,
(in millions)2021202020212020
Net Income$1,276 $1,234 $2,915 $1,232 
Other Comprehensive Income (Loss), net of tax(a)
Pension and OPEB adjustments1 1 3 1 
Net unrealized gains (losses) on cash flow hedges9 (83)(59)(159)
Reclassification into earnings from cash flow hedges2 4 9 8 
Unrealized (losses) gains on available-for-sale securities(2)(2)(6)5 
Other Comprehensive Income (Loss), net of tax10 (80)(53)(145)
Comprehensive Income1,286 1,154 2,862 1,087 
Add: Comprehensive Loss Attributable to Noncontrolling Interests128 70 240 220 
Comprehensive Income Attributable to Duke Energy1,414 1,224 3,102 1,307 
Less: Preferred Dividends39 39 92 93 
Comprehensive Income Available to Duke Energy Corporation Common Stockholders$1,375 $1,185 $3,010 $1,214 
(a)Net of income tax impacts of approximately $24 million for the three months ended September 30, 2020, and $16 million and $43 million for the nine months ended September 30, 2021, and 2020, respectively. All other periods presented include immaterial income tax impacts.
See Notes to Condensed Consolidated Financial Statements
10
FINANCIAL STATEMENTS
DUKE ENERGY CORPORATION
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)September 30, 2021December 31, 2020
ASSETS
Current Assets
Cash and cash equivalents$548 $259 
Receivables (net of allowance for doubtful accounts of $48 at 2021 and $29 at 2020)
998 1,009 
Receivables of VIEs (net of allowance for doubtful accounts of $75 at 2021 and $117 at 2020)
2,431 2,144 
Inventory2,900 3,167 
Regulatory assets (includes $54 at 2021 and $53 at 2020 related to VIEs)
1,791 1,641 
Other (includes $347 at 2021 and $296 at 2020 related to VIEs)
768 462 
Total current assets9,436 8,682 
Property, Plant and Equipment
Cost160,652 155,580 
Accumulated depreciation and amortization(50,543)(48,827)
Facilities to be retired, net127 29 
Net property, plant and equipment110,236 106,782 
Other Noncurrent Assets
Goodwill19,303 19,303 
Regulatory assets (includes $896 at 2021 and $937 at 2020 related to VIEs)
12,247 12,421 
Nuclear decommissioning trust funds9,861 9,114 
Operating lease right-of-use assets, net1,287 1,524 
Investments in equity method unconsolidated affiliates951 961 
Other (includes $134 at 2021 and $81 at 2020 related to VIEs)
3,686 3,601 
Total other noncurrent assets47,335 46,924 
Total Assets$167,007 $162,388 
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable$2,888 $3,144 
Notes payable and commercial paper2,098 2,873 
Taxes accrued908 482 
Interest accrued558 537 
Current maturities of long-term debt (includes $221 at 2021 and $472 at 2020 related to VIEs)
4,873 4,238 
Asset retirement obligations673 718 
Regulatory liabilities1,319 1,377 
Other 2,239 2,936 
Total current liabilities15,556 16,305 
Long-Term Debt (includes $3,923 at 2021 and $3,535 at 2020 related to VIEs)
57,929 55,625 
Other Noncurrent Liabilities
Deferred income taxes9,875 9,244 
Asset retirement obligations12,278 12,286 
Regulatory liabilities15,530 15,029 
Operating lease liabilities1,093 1,340 
Accrued pension and other post-retirement benefit costs988 969 
Investment tax credits804 687 
Other (includes $341 at 2021 and $316 at 2020 related to VIEs)
1,714 1,719 
Total other noncurrent liabilities42,282 41,274 
Commitments and Contingencies
Equity
Preferred stock, Series A, $0.001 par value, 40 million depositary shares authorized and outstanding at 2021 and 2020
973 973 
Preferred stock, Series B, $0.001 par value, 1 million shares authorized and outstanding at 2021 and 2020
989 989 
Common stock, $0.001 par value, 2 billion shares authorized; 769 million shares outstanding at 2021 and 2020
1 1 
Additional paid-in capital44,348 43,767 
Retained earnings3,293 2,471 
Accumulated other comprehensive loss(297)(237)
Total Duke Energy Corporation stockholders' equity49,307 47,964 
Noncontrolling interests1,933 1,220 
Total equity51,240 49,184 
Total Liabilities and Equity$167,007 $162,388 

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)20212020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income$2,915 $1,232 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)4,189 4,081 
Equity in (earnings) losses of unconsolidated affiliates(14)2,004 
Equity component of AFUDC(126)(112)
Impairment of assets and other charges342 36 
Deferred income taxes206 210 
Payments for asset retirement obligations(389)(463)
Provision for rate refunds(41)(15)
Refund of AMT credit carryforwards— 572 
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions116 87 
Receivables(167)58 
Inventory268 43 
Other current assets(643)199 
Increase (decrease) in
Accounts payable(146)(563)
Taxes accrued431 386 
Other current liabilities10 (284)
Other assets199 (338)
Other liabilities77 (367)
Net cash provided by operating activities7,227 6,766 
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures(7,089)(7,408)
Contributions to equity method investments(30)(276)
Purchases of debt and equity securities(4,292)(6,160)
Proceeds from sales and maturities of debt and equity securities4,335 6,087 
Disbursements to canceled equity method investments(855)— 
Other(269)(207)
Net cash used in investing activities(8,200)(7,964)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt6,379 6,162 
Issuance of common stock5 75 
Payments for the redemption of long-term debt(3,696)(3,468)
Proceeds from the issuance of short-term debt with original maturities greater than 90 days109 2,372 
Payments for the redemption of short-term debt with original maturities greater than 90 days(997)(1,143)
Notes payable and commercial paper165 (969)
Contributions from noncontrolling interests1,556 402 
Dividends paid(2,340)(2,113)
Other(21)(93)
Net cash provided by financing activities1,160 1,225 
Net increase in cash, cash equivalents and restricted cash187 27 
Cash, cash equivalents and restricted cash at beginning of period556 573 
Cash, cash equivalents and restricted cash at end of period$743 $600 
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures$998 $992 
Non-cash dividends— 82 

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, 2020 and 2021
Accumulated Other Comprehensive
 (Loss) Income
Net UnrealizedTotal
Net Gains(Losses) Gains Duke Energy
CommonAdditional(Losses) onon Available-Pension and Corporation
PreferredStockCommonPaid-inRetainedCash Flowfor-Sale-OPEB Stockholders'NoncontrollingTotal
(in millions)StockSharesStockCapitalEarningsHedgesSecuritiesAdjustmentsEquityInterestsEquity
Balance at June 30, 2020$1,962 735 $1 $40,997 $2,707 $(111)$10 $(82)$45,484 $1,127 $46,611 
Net income (loss)— — — — 1,265 — — — 1,265 (70)1,195 
Other comprehensive (loss) income— — — — — (79)(2)1 (80)— (80)
Common stock issuances, including dividend reinvestment and employee benefits— 1 — 65 — — — — 65 — 65 
Common stock dividends— — — — (712)— — — (712)— (712)
Contribution from noncontrolling interests, net of transaction costs(a)
— — — (17)— — — — (17)239 222 
Distributions to noncontrolling interest in subsidiaries— — — — — — — — — (8)(8)
Other— — — 1 — — — — 1 1 2 
Balance at September 30, 2020$1,962 $736 $1 $41,046 $3,260 $(190)$8 $(81)$46,006 $1,289 $47,295 
Balance at June 30, 2021$1,962 769 $1 $43,788 $2,687 $(234)$2 $(74)$48,132 $1,413 $49,545 
Net income (loss)— — — — 1,366 — — — 1,366 (129)1,237 
Other comprehensive income (loss)— — — — — 10 (2)1 9 1 10 
Common stock issuances, including dividend reinvestment and employee benefits— — — 20 — — — — 20 — 20 
Common stock dividends— — — — (760)— — — (760)— (760)
Sale of noncontrolling interest(c)
— — — 545 — — — — 545 454 999 
Contribution from noncontrolling interests, net of transaction costs(a)
— — — (3)— — — — (3)213 210 
Distributions to noncontrolling interest in subsidiaries— — — — — — — — — (22)(22)
Other— — — (2)— — — — (2)3 1 
Balance at September 30, 2021$1,962 $769 $1 $44,348 $3,293 $(224)$— $(73)$49,307 $1,933 $51,240 

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, 2020 and 2021
Accumulated Other Comprehensive
 (Loss) Income
Net UnrealizedTotal
Net GainsGains (Losses)Duke Energy
CommonAdditional(Losses) onon Available-Pension and Corporation
PreferredStockCommonPaid-inRetainedCash Flowfor-Sale-OPEB Stockholders'NoncontrollingTotal
(in millions)StockSharesStockCapitalEarningsHedgesSecuritiesAdjustmentsEquityInterestsEquity
Balance at December 31, 2019$1,962 733 $1 $40,881 $4,108 $(51)$3 $(82)$46,822 $1,129 $47,951 
Net income (loss)— — — — 1,347 — — — 1,347 (208)1,139 
Other comprehensive (loss) income— — — — — (139)5 1 (133)(12)(145)
Common stock issuances, including dividend reinvestment and employee benefits— 3 — 181 — — — — 181 — 181 
Common stock dividends— — — — (2,103)— — — (2,103)— (2,103)
Contributions from noncontrolling interests, net of transaction costs(a)
— — — (17)— — — — (17)402 385 
Distributions to noncontrolling interest in subsidiaries— — — — — — — — — (22)(22)
Other(b)
— — — 1 (92)— — — (91)— (91)
Balance at September 30, 2020$1,962 736 $1 $41,046 $3,260 $(190)$8 $(81)$46,006 $1,289 $47,295 
Balance at December 31, 2020$1,962 769 $1 $43,767 $2,471 $(167)$6 $(76)$47,964 $1,220 $49,184 
Net income (loss)— — — — 3,070 — — — 3,070 (247)2,823 
Other comprehensive (loss) income— — — — — (57)(6)3 (60)7 (53)
Common stock issuances, including dividend reinvestment and employee benefits— — — 43 — — — — 43 — 43 
Common stock dividends— — — — (2,248)— — — (2,248)— (2,248)
Sale of noncontrolling interest(c)
— — — 545 — — — — 545 454 999 
Contributions from noncontrolling interests, net of transaction costs(a)
— — — (6)— — — — (6)531 525 
Distributions to noncontrolling interest in subsidiaries— — — — — — — — — (34)(34)
Other— — — (1)— — — — (1)2 1 
Balance at September 30, 2021$1,962 769 $1 $44,348 $3,293 $(224)$— $(73)$49,307 $1,933 $51,240 
(a)Relates to tax equity financing activity in the Commercial Renewables segment.
(b)Amounts in Retained earnings primarily represent impacts due to implementation of a new accounting standard related to Current Estimated Credit Losses. See Note 1 for additional discussion.
(c)Relates to the sale of a noncontrolling interest in Duke Energy Indiana. See Note 2 for additional discussion.
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 EndedNine Months Ended
September 30,September 30,
(in millions)2021202020212020
Operating Revenues$2,104 $2,058 $5,430 $5,416 
Operating Expenses
Fuel used in electric generation and purchased power452 497 1,218 1,326 
Operation, maintenance and other471 402 1,347 1,218 
Depreciation and amortization366 372 1,088 1,090 
Property and other taxes91 57 248 213 
Impairment of assets and other charges163 20 238 22 
Total operating expenses1,543 1,348 4,139 3,869 
(Losses) Gains on Sales of Other Assets and Other, net(1)1 1 1 
Operating Income560 711 1,292 1,548 
Other Income and Expenses, net126 42 218 128 
Interest Expense137 122 400 370 
Income Before Income Taxes549 631 1,110 1,306 
Income Tax Expense16 76 40 178 
Net Income and Comprehensive Income$533 $555 $1,070 $1,128 

See Notes to Condensed Consolidated Financial Statements
15
FINANCIAL STATEMENTS
DUKE ENERGY CAROLINAS, LLC
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)September 30, 2021December 31, 2020
ASSETS
Current Assets
Cash and cash equivalents$21 $21 
Receivables (net of allowance for doubtful accounts of $2 at 2021 and $1 at 2020)
278 247 
Receivables of VIEs (net of allowance for doubtful accounts of $40 at 2021 and $22 at 2020)
915 696 
Receivables from affiliated companies85 124 
Inventory969 1,010 
Regulatory assets460 473 
Other104 20 
Total current assets2,832 2,591 
Property, Plant and Equipment
Cost51,790 50,640 
Accumulated depreciation and amortization(17,959)(17,453)
Facilities to be retired, net89 — 
Net property, plant and equipment33,920 33,187 
Other Noncurrent Assets
Regulatory assets2,743 2,996 
Nuclear decommissioning trust funds5,434 4,977 
Operating lease right-of-use assets, net95 110 
Other1,197 1,187 
Total other noncurrent assets9,469 9,270 
Total Assets$46,221 $45,048 
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable$673 $1,000 
Accounts payable to affiliated companies184 199 
Notes payable to affiliated companies86 506 
Taxes accrued391 76 
Interest accrued137 117 
Current maturities of long-term debt357 506 
Asset retirement obligations245 264 
Regulatory liabilities503 473 
Other 516 546 
Total current liabilities3,092 3,687 
Long-Term Debt12,318 11,412 
Long-Term Debt Payable to Affiliated Companies300 300 
Other Noncurrent Liabilities
Deferred income taxes3,893 3,842 
Asset retirement obligations5,134 5,086 
Regulatory liabilities6,867 6,535 
Operating lease liabilities83 97 
Accrued pension and other post-retirement benefit costs64 73 
Investment tax credits288 236 
Other558 626 
Total other noncurrent liabilities16,887 16,495 
Commitments and Contingencies
Equity
Member's equity13,631 13,161 
Accumulated other comprehensive loss(7)(7)
Total equity13,624 13,154 
Total Liabilities and Equity$46,221 $45,048 

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)20212020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income$1,070 $1,128 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)1,295 1,295 
Equity component of AFUDC(46)(46)
Loss on sales of other assets(1)— 
Impairment of assets and other charges238 22 
Deferred income taxes(146)(103)
Payments for asset retirement obligations(132)(127)
Provision for rate refunds(29)(1)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions(1)— 
Receivables(172)41 
Receivables from affiliated companies39 50 
Inventory41 4 
Other current assets(153)197 
Increase (decrease) in
Accounts payable(254)(313)
Accounts payable to affiliated companies(15)(55)
Taxes accrued315 352 
Other current liabilities72 (121)
Other assets52 (72)
Other liabilities167 (23)
Net cash provided by operating activities2,340 2,228 
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures(1,947)(1,931)
Purchases of debt and equity securities(2,465)(1,313)
Proceeds from sales and maturities of debt and equity securities2,465 1,313 
Notes receivable from affiliated companies— (65)
Other(122)(105)
Net cash used in investing activities(2,069)(2,101)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt1,367 965 
Payments for the redemption of long-term debt(616)(457)
Notes payable to affiliated companies(421)(29)
Distributions to parent(600)(600)
Other(1)(1)
Net cash used in financing activities(271)(122)
Net increase in cash and cash equivalents— 5 
Cash and cash equivalents at beginning of period21 18 
Cash and cash equivalents at end of period$21 $23 
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures$308 $295 

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, 2020 and 2021
Accumulated Other
Comprehensive
Loss
Member'sNet Losses onTotal
(in millions)EquityCash Flow HedgesEquity
Balance at June 30, 2020$13,079 $(7)$13,072 
Net income555 — 555 
Distributions to parent(300)— (300)
Other(1)— (1)
Balance at September 30, 2020$13,333 $(7)$13,326 
Balance at June 30, 2021$13,399 $(7)$13,392 
Net income533 — 533 
Distributions to parent(300)— (300)
Other(1)— (1)
Balance at September 30, 2021$13,631 $(7)$13,624 
Nine Months Ended September 30, 2020 and 2021
Accumulated Other
Comprehensive
Loss
Member'sNet Losses onTotal
(in millions)EquityCash Flow HedgesEquity
Balance at December 31, 2019$12,818 $(7)$12,811 
Net income1,128 — 1,128 
Distributions to parent(600)— (600)
Other(a)
(13)— (13)
Balance at September 30, 2020$13,333 $(7)$13,326 
Balance at December 31, 2020$13,161 $(7)$13,154 
Net income1,070 — 1,070 
Distributions to parent(600)— (600)
Balance at September 30, 2021$13,631 $(7)$13,624 
(a)Amounts primarily represent impacts due to implementation of a new accounting standard related to Current Estimated Credit Losses. See Note 1 for additional discussion.
See Notes to Condensed Consolidated Financial Statements
18
FINANCIAL STATEMENTS

PROGRESS ENERGY, INC.
Condensed Consolidated Statements of Operations and Comprehensive Income
(Unaudited)
Three Months EndedNine Months Ended
September 30,September 30,
(in millions)2021202020212020
Operating Revenues$3,233 $3,197 $8,417 $8,117 
Operating Expenses
Fuel used in electric generation and purchased power1,074 1,088 2,702 2,628 
Operation, maintenance and other636 646 1,863 1,789 
Depreciation and amortization504 472 1,430 1,356 
Property and other taxes144 147 419 419 
Impairment of assets and other charges42 1 79 1 
Total operating expenses2,400 2,354 6,493 6,193 
Gains on Sales of Other Assets and Other, net8 3 9 9 
Operating Income841 846 1,933 1,933 
Other Income and Expenses, net86 24 167 89 
Interest Expense200 194 592 599 
Income Before Income Taxes727 676 1,508 1,423 
Income Tax Expense94 70 174 190 
Net Income633 606 $1,334 $1,233 
Less: Net Income Attributable to Noncontrolling Interests1 1 1 1 
Net Income Attributable to Parent$632 $605 $1,333 $1,232 
Net Income$633 $606 $1,334 $1,233 
Other Comprehensive Income, net of tax
Pension and OPEB adjustments (1)— — 1 
Net unrealized gains on cash flow hedges1 1 2 3 
Unrealized gains on available-for-sale securities— 1 — 1 
Other Comprehensive Income, net of tax— 2 2 5 
Comprehensive Income633 608 $1,336 $1,238 
Less: Comprehensive Income Attributable to Noncontrolling Interests1 1 1 1 
Comprehensive Income Attributable to Parent$632 $607 $1,335 $1,237 

See Notes to Condensed Consolidated Financial Statements
19
FINANCIAL STATEMENTS
PROGRESS ENERGY, INC.
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)September 30, 2021December 31, 2020
ASSETS
Current Assets
Cash and cash equivalents$102 $59 
Receivables (net of allowance for doubtful accounts of $11 at 2021 and $8 at 2020)
268 228 
Receivables of VIEs (net of allowance for doubtful accounts of $25 at 2021 and $29 at 2020)
981 901 
Receivables from affiliated companies61 157 
Inventory1,255 1,375 
Regulatory assets (includes $54 at 2021 and $53 at 2020 related to VIEs)
864 758 
Other (includes $17 at 2021 and $39 at 2020 related to VIEs)
178 109 
Total current assets3,709 3,587 
Property, Plant and Equipment
Cost59,976 57,892 
Accumulated depreciation and amortization(19,211)(18,368)
Facilities to be retired, net27 29 
Net property, plant and equipment40,792 39,553 
Other Noncurrent Assets
Goodwill3,655 3,655 
Regulatory assets (includes $896 at 2021 and $937 at 2020 related to VIEs)
5,785 5,775 
Nuclear decommissioning trust funds4,427 4,137 
Operating lease right-of-use assets, net714 690 
Other1,175 1,227 
Total other noncurrent assets15,756 15,484 
Total Assets$60,257 $58,624 
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable$898 $919 
Accounts payable to affiliated companies221 289 
Notes payable to affiliated companies3,123 2,969 
Taxes accrued284 121 
Interest accrued175 202 
Current maturities of long-term debt (includes $56 at 2021 and $305 at 2020 related to VIEs)
1,932 1,426 
Asset retirement obligations234 283 
Regulatory liabilities541 640 
Other856 793 
Total current liabilities8,264 7,642 
Long-Term Debt (includes $1,546 at 2021 and $1,252 at 2020 related to VIEs)
17,406 17,688 
Long-Term Debt Payable to Affiliated Companies150 150 
Other Noncurrent Liabilities
Deferred income taxes4,784 4,396 
Asset retirement obligations5,850 5,866 
Regulatory liabilities5,335 5,051 
Operating lease liabilities623 623 
Accrued pension and other post-retirement benefit costs490 505 
Other473 462 
Total other noncurrent liabilities17,555 16,903 
Commitments and Contingencies
Equity
Common Stock, $0.01 par value, 100 shares authorized and outstanding at 2021 and 2020
— — 
Additional paid-in capital9,149 9,143 
Retained earnings7,743 7,109 
Accumulated other comprehensive loss(13)(15)
Total Progress Energy, Inc. stockholders' equity16,879 16,237 
Noncontrolling interests3 4 
Total equity16,882 16,241 
Total Liabilities and Equity$60,257 $58,624 
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)20212020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income$1,334 $1,233 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)1,707 1,734 
Equity component of AFUDC(37)(30)
Impairment of assets and other charges79 1 
Deferred income taxes235 (3)
Payments for asset retirement obligations(206)(287)
Provision for rate refunds(22)4 
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions117 (13)
Receivables(123)(207)
Receivables from affiliated companies96 32 
Inventory120 46 
Other current assets(347)214 
Increase (decrease) in
Accounts payable79 (124)
Accounts payable to affiliated companies(68)(102)
Taxes accrued161 263 
Other current liabilities(36)(41)
Other assets(3)(154)
Other liabilities(139)(102)
Net cash provided by operating activities2,947 2,464 
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures(2,628)(2,602)
Purchases of debt and equity securities(1,583)(4,554)
Proceeds from sales and maturities of debt and equity securities1,649 4,543 
Notes receivable from affiliated companies— 164 
Other(131)(114)
Net cash used in investing activities(2,693)(2,563)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt1,190 1,791 
Payments for the redemption of long-term debt(977)(1,555)
Notes payable to affiliated companies154 338 
Dividends to parent(700)(400)
Other(2)(13)
Net cash (used in) provided by financing activities(335)161 
Net (decrease) increase in cash, cash equivalents and restricted cash(81)62 
Cash, cash equivalents and restricted cash at beginning of period200 126 
Cash, cash equivalents and restricted cash at end of period$119 $188 
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures$290 $311 
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, 2020 and 2021
Accumulated Other Comprehensive Loss
Net GainsNet UnrealizedTotal Progress
Additional(Losses) onGains (Losses) onPension andEnergy, Inc.
Paid-inRetainedCash FlowAvailable-for-OPEBStockholders'NoncontrollingTotal
(in millions)CapitalEarningsHedgesSale SecuritiesAdjustmentsEquityInterestsEquity
Balance at June 30, 2020$9,143 $7,090 $(8)$(1)$(6)$16,218 $3 $16,221 
Net income— 605 — — — 605 1 606 
Other comprehensive income— — 1 1 — 2 — 2 
Dividends to parent— (400)— — — (400)— (400)
Other— 1 — — — 1 (1)— 
Balance at September 30, 2020$9,143 $7,296 $(7)$— $(6)$16,426 $3 $16,429 
Balance at June 30, 2021$9,143 $7,809 $(4)$(2)$(7)$16,939 $3 $16,942 
Net income— 632 — — — 632 1 633 
Other comprehensive income (loss)— — 1 — (1)— — — 
Dividends to parent— (700)— — — (700)— (700)
Other6 2 — — — 8 (1)7 
Balance at September 30, 2021$9,149 $7,743 $(3)$(2)$(8)$16,879 $3 $16,882 
Nine Months Ended September 30, 2020 and 2021
Accumulated Other Comprehensive Loss
Net GainsNet UnrealizedTotal Progress
Additional(Losses) onGains (Losses) onPension andEnergy, Inc.
Paid-inRetainedCash FlowAvailable-for-OPEBStockholders'NoncontrollingTotal
CapitalEarningsHedgesSale SecuritiesAdjustmentsEquityInterestsEquity
Balance at December 31, 2019$9,143 $6,465 $(10)$(1)$(7)$15,590 $3 $15,593 
Net income— 1,232 — — — 1,232 1 1,233 
Other comprehensive income— — 3 1 1 5 — 5 
Distributions to noncontrolling interests— — — — — — (1)(1)
Dividends to parent— (400)— — — (400)— (400)
Other— (1)— — — (1)— (1)
Balance at September 30, 2020$9,143 $7,296 $(7)$— $(6)$16,426 $3 $16,429 
Balance at December 31, 2020$9,143 $7,109 $(5)$(2)$(8)$16,237 $4 $16,241 
Net income— 1,333 — — — 1,333 1 1,334 
Other comprehensive income— — 2 — — 2 — 2 
Distributions to noncontrolling interests— — — — — — (1)(1)
Dividends to parent— (700)— — — (700)— (700)
Other6 1 — — — 7 (1)6 
Balance at September 30, 2021$9,149 $7,743 $(3)$(2)$(8)$16,879 $3 $16,882 
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 EndedNine Months Ended
September 30,September 30,
(in millions)2021202020212020
Operating Revenues$1,667 $1,626 $4,417 $4,207 
Operating Expenses
Fuel used in electric generation and purchased power523 537 1,368 1,337 
Operation, maintenance and other368 348 1,092 970 
Depreciation and amortization290 289 811 833 
Property and other taxes39 38 129 129 
Impairment of assets and other charges42 5 60 5 
Total operating expenses1,262 1,217 3,460 3,274 
Gains on Sales of Other Assets and Other, net7 3 8 8 
Operating Income412 412 965 941 
Other Income and Expenses, net67 11 111 52 
Interest Expense79 66 226 203 
Income Before Income Taxes400 357 850 790 
Income Tax Expense25 11 50 79 
Net Income and Comprehensive Income$375 $346 $800 $711 

See Notes to Condensed Consolidated Financial Statements
23
FINANCIAL STATEMENTS
DUKE ENERGY PROGRESS, LLC
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)September 30, 2021December 31, 2020
ASSETS
Current Assets
Cash and cash equivalents$51 $39 
Receivables (net of allowance for doubtful accounts of $4 at 2021 and 2020)
162 132 
Receivables of VIEs (net of allowance for doubtful accounts of $17 at 2021 and $19 at 2020)
532 500 
Receivables from affiliated companies68 50 
Inventory815 911 
Regulatory assets499 492 
Other116 60 
Total current assets2,243 2,184 
Property, Plant and Equipment
Cost36,666 35,759 
Accumulated depreciation and amortization(13,365)(12,801)
Facilities to be retired, net27 29 
Net property, plant and equipment23,328 22,987 
Other Noncurrent Assets
Regulatory assets3,955 3,976 
Nuclear decommissioning trust funds3,857 3,500 
Operating lease right-of-use assets, net402 346 
Other772 740 
Total other noncurrent assets8,986 8,562 
Total Assets$34,557 $33,733 
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable$392 $454 
Accounts payable to affiliated companies113 215 
Notes payable to affiliated companies117 295 
Taxes accrued163 85 
Interest accrued68 99 
Current maturities of long-term debt1,207 603 
Asset retirement obligations234 283 
Regulatory liabilities439 530 
Other442 411 
Total current liabilities3,175 2,975 
Long-Term Debt8,491 8,505 
Long-Term Debt Payable to Affiliated Companies150 150 
Other Noncurrent Liabilities
Deferred income taxes2,488 2,298 
Asset retirement obligations5,407 5,352 
Regulatory liabilities4,685 4,394 
Operating lease liabilities359 323 
Accrued pension and other post-retirement benefit costs234 242 
Investment tax credits129 132 
Other79 102 
Total other noncurrent liabilities13,381 12,843 
Commitments and Contingencies
Equity
Member's Equity9,360 9,260 
Total Liabilities and Equity$34,557 $33,733 

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)20212020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income$800 $711 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)951 972 
Equity component of AFUDC(25)(22)
Impairment of assets and other charges60 5 
Deferred income taxes22 (33)
Payments for asset retirement obligations(129)(249)
Provision for rate refunds(22)4 
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions108 — 
Receivables(66)(34)
Receivables from affiliated companies(18)7 
Inventory95 24 
Other current assets(79)82 
Increase (decrease) in
Accounts payable20 (185)
Accounts payable to affiliated companies(102)(59)
Taxes accrued75 190 
Other current liabilities(36)(24)
Other assets48 (185)
Other liabilities(32)21 
Net cash provided by operating activities1,670 1,225 
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures(1,313)(1,142)
Purchases of debt and equity securities(1,306)(1,269)
Proceeds from sales and maturities of debt and equity securities1,291 1,238 
Other(36)(31)
Net cash used in investing activities(1,364)(1,204)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt1,190 1,296 
Payments for the redemption of long-term debt(605)(985)
Notes payable to affiliated companies(178)101 
Distributions to parent(700)(400)
Other(1)(12)
Net cash used in financing activities(294)— 
Net increase in cash and cash equivalents12 21 
Cash and cash equivalents at beginning of period39 22 
Cash and cash equivalents at end of period$51 $43 
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures$82 $124 

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, 2020 and 2021
(in millions)Member's Equity
Balance at June 30, 2020$9,610 
Net income346 
Distributions to parent(400)
Balance at September 30, 2020$9,556 
Balance at June 30, 2021$9,685 
Net income375 
Distributions to parent(700)
Balance at September 30, 2021$9,360 
Nine Months Ended
September 30, 2020 and 2021
(in millions)Member's Equity
Balance at December 31, 2019$9,246 
Net income711 
Distributions to parent(400)
Other(1)
Balance at September 30, 2020$9,556 
Balance at December 31, 2020$9,260 
Net income800 
Distributions to parent(700)
Balance at September 30, 2021$9,360 

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 EndedNine Months Ended
September 30,September 30,
(in millions)2021202020212020
Operating Revenues$1,561 $1,567 $3,987 $3,897 
Operating Expenses
Fuel used in electric generation and purchased power552 551 1,335 1,291 
Operation, maintenance and other263 292 760 806 
Depreciation and amortization214 183 619 523 
Property and other taxes105 110 290 290 
Impairment of assets and other charges— (4)19 (4)
Total operating expenses1,134 1,132 3,023 2,906 
Gains on Sales of Other Assets and Other, net1 — 1 — 
Operating Income428 435 965 991 
Other Income and Expenses, net18 11 54 36 
Interest Expense79 81 239 245 
Income Before Income Taxes367 365 780 782 
Income Tax Expense70 78 149 159 
Net Income$297 $287 $631 $623 
Other Comprehensive Income, net of tax
Unrealized gains on available-for-sale securities— 1 — 1 
Comprehensive Income$297 $288 $631 $624 

See Notes to Condensed Consolidated Financial Statements
27
FINANCIAL STATEMENTS
DUKE ENERGY FLORIDA, LLC
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)September 30, 2021December 31, 2020
ASSETS
Current Assets
Cash and cash equivalents$40 $11 
Receivables (net of allowance for doubtful accounts of $8 at 2021 and $4 at 2020)
104 94 
Receivables of VIEs (net of allowance for doubtful accounts of $8 at 2021 and $10 at 2020)
449 401 
Receivables from affiliated companies3 3 
Inventory439 464 
Regulatory assets (includes $54 at 2021 and $53 at 2020 related to VIEs)
365 265 
Other (includes $17 at 2021 and $39 at 2020 related to VIEs)
35 41 
Total current assets1,435 1,279 
Property, Plant and Equipment
Cost23,300 22,123 
Accumulated depreciation and amortization(5,839)(5,560)
Net property, plant and equipment17,461 16,563 
Other Noncurrent Assets
Regulatory assets (includes $896 at 2021 and $937 at 2020 related to VIEs)
1,829 1,799 
Nuclear decommissioning trust funds570 637 
Operating lease right-of-use assets, net312 344 
Other351 335 
Total other noncurrent assets3,062 3,115 
Total Assets$21,958 $20,957 
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable$506 $465 
Accounts payable to affiliated companies129 85 
Notes payable to affiliated companies603 196 
Taxes accrued177 82 
Interest accrued72 69 
Current maturities of long-term debt (includes $56 at 2021 and $305 at 2020 related to VIEs)
276 823 
Regulatory liabilities102 110 
Other403 374 
Total current liabilities2,268 2,204 
Long-Term Debt (includes $1,196 at 2021 and $1,002 at 2020 related to VIEs)
7,273 7,092 
Other Noncurrent Liabilities
Deferred income taxes2,382 2,191 
Asset retirement obligations443 514 
Regulatory liabilities649 658 
Operating lease liabilities265 300 
Accrued pension and other post-retirement benefit costs225 231 
Other265 209 
Total other noncurrent liabilities4,229 4,103 
Commitments and Contingencies
Equity
Member's equity8,190 7,560 
Accumulated other comprehensive loss(2)(2)
Total equity8,188 7,558 
Total Liabilities and Equity$21,958 $20,957 

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)20212020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income$631 $623 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion752 755 
Equity component of AFUDC(12)(8)
Impairment of assets and other charges19 (4)
Deferred income taxes207 19 
Payments for asset retirement obligations(77)(38)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions7 (17)
Receivables(57)(172)
Receivables from affiliated companies— (3)
Inventory25 22 
Other current assets(247)41 
Increase (decrease) in
Accounts payable59 63 
Accounts payable to affiliated companies44 (54)
Taxes accrued95 217 
Other current liabilities(5)(20)
Other assets(46)48 
Other liabilities(94)(136)
Net cash provided by operating activities1,301 1,336 
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures(1,316)(1,460)
Purchases of debt and equity securities(277)(3,284)
Proceeds from sales and maturities of debt and equity securities358 3,305 
Notes receivable from affiliated companies— 173 
Other(95)(82)
Net cash used in investing activities(1,330)(1,348)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt— 495 
Payments for the redemption of long-term debt(372)(570)
Notes payable to affiliated companies408 66 
Net cash provided by (used in) financing activities36 (9)
Net increase (decrease) in cash, cash equivalents and restricted cash7 (21)
Cash, cash equivalents and restricted cash at beginning of period50 56 
Cash, cash equivalents and restricted cash at end of period$57 $35 
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures$208 $187 

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, 2020 and 2021
Accumulated
Other
Comprehensive
Income (Loss)
Net Unrealized
Losses on
Member'sAvailable-for-SaleTotal
(in millions)EquitySecuritiesEquity
Balance at June 30, 2020$7,125 $(1)$7,124 
Net income287 — 287 
Other comprehensive income— 1 1 
Other(1)— (1)
Balance at September 30, 2020$7,411 $— $7,411 
Balance at June 30, 2021$7,893 $(2)$7,891 
Net income297 — 297 
Balance at September 30, 2021$8,190 $(2)$8,188 
Nine Months Ended September 30, 2020 and 2021
Accumulated
Other
Comprehensive
Income (Loss)
Net Unrealized
Losses on
Member'sAvailable-for-SaleTotal
(in millions)EquitySecuritiesEquity
Balance at December 31, 2019$6,789 $(1)$6,788 
Net income623 — 623 
Other comprehensive income— 1 1 
Other(1)— (1)
Balance at September 30, 2020$7,411 $— $7,411 
Balance at December 31, 2020$7,560 $(2)$7,558 
Net income631 — 631 
Other(1)— (1)
Balance at September 30, 2021$8,190 $(2)$8,188 
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 EndedNine Months Ended
September 30,September 30,
(in millions)2021202020212020
Operating Revenues
Regulated electric$413 $394 $1,119 $1,070 
Regulated natural gas93 79 375 324 
Total operating revenues506 473 1,494 1,394 
Operating Expenses
Fuel used in electric generation and purchased power119 94 294 258 
Cost of natural gas9 3 76 46 
Operation, maintenance and other116 115 335 333 
Depreciation and amortization79 72 228 208 
Property and other taxes91 83 266 244 
Impairment of assets and other charges— — 5 — 
Total operating expenses414 367 1,204 1,089 
Operating Income92 106 290 305 
Other Income and Expenses, net4 4 14 11 
Interest Expense29 26 82 75 
Income Before Income Taxes67 84 222 241 
Income Tax Expense9 14 34 40 
Net Income and Comprehensive Income$58 $70 $188 $201 

See Notes to Condensed Consolidated Financial Statements
31
FINANCIAL STATEMENTS
DUKE ENERGY OHIO, INC.
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)September 30, 2021December 31, 2020
ASSETS
Current Assets
Cash and cash equivalents$16 $14 
Receivables (net of allowance for doubtful accounts of $4 at 2021 and 2020)
107 98 
Receivables from affiliated companies77 102 
Inventory114 110 
Regulatory assets61 39 
Other45 31 
Total current assets420 394 
Property, Plant and Equipment
Cost11,531 11,022 
Accumulated depreciation and amortization(3,102)(3,013)
Net property, plant and equipment8,429 8,009 
Other Noncurrent Assets
Goodwill920 920 
Regulatory assets634 610 
Operating lease right-of-use assets, net19 20 
Other83 72 
Total other noncurrent assets1,656 1,622 
Total Assets$10,505 $10,025 
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable$304 $279 
Accounts payable to affiliated companies59 68 
Notes payable to affiliated companies451 169 
Taxes accrued210 247 
Interest accrued32 31 
Current maturities of long-term debt50 50 
Asset retirement obligations17 3 
Regulatory liabilities63 65 
Other68 70 
Total current liabilities1,254 982 
Long-Term Debt3,017 3,014 
Long-Term Debt Payable to Affiliated Companies25 25 
Other Noncurrent Liabilities
Deferred income taxes1,032 981 
Asset retirement obligations95 108 
Regulatory liabilities734 748 
Operating lease liabilities19 20 
Accrued pension and other post-retirement benefit costs114 113 
Other92 99 
Total other noncurrent liabilities2,086 2,069 
Commitments and Contingencies
Equity
Common Stock, $8.50 par value, 120 million shares authorized; 90 million shares outstanding at 2021 and 2020
762 762 
Additional paid-in capital2,776 2,776 
Retained earnings585 397 
Total equity4,123 3,935 
Total Liabilities and Equity$10,505 $10,025 

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)20212020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income$188 $201 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization231 211 
Equity component of AFUDC(5)(4)
Impairment of assets and other charges5 — 
Deferred income taxes27 31 
Payments for asset retirement obligations(1)(1)
Provision for rate refunds12 10 
(Increase) decrease in
Receivables(9)(5)
Receivables from affiliated companies(11)35 
Inventory(4)5 
Other current assets(34)5 
Increase (decrease) in
Accounts payable27 (28)
Accounts payable to affiliated companies(9)(14)
Taxes accrued(37)(23)
Other current liabilities(12)6 
Other assets(35)(24)
Other liabilities8 (7)
Net cash provided by operating activities341 398 
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures(615)(611)
Notes receivable from affiliated companies36 — 
Other(42)(34)
Net cash used in investing activities(621)(645)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt— 467 
Notes payable to affiliated companies282 (227)
Net cash provided by financing activities282 240 
Net increase (decrease) in cash and cash equivalents2 (7)
Cash and cash equivalents at beginning of period14 17 
Cash and cash equivalents at end of period$16 $10 
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures$103 $92 

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, 2020 and 2021
Additional
CommonPaid-inRetainedTotal
(in millions)StockCapitalEarningsEquity
Balance at June 30, 2020$762 $2,776 $276 $3,814 
Net income— — 70 70 
Balance at September 30, 2020$762 $2,776 $346 $3,884 
Balance at June 30, 2021$762 $2,776 $527 $4,065 
Net income— — 58 58 
Balance at September 30, 2021$762 $2,776 $585 $4,123 
Nine Months Ended September 30, 2020 and 2021
Additional
CommonPaid-inRetainedTotal
(in millions)StockCapitalEarningsEquity
Balance at December 31, 2019$762 $2,776 $145 $3,683 
Net income— — 201 201 
Balance at September 30, 2020$762 $2,776 $346 $3,884 
Balance at December 31, 2020$762 $2,776 $397 $3,935 
Net income— — 188 188 
Balance at September 30, 2021$762 $2,776 $585 $4,123 
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 EndedNine Months Ended
September 30,September 30,
(in millions)2021202020212020
Operating Revenues$886 $761 $2,366 $2,070 
Operating Expenses
Fuel used in electric generation and purchased power292 222 710 577 
Operation, maintenance and other173 207 543 564 
Depreciation and amortization154 149 458 415 
Property and other taxes16 15 57 57 
Impairment of assets and other charges— — 8 — 
Total operating expenses635 593 1,776 1,613 
Gains on Sales of Other Assets and Other, net1 — — — 
Operating Income252 168 590 457 
Other Income and Expenses, net12 9 31 28 
Interest Expense49 29 148 114 
Income Before Income Taxes215 148 473 371 
Income Tax Expense34 29 77 72 
Net Income and Comprehensive Income$181 $119 $396 $299 

See Notes to Condensed Consolidated Financial Statements
35
FINANCIAL STATEMENTS
DUKE ENERGY INDIANA, LLC
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)September 30, 2021December 31, 2020
ASSETS
Current Assets
Cash and cash equivalents$14 $7 
Receivables (net of allowance for doubtful accounts of $3 at 2021 and 2020)
81 55 
Receivables from affiliated companies62 112 
Notes receivable from affiliated companies252 — 
Inventory367 473 
Regulatory assets196 125 
Other59 37 
Total current assets1,031 809 
Property, Plant and Equipment
Cost17,320 17,382 
Accumulated depreciation and amortization(5,550)(5,661)
Net property, plant and equipment11,770 11,721 
Other Noncurrent Assets
Regulatory assets1,300 1,203 
Operating lease right-of-use assets, net51 55 
Other276 253 
Total other noncurrent assets1,627 1,511 
Total Assets$14,428 $14,041 
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable$239 $188 
Accounts payable to affiliated companies198 88 
Notes payable to affiliated companies— 131 
Taxes accrued83 62 
Interest accrued59 51 
Current maturities of long-term debt151 70 
Asset retirement obligations177 168 
Regulatory liabilities147 111 
Other104 83 
Total current liabilities1,158 952 
Long-Term Debt3,791 3,871 
Long-Term Debt Payable to Affiliated Companies150 150 
Other Noncurrent Liabilities
Deferred income taxes1,289 1,228 
Asset retirement obligations966 1,008 
Regulatory liabilities1,573 1,627 
Operating lease liabilities49 53 
Accrued pension and other post-retirement benefit costs172 171 
Investment tax credits172 168 
Other53 30 
Total other noncurrent liabilities4,274 4,285 
Commitments and Contingencies
Equity
Member's Equity5,055 4,783 
Total Liabilities and Equity$14,428 $14,041 

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)20212020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income$396 $299 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion460 416 
Equity component of AFUDC(19)(18)
Impairment of assets and other charges8 — 
Deferred income taxes19 11 
Payments for asset retirement obligations(49)(48)
(Increase) decrease in
Receivables(7)15 
Receivables from affiliated companies17 (5)
Inventory106 10 
Other current assets(58)12 
Increase (decrease) in
Accounts payable46 (1)
Accounts payable to affiliated companies(15)(22)
Taxes accrued25 65 
Other current liabilities23 (2)
Other assets11 (41)
Other liabilities3 104 
Net cash provided by operating activities966 795 
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures(584)(669)
Purchases of debt and equity securities(34)(24)
Proceeds from sales and maturities of debt and equity securities16 15 
Notes receivable from affiliated companies(218)— 
Other(8)(24)
Net cash used in investing activities(828)(702)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt— 544 
Payments for the redemption of long-term debt— (500)
Notes payable to affiliated companies(131)53 
Distributions to parent— (200)
Net cash used in financing activities(131)(103)
Net increase (decrease) in cash and cash equivalents7 (10)
Cash and cash equivalents at beginning of period7 25 
Cash and cash equivalents at end of period$14 $15 
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures$105 $73 
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, 2020 and 2021
(in millions)Member's Equity
Balance at June 30, 2020$4,655 
Net income119 
Distributions to parent(100)
Balance at September 30, 2020$4,674 
Balance at June 30, 2021$4,999 
Net income181 
Distributions to parent(125)
Balance at September 30, 2021$5,055 
Nine Months Ended
September 30, 2020 and 2021
(in millions)Member's Equity
Balance at December 31, 2019$4,575 
Net income299 
Distributions to parent(200)
Balance at September 30, 2020$4,674 
Balance at December 31, 2020$4,783 
Net income396 
Distributions to parent(125)
Other1 
Balance at September 30, 2021$5,055 

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 EndedNine Months Ended
September 30,September 30,
(in millions)2021202020212020
Operating Revenues$195 $162 $1,016 $871 
Operating Expenses
Cost of natural gas66 39 354 254 
Operation, maintenance and other77 75 231 234 
Depreciation and amortization51 45 150 133 
Property and other taxes16 13 44 37 
Impairment of assets and other charges4 7 9 7 
Total operating expenses214 179 788 665 
Operating (Loss) Income(19)(17)228 206 
Other Income and Expenses, net16 16 51 44 
Interest Expense29 29 88 89 
(Loss) Income Before Income Taxes(32)(30)191 161 
Income Tax (Benefit) Expense(8)(5)16 6 
Net (Loss) Income and Comprehensive (Loss) Income$(24)$(25)$175 $155 

See Notes to Condensed Consolidated Financial Statements
39
FINANCIAL STATEMENTS
PIEDMONT NATURAL GAS COMPANY, INC.
Condensed Consolidated Balance Sheets
(Unaudited)
(in millions)September 30, 2021December 31, 2020
ASSETS
Current Assets
Receivables (net of allowance for doubtful accounts of $15 at 2021 and $12 at 2020)
$96 $250 
Receivables from affiliated companies11 10 
Inventory68 68 
Regulatory assets125 153 
Other59 20 
Total current assets359 501 
Property, Plant and Equipment
Cost9,733 9,134 
Accumulated depreciation and amortization(1,862)(1,749)
Facilities to be retired, net11 — 
Net property, plant and equipment7,882 7,385 
Other Noncurrent Assets
Goodwill49 49 
Regulatory assets335 302 
Operating lease right-of-use assets, net17 20 
Investments in equity method unconsolidated affiliates100 88 
Other282 270 
Total other noncurrent assets783 729 
Total Assets$9,024 $8,615 
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable$184 $230 
Accounts payable to affiliated companies31 79 
Notes payable to affiliated companies315 530 
Taxes accrued41 23 
Interest accrued35 34 
Current maturities of long-term debt— 160 
Regulatory liabilities64 88 
Other76 69 
Total current liabilities746 1,213 
Long-Term Debt2,968 2,620 
Other Noncurrent Liabilities
Deferred income taxes875 821 
Asset retirement obligations21 20 
Regulatory liabilities1,004 1,044 
Operating lease liabilities15 19 
Accrued pension and other post-retirement benefit costs6 8 
Other175 155 
Total other noncurrent liabilities2,096 2,067 
Commitments and Contingencies
Equity
Common stock, no par value: 100 shares authorized and outstanding at 2021 and 2020
1,635 1,310 
Retained earnings1,579 1,405 
Total equity3,214 2,715 
Total Liabilities and Equity$9,024 $8,615 

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)20212020
CASH FLOWS FROM OPERATING ACTIVITIES
Net income$175 $155 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization152 135 
Equity component of AFUDC(19)(14)
Impairment of assets and other charges10 7 
Deferred income taxes10 24 
Equity in earnings from unconsolidated affiliates(7)(7)
Provision for rate refunds(3)(27)
(Increase) decrease in
Receivables151 164 
Receivables from affiliated companies(1)(1)
Inventory— 25 
Other current assets7 (59)
Increase (decrease) in
Accounts payable(55)(53)
Accounts payable to affiliated companies(48)60 
Taxes accrued17 16 
Other current liabilities(32)(4)
Other assets3 (14)
Other liabilities2 7 
Net cash provided by operating activities362 414 
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures(628)(641)
Contributions to equity method investments(9)— 
Return of investment capital1 — 
Other(23)(18)
Net cash used in investing activities(659)(659)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt347 394 
Payments for the redemption of long-term debt(160)— 
Notes payable to affiliated companies(215)(149)
Capital contributions from parent325 — 
Net cash provided by financing activities297 245 
Net increase in cash and cash equivalents— — 
Cash and cash equivalents at beginning of period— — 
Cash and cash equivalents at end of period$— $— 
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures$115 $123 

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, 2020 and 2021
CommonRetainedTotal
(in millions)StockEarningsEquity
Balance at June 30, 2020$1,310 $1,312 $2,622 
Net loss— (25)(25)
Balance at September 30, 2020$1,310 $1,287 $2,597 
Balance at June 30, 2021$1,635 $1,604 $3,239 
Net loss— (24)(24)
Other— (1)(1)
Balance at September 30, 2021$1,635 $1,579 $3,214 
Nine Months Ended September 30, 2020 and 2021
CommonRetainedTotal
(in millions)StockEarningsEquity
Balance at December 31, 2019$1,310 $1,133 $2,443 
Net income— 155 155 
Other— (1)(1)
Balance at September 30, 2020$1,310 $1,287 $2,597 
Balance at December 31, 2020$1,310 $1,405 $2,715 
Net income— 175 175 
Contribution from parent325 — 325 
Other— (1)(1)
Balance at September 30, 2021$1,635 $1,579 $3,214 

See Notes to Condensed Consolidated Financial Statements
42
FINANCIAL STATEMENTSORGANIZATION 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
Registrant12345678910111213141516
Duke Energy•••••••••••••••
Duke Energy Carolinas••••••••••••••
Progress Energy•••••••••••••••
Duke Energy Progress••••••••••••••
Duke Energy Florida••••••••••••••
Duke Energy Ohio••••••••••••••
Duke Energy Indiana••••••••••••••
Piedmont•••••••••••••
Tables within the notes may not sum across due to (i) Progress Energy's consolidation of Duke Energy Progress, Duke Energy Florida and other subsidiaries that are not registrants and (ii) subsidiaries that are not registrants but included in the consolidated Duke Energy balances.
1. ORGANIZATION AND BASIS OF PRESENTATION
BASIS OF PRESENTATION
These Condensed Consolidated Financial Statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all information and notes required by GAAP for annual financial statements and should be read in conjunction with the Consolidated Financial Statements in the Duke Energy Registrants’ combined Annual Report on Form 10-K for the year ended December 31, 2020.
The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to Combined Notes to Condensed Consolidated Financial Statements. However, none of the registrants make any representations as to information related solely to Duke Energy or the subsidiaries of Duke Energy other than itself.
These Condensed Consolidated Financial Statements, in the opinion of the respective companies’ management, reflect all normal recurring adjustments necessary to fairly present the financial position and results of operations of each of the Duke Energy Registrants. Amounts reported in Duke Energy’s interim Condensed Consolidated Statements of Operations and each of the Subsidiary Registrants’ interim Condensed Consolidated Statements of Operations and Comprehensive Income are not necessarily indicative of amounts expected for the respective annual periods due to effects of seasonal temperature variations on energy consumption, regulatory rulings, timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices and other factors.
In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates.
BASIS OF CONSOLIDATION
These Condensed Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and subsidiaries or VIEs where the respective Duke Energy Registrants have control. See Note 11 for additional information on VIEs. These Condensed Consolidated Financial Statements also reflect the Duke Energy Registrants’ proportionate share of certain jointly owned generation and transmission facilities.
OTHER CURRENT LIABILITIES
Included in Other within Current Liabilities on the Duke Energy Condensed Consolidated Balance Sheet is a current liability of $36 million and $936 million as of September 30, 2021, and December 31, 2020, respectively. The current liability, initially recorded in 2020, primarily represented Duke Energy's share of ACP's obligations of outstanding debt and to satisfy ARO requirements to restore construction sites. See Notes 3 and 11 for further information.
NONCONTROLLING INTEREST
Duke Energy maintains a controlling financial interest in certain less than wholly owned nonregulated subsidiaries. As a result, Duke Energy consolidates these subsidiaries and presents the third-party investors' portion of Duke Energy's net income (loss), net assets and comprehensive income (loss) as noncontrolling interest. Noncontrolling interest is included as a component of equity on the Condensed Consolidated Balance Sheet.
Several operating agreements of Duke Energy's subsidiaries with noncontrolling interest are subject to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements that vary throughout the lives of the subsidiaries. Therefore, Duke Energy and the other investors' (the owners) interests in the subsidiaries are not fixed, and the subsidiaries apply the Hypothetical Liquidation at Book Value (HLBV) method in allocating income or loss and other comprehensive income or loss (all measured on a pretax basis) to the owners. The HLBV method measures the amounts that each owner would hypothetically claim at each balance sheet reporting date, including tax benefits realized by the owners over the IRS recapture period, upon a hypothetical liquidation of the subsidiary at the net book value of its underlying assets. The change in the amount that each owner would hypothetically receive at the reporting date compared to the amount it would have received on the previous reporting date represents the amount of income or loss allocated to each owner for the reporting period.
43
FINANCIAL STATEMENTSORGANIZATION AND BASIS OF PRESENTATION

During September 2021, Duke Energy completed the initial minority interest investment in a portion of Duke Energy Indiana to an affiliate of GIC. GIC's ownership interest in Duke Energy Indiana represents a noncontrolling interest. See Note 2 for additional information on the sale.
Other operating agreements of Duke Energy's subsidiaries with noncontrolling interest allocate profit and loss based on their pro rata shares of the ownership interest in the respective subsidiary. Therefore, Duke Energy allocates net income or loss and other comprehensive income or loss of these subsidiaries to the owners based on their pro rata shares.
The following table presents allocated losses to noncontrolling interest for the three and nine months ended September 30, 2021, and 2020.
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)2021202020212020
Noncontrolling Interest Allocation of Income
Allocated losses to noncontrolling tax equity members utilizing the HLBV method$119 $59 $217 $187 
Allocated losses to noncontrolling members based on pro rata shares of ownership10 11 30 21 
Total Noncontrolling Interest Allocated Losses$129 $70 $247 $208 
CASH, CASH EQUIVALENTS AND RESTRICTED CASH
Duke Energy, Progress Energy and Duke Energy Florida have restricted cash balances related primarily to collateral assets, escrow deposits and VIEs. See Notes 9 and 11 for additional information. Restricted cash amounts are included in Other within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets. The following table presents the components of cash, cash equivalents and restricted cash included in the Condensed Consolidated Balance Sheets.
September 30, 2021December 31, 2020
DukeDuke
DukeProgressEnergyDukeProgressEnergy
EnergyEnergyFloridaEnergyEnergyFlorida
Current Assets
Cash and cash equivalents$548 $102 $40 $259 $59 $11 
Other194 17 17 194 39 39 
Other Noncurrent Assets
Other1 — — 103 102 — 
Total cash, cash equivalents and restricted cash$743 $119 $57 $556 $200 $50 
INVENTORY
Provisions for inventory write-offs were not material at September 30, 2021, and December 31, 2020. The components of inventory are presented in the tables below.
 September 30, 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions) EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Materials and supplies $2,317 $779 $1,009 $674 $336 $85 $305 $11 
Coal312 152 89 45 43 10 61 — 
Natural gas, oil and other fuel271 38 157 96 60 19 1 57 
Total inventory $2,900 $969 $1,255 $815 $439 $114 $367 $68 
 December 31, 2020
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions) EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Materials and supplies $2,312 $785 $999 $673 $325 $78 $307 $12 
Coal561 186 193 131 63 16 165 — 
Natural gas, oil and other fuel294 39 183 107 76 16 1 56 
Total inventory $3,167 $1,010 $1,375 $911 $464 $110 $473 $68 
44
FINANCIAL STATEMENTSORGANIZATION AND BASIS OF PRESENTATION

PROPERTY, PLANT & EQUIPMENT AND LEASES
Duke Energy continues to execute on its business transformation strategy, including the evaluation of in-office work policies considering the experience with the COVID-19 pandemic and also workforce realignment of roles and responsibilities. In May 2021, Duke Energy management approved the sale of certain properties and entered into an agreement to exit certain leased space on December 31, 2021. The sale of the properties is subject to abandonment accounting and resulted in an impairment charge. Additionally, the exit of the leased space resulted in the impairment of related furniture, fixtures and equipment. The total 2021 charges related to the reduction in physical workspace, including these impairments, are expected to be approximately $200 million. During the three months ended September 30, 2021, Duke Energy recorded a pretax charge to earnings of $9 million on the Condensed Consolidated Statements of Operations, which includes $8 million within Impairment of assets and other charges and $1 million within Operations, maintenance and other. During the nine months ended September 30, 2021, Duke Energy recorded a pretax charge to earnings of $184 million on the Condensed Consolidated Statements of Operations, which includes $139 million within Impairment of assets and other charges, $28 million within Operations, maintenance and other and $17 million within Depreciation and amortization.
NEW ACCOUNTING STANDARDS
The following new accounting standard was adopted by the Duke Energy Registrants in 2021.
Leases with Variable Lease Payments. In July 2021, the Financial Accounting Standards Board (FASB) issued new accounting guidance requiring lessors to classify a lease with variable lease payments that do not depend on a reference index or rate as an operating lease if both of the following are met: (1) the lease would have to be classified as a sales-type or direct financing lease under prior guidance, and (2) the lessor would have recognized a day-one loss. Duke Energy elected to adopt the guidance immediately upon issuance of the new standard and will be applying the new standard prospectively to new lease arrangements meeting the criteria. Duke Energy does not currently have any lease arrangements that this new accounting guidance will materially impact.
The following accounting standard was adopted by the Duke Energy Registrants in 2020.
Current Expected Credit Losses. In June 2016, the FASB issued new accounting guidance for credit losses. Duke Energy adopted the new accounting guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year results. Duke Energy did not adopt any practical expedients.
Duke Energy recognizes allowances for credit losses based on management's estimate of losses expected to be incurred over the lives of certain assets or guarantees. Management monitors credit quality, changes in expected credit losses and the appropriateness of the allowance for credit losses on a forward-looking basis. Management reviews the risk of loss periodically as part of the existing assessment of collectability of receivables.
Duke Energy reviews the credit quality of its counterparties as part of its regular risk management process and requires credit enhancements, such as deposits or letters of credit, as appropriate and as allowed by regulators.
Duke Energy recorded cumulative effects of changes in accounting principles related to the adoption of the new credit loss standard for allowances for credit losses of trade and other receivables, insurance receivables and financial guarantees. These amounts are included in the Condensed Consolidated Balance Sheets in Receivables, Receivables of VIEs, Other Noncurrent Assets and Other Noncurrent Liabilities. See Notes 4 and 12 for more information.
Duke Energy recorded an adjustment for the cumulative effect of a change in accounting principle due to the adoption of this standard on January 1, 2020, as shown in the table below:
 January 1, 2020
DukeDukeDuke
DukeEnergyProgressEnergyEnergy
(in millions) EnergyCarolinasEnergyProgressFloridaPiedmont
Total pretax impact to Retained Earnings$120 $16 $2 $1 $1 $1 
The following new accounting standard has been issued but not yet adopted by the Duke Energy Registrants as of September 30, 2021.
Reference Rate Reform. In March 2020, the FASB issued new accounting guidance for reference rate reform. This guidance is elective and provides expedients to facilitate financial reporting for the anticipated transition away from the London Inter-bank Offered Rate (LIBOR) and other interbank reference rates by the end of 2022. The optional expedients are effective for modification of existing contracts or new arrangements executed between March 12, 2020, through December 31, 2022.
Duke Energy has variable-rate debt and manages interest rate risk by entering into financial contracts including interest rate swaps that are generally indexed to LIBOR. Impacted financial arrangements extending beyond 2022 may require contractual amendment or termination to fully adapt to a post-LIBOR environment. Duke Energy is assessing these financial arrangements and is evaluating the use of optional expedients outlined in the new accounting guidance. Alternative index provisions are also being assessed and incorporated into new financial arrangements that extend beyond 2022. The full outcome of the transition away from LIBOR cannot be determined at this time, but is not expected to have a material impact on the financial statements.
2. BUSINESS SEGMENTS
Duke Energy
Duke Energy's segment structure includes the following segments: Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables.
45
FINANCIAL STATEMENTSBUSINESS SEGMENTS

The Electric Utilities and Infrastructure segment primarily includes Duke Energy's regulated electric utilities in the Carolinas, Florida and the Midwest. On January 28, 2021, Duke Energy executed an agreement providing for an investment by an affiliate of GIC in Duke Energy Indiana in exchange for a 19.9% minority interest issued by Duke Energy Indiana Holdco, LLC, the holding company for Duke Energy Indiana. The transaction will be completed following two closings for an aggregate purchase price of approximately $2 billion. The first closing, which occurred on September 8, 2021, resulted in Duke Energy Indiana Holdco, LLC issuing 11.05% of its membership interests in exchange for approximately $1,025 million or 50% of the purchase price. Duke Energy retained indirect control of these assets, and, therefore, no gain or loss was recognized on the Condensed Consolidated Statements of Operations. The difference between the cash consideration received, net of transaction costs of approximately $27 million, and the carrying value of the noncontrolling interest is $545 million and was recorded as an increase to equity.
The Gas Utilities and Infrastructure segment includes Piedmont, Duke Energy's natural gas local distribution companies in Ohio and Kentucky and Duke Energy's natural gas storage, midstream pipeline and renewable natural gas investments.
The Commercial Renewables segment is primarily comprised of nonregulated utility-scale wind and solar generation assets located throughout the U.S. In 2021, Duke Energy continues to monitor recoverability of its renewable merchant plants located in the Electric Reliability Council of Texas West market and in the PJM West market due to fluctuating market pricing and long-term forecasted energy prices. The assets were not impaired as of September 30, 2021, because the carrying value of approximately $206 million continues to approximate the aggregate estimated future undiscounted cash flows. Duke Energy has a 50% ownership interest in these assets. A continued decline in energy market pricing or other factors unfavorably impacting the economics would likely result in a future impairment.
The remainder of Duke Energy’s operations is presented as Other, which is primarily comprised of interest expense on holding company debt, unallocated corporate costs, Duke Energy’s wholly owned captive insurance company, Bison, and Duke Energy's ownership interest in National Methanol Company.
Business segment information is presented in the following tables. Segment assets presented exclude intercompany assets.
Three Months Ended September 30, 2021
ElectricGasTotal
Utilities andUtilities andCommercialReportable
(in millions)InfrastructureInfrastructureRenewablesSegmentsOtherEliminationsTotal
Unaffiliated revenues$6,560 $266 $117 $6,943 $8 $— $6,951 
Intersegment revenues9 23 — 32 20 (52)— 
Total revenues$6,569 $289 $117 $6,975 $28 $(52)$6,951 
Segment income (loss)(a)
$1,425 $(3)$78 $1,500 $(134)$— $1,366 
Less: Noncontrolling interests129 
Add: Preferred stock dividend39 
Net Income$1,276 
Segment assets$141,565 $14,692 $7,037 $163,294 $3,717 $(4)$167,007 
Three Months Ended September 30, 2020
ElectricGasTotal
Utilities andUtilities andCommercialReportable
(in millions)InfrastructureInfrastructureRenewablesSegmentsOtherEliminationsTotal
Unaffiliated revenues$6,371 $217 $126 $6,714 $7 $— $6,721 
Intersegment revenues8 24 — 32 17 (49)— 
Total revenues$6,379 $241 $126 $6,746 $24 $(49)$6,721 
Segment income (loss)(b)
$1,381 $(73)$60 $1,368 $(103)$— $1,265 
Less: Noncontrolling interests70 
Add: Preferred stock dividend39 
Net Income$1,234 
46
FINANCIAL STATEMENTSBUSINESS SEGMENTS

(a)Gas Utilities and Infrastructure includes $3 million, recorded within Equity in earnings (losses) of unconsolidated affiliates on the Condensed Consolidated Statements of Operations, related to gas pipeline investments. See Note 3 for additional information. Other includes $8 million recorded within Impairment of assets and other charges, $1 million within Operations, maintenance and other on the Condensed Consolidated Statements of Operations, related to the workplace and workforce realignment. See Note 1 for additional information. Electric Utilities and Infrastructure includes $160 million recorded within Impairment of assets and other charges, $77 million within Other Income and expenses, $5 million within Operations, maintenance and other, $13 million within Regulated electric operating revenues and $3 million within Interest expense on the Duke Energy Carolinas' Condensed Consolidated Statement of Operations related to the 2018 South Carolina rate cases and the CCR settlement and insurance proceeds distributed in accordance with that agreement; it also includes $42 million recorded within Impairment of assets and other charges, $34 million within Other Income and expenses, $7 million within Operations, maintenance, and other, $15 million within Regulated electric operating revenues and $5 million within Interest expense on the Duke Energy Progress' Condensed Consolidated Statement of Operations. See Notes 3 and 4 for more information.
(b)Electric Utilities and Infrastructure includes $19 million recorded within Impairment charges and $8 million recorded within Operations, maintenance and other on the Duke Energy Carolinas' Condensed Consolidated Statements of Operations related to a partial settlement in the Duke Energy Carolinas' 2019 North Carolina rate case and $8 million recorded within Operations, maintenance and other on Duke Energy Progress' Condensed Consolidated Statements of Operation related to a partial settlement in the Duke Energy Progress' 2019 North Carolina rate case. See Note 3 for more information. Additionally, Electric Utilities and Infrastructure includes $5 million of Impairment charges related to gas pipeline assets recorded on Duke Energy Progress' Condensed Consolidated Statement of Operations. Gas Utilities and Infrastructure includes $78 million recorded within Equity in earnings (losses) of unconsolidated affiliates on the Condensed Consolidated Statements of Operations and $7 million in Impairment charges recorded on the Piedmont Condensed Consolidated Statements of Operations related to gas pipeline investments.
Nine Months Ended September 30, 2021
ElectricGasTotal
Utilities andUtilities andCommercialReportable
(in millions)InfrastructureInfrastructureRenewablesSegmentsOtherEliminationsTotal
Unaffiliated revenues$17,161 $1,323 $355 $18,839 $20 $— $18,859 
Intersegment revenues24 68 — 92 61 (153)— 
Total revenues$17,185 $1,391 $355 $18,931 $81 $(153)$18,859 
Segment income (loss)(a)
$3,180 $259 $152 $3,591 $(521)$— $3,070 
Less: Noncontrolling interests247 
Add: Preferred stock dividend92 
Net Income$2,915 
Nine Months Ended September 30, 2020
ElectricGasTotal
Utilities andUtilities andCommercialReportable
(in millions)InfrastructureInfrastructureRenewablesSegmentsOtherEliminationsTotal
Unaffiliated revenues$16,571 $1,122 $378 $18,071 $20 $— $18,091 
Intersegment revenues25 72 — 97 53 (150)— 
Total revenues$16,596 $1,194 $378 $18,168 $73 $(150)$18,091 
Segment income (loss)(b)
$2,839 $(1,400)$207 $1,646 $(299)$— $1,347 
Less: Noncontrolling interests208 
Add: Preferred stock dividend93 
Net Income$1,232 
47
FINANCIAL STATEMENTSBUSINESS SEGMENTS

(a)Gas Utilities and Infrastructure includes $19 million, recorded within Equity in earnings (losses) of unconsolidated affiliates on the Condensed Consolidated Statements of Operations, related to gas pipeline investments. See Note 3 for additional information. Commercial Renewables includes a $35 million loss related to Texas Storm Uri, of which ($8 million) is recorded within Nonregulated electric and other revenues, $2 million within Operations, maintenance and other, $29 million within Equity in earnings (losses) of unconsolidated affiliates and $12 million within Loss Attributable to Noncontrolling Interests on the Condensed Consolidated Statements of Operations. See Note 4 for additional information. Other includes $139 million recorded within Impairment of assets and other charges, $28 million within Operations, maintenance and other, and $17 million within Depreciation and amortization on the Condensed Consolidated Statements of Operations, related to the workplace and workplace realignment. See Note 1 for additional information. Electric Utilities and Infrastructure includes $160 million recorded within Impairment of assets and other charges, $77 million within Other Income and expenses, $5 million within Operations, maintenance and other, $13 million within regulated operating revenues and $3 million within interest expense on the Duke Energy Carolinas' Condensed Consolidated Statement of Operations related to the 2018 South Carolina rate cases and the CCR settlement and insurance proceeds distributed in accordance with that agreement; it also includes $42 million recorded within Impairment of assets and other charges, $34 million within Other Income and expenses, $7 million within Operations, maintenance, and other, $15 million within Regulated electric operating revenues and $5 million within interest expense on the Duke Energy Progress' Condensed Consolidated Statement of Operations. See Notes 3 and 4 for more information.
(b)Gas Utilities and Infrastructure includes $2 billion recorded within Equity in earnings (losses) of unconsolidated affiliates on the Condensed Consolidated Statements of Operations, related to gas pipeline investments. See Note 3 for additional information. Other includes a $98 million reversal, included in Operations, maintenance and other on the Condensed Consolidated Statements of Operations, of 2018 severance costs due to a partial settlement in the Duke Energy Carolinas' 2019 North Carolina rate case. See Note 3 for additional information. Electric Utilities and Infrastructure includes $19 million recorded within Impairment charges and $8 million recorded within Operations, maintenance and other on the Duke Energy Carolinas' Condensed Consolidated Statements of Operations related to a partial settlement in the Duke Energy Carolinas' 2019 North Carolina rate case and $8 million recorded within Operations, maintenance and other on Duke Energy Progress' Condensed Consolidated Statements of Operation related to a partial settlement in the Duke Energy Progress' 2019 North Carolina rate case. See Note 3 for more information. Additionally, Electric Utilities and Infrastructure includes $5 million of Impairment charges related to gas pipeline assets recorded on Duke Energy Progress' Condensed Consolidated Statement of Operations in the prior year.
Duke Energy Ohio
Duke Energy Ohio has two reportable segments, Electric Utilities and Infrastructure and Gas Utilities and Infrastructure. The remainder of Duke Energy Ohio's operations is presented as Other.
Three Months Ended September 30, 2021
ElectricGasTotal
Utilities andUtilities andReportable
(in millions)InfrastructureInfrastructureSegmentsOtherEliminationsTotal
Total revenues$413 $93 $506 $— $— $506 
Segment income/Net (loss) income$48 $11 $59 $(1)$— $58 
Segment assets$6,716 $3,783 $10,499 $27 $(21)$10,505 
Three Months Ended September 30, 2020
ElectricGasTotal
Utilities andUtilities andReportable
(in millions)InfrastructureInfrastructureSegmentsOtherTotal
Total revenues$394 $79 $473 $— $473 
Segment income/Net (loss) income$63 $9 $72 $(2)$70 
Nine Months Ended September 30, 2021
ElectricGasTotal
Utilities andUtilities andReportable
(in millions)InfrastructureInfrastructureSegmentsOtherTotal
Total revenues$1,119 $375 $1,494 $— $1,494 
Segment income/Net (loss) income$122 $77 $199 $(11)$188 
Nine Months Ended September 30, 2020
ElectricGasTotal
Utilities andUtilities andReportable
(in millions)InfrastructureInfrastructureSegmentsOtherTotal
Total revenues$1,070 $324 $1,394 $— $1,394 
Segment income/Net (loss) income$137 $68 $205 $(4)$201 
48
FINANCIAL STATEMENTSREGULATORY MATTERS

3. REGULATORY MATTERS
RATE-RELATED INFORMATION
The NCUC, PSCSC, FPSC, IURC, PUCO, TPUC and KPSC approve rates for retail electric and natural gas services within their states. The FERC approves rates for electric sales to wholesale customers served under cost-based rates (excluding Ohio and Indiana), as well as sales of transmission service. The FERC also regulates certification and siting of new interstate natural gas pipeline projects.
Duke Energy Carolinas and Duke Energy Progress
2021 Coal Ash Settlement
On January 22, 2021, Duke Energy Carolinas and Duke Energy Progress entered into the Coal Combustion Residuals Settlement Agreement (the “CCR Settlement Agreement”) with the North Carolina Public Staff (Public Staff), the North Carolina Attorney General’s Office and the Sierra Club (collectively, the "Settling Parties"), which was filed with the NCUC on January 25, 2021. The CCR Settlement Agreement resolves all coal ash prudence and cost recovery issues in connection with 2019 rate cases filed by Duke Energy Carolinas and Duke Energy Progress with the NCUC, as well as the equitable sharing issue on remand from the 2017 Duke Energy Carolinas and Duke Energy Progress North Carolina rate cases as a result of the December 11, 2020 North Carolina Supreme Court opinion. The settlement also provides clarity on coal ash cost recovery in North Carolina for Duke Energy Carolinas and Duke Energy Progress through January 2030 and February 2030 (the "Term"), respectively.
Duke Energy Carolinas and Duke Energy Progress agreed not to seek recovery of approximately $1 billion of systemwide deferred coal ash expenditures, but will retain the ability to earn a debt and equity return during the amortization period, which shall be five years under the 2019 North Carolina rate cases and will be set by the NCUC in future rate case proceedings. The equity return and the amortization period on deferred coal ash costs under the 2017 Duke Energy Carolinas and Duke Energy Progress North Carolina rate cases will remain unaffected. The equity return on deferred coal ash costs under the 2019 North Carolina rate cases and future rate cases in North Carolina will be set at 150 basis points lower than the authorized return on equity (ROE) then in effect, with a capital structure composed of 48% debt and 52% equity. Duke Energy Carolinas and Duke Energy Progress retain the ability to earn a full WACC return during the deferral period, which is the period from when costs are incurred until they are recovered in rates.
The Settling Parties agreed that execution by Duke Energy Carolinas and Duke Energy Progress of a settlement agreement between themselves and the NCDEQ dated December 31, 2019, (the “DEQ Settlement”) and the coal ash management plans included therein or subsequently approved by DEQ are reasonable and prudent. The Settling Parties retain the right to challenge the reasonableness and prudence of actions taken by Duke Energy Carolinas and Duke Energy Progress and costs incurred to implement the scope of work agreed upon in the DEQ Settlement, after February 1, 2020, and March 1, 2020, for Duke Energy Carolinas and Duke Energy Progress, respectively. The Settling Parties further agreed to waive rights through the Term to challenge the reasonableness or prudence of Duke Energy Carolinas’ and Duke Energy Progress’ historical coal ash management practices, and to waive the right to assert any arguments that future coal ash costs, including financing costs, shall be shared between either company and customers through equitable sharing or any other rate base or return adjustment that shares the revenue requirement burden of coal ash costs not otherwise disallowed due to imprudence.
The Settling Parties agreed to a sharing arrangement for future coal ash insurance litigation proceeds between Duke Energy Carolinas and Duke Energy Progress and North Carolina customers. For more information, see Note 4 "Commitments and Contingencies."
As a result of the CCR Settlement Agreement, Duke Energy Carolinas and Duke Energy Progress recorded a pretax charge of approximately $454 million and $494 million, respectively, in the fourth quarter of 2020 to Impairment charges and a reversal of approximately $50 million and $102 million, respectively, to Regulated electric operating revenues on the respective Consolidated Statements of Operations.
The Coal Ash Settlement was approved without modification in the NCUC Orders in the 2019 rate cases on March 31, 2021, and April 16, 2021, for Duke Energy Carolinas and Duke Energy Progress, respectively. The NCUC issued an Order on Remand Accepting CCR Settlement and Affirming Previous Orders Setting Rates and Imposing Penalties in the 2017 rate cases on June 25, 2021.
2020 North Carolina Storm Securitization Filings
On October 26, 2020, Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the NCUC, as agreed to in partial settlements reached in the 2019 North Carolina Rate Cases for Duke Energy Carolinas and Duke Energy Progress, seeking authorization for the financing of the costs of each utility's storm recovery activities required as a result of Hurricane Florence, Hurricane Michael, Hurricane Dorian and Winter Storm Diego. Specifically, Duke Energy Carolinas and Duke Energy Progress requested that the NCUC find that their storm recovery costs and related financing costs are appropriately financed by debt secured by storm recovery property, and that the commission issue financing orders by which each utility may accomplish such financing using a securitization structure. On January 27, 2021, Duke Energy Carolinas, Duke Energy Progress and the Public Staff filed an Agreement and Stipulation of Partial Settlement, subject to review and approval of the NCUC, resolving certain accounting issues, including agreement to support an 18- to 20-year bond period. The total revenue requirement over a proposed 20-year bond period for the storm recovery charges is approximately $287 million for Duke Energy Carolinas and $920 million for Duke Energy Progress and will be finalized upon issuance of the bonds. A remote evidentiary hearing ended on January 29, 2021. In the NCUC Orders in the 2019 rate cases issued on March 31, 2021, and April 16, 2021, for Duke Energy Carolinas and Duke Energy Progress, respectively, the reasonableness and prudence of the deferred storm costs was approved. On May 10, 2021, the NCUC issued financing orders authorizing the companies to issue storm recovery bonds, subject to the terms of the financing orders, and approving the Agreement and Stipulation of Partial Settlement in its entirety. Duke Energy Carolinas and Duke Energy Progress are currently in the process of structuring and marketing the bonds that will be presented to the market. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.
49
FINANCIAL STATEMENTSREGULATORY MATTERS

COVID-19 Filings
North Carolina
Duke Energy Carolinas and Duke Energy Progress filed a joint petition on August 7, 2020, with the NCUC for deferral treatment of incremental costs and the cost of waived customer fees due to the COVID-19 pandemic. Comments on the joint petition were filed on November 5, 2020, and reply comments were filed on November 30, 2020. A summary of incremental COVID-19 costs incurred as of June 30, 2021, was filed with the NCUC by Duke Energy Carolinas and Duke Energy Progress on August 6, 2021. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.
South Carolina
Duke Energy Carolinas and Duke Energy Progress filed a report on June 30, 2020, as required by PSCSC order, reporting revenue impact, costs and savings related to COVID-19 to date. On August 14, 2020, Duke Energy Carolinas and Duke Energy Progress filed a joint petition with the PSCSC for approval of an accounting order to defer incremental COVID-19 related costs incurred through June 30, 2020, and for the ongoing months during the duration of the COVID-19 pandemic. Duke Energy Carolinas and Duke Energy Progress withdrew their joint petition on May 17, 2021.
Duke Energy Carolinas
2017 North Carolina Rate Case
On August 25, 2017, Duke Energy Carolinas filed an application with the NCUC for a rate increase for retail customers of approximately $647 million. On February 28, 2018, Duke Energy Carolinas and the Public Staff filed an Agreement and Stipulation of Partial Settlement resolving certain portions of the proceeding. Terms of the settlement included an ROE of 9.9% and a capital structure of 52% equity and 48% debt. On June 22, 2018, the NCUC issued an order approving the Stipulation of Partial Settlement and requiring a revenue reduction.
The North Carolina Attorney General and other parties separately filed Notices of Appeal to the North Carolina Supreme Court. The North Carolina Supreme Court consolidated the Duke Energy Carolinas and Duke Energy Progress appeals. On December 11, 2020, the North Carolina Supreme Court issued an opinion, which affirmed, in part, and reversed and remanded, in part, the NCUC’s decisions. In the Opinion, the court upheld the NCUC's decision to include coal ash costs in the cost of service, as well as the NCUC’s discretion to allow a return on the unamortized balance of coal ash costs. The court also remanded to the NCUC a single issue to consider the assessment of support for the Public Staff’s equitable sharing argument. On January 22, 2021, Duke Energy Carolinas and Duke Energy Progress entered into the CCR Settlement Agreement with the Settling Parties, which was filed with the NCUC on January 25, 2021, and approved by the NCUC on March 31, 2021. The NCUC issued an Order on Remand Accepting CCR Settlement and Affirming Previous Orders Setting Rates and Imposing Penalties on June 25, 2021.
2019 North Carolina Rate Case
On September 30, 2019, Duke Energy Carolinas filed an application with the NCUC for a net rate increase for retail customers of approximately $291 million, which represented an approximate 6% increase in annual base revenues. The gross rate case revenue increase request was $445 million, which was offset by an EDIT rider of $154 million to return to customers North Carolina and federal EDIT resulting from recent reductions in corporate tax rates. The request for a rate increase was driven by major capital investments subsequent to the previous base rate case, coal ash pond closure costs, accelerated coal plant depreciation and deferred 2018 storm costs. Duke Energy Carolinas requested rates be effective no later than August 1, 2020.
On March 25, 2020, Duke Energy Carolinas and the Public Staff filed an Agreement and Stipulation of Partial Settlement, subject to review and approval of the NCUC, resolving certain issues in the base rate proceeding. On July 24, 2020, Duke Energy Carolinas filed its request for approval of its notice to customers required to implement temporary rates. On July 27, 2020, Duke Energy Carolinas filed a joint motion with Duke Energy Progress and the Public Staff notifying the commission that the parties reached a joint partial settlement with the Public Staff. Also on July 27, 2020, Duke Energy Carolinas filed a letter stating that it intended to update its temporary rates calculation to reflect the terms of the partial settlement. On July 31, 2020, Duke Energy Carolinas and the Public Staff filed a Second Agreement and Stipulation of Partial Settlement (Second Partial Settlement), subject to review and approval of the NCUC, resolving certain remaining issues in the base rate proceeding. The remaining items litigated at hearing included recovery of deferred coal ash compliance costs that are subject to asset retirement obligation accounting, implementation of new depreciation rates and the amortization period of the loss on the hydro station sale.
On August 4, 2020, Duke Energy Carolinas filed an amended motion for approval of its amended notice to customers, seeking to exercise its statutory right to implement temporary rates subject to refund on or after August 24, 2020. The revenue requirement to be recovered, subject to refund, through the temporary rates was based on and consistent with the base rate component of the Second Partial Settlement and excluded the items to be litigated noted above. The NCUC approved the August 4, 2020 amended temporary rates motion on August 6, 2020, and temporary rates went into effect on August 24, 2020.
The Duke Energy Carolinas evidentiary hearing concluded on September 18, 2020, and post-hearing filings were made with the NCUC from all parties by November 4, 2020. On January 22, 2021, Duke Energy Carolinas and Duke Energy Progress entered into the CCR Settlement Agreement with the Settling Parties, which was filed with the NCUC on January 25, 2021.
On March 31, 2021, the NCUC issued an order approving the March 25, 2020, and July 31, 2020, partial settlements. The order includes approval of 1) an ROE of 9.6% based upon a capital structure of 52% equity and 48% debt; 2) deferral treatment of approximately $800 million of grid improvement projects with a return; 3) a flow back period of five years for unprotected federal EDIT; and 4) the reasonableness and prudence of $213 million of deferred storm costs, which were removed from the rate case and for which Duke Energy Carolinas filed a petition seeking securitization in October 2020. Additionally, the order approved without modification the CCR Settlement Agreement.
50
FINANCIAL STATEMENTSREGULATORY MATTERS

The order denied Duke Energy Carolinas' proposal to shorten the remaining depreciable lives of certain Duke Energy Carolinas coal-fired generating units, indicating the NCUC has not had the chance to fully examine the issue within the context of an integrated resource planning (IRP) proceeding, and upon retirement the remaining net book value of these units should be placed in a regulatory asset account to be amortized over an appropriate period to be determined in a future rate case.
On May 21, 2021, the NCUC issued an Order Approving Rate Schedules, which resulted in a net increase of approximately $33 million. Revised customer rates became effective on June 1, 2021. The deadline to appeal has passed and no parties appealed the NCUC's order.
2018 South Carolina Rate Case
On November 8, 2018, Duke Energy Carolinas filed an application with the PSCSC for a rate increase for retail customers of approximately $168 million.
After hearings in March 2019, the PSCSC issued an order on May 21, 2019, which included an ROE of 9.5% and a capital structure of 53% equity and 47% debt. The order also included the following material components:
•Approval of cancellation of the Lee Nuclear Project, with Duke Energy Carolinas maintaining the Combined Operating License;
•Approval of recovery of $125 million (South Carolina retail portion) of Lee Nuclear Project development costs (including AFUDC through December 2017) over a 12-year period, but denial of a return on the deferred balance of costs;
•Approval of recovery of $96 million of coal ash costs over a five-year period with a return at Duke Energy Carolinas' WACC;
•Denial of recovery of $115 million of certain coal ash costs deemed to be related to the Coal Ash Act and incremental to the federal CCR rule;
•Approval of a $66 million decrease to base rates to reflect the change in ongoing tax expense, primarily the reduction in the federal income tax rate from 35% to 21%;
•Approval of a $45 million decrease through the EDIT Rider to return EDIT resulting from the federal tax rate change and deferred revenues since January 2018 related to the change, to be returned in accordance with the Average Rate Assumption Method (ARAM) for protected EDIT, over a 20-year period for unprotected EDIT associated with Property, Plant and Equipment, over a five-year period for unprotected EDIT not associated with Property, Plant and Equipment and over a five-year period for the deferred revenues; and
•Approval of a $17 million decrease through the EDIT Rider related to reductions in the North Carolina state income tax rate from 6.9% to 2.5% to be returned over a five-year period.
As a result of the order, revised customer rates were effective June 1, 2019. On May 31, 2019, Duke Energy Carolinas filed a Petition for Rehearing or Reconsideration of that order contending substantial rights of Duke Energy Carolinas were prejudiced by unlawful, arbitrary and capricious rulings by the PSCSC on certain issues presented in the proceeding. On June 19, 2019, the PSCSC issued a Directive denying Duke Energy Carolinas' request to rehear or reconsider the commission's rulings on certain issues presented in the proceeding including coal ash remediation and disposal costs, ROE and the recovery of a return on deferred operation and maintenance expenses. An order detailing the commission's decision in the Directive was issued on October 18, 2019. Duke Energy Carolinas filed a notice of appeal on November 15, 2019, with the Supreme Court of South Carolina. On November 20, 2019, the South Carolina Energy Users Committee filed a Notice of Appeal with the Supreme Court of South Carolina. Initial briefs were filed on April 21, 2020, which included the South Carolina Energy User's Committee brief arguing that the PSCSC erred in allowing Duke Energy Carolinas' recovery of costs related to the Lee Nuclear Station. Response briefs were filed on July 6, 2020, and reply briefs were filed on August 11, 2020. Oral arguments were heard before the Supreme Court of South Carolina on May 26, 2021.
On October 27, 2021, the Supreme Court of South Carolina affirmed the PSCSC's May 2019 order to:
•Disallow cost recovery on certain CCR compliance costs the PSCSC deemed to be incremental to the federal CCR rules;
•Disallow recovery of certain coal ash litigation expenses;
•Disallow a return on certain deferred expenses; and
•Allow recovery of Lee Nuclear Project preconstruction costs.
The Supreme Court's decision notes the prior determination made by the PSCSC that Duke Energy could submit coal ash costs for recovery that were not initially approved in the rate case order if such costs can be attributed to the CCR rules. As a result of the Court's opinion, Duke Energy Carolinas recognized a pretax charge of approximately $160 million to Impairment of assets and other charges, and a $31 million increase in Other income and expenses, net, in the Condensed Consolidated Statement of Operations for the three and nine months ended September 30, 2021, principally related to coal ash remediation at retired coal ash basin sites. Duke Energy Carolinas is evaluating whether to file a Petition for rehearing on the Supreme Court's decision. Petitions are due November 11, 2021, unless an extension is sought and granted.
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Oconee Nuclear Station Subsequent License Renewal
On June 7, 2021, Duke Energy Carolinas filed a subsequent license renewal 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 subsequent license renewal would extend operations of the facility from 60 to 80 years. The current license 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 proposes three contentions purporting to challenge Duke Energy Carolinas’ environmental report (ER). In general, the proposed contentions claim that the ER does not consider certain information regarding the environmental aspects of Severe Accidents caused by a hypothetical failure of the Jocassee Dam, and therefore does not satisfy the National Environmental Policy Act of 1969, as amended (NEPA), or the NRC’s NEPA-implementing regulations. Duke Energy Carolinas filed its answer to the proposed contentions on October 22, 2021, and the Petitioners have until November 5, 2021, to respond to Duke Energy Carolina’s answer.
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. New depreciation rates were implemented for all of the nuclear facilities during the second quarter of 2021. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.
Duke Energy Progress
2017 North Carolina Rate Case
On June 1, 2017, Duke Energy Progress filed an application with the NCUC for a rate increase for retail customers of approximately $477 million, which was subsequently adjusted to $420 million. On November 22, 2017, Duke Energy Progress and the Public Staff filed an Agreement and Stipulation of Partial Settlement resolving certain portions of the proceeding. Terms of the settlement included an ROE of 9.9% and a capital structure of 52% equity and 48% debt. On February 23, 2018, the NCUC issued an order approving the stipulation. The Public Staff, the North Carolina Attorney General and the Sierra Club filed notices of appeal to the North Carolina Supreme Court.
The North Carolina Supreme Court consolidated the Duke Energy Carolinas and Duke Energy Progress appeals. On December 11, 2020, the North Carolina Supreme Court issued an opinion, which affirmed, in part, and reversed and remanded, in part, the NCUC’s decisions. In the Opinion, the court upheld the NCUC's decision to include coal ash costs in the cost of service, as well as the NCUC’s discretion to allow a return on the unamortized balance of coal ash costs. The court also remanded to the NCUC a single issue to consider the assessment of support for the Public Staff’s equitable sharing argument. On January 22, 2021, Duke Energy Progress and Duke Energy Carolinas entered into the CCR Settlement Agreement with the Settling Parties, which was filed with the NCUC on January 25, 2021, and approved by the NCUC on April 16, 2021. The NCUC issued an Order on Remand Accepting CCR Settlement and Affirming Previous Orders Setting Rates and Imposing Penalties on June 25, 2021.
2019 North Carolina Rate Case
On October 30, 2019, Duke Energy Progress filed an application with the NCUC for a net rate increase for retail customers of approximately $464 million, which represented an approximate 12.3% increase in annual base revenues. The gross rate case revenue increase request was $586 million, which was offset by riders of $122 million, primarily an EDIT rider of $120 million to return to customers North Carolina and federal EDIT resulting from recent reductions in corporate tax rates. The request for a rate increase was driven by major capital investments subsequent to the previous base rate case, coal ash pond closure costs, accelerated coal plant depreciation and deferred 2018 storm costs. Duke Energy Progress sought to defer and recover incremental Hurricane Dorian storm costs in this proceeding and requested rates be effective no later than September 1, 2020. As a result of the COVID-19 pandemic, on March 24, 2020, the NCUC suspended the procedural schedule and postponed the previously scheduled evidentiary hearing on this matter indefinitely.
On June 2, 2020, Duke Energy Progress and the Public Staff filed an Agreement and Stipulation of Partial Settlement, subject to review and approval of the NCUC, resolving certain issues in the base rate proceeding. On July 27, 2020, Duke Energy Progress filed a joint motion with Duke Energy Carolinas and the Public Staff notifying the commission that the parties reached a joint partial settlement with the Public Staff. On July 31, 2020, Duke Energy Progress and the Public Staff filed a Second Agreement and Stipulation of Partial Settlement, subject to review and approval of the NCUC, resolving certain remaining issues in the base rate proceeding. The remaining items litigated at hearing included recovery of deferred coal ash compliance costs that are subject to asset retirement obligation accounting and implementation of new depreciation rates.
On August 7, 2020, Duke Energy Progress filed a motion for approval of notice required to implement temporary rates, seeking to exercise its statutory right to implement temporary rates subject to refund on or after September 1, 2020. The revenue requirement to be recovered subject to refund through the temporary rates was based on and consistent with the terms of the base rate component of the settlement agreements with the Public Staff and excluded items to be litigated noted above. In addition, Duke Energy Progress also sought authorization to place a temporary decrement EDIT Rider into effect, concurrent with the temporary base rate change. The NCUC approved the August 7, 2020 temporary rates motion on August 11, 2020, and temporary rates went into effect on September 1, 2020.
The Duke Energy Progress evidentiary hearing concluded on October 6, 2020, and post-hearing filings were filed with the NCUC from all parties by December 4, 2020. On January 22, 2021, Duke Energy Progress and Duke Energy Carolinas entered into the CCR Settlement Agreement with the Settling Parties, which was filed with the NCUC on January 25, 2021.
On April 16, 2021, the NCUC issued an order approving the June 2, 2020, and July 31, 2020, partial settlements. The order includes approval of 1) an ROE of 9.6% based upon a capital structure of 52% equity and 48% debt; 2) deferral treatment of approximately $400 million of grid improvement projects with a return; 3) a flow back period of five years for unprotected federal EDIT; and 4) the reasonableness and prudence of approximately $714 million of deferred storm costs, which were removed from the rate case and for which Duke Energy Progress filed a petition seeking securitization in October 2020. Additionally, the order approved without modification the CCR Settlement Agreement.
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The order denied Duke Energy Progress' proposal to shorten the remaining depreciable lives of certain Duke Energy Progress coal-fired generating units, indicating the NCUC has not had the chance to fully examine the issue within the context of an IRP proceeding, and upon retirement the remaining net book value of these units should be placed in a regulatory asset account to be amortized over an appropriate period to be determined in a future rate case.
On May 21, 2021, the NCUC issued an Order Approving Rate Schedules, which resulted in a net increase of approximately $178 million. Revised customer rates became effective on June 1, 2021. The deadline to appeal has passed and no parties appealed the NCUC's order.
2018 South Carolina Rate Case
On November 8, 2018, Duke Energy Progress filed an application with the PSCSC for a rate increase for retail customers of approximately $59 million.
After hearings in April 2019, the PSCSC issued an order on May 21, 2019, which included an ROE of 9.5% and a capital structure of 53% equity and 47% debt. The order also included the following material components:
•Approval of recovery of $4 million of coal ash costs over a five-year period with a return at Duke Energy Progress' WACC;
•Denial of recovery of $65 million of certain coal ash costs deemed to be related to the Coal Ash Act and incremental to the federal CCR rule;
•Approval of a $17 million decrease to base rates to reflect the change in ongoing tax expense, primarily the reduction in the federal income tax rate from 35% to 21%;
•Approval of a $12 million decrease through the EDIT Tax Savings Rider resulting from the federal tax rate change and deferred revenues since January 2018 related to the change, to be returned in accordance with ARAM for protected EDIT, over a 20-year period for unprotected EDIT associated with Property, Plant and Equipment, over a five-year period for unprotected EDIT not associated with Property, Plant and Equipment and over a three-year period for the deferred revenues; and
•Approval of a $12 million increase due to the expiration of EDIT related to reductions in the North Carolina state income tax rate from 6.9% to 2.5%.
As a result of the order, revised customer rates were effective June 1, 2019. On May 31, 2019, Duke Energy Progress filed a Petition for Rehearing or Reconsideration of that order contending substantial rights of Duke Energy Progress were prejudiced by unlawful, arbitrary and capricious rulings by the PSCSC on certain issues presented in the proceeding. On June 19, 2019, the PSCSC issued a Directive denying Duke Energy Progress' request to rehear or reconsider the commission's rulings on certain issues presented in the proceeding including coal ash remediation and disposal costs, ROE and the recovery of a return on deferred operation and maintenance expenses, but allowing additional litigation-related costs. As a result of the Directive allowing litigation-related costs, customer rates were revised effective July 1, 2019. An order detailing the commission's decision in the Directive was issued on October 18, 2019. Duke Energy Progress filed a notice of appeal on November 15, 2019, with the Supreme Court of South Carolina. Initial briefs were filed on April 21, 2020. Response briefs were filed on July 6, 2020, and reply briefs were filed on August 11, 2020. Oral arguments were heard before the Supreme Court of South Carolina on May 26, 2021.
On October 27, 2021, the Supreme Court of South Carolina affirmed the PSCSC's May 2019 order to:
•Disallow cost recovery on certain CCR compliance costs the PSCSC deemed to be incremental to the federal CCR rules;
•Disallow recovery of certain coal ash litigation expenses; and
•Disallow a return on certain deferred expenses.
The Supreme Court's decision notes the prior determination made by the PSCSC that Duke Energy could submit coal ash costs for recovery that were not initially approved in the rate case order if such costs can be attributed to the CCR rules. As a result of the Court's opinion, Duke Energy Progress recognized a pretax charge of approximately $42 million to Impairment of assets and other charges, and a $6 million increase in Other income and expenses, net, in the Condensed Consolidated Statement of Operations for the three and nine months ended September 30, 2021, principally related to coal ash remediation at retired coal ash basin sites. Duke Energy Progress is evaluating whether to file a Petition for rehearing on the Supreme Court's decision. Petitions are due November 11, 2021, unless an extension is sought and granted.
Western Carolinas Modernization Plan
On October 8, 2018, Duke Energy Progress filed an application with the NCUC for a CPCN to construct the Hot Springs Microgrid Solar and Battery Storage Facility, which was approved with certain conditions on May 10, 2019. A hearing to update the NCUC on the status of the project was held on March 5, 2020. Construction began in May 2020 with commercial operation expected to begin in December 2021.
On July 27, 2020, Duke Energy Progress filed an application with the NCUC for a CPCN to construct the Woodfin Solar Facility, a 5-MW solar generating facility to be constructed on a closed landfill in Buncombe County. The expert hearing was held on November 18, 2020. The application was approved and a CPCN was granted by order of the NCUC on April 20, 2021. Construction began in April 2021 with an expected in-service date in March 2022.
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FERC Return on Equity Complaints
On October 11, 2019, North Carolina Eastern Municipal Power Agency (NCEMPA) filed a complaint at the FERC against Duke Energy Progress pursuant to Section 206 of the Federal Power Act (FPA), alleging that the 11% stated ROE component contained in the demand formula rate in the Full Requirements Power Purchase Agreement (FRPPA) between NCEMPA and Duke Energy Progress is unjust and unreasonable. On July 16, 2020, the FERC set this matter for hearing and settlement judge procedures and established a refund effective date of October 11, 2019. In its order setting the matter for settlement, the FERC allowed for the consideration of variations to the base transmission-related ROE methodology developed in its Order No. 569-A, through the introduction of “specific facts and circumstances” involving issues specific to the case. The parties reached a settlement in principle at a settlement conference on January 7, 2021, and filed a settlement package on March 10, 2021. The FERC Trial Staff filed comments in support of the settlement. On April 19, 2021, the Settlement Judge certified the settlement to the FERC as an uncontested settlement. The FERC approved the settlement on May 25, 2021, and Duke Energy Progress filed compliance documents on June 10, 2021. The FERC accepted the compliance filing on October 8, 2021.
On October 16, 2020, North Carolina Electric Membership Corporation (NCEMC) filed a complaint at the FERC against Duke Energy Progress pursuant to Section 206 of the FPA, alleging that the 11% stated ROE component in the demand formula rate in the Power Supply and Coordination Agreement between NCEMC and Duke Energy Progress is unjust and unreasonable. Under FPA Section 206, the earliest refund effective date that the FERC can establish is the date of the filing of the complaint. Duke Energy Progress responded to the complaint on November 20, 2020, seeking dismissal, demonstrating that the 11% ROE is just and reasonable for the service provided. The parties filed responsive pleadings and are awaiting an order from the FERC. Duke Energy Progress cannot predict the outcome of this matter.
Duke Energy Florida
2021 Settlement Agreement
On January 14, 2021, Duke Energy Florida filed a Settlement Agreement (the “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 on a capital structure of 53% equity and 47% debt. The ROE band can be increased by 25 basis points if the average 30-year U.S. Treasury rate increases 50 basis points or more over a six-month period in which case the midpoint ROE would rise from 9.85% to 10.10%. Duke Energy Florida will also be able to retain the DOE award of approximately $173 million for spent nuclear fuel, which is expected to be received in 2022, in order to mitigate customer rates over the term of the 2021 Settlement. In return, Duke Energy Florida will be able to recognize the $173 million into earnings from 2022 through 2024.
In addition to these terms, the 2021 Settlement contains 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 resolves remaining unrecovered storm costs for Hurricane Dorian and Hurricane Michael.
The FPSC approved the 2021 Settlement on May 4, 2021, issuing an order on June 4, 2021. Revised customer rates will be effective January 1, 2022, with subsequent base rate increases effective January 1, 2023, and January 1, 2024.
Storm Restoration Cost Recovery
Duke Energy Florida filed a petition with the FPSC on April 30, 2019, to recover $223 million of estimated retail incremental storm restoration costs for Hurricane Michael, consistent with the provisions in the 2017 Settlement, and the FPSC approved the petition on June 11, 2019. The FPSC also approved allowing Duke Energy Florida to use the tax savings resulting from the Tax Act to recover these storm costs in lieu of implementing a storm surcharge. Approved storm costs are currently expected to be fully recovered by year-end 2021. On November 22, 2019, Duke Energy Florida filed a petition for approval of actual retail recoverable storm restoration costs related to Hurricane Michael in the amount of $191 million plus interest. On May 19, 2020, Duke Energy Florida filed a supplemental true up reducing the actual retail recoverable storm restoration costs related to Hurricane Michael by approximately $3 million, resulting in a total request to recover $188 million actual retail recoverable storm restoration costs, plus interest. Approximately $80 million of these costs are included in Regulatory assets within Current Assets and Other Noncurrent Assets on the Condensed Consolidated Balance Sheets as of December 31, 2020.
Duke Energy Florida filed a petition with the FPSC on December 19, 2019, to recover $169 million of estimated retail incremental storm restoration costs for Hurricane Dorian, consistent with the provisions in the 2017 Settlement and the FPSC approved the petition on February 24, 2020. The final actual amount of $145 million was filed on September 30, 2020. The 2021 Settlement resolved all matters regarding storm cost recovery relating to Hurricane Michael and Hurricane Dorian.
Clean Energy Connection
On July 1, 2020, Duke Energy Florida petitioned the FPSC for approval of a voluntary solar program. The program consists of 10 new solar generating facilities with combined capacity of approximately 750 MW. The program allows participants to support cost-effective solar development in Florida by paying a subscription fee based on per kilowatt-subscriptions and receiving a credit on their bill based on the actual generation associated with their portion of the solar portfolio. The estimated cost of the 10 new solar generation facilities is approximately $1 billion over the next four years, and this investment will be included in base rates offset by the revenue from the subscription fees. The credits will be included for recovery in the fuel cost recovery clause. A remote hearing was held on November 17, 2020, and post-hearing briefs were filed with the FPSC from all parties by December 9, 2020. The FPSC voted to approve the program on January 5, 2021, and issued its written order on January 26, 2021.
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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. LULAC's initial brief was filed on May 26, 2021, and Appellees' response briefs were filed on July 26, 2021. LULAC's reply brief was filed on September 24, 2021, and its request for oral argument was filed on September 28, 2021. The FPSC approval order remains in effect pending the outcome of the appeal. Duke Energy Florida cannot predict the outcome of this matter.
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 and an ROE of 10.3%. This is an approximate 3.3% average increase across all customer classes. The drivers for this case are capital invested since Duke Energy Ohio's last electric distribution base rate case in 2017. Duke Energy Ohio is also seeking to adjust the caps on its Distribution Capital Investment Rider (DCI Rider). Duke Energy Ohio anticipates the PUCO will rule on the request by the summer of 2022. Duke Energy Ohio cannot predict the outcome of this matter.
Ohio House Bill 6
On July 23, 2019, House Bill 6 was signed into law and became effective January 1, 2020. Among other things, the bill allows for funding, through a rider mechanism referred to as the Clean Air Fund (Rider CAF), of two nuclear generating facilities located in Northern Ohio owned by Energy Harbor (f/k/a FirstEnergy Solutions) and certain renewable resources, repeal of energy efficiency mandates and recovery of prudently incurred costs, net of any revenues, for Ohio investor-owned utilities that are participants under the OVEC power agreement. The OVEC recovery is through a non-bypassable rider that replaced any existing recovery mechanism approved by the PUCO and will remain in place through 2030. As such, Duke Energy Ohio created the Legacy Generation Rider (Rider LGR) that replaced Rider PSR effective January 1, 2020. The amounts recoverable from customers are subject to an annual cap, with incremental costs that exceed such cap eligible for deferral and recovery subject to review. See Note 11 for additional discussion of Duke Energy Ohio's ownership interest in OVEC. House Bill 128 was signed into law on March 31, 2021, and became effective June 30, 2021. The bill removes nuclear plant funding included in HB 6, eliminates Rider CAF and establishes the Solar Generation Fund Rider (Rider SGF) to recover the renewable investments originally included in HB 6. HB 128 does not impact OVEC cost recovery or any transmission or distribution rider.
Energy Efficiency Cost Recovery
On February 26, 2020, the PUCO issued an order directing utilities to wind down their demand-side management programs by September 30, 2020, and to terminate the programs by December 31, 2020, in response to changes in Ohio law that eliminated Ohio's energy efficiency mandates. On March 27, 2020, Duke Energy Ohio filed an Application for Rehearing seeking clarification on the final true up and reconciliation process after 2020. On November 18, 2020, the PUCO issued two orders on the application for rehearing. The first order was a Third Entry on Rehearing on the Duke Energy Ohio portfolio holding the cost cap previously imposed was unlawful, a shared savings cap of $8 million pretax should be imposed and lost distribution revenues could not be recovered after December 31, 2020. The second order directs all utilities set the rider to zero effective January 1, 2021, and to file a separate application for final reconciliation of all energy efficiency costs prior to December 31, 2020. On December 18, 2020, Duke Energy Ohio filed an application for rehearing. On January 13, 2021, the application for rehearing was granted for further consideration. Duke Energy Ohio cannot predict the outcome of this matter.
On October 9, 2020, Duke Energy Ohio filed an application to implement a voluntary energy efficiency program portfolio to commence on January 1, 2021. The application proposes a mechanism for recovery of program costs and a benefit associated with avoided transmission and distribution costs. The application remains under review. Effective January 1, 2021, Duke Energy Ohio suspended its energy efficiency programs due to changes in Ohio law. On June 14, 2021, the PUCO issued an entry for each utility to file by July 15, 2021, a proposal to reestablish low-income programs through December 31, 2021. Duke Energy Ohio filed its application on July 14, 2021. Duke Energy Ohio cannot predict the outcome of this matter.
Natural Gas Pipeline Extension
Duke Energy Ohio is installing a new natural gas pipeline (the Central Corridor Project) in its Ohio service territory to increase system reliability and enable the retirement of older infrastructure. Duke Energy Ohio currently estimates the pipeline development costs and construction activities will range from $185 million to $205 million in direct costs (excluding overheads and AFUDC) and that construction of the pipeline extension will be completed in time for use during the 2021/2022 winter season. An evidentiary hearing on Duke Energy Ohio's application for a Certificate of Environmental Compatibility and Public Need concluded on April 11, 2019. On November 21, 2019, the Ohio Power Siting Board (OPSB) approved Duke Energy Ohio's application subject to 41 conditions on construction. Applications for rehearing were filed by several stakeholders on December 23, 2019, arguing that the OPSB approval was incorrect. On February 20, 2020, the OPSB denied the rehearing requests. On April 15, 2020, those stakeholders filed a notice of appeal at the Supreme Court of Ohio of the OPSB’s decision approving Duke Energy Ohio’s Central Corridor project application. The Ohio Supreme Court affirmed the OPSB order on September 22, 2021.
On September 22, 2020, Duke Energy Ohio filed an application with the OPSB for approval to amend the certificated pipeline route due to changes in the route negotiated with property owners and municipalities. On January 21, 2021, the OPSB approved the amended filing with recommended conditions that reaffirm previous conditions and provide guidance regarding local permitting and construction supervision.
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MGP Cost Recovery
In an order issued in 2013, the PUCO approved Duke Energy Ohio's deferral and recovery of costs related to environmental remediation at two sites (East End and West End) that housed former MGP operations. Duke Energy Ohio has collected approximately $55 million in environmental remediation costs incurred between 2008 through 2012 through Rider MGP, which is currently suspended. Duke Energy Ohio has made annual applications with the PUCO to recover its incremental remediation costs consistent with the PUCO’s directive in Duke Energy Ohio’s 2012 natural gas base rate case. To date, the PUCO has not ruled on Duke Energy Ohio’s annual applications for the calendar years 2013 through 2019. On September 28, 2018, the Staff of the PUCO (Staff) issued a report recommending a disallowance of approximately $12 million of the $26 million in MGP remediation costs incurred between 2013 through 2017 that Staff believes are not eligible for recovery. Staff interprets the PUCO’s 2013 order granting Duke Energy Ohio recovery of MGP remediation as limiting the recovery to work directly on the East End and West End sites. On October 30, 2018, Duke Energy Ohio filed reply comments objecting to the Staff’s recommendations and explaining, among other things, the obligation Duke Energy Ohio has under Ohio law to remediate all areas impacted by the former MGPs and not just physical property that housed the former plants and equipment. On March 29, 2019, Duke Energy Ohio filed its annual application to recover incremental remediation expense for the calendar year 2018 seeking recovery of approximately $20 million in remediation costs. On July 12, 2019, the Staff recommended a disallowance of approximately $11 million for work that the Staff believes occurred in areas not authorized for recovery. Additionally, the Staff recommended that any discussion pertaining to Duke Energy Ohio's recovery of ongoing MGP costs should be directly tied to or netted against insurance proceeds collected by Duke Energy Ohio. An evidentiary hearing concluded on November 21, 2019. Initial briefs were filed on January 17, 2020, and reply briefs were filed on February 14, 2020.
On March 31, 2020, Duke Energy Ohio filed its annual application to recover incremental MGP remediation expense, seeking recovery of approximately $39 million in remediation costs incurred during 2019. On July 23, 2020, the Staff recommended a disallowance of approximately $4 million for work the Staff believes occurred in areas not authorized for recovery. Additionally, the Staff recommended insurance proceeds, net of litigation costs and attorney fees, should be paid to customers and not be held by Duke Energy Ohio until all investigation and remediation is complete. Duke Energy Ohio filed comments in response to the Staff report on August 21, 2020, and intervenor comments were filed on November 9, 2020.
The 2013 PUCO order also contained conditional deadlines for completing the MGP environmental remediation and the deferral of related remediation costs. Subsequent to the order, the deadline was extended to December 31, 2019. On May 10, 2019, Duke Energy Ohio filed an application requesting a continuation of its existing deferral authority for MGP remediation that must occur after December 31, 2019. On July 12, 2019, the Staff recommended the commission deny the deferral authority request. On September 13, 2019, intervenor comments were filed opposing Duke Energy Ohio's request for continuation of existing deferral authority and on October 2, 2019, Duke Energy Ohio filed reply comments.
A Stipulation and Recommendation was filed jointly by Duke Energy Ohio, the Staff, the Office of the Ohio Consumers' Counsel and the Ohio Energy Group on August 31, 2021, which is subject to review and approval by the PUCO. If approved, the Stipulation and Recommendation would, among other things, resolve all open issues regarding MGP remediation costs incurred between 2013 and 2019, including Duke Energy Ohio’s request for additional deferral authority beyond 2019, and the pending issues related to the Tax Act as it relates to Duke Energy Ohio’s natural gas operations. These impacts are not expected to have a material impact on the Duke Energy Ohio financial statements. The Stipulation and Recommendation further acknowledges Duke Energy Ohio’s ability to file a request for additional deferral authority in the future related to environmental remediation of any MGP impacts in the Ohio River if necessary, subject to specific conditions. On October 15, 2021, the PUCO granted motions to intervene filed in September 2021 by Interstate Gas Supply, Inc. and Retail Energy Supply Association on a limited basis. An evidentiary hearing is scheduled for November 22, 2021. Duke Energy Ohio cannot predict the outcome of this matter.
Tax Act – Ohio
On December 21, 2018, Duke Energy Ohio filed an application to change its base rate tariffs and establish a new rider to implement the benefits of the Tax Act for natural gas customers. Duke Energy Ohio requested commission approval to implement the tariff changes and rider effective April 1, 2019. The new rider will flow through to customers the benefit of the reduction in the statutory federal tax rate from 35% to 21% since January 1, 2018, all future benefits of the lower tax rates and a full refund of deferred income taxes collected at the higher tax rates in prior years. Deferred income taxes subject to normalization rules will be refunded consistent with federal law and deferred income taxes not subject to normalization rules will be refunded over a 10-year period. The PUCO established a procedural schedule and testimony was filed on July 31, 2019. An evidentiary hearing occurred on August 7, 2019. Initial briefs were filed on September 11, 2019. Reply briefs were filed on September 25, 2019. The Stipulation and Recommendation filed on August 31, 2021, disclosed in the MGP Cost Recovery matter above, also resolves the outstanding issues in this proceeding. On October 15, 2021, the PUCO granted motions to intervene filed in September 2021 by Interstate Gas Supply, Inc. and Retail Energy Supply Association on a limited basis. An evidentiary hearing is scheduled for November 22, 2021. Duke Energy Ohio cannot predict the outcome of this matter.
Duke Energy Kentucky Natural Gas Base Rate Case
On June 1, 2021, Duke Energy Kentucky filed an application with the KPSC requesting an increase in natural gas base rates of approximately $15 million, an approximate 13% average increase across all customer classes. The drivers for this case are capital invested since Duke Energy Kentucky's last natural gas base rate case in 2018. Duke Energy Kentucky is also seeking implementation of a Governmental Mandate Adjustment mechanism (Rider GMA) in order to recover from or pay to customers the financial impact of governmental directives and mandates, including changes in federal or state tax rates and regulations issued by the Pipeline and Hazardous Materials Safety Administration (PHMSA). On October 8, 2021, Duke Energy Kentucky filed a Stipulation and Recommendation jointly with the Kentucky Attorney General, subject to review and approval by the KPSC, which if approved, would resolve the case. The Stipulation and Recommendation includes a $9 million increase in base revenues, an ROE of 9.375% for natural gas base rates and 9.3% for natural gas riders, a rider for PHMSA-required capital investments with an annual 5% rate increase cap and a four-year natural gas base rate case stay-out. The hearing was held on October 18, 2021. Duke Energy Kentucky anticipates the KPSC will rule on the request by the end of 2021. Duke Energy Kentucky cannot predict the outcome of this matter.
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Midwest Propane Caverns
Duke Energy Ohio uses propane stored in caverns to meet peak demand during winter. Once the Central Corridor Project is complete, the propane peaking facilities will no longer be necessary and will be retired. On October 7, 2021, Duke Energy Ohio requested deferral treatment of the property, plant and equipment as well as costs related to propane inventory and decommissioning costs. There is approximately $27 million in Property, Plant and Equipment on the Condensed Consolidated Balance Sheets as of September 30, 2021, and December 31, 2020, related to the propane caverns. Duke Energy Ohio cannot predict the outcome of this matter.
Duke Energy Indiana
2019 Indiana Rate Case
On July 2, 2019, Duke Energy Indiana filed a general rate case with the IURC for a rate increase for retail customers of approximately $395 million. The rebuttal case, filed on December 4, 2019, updated the requested revenue requirement to result in a 15.6% or $396 million average retail rate increase, including the impacts of the Utility Receipts Tax. Hearings concluded on February 7, 2020. On June 29, 2020, the IURC issued an order in the rate case approving a revenue increase of $146 million before certain adjustments and ratemaking refinements. The order approved Duke Energy Indiana’s requested forecasted rate base of $10.2 billion as of December 31, 2020, including the Edwardsport Integrated Gasification Combined Cycle (IGCC) Plant. The IURC reduced Duke Energy Indiana’s request by slightly more than $200 million, when accounting for the utility receipts tax and other adjustments. Approximately 50% of the reduction was due to a prospective change in depreciation and use of regulatory asset for the end-of-life inventory at retired generating plants, approximately 20% was due to the approved ROE of 9.7% versus the requested ROE of 10.4% and approximately 20% was related to miscellaneous earnings neutral adjustments. Step one rates were estimated to be approximately 75% of the total and became effective on July 30, 2020. Step two rates are estimated to be the remaining 25% of the total rate increase. Step two rates were approved July 28, 2021, and implemented in August 2021. Step two rates are based on a return on equity of 9.7% and actual December 31, 2020 capital structure with a 54% equity component. Step two rates will be reconciled to January 1, 2021. Several groups appealed the IURC order to the Indiana Court of Appeals. Appellate briefs were filed on October 14, 2020, focusing on three issues: wholesale sales allocations, coal ash basin cost recovery and the Edwardsport IGCC operating and maintenance expense level approved. The appeal was fully briefed in January 2021 and an oral argument was held on April 8, 2021. The Indiana Court of Appeals affirmed the IURC decision on May 13, 2021. The Indiana Office of Utility Consumer Counselor (OUCC) and the Duke Industrial Group filed a joint petition to transfer the rate case appeal to the Indiana Supreme Court on June 28, 2021. Response briefs were filed July 19, 2021. The Indiana Supreme Court granted the petition to transfer on September 16, 2021, and scheduled oral argument for November 16, 2021. Duke Energy Indiana cannot predict the outcome of this matter.
2020 Indiana Coal Ash Recovery Case
In Duke Energy Indiana’s 2019 rate case, the IURC approved coal ash basin closure costs expended through 2018 including financing costs as a regulatory asset and included in rate base. The IURC also opened a subdocket for post-2018 coal ash related expenditures. Duke Energy Indiana filed testimony on April 15, 2020, in the coal ash subdocket requesting recovery for the post-2018 coal ash basin closure costs for plans that have been approved by the Indiana Department of Environmental Management (IDEM) as well as continuing deferral, with carrying costs, on the balance. An evidentiary hearing was held on September 14, 2020. Briefing was completed by mid-September 2021. 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 IURC order is subject to appeal within 30 days to the IURC or the Indiana Court of Appeals. Duke Energy Indiana cannot predict the outcome of this matter.

Piedmont
2020 Tennessee Rate Case
On July 2, 2020, Piedmont filed an application with the TPUC, its first general rate case in Tennessee in nine years, for a rate increase for retail customers of approximately $30 million, which represents an approximate 15% increase in annual revenues. The rate increase is driven by significant infrastructure upgrade investments since Piedmont's previous rate case. Approximately half of the plant additions being added to rate base are categories of capital investment not covered under the IMR mechanism, which was approved in 2013. Piedmont amended its requested increase to approximately $26 million in December 2020. As authorized under Tennessee law, Piedmont implemented interim rates on January 2, 2021, at the level requested in its adjusted request. A settlement reached with the Tennessee Consumer Advocate in mid-January was filed with the TPUC on February 2, 2021. The settlement results in an increase of revenues of approximately $16 million and an ROE of 9.8%. On May 6, 2021, the TPUC issued an order approving the settlement. Revised customer rates became effective January 2, 2021. Piedmont refunded customers the difference between bills previously rendered under interim rates and such bills if rendered under approved rates, plus interest, in April 2021.
2021 North Carolina Rate Case
On March 22, 2021, Piedmont filed an application with the NCUC for a rate increase for retail customers of approximately $109 million, which represents an approximate 10% increase in retail revenues. The rate increase is driven by customer growth and significant infrastructure upgrade investments (plant additions) since the last general rate case. Approximately 70% of the plant additions being rolled into rate base are categories of plant investment not covered under the IMR mechanism, which was originally approved as part of the 2013 North Carolina Rate Case. On July 28, 2021, Piedmont amended its requested increase to approximately $97 million.
57
FINANCIAL STATEMENTSREGULATORY MATTERS

On September 7, 2021, Piedmont and the Public Staff, the Carolina Utility Customers Association, Inc. and the Carolina Industrial Group for Fair Utility Rates IV filed a Stipulation of Partial Settlement (Stipulation), which is subject to review and approval by the NCUC, resolving most issues between these parties. Major components of the Stipulation include:
•A return on equity of 9.6% and a capital structure of 51.6% equity and 48.4% debt;
•Continuation of the IMR mechanism and margin decoupling; and
•A revenue increase of $67 million, subject to completion of the Robeson County LNG facility and the Pender Onslow County expansion project.
An evidentiary hearing to review the Stipulation and other issues concluded on September 9, 2021. On October 12, 2021, Piedmont notified the NCUC of its intent to implement the stipulated rates effective November 1, 2021, on a temporary basis and subject to refund. On October 18, 2021, Piedmont and the Public Staff filed supplemental testimony attesting to the completion of the Robeson County LNG facility and the Pender Onslow County expansion project and to the propriety of including the capital investment for these two projects in this proceeding. Piedmont cannot predict the outcome of this matter.
OTHER REGULATORY MATTERS
Atlantic Coast Pipeline, LLC
Atlantic Coast Pipeline (ACP pipeline) was planned to be an approximately 600-mile interstate natural gas pipeline running from West Virginia to North Carolina. Duke Energy indirectly owns a 47% interest, which is accounted for as an equity method investment through its Gas Utilities and Infrastructure segment.
As a result of the uncertainty created by various legal rulings, the potential impact on the cost and schedule for the project, the ongoing legal challenges and the risk of additional legal challenges and delays through the construction period and Dominion’s decision to sell substantially all of its gas transmission and storage segment assets, Duke Energy's Board of Directors and management decided that it was not prudent to continue to invest in the project. On July 5, 2020, Duke Energy and Dominion announced the cancellation of the ACP pipeline project.
As part of the pretax charges to earnings of approximately $2.1 billion recorded in June 2020, within Equity in (losses) earnings of unconsolidated affiliates on the Duke Energy Condensed Consolidated Statements of Operations, Duke Energy established liabilities related to the cancellation of the ACP pipeline project. In February 2021, Duke Energy paid approximately $855 million to fund ACP's outstanding debt, relieving Duke Energy of its guarantee. At September 30, 2021, there is $36 million and $63 million within Other Current Liabilities and Other Noncurrent Liabilities, respectively, in the Gas Utilities and Infrastructure segment. The liabilities represent Duke Energy's obligation of approximately $99 million to satisfy remaining ARO requirements to restore construction sites.
See Notes 1 and 11 for additional information regarding this transaction.
Potential Coal Plant Retirements
The Subsidiary Registrants periodically file IRPs with their state regulatory commissions. The IRPs provide a view of forecasted energy needs over a long term (10 to 20 years) and options being considered to meet those needs. IRPs filed by the Subsidiary Registrants included planning assumptions to potentially retire certain coal-fired generating facilities in North Carolina and Indiana earlier than their current estimated useful lives. Duke Energy continues to evaluate the potential need to retire these coal-fired generating facilities earlier than the current estimated useful lives and plans to seek regulatory recovery for amounts that would not be otherwise recovered when any of these assets are retired.
The table below contains the net carrying value of generating facilities planned for retirement or included in recent IRPs as evaluated for potential retirement. Dollar amounts in the table below are included in Net property, plant and equipment on the Condensed Consolidated Balance Sheets as of September 30, 2021, and exclude capitalized asset retirement costs.
Remaining Net
CapacityBook Value
(in MW)(in millions)
Duke Energy Carolinas
Allen Steam Station Units 1-2(a)
324 $19 
Allen Steam Station Units 4-5(b)
516 362 
Cliffside Unit 5(b)
544 367 
Duke Energy Progress
Mayo Unit 1(b)
704 640 
Roxboro Units 3-4(b)
1,392 465 
Duke Energy Florida
Crystal River Units 4-5(c)
1,410 1,658 
Duke Energy Indiana (d)
Gibson Units 1-5(e)
2,822 1,814 
Cayuga Units 1-2(e)
995 713 
Total Duke Energy8,707 $6,038 
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FINANCIAL STATEMENTSREGULATORY MATTERS

(a)As part of the 2015 resolution of a lawsuit involving alleged New Source Review violations, Duke Energy Carolinas must retire Allen Steam Station Units 1 through 3 by December 31, 2024. The long-term energy options considered in the IRP could result in retirement of these units earlier than their current estimated useful lives. Unit 3 with a capacity of 270 MW and a net book value of $26 million at December 31, 2020, was retired in March 2021.
(b)These units were included in the IRP filed by Duke Energy Carolinas and Duke Energy Progress in North Carolina and South Carolina on September 1, 2020. The long-term energy options considered in the IRP could result in retirement of these units earlier than their current estimated useful lives. In 2019, Duke Energy Carolinas and Duke Energy Progress filed North Carolina rate cases that included depreciation studies that accelerate end-of-life dates for these plants. The NCUC issued orders in the 2019 rate cases of Duke Energy Carolinas and Duke Energy Progress on March 31, 2021, and April 16, 2021, respectively, in which the proposals to shorten the remaining depreciable lives of these units were denied, while indicating the IRP proceeding was the appropriate proceeding for the review of generating plant retirements.
(c)On January 14, 2021, Duke Energy Florida filed a settlement agreement with the FPSC, which proposed depreciation rates reflecting retirement dates for Duke Energy Florida's last two coal-fired generating facilities, Crystal River Units 4-5, eight years ahead of schedule in 2034 rather than in 2042. The settlement was approved by the FPSC on May 4, 2021.
(d)Gallagher Units 2 and 4 with a total capacity of 280 MW and a total net book value of $102 million at December 31, 2020, were retired on June 1, 2021.
(e)The rate case filed July 2, 2019, included proposed depreciation rates reflecting retirement dates from 2026 to 2038. The depreciation rates reflecting these updated retirement dates were approved by the IURC as part of the rate case order issued on June 29, 2020.
4. COMMITMENTS AND CONTINGENCIES
ENVIRONMENTAL
The Duke Energy Registrants are subject to federal, state and local regulations regarding air and water quality, hazardous and solid waste disposal, coal ash and other environmental matters. These regulations can be changed from time to time, imposing new obligations on the Duke Energy Registrants. The following environmental matters impact all Duke Energy Registrants.
Remediation Activities
In addition to AROs recorded as a result of various environmental regulations, the Duke Energy Registrants are responsible for environmental remediation at various sites. These include certain properties that are part of ongoing operations and sites formerly owned or used by Duke Energy entities. These sites are in various stages of investigation, remediation and monitoring. Managed in conjunction with relevant federal, state and local agencies, remediation activities vary based upon site conditions and location, remediation requirements, complexity and sharing of responsibility. If remediation activities involve joint and several liability provisions, strict liability, or cost recovery or contribution actions, the Duke Energy Registrants could potentially be held responsible for environmental impacts caused by other potentially responsible parties and may also benefit from insurance policies or contractual indemnities that cover some or all cleanup costs. Liabilities are recorded when losses become probable and are reasonably estimable. The total costs that may be incurred cannot be estimated because the extent of environmental impact, allocation among potentially responsible parties, remediation alternatives and/or regulatory decisions have not yet been determined at all sites. Additional costs associated with remediation activities are likely to be incurred in the future and could be significant. Costs are typically expensed as Operation, maintenance and other on the Condensed Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.
The following table contains information regarding reserves for probable and estimable costs related to the various environmental sites. These reserves are recorded in Other within Other Noncurrent Liabilities on the Condensed Consolidated Balance Sheets.
(in millions)September 30, 2021December 31, 2020
Reserves for Environmental Remediation
Duke Energy$74 $75 
Duke Energy Carolinas19 19 
Progress Energy17 19 
Duke Energy Progress6 6 
Duke Energy Florida11 12 
Duke Energy Ohio21 22 
Duke Energy Indiana5 6 
Piedmont12 10 
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
Duke Energy
Texas Storm Uri Tort Litigation
Duke Energy and several Duke Energy renewables project companies have been named in multiple lawsuits arising out of Texas Storm Uri in mid-February 2021, and particularly, in the deregulated market managed by the Electric Reliability Council of Texas. There are 30 state court actions pending. These lawsuits seek recovery for property damages, personal injury and for wrongful death allegedly incurred by the plaintiffs as a result of power outages, which the plaintiffs claim was the result of the defendants' failures. The cases pending in state court have been consolidated into a Texas state court multidistrict litigation proceeding before a single judge to handle all pretrial coordination. Duke Energy cannot predict the outcomes of these matters.
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FINANCIAL STATEMENTSCOMMITMENTS AND CONTINGENCIES

Duke Energy Carolinas and Duke Energy Progress
Coal Ash Insurance Coverage Litigation
In March 2017, Duke Energy Carolinas and Duke Energy Progress filed a civil action in the North Carolina Business Court against various insurance providers. The lawsuit seeks payment for coal ash related liabilities covered by third-party liability insurance policies. The insurance policies were issued between 1971 and 1986 and provide third-party liability insurance for property damage. The civil action seeks damages for breach of contract and indemnification for costs arising from the Coal Ash Act and the U.S. Environmental Protection Agency CCR rule at 15 coal-fired plants in North Carolina and South Carolina.
Duke Energy Carolinas and Duke Energy Progress have resolved claims against all, but two of the insurers, sued in this litigation and are dismissing their claims against the settling insurers. Duke Energy Carolinas and Duke Energy Progress have received approximately $418 million of coal ash insurance litigation proceeds from settlements with insurer-defendants and these proceeds will be distributed in accordance with the terms of the CCR settlement agreement. The companies are assessing their options with regard to the two remaining foreign insurers that have defaulted. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of this matter.
Duke Energy Carolinas
Ruben Villano, et al. v. Duke Energy Carolinas, LLC
On June 16, 2021, a group of nine individuals went over a low head dam adjacent to the Dan River Steam Station in Eden, North Carolina, while water tubing. Emergency personnel rescued four people and five others were confirmed deceased. On August 11, 2021, Duke Energy Carolinas was served with the complaint filed in Durham County Superior Court on behalf of four survivors, which was later amended to include all the decedents along with the survivors. The lawsuit alleges that Duke Energy Carolinas knew that the river was used for recreational purposes and that Duke Energy did not adequately warn about the dam. On September 30, 2021, Duke Energy Carolinas filed its Motion to Dismiss and Motion for Transfer of Venue from Durham County to Rockingham County. A hearing on these motions is set for November 15, 2021, and discovery has commenced. Duke Energy Carolinas cannot predict the outcome of this matter.
NTE Carolinas II, LLC Litigation
In November 2017, Duke Energy Carolinas entered into a standard FERC large generator interconnection agreement (LGIA) with NTE Carolinas II, LLC (NTE), a company that proposed to build a combined-cycle natural gas plant in Rockingham County, North Carolina. On September 6, 2019, Duke Energy Carolinas filed a lawsuit in Mecklenburg County Superior Court against NTE for breach of contract, alleging that NTE's failure to pay benchmark payments for Duke Energy Carolinas' transmission system upgrades required under the interconnection agreement constituted a termination of the interconnection agreement. Duke Energy Carolinas is seeking a monetary judgment against NTE because NTE failed to make multiple milestone payments. The lawsuit was moved to federal court in North Carolina. NTE filed a motion to dismiss Duke Energy Carolinas’ complaint and brought counterclaims alleging anti-competitive conduct and violations of state and federal statutes. Duke Energy Carolinas filed a motion to dismiss NTE's counterclaims.
On May 21, 2020, in response to a NTE petition challenging Duke Energy Carolinas' termination of the LGIA, FERC issued a ruling that 1) it has exclusive jurisdiction to determine whether a transmission provider may terminate a 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. Duke Energy Carolinas is cooperating with the Office of Enforcement but cannot predict the outcome of this investigation.
On August 17, 2020, the court denied both NTE’s and Duke Energy Carolinas’ Motion to Dismiss. The parties are in active discovery and trial is scheduled for June 20, 2022. Duke Energy Carolinas cannot predict the outcome of this matter.
Asbestos-related Injuries and Damages Claims
Duke Energy Carolinas has experienced numerous claims for indemnification and medical cost reimbursement related to asbestos exposure. These claims relate to damages for bodily injuries alleged to have arisen from exposure to or use of asbestos in connection with construction and maintenance activities conducted on its electric generation plants prior to 1985. As of September 30, 2021, there were 74 asserted claims for non-malignant cases with cumulative relief sought of up to $15 million, and 58 asserted claims for malignant cases with cumulative relief sought of up to $21 million. Based on Duke Energy Carolinas’ experience, it is expected that the ultimate resolution of most of these claims likely will be less than the amount claimed.
Duke Energy Carolinas has recognized asbestos-related reserves of $508 million at September 30, 2021, and $572 million at December 31, 2020. These reserves are classified in Other within Other Noncurrent Liabilities and Other within Current Liabilities on the Condensed Consolidated Balance Sheets. These reserves are based upon Duke Energy Carolinas' best estimate for current and future asbestos claims through 2041 and are recorded on an undiscounted basis. In light of the uncertainties inherent in a longer-term forecast, management does not believe they can reasonably estimate the indemnity and medical costs that might be incurred after 2041 related to such potential claims. It is possible Duke Energy Carolinas may incur asbestos liabilities in excess of the recorded reserves.
Duke Energy Carolinas has third-party insurance to cover certain losses related to asbestos-related injuries and damages above an aggregate self-insured retention. Duke Energy Carolinas’ cumulative payments began to exceed the self-insured retention in 2008. Future payments up to the policy limit will be reimbursed by the third-party insurance carrier. The insurance policy limit for potential future insurance recoveries indemnification and medical cost claim payments is $697 million in excess of the self-insured retention. Receivables for insurance recoveries were $644 million at September 30, 2021, and $704 million at December 31, 2020. These amounts are classified in Other within Other Noncurrent Assets and Receivables within Current Assets on the Condensed Consolidated Balance Sheets. Duke Energy Carolinas is not aware of any uncertainties regarding the legal sufficiency of insurance claims. Duke Energy Carolinas believes the insurance recovery asset is probable of recovery as the insurance carrier continues to have a strong financial strength rating.
60
FINANCIAL STATEMENTSCOMMITMENTS AND CONTINGENCIES

As described in Note 1, Duke Energy adopted the new guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. The reserve for credit losses for insurance receivables based on adoption of the new standard is $15 million for Duke Energy and Duke Energy Carolinas as of September 30, 2021, and December 31, 2020. The insurance receivable is evaluated based on the risk of default and the historical losses, current conditions and expected conditions around collectability. Management evaluates the risk of default annually based on payment history, credit rating and changes in the risk of default from credit agencies.
Duke Energy Progress and Duke Energy Florida
Spent Nuclear Fuel Matters
On June 18, 2018, Duke Energy Progress and Duke Energy Florida sued the U.S. in the U.S. Court of Federal Claims for damages incurred for the period 2014 through 2018. The lawsuit claimed the Department of Energy breached a contract in failing to accept spent nuclear fuel under the Nuclear Waste Policy Act of 1982 and asserted damages for the cost of on-site storage in the amount of $100 million and $200 million for Duke Energy Progress and Duke Energy Florida, respectively. Discovery is now complete, and trial is anticipated to be scheduled in 2022. Duke Energy Progress and Duke Energy Florida cannot predict the outcome of this matter.
Duke Energy Florida
Power Purchase Dispute Arbitration
Duke Energy Florida, on behalf of its customers, entered into a PPA for the purchase of firm capacity and energy from a qualifying facility under the Public Utilities Regulatory Policies Act of 1978. Duke Energy Florida determined the qualifying facility did not perform in accordance with the PPA, and Duke Energy Florida terminated the PPA. The qualifying facility counterparty filed a confidential American Arbitration Association (AAA) arbitration demand, challenging the termination of the PPA and seeking damages.
The final arbitration hearing occurred during the week of December 7, 2020. An interim arbitral award was issued in March 2021, upholding Duke Energy Florida's positions on all issues and awarding the company termination costs. In May 2021, the final arbitral award was issued awarding Duke Energy Florida its claimed fees and costs. On August 18, 2021, Duke Energy Florida filed a motion in Florida state court to confirm the arbitral award.
Duke Energy Indiana
Coal Ash Basin Closure Plan Appeal
On January 27, 2020, Hoosier Environmental Council (HEC) filed a Petition for Administrative Review with the Indiana Office of Environmental Adjudication challenging the Indiana Department of Environmental Management’s (IDEM's) December 10, 2019, partial approval of Duke Energy Indiana’s ash pond closure plan. After hearing oral arguments in early April 2021 on Duke Energy Indiana's and HEC's competing Motions for Summary Judgment, on May 4, 2021, the administrative court rejected all of HEC’s claims and issued a ruling in favor of Duke Energy Indiana. On June 3, 2021, HEC filed an appeal in Superior Court to seek judicial review of the order. On June 25, 2021, Duke Energy Indiana filed its response to the Petition to Review. On August 30, 2021, HEC served Duke Energy Indiana with its Brief in Support of Petition for Judicial Review. On October 29, 2021, Duke Energy Indiana and IDEM filed their response briefs. HEC's Reply Brief is due on or before November 22, 2021. Oral argument will be heard in December 2021, in Marion County Superior Court. Duke Energy Indiana cannot predict the outcome of this matter.
Other Litigation and Legal Proceedings
The Duke Energy Registrants are involved in other legal, tax and regulatory proceedings arising in the ordinary course of business, some of which involve significant amounts. The Duke Energy Registrants believe the final disposition of these proceedings will not have a material effect on their results of operations, cash flows or financial position. 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.
61
FINANCIAL STATEMENTSDEBT AND CREDIT FACILITIES

5. DEBT AND CREDIT FACILITIES
SUMMARY OF SIGNIFICANT DEBT ISSUANCES
The following table summarizes significant debt issuances (in millions).
Nine Months Ended September 30, 2021
Duke DukeDuke
MaturityInterestDukeEnergyEnergyEnergy
Issuance DateDateRateEnergy(Parent)CarolinasProgressPiedmont
Unsecured Debt
March 2021(a)
March 20312.500 %$350 $— $— $— $350 
June 2021(b)(c)
June 20232.500 %500 500 — — — 
June 2021(c)
June 20312.550 %1,000 1,000 — — — 
June 2021(c)
June 20413.300 %750 750 — — — 
June 2021(c)
June 20513.500 %750 750 — — — 
September 2021(d)
January 20823.250 %500 500 — — — 
First Mortgage Bonds
April 2021(e)
April 20312.550 %550 — 550 — — 
April 2021(e)
April 20513.450 %450 — 450 — — 
August 2021(f)
August 20312.000 %650 — — 650 — 
August 2021(f)
August 20512.900 %450 — — 450 — 
Total issuances$5,950 $3,500 $1,000 $1,100 $350 
(a)Debt issued to repay at maturity $160 million senior unsecured notes due June 2021, pay down short-term debt and for general corporate purposes.
(b)Debt issuance has a floating interest rate.
(c)Debt issued to repay $1.75 billion of Duke Energy (Parent) 2021 debt maturities, to repay a portion of short-term debt and for general corporate purposes.
(d)Debt issued to repay in October 2021 $500 million of Duke Energy (Parent) unsecured notes. The interest rate resets every five years.
(e)Debt issued to repay at maturity $500 million first mortgage bonds due June 2021, pay down short-term debt and for general company purposes.
(f)Debt issued to repay at maturity a total of $600 million first mortgage bonds due September 2021, pay down short-term debt and for general company purposes.
CURRENT MATURITIES OF LONG-TERM DEBT
The following table shows the significant components of Current maturities of long-term debt on the Condensed Consolidated Balance Sheets. The Duke Energy Registrants currently anticipate satisfying these obligations with cash on hand and proceeds from additional borrowings.
(in millions)Maturity DateInterest RateSeptember 30, 2021
Unsecured Debt
Duke Energy (Parent)(a)
October 20215.125 %500 
Duke Energy Florida(b)
November 20210.372 %200 
Duke Energy Progress(b)
February 20220.305 %700 
Duke Energy (Parent)March 20223.227 %300 
Duke Energy (Parent)(b)
March 20220.764 %300 
Progress EnergyApril 20223.150 %450 
Duke Energy (Parent)August 20223.050 %500 
Duke Energy (Parent)August 20222.400 %500 
First Mortgage Bonds
Duke Energy IndianaJanuary 20228.850 %53 
Duke Energy CarolinasMay 20223.350 %350 
Duke Energy ProgressMay 20222.800 %500 
Other(c)
520 
Current maturities of long-term debt$4,873 
(a)Junior unsecured notes due January 2073 were redeemed on October 7, 2021.
(b)Debt has a floating interest rate.
(c)Includes finance lease obligations, amortizing debt, tax-exempt bonds with mandatory put options and small bullet maturities.
62
FINANCIAL STATEMENTSDEBT AND CREDIT FACILITIES

AVAILABLE CREDIT FACILITIES
Master Credit Facility
In March 2021, Duke Energy amended its existing $8 billion Master Credit Facility to extend the termination date to March 2026. 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.
The table below includes the current borrowing sublimits and available capacity under these credit facilities.
September 30, 2021
DukeDukeDukeDukeDukeDuke
DukeEnergyEnergyEnergyEnergyEnergyEnergy
(in millions)Energy(Parent)CarolinasProgressFloridaOhioIndianaPiedmont
Facility size(a)
$8,000 $2,650 $1,275 $1,150 $850 $775 $600 $700 
Reduction to backstop issuances
Commercial paper(b)
(1,611)389 (375)(253)(527)(419)(150)(276)
Outstanding letters of credit(31)(25)(4)(2)— — — — 
Tax-exempt bonds(81)— — — — — (81)— 
Available capacity under the Master Credit Facility$6,277 $3,014 $896 $895 $323 $356 $369 $424 
(a)Represents the sublimit of each borrower.
(b)Duke Energy issued $625 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana. The balances are classified as Long-Term Debt Payable to Affiliated Companies on the Condensed Consolidated Balance Sheets.
Other Credit Facilities
September 30, 2021
(in millions)Facility sizeAmount drawn
Duke Energy (Parent) Three-Year Revolving Credit Facility(a)
$1,000 $500 
(a)During March 2021, Duke Energy extended the maturity date of the Three-Year Revolving Credit Facility from May 2022 to May 2024.
Duke Energy Ohio Term Loan Facility
In October 2021, Duke Energy Ohio entered into a two-year term loan facility with commitments totaling $100 million. Borrowings under the facility will be used to pay down short-term debt and for general corporate purposes. The term loan was fully drawn at the time of closing in October. The balance will be classified as Long-Term Debt on Duke Energy Ohio’s Condensed Consolidated Balance Sheets.
Duke Energy Kentucky Term Loan Facility
In October 2021, Duke Energy Kentucky entered into a two-year term loan facility with commitments totaling $50 million. Borrowings under the facility will be used to pay down short-term debt and for general corporate purposes. The term loan was fully drawn at the time of closing in October. The balance will be classified as Long-Term Debt on Duke Energy Ohio's Condensed Consolidated Balance Sheet.
Duke Energy Indiana Term Loan Facility
In October 2021, Duke Energy Indiana entered into a two-year term loan facility with commitments totaling $300 million. Borrowings under the facility will be used to pay down short-term debt and for general corporate purposes. The term loan was fully drawn at the time of closing in October. The balance will be classified as Long-Term Debt on Duke Energy Indiana’s Condensed Consolidated Balance Sheet.
6. GOODWILL
Duke Energy
The following table presents the goodwill by reportable segment included on Duke Energy's Condensed Consolidated Balance Sheets at September 30, 2021, and December 31, 2020.
Electric UtilitiesGas UtilitiesCommercial
(in millions)and Infrastructureand InfrastructureRenewablesTotal
Goodwill balance$17,379 $1,924 $122 $19,425 
Accumulated impairment charges— — (122)(122)
Goodwill, adjusted for accumulated impairment charges$17,379 $1,924 $— $19,303 
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FINANCIAL STATEMENTSGOODWILL

Duke Energy Ohio
Duke Energy Ohio's Goodwill balance of $920 million, allocated $596 million to Electric Utilities and Infrastructure and $324 million to Gas Utilities and Infrastructure, is presented net of accumulated impairment charges of $216 million on the Condensed Consolidated Balance Sheets at September 30, 2021, and December 31, 2020.
Progress Energy
Progress Energy's Goodwill is included in the Electric Utilities and Infrastructure segment and there are no accumulated impairment charges.
Piedmont
Piedmont's Goodwill is included in the Gas Utilities and Infrastructure segment and there are no accumulated impairment charges.
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 2021.
7. RELATED PARTY TRANSACTIONS
The Subsidiary Registrants engage in related party transactions in accordance with applicable state and federal commission regulations. Refer to the Condensed Consolidated Balance Sheets of the Subsidiary Registrants for balances due to or due from related parties. Material amounts related to transactions with related parties included on the Condensed Consolidated Statements of Operations and Comprehensive Income are presented in the following table.
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)2021202020212020
Duke Energy Carolinas
Corporate governance and shared service expenses(a)
$207 $198 $653 $528 
Indemnification coverages(b)
6 5 18 15 
Joint Dispatch Agreement (JDA) revenue(c)
6 6 32 16 
JDA expense(c)
68 28 133 72 
Intercompany natural gas purchases(d)
14 10 43 26 
Progress Energy
Corporate governance and shared service expenses(a)
$201 $185 $615 $520 
Indemnification coverages(b)
10 9 31 27 
JDA revenue(c)
68 28 133 72 
JDA expense(c)
6 6 32 16 
Intercompany natural gas purchases(d)
19 18 56 56 
Duke Energy Progress
Corporate governance and shared service expenses(a)
$121 $113 $367 $301 
Indemnification coverages(b)
4 4 14 13 
JDA revenue(c)
68 28 133 72 
JDA expense(c)
6 6 32 16 
Intercompany natural gas purchases(d)
19 18 56 56 
Duke Energy Florida
Corporate governance and shared service expenses(a)
$80 $72 $248 $219 
Indemnification coverages(b)
6 5 17 14 
Duke Energy Ohio
Corporate governance and shared service expenses(a)
$79 $80 $237 $241 
Indemnification coverages(b)
1 1 3 3 
Duke Energy Indiana
Corporate governance and shared service expenses(a)
$96 $102 $302 $300 
Indemnification coverages(b)
2 2 6 6 
Piedmont
Corporate governance and shared service expenses(a)
$32 $31 $101 $102 
Indemnification coverages(b)
1 1 3 2 
Intercompany natural gas sales(d)
33 28 99 82 
Natural gas storage and transportation costs(e)
6 6 17 17 
64
FINANCIAL STATEMENTSRELATED PARTY TRANSACTIONS

(a)The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, employee benefits, information technology, legal and accounting fees, as well as other third-party costs. These amounts are primarily recorded in Operation, maintenance and other 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.
In addition to the amounts presented above, the Subsidiary Registrants have other affiliate transactions, including rental of office space, participation in a money pool arrangement, other operational transactions, such as pipeline lease arrangements, and their proportionate share of certain charged expenses. These transactions of the Subsidiary Registrants are incurred in the ordinary course of business and are eliminated in consolidation.
As discussed in Note 11, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to CRC, an affiliate formed by a subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but do include a subordinated note from CRC for a portion of the purchase price.
Intercompany Income Taxes
Duke Energy and the Subsidiary Registrants file a consolidated federal income tax return and other state and jurisdictional returns. The Subsidiary Registrants have a tax sharing agreement with Duke Energy for the allocation of consolidated tax liabilities and benefits. Income taxes recorded represent amounts the Subsidiary Registrants would incur as separate C-Corporations. The following table includes the balance of intercompany income tax receivables and payables for the Subsidiary Registrants.
DukeDukeDukeDukeDuke
EnergyProgressEnergyEnergyEnergyEnergy
(in millions)CarolinasEnergyProgressFloridaOhioIndianaPiedmont
September 30, 2021
Intercompany income tax receivable$— $36 $— $8 $1 $— $14 
Intercompany income tax payable133 — 51 — — 17 — 
December 31, 2020
Intercompany income tax receivable$— $— $— $— $— $9 $10 
Intercompany income tax payable31 33 46 35 2 — — 
8. DERIVATIVES AND HEDGING
The Duke Energy Registrants use commodity and interest rate contracts to manage commodity price risk and interest rate risk. The primary use of commodity derivatives is to hedge the generation portfolio against changes in the prices of electricity and natural gas. Piedmont enters into natural gas supply contracts to provide diversification, reliability and natural gas cost benefits to its customers. Interest rate derivatives are used to manage interest rate risk associated with borrowings.
All derivative instruments not identified as NPNS are recorded at fair value as assets or liabilities on the Condensed Consolidated Balance Sheets. Cash collateral related to derivative instruments executed under master netting arrangements is offset against the collateralized derivatives on the Condensed Consolidated Balance Sheets. The cash impacts of settled derivatives are recorded as operating activities on the Condensed Consolidated Statements of Cash Flows.
INTEREST RATE RISK
The Duke Energy Registrants are exposed to changes in interest rates as a result of their issuance or anticipated issuance of variable-rate and fixed-rate debt and commercial paper. Interest rate risk is managed by limiting variable-rate exposures to a percentage of total debt and by monitoring changes in interest rates. To manage risk associated with changes in interest rates, the Duke Energy Registrants may enter into interest rate swaps, U.S. Treasury lock agreements and other financial contracts. In anticipation of certain fixed-rate debt issuances, a series of forward-starting interest rate swaps or Treasury locks may be executed to lock in components of current market interest rates. These instruments are later terminated prior to or upon the issuance of the corresponding debt.
65
FINANCIAL STATEMENTSDERIVATIVES AND HEDGING

Cash Flow Hedges
For a derivative designated as hedging the exposure to variable cash flows of a future transaction, referred to as a cash flow hedge, the effective portion of the derivative's gain or loss is initially reported as a component of other comprehensive income and subsequently reclassified into earnings once the future transaction impacts earnings. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt. Gains and losses reclassified out of accumulated other comprehensive loss for the three and nine months ended September 30, 2021, and 2020, were not material. Duke Energy's interest rate derivatives designated as hedges include interest rate swaps used to hedge existing debt within the Commercial Renewables segment and forward-starting interest rate swaps not accounted for under regulatory accounting.
Undesignated Contracts
Undesignated contracts primarily include contracts not designated as a hedge because they are accounted for under regulatory accounting or contracts that do not qualify for hedge accounting.
Duke Energy’s interest rate swaps for its regulated operations employ regulatory accounting. With regulatory accounting, the mark-to-market gains or losses on the swaps are deferred as regulatory liabilities or regulatory assets, respectively. Regulatory assets and liabilities are amortized consistent with the treatment of the related costs in the ratemaking process. The accrual of interest on the swaps is recorded as Interest Expense on the Duke Energy Registrant's Condensed Consolidated Statements of Operations and Comprehensive Income.
The following table shows notional amounts of outstanding derivatives related to interest rate risk.
September 30, 2021
DukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhio
Cash flow hedges$2,094 $— $— $— $— $— 
Undesignated contracts1,371 350 900 400 500 27 
Total notional amount(a)
$3,465 $350 $900 $400 $500 $27 
December 31, 2020
DukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhio
Cash flow hedges$632 $— $— $— $— $— 
Undesignated contracts1,177 400 750 750 — 27 
Total notional amount(a)
$1,809 $400 $750 $750 $— $27 
(a)Duke Energy includes amounts related to consolidated VIEs of $594 million in cash flow hedges and $94 million in undesignated contracts as of September 30, 2021, and $632 million in cash flow hedges as of December 31, 2020.
COMMODITY PRICE RISK
The Duke Energy Registrants are exposed to the impact of changes in the prices of electricity purchased and sold in bulk power markets and natural gas purchases, including Piedmont's natural gas supply contracts. Exposure to commodity price risk is influenced by a number of factors including the term of contracts, the liquidity of markets and delivery locations. To manage risk associated with commodity prices, the Duke Energy Registrants may enter into long-term power purchase or sales contracts and long-term natural gas supply agreements.
Cash Flow Hedges
For derivatives designated as hedging the exposure to variable cash flows of a future transaction, referred to as a cash flow hedge, the derivative's gain or loss is initially reported as a component of other comprehensive income and subsequently reclassified into earnings once the future transaction impacts earnings. Gains and losses reclassified out of accumulated other comprehensive loss for the three and nine months ended September 30, 2021, and 2020, were not material. Duke Energy’s commodity derivatives designated as hedges include long-term electricity sales in the Commercial Renewables segment.
Undesignated Contracts
For the Subsidiary Registrants, bulk power electricity and natural gas purchases flow through fuel adjustment clauses, formula-based contracts or other cost-sharing mechanisms. Differences between the costs included in rates and the incurred costs, including undesignated derivative contracts, are largely deferred as regulatory assets or regulatory liabilities. Piedmont policies allow for the use of financial instruments to hedge commodity price risks. The strategy and objective of these hedging programs are to use the financial instruments to reduce natural gas costs volatility for customers.
66
FINANCIAL STATEMENTSDERIVATIVES AND HEDGING

Volumes
The tables below include volumes of outstanding commodity derivatives. Amounts disclosed represent the absolute value of notional volumes of commodity contracts excluding NPNS. The Duke Energy Registrants have netted contractual amounts where offsetting purchase and sale contracts exist with identical delivery locations and times of delivery. Where all commodity positions are perfectly offset, no quantities are shown.
September 30, 2021
DukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergy
EnergyCarolinasEnergyProgressOhioIndianaPiedmont
Electricity (GWh)(a)
29,044 — — — 3,004 15,881 — 
Natural gas (millions of dekatherms)772 230 190 190 — 7 345 
December 31, 2020
DukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergy
EnergyCarolinasEnergyProgressOhioIndianaPiedmont
Electricity (GWh)(a)
35,409 — — — 2,559 10,802 — 
Natural gas (millions of dekatherms)678 145 158 158 — 2 373 
(a)Duke Energy includes 10,159 GWh and 22,048 GWh related to cash flow hedges as of September 30, 2021, and December 31, 2020, respectively.
LOCATION AND FAIR VALUE OF DERIVATIVE ASSETS AND LIABILITIES RECOGNIZED ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
The following tables show the fair value and balance sheet location of derivative instruments. Although derivatives subject to master netting arrangements are netted on the Condensed Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.
Derivative AssetsSeptember 30, 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current$359 $171 $135 $135 $— $4 $36 $12 
Noncurrent177 100 78 78 — — — — 
Total Derivative Assets – Commodity Contracts$536 $271 $213 $213 $— $4 $36 $12 
Interest Rate Contracts
Designated as Hedging Instruments
Current$2 $— $— $— $— $— $— $— 
Noncurrent3 — — — — — — — 
Not Designated as Hedging Instruments
Current$2 $— $2 $2 $— $— $— $— 
Total Derivative Assets – Interest Rate Contracts$7 $— $2 $2 $— $— $— $— 
Total Derivative Assets$543 $271 $215 $215 $— $4 $36 $12 
67
FINANCIAL STATEMENTSDERIVATIVES AND HEDGING

Derivative LiabilitiesSeptember 30, 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Commodity Contracts
Designated as Hedging Instruments
Current$37 $— $— $— $— $— $— — 
Noncurrent120 — — — — — — — 
Not Designated as Hedging Instruments
Current$33 $12 $— $— $— $— $2 $20 
Noncurrent128 — — — — — — 128 
Total Derivative Liabilities – Commodity Contracts$318 $12 $— $— $— $— $2 $148 
Interest Rate Contracts
Designated as Hedging Instruments
Current$45 $— $— $— $— $— $— $— 
Noncurrent29 — — — — — — — 
Not Designated as Hedging Instruments
Current19 6 12 — 12 1 — — 
Noncurrent4 — — — — 4 — — 
Total Derivative Liabilities – Interest Rate Contracts$97 $6 $12 $— $12 $5 $— $— 
Total Derivative Liabilities$415 $18 $12 $— $12 $5 $2 $148 
Derivative AssetsDecember 31, 2020
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Commodity Contracts
Not Designated as Hedging Instruments
Current$30 $14 $9 $9 $— $1 $6 $1 
Noncurrent13 6 6 6 — — — — 
Total Derivative Assets – Commodity Contracts$43 $20 $15 $15 $— $1 $6 $1 
Interest Rate Contracts
Not Designated as Hedging Instruments
Current$18 $— $18 $18 $— $— $— $— 
Total Derivative Assets – Interest Rate Contracts$18 $— $18 $18 $— $— $— $— 
Total Derivative Assets$61 $20 $33 $33 $— $1 $6 $1 
68
FINANCIAL STATEMENTSDERIVATIVES AND HEDGING

Derivative LiabilitiesDecember 31, 2020
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Commodity Contracts
Designated as Hedging Instruments
Current$14 $— $— $— $— $— $— $— 
Noncurrent70 — — — — — — — 
Not Designated as Hedging Instruments
Current$30 $13 $2 $2 $— $— $1 $15 
Noncurrent137 3 27 12 — — — 107 
Total Derivative Liabilities – Commodity Contracts$251 $16 $29 $14 $— $— $1 $122 
Interest Rate Contracts
Designated as Hedging Instruments
Current$15 $— $— $— $— $— $— $— 
Noncurrent48 — — — — — — — 
Not Designated as Hedging Instruments
Current5 4 — — — 1 — — 
Noncurrent5 — — — — 5 — — 
Total Derivative Liabilities – Interest Rate Contracts$73 $4 $— $— $— $6 $— $— 
Total Derivative Liabilities$324 $20 $29 $14 $— $6 $1 $122 
OFFSETTING ASSETS AND LIABILITIES
The following tables present the line items on the Condensed Consolidated Balance Sheets where derivatives are reported. Substantially all of Duke Energy's outstanding derivative contracts are subject to enforceable master netting arrangements. The gross amounts offset in the tables below show the effect of these netting arrangements on financial position, and include collateral posted to offset the net position. The amounts shown are calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.
Derivative AssetsSeptember 30, 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Current
Gross amounts recognized$363 $171 $137 $137 $— $4 $36 $12 
Gross amounts offset(143)(87)(56)(56)— — — — 
Net amounts presented in Current Assets: Other$220 $84 $81 $81 $— $4 $36 $12 
Noncurrent
Gross amounts recognized$180 $100 $78 $78 $— $— $— $— 
Gross amounts offset(71)(45)(26)(26)— — — — 
Net amounts presented in Other Noncurrent Assets: Other$109 $55 $52 $52 $— $— $— $— 
69
FINANCIAL STATEMENTSDERIVATIVES AND HEDGING

Derivative LiabilitiesSeptember 30, 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Current
Gross amounts recognized$134 $18 $12 $— $12 $1 $2 $20 
Gross amounts offset— — — — — — — — 
Net amounts presented in Current Liabilities: Other$134 $18 $12 $— $12 $1 $2 $20 
Noncurrent
Gross amounts recognized$281 $— $— $— $— $4 $— $128 
Gross amounts offset— — — — — — — — 
Net amounts presented in Other Noncurrent Liabilities: Other$281 $— $— $— $— $4 $— $128 
Derivative AssetsDecember 31, 2020
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Current
Gross amounts recognized$48 $14 $27 $27 $— $1 $6 $1 
Gross amounts offset(3)(2)(2)(2)— — — — 
Net amounts presented in Current Assets: Other$45 $12 $25 $25 $— $1 $6 $1 
Noncurrent
Gross amounts recognized$13 $6 $6 $6 $— $— $— $— 
Gross amounts offset(5)(1)(4)(4)— — — — 
Net amounts presented in Other Noncurrent Assets: Other$8 $5 $2 $2 $— $— $— $— 
Derivative LiabilitiesDecember 31, 2020
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Current
Gross amounts recognized$64 $17 $2 $2 $— $1 $1 $15 
Gross amounts offset(3)(2)(2)(2)— — — — 
Net amounts presented in Current Liabilities: Other$61 $15 $— $— $— $1 $1 $15 
Noncurrent
Gross amounts recognized$260 $3 $27 $12 $— $5 $— $107 
Gross amounts offset(5)(1)(4)(4)— — — — 
Net amounts presented in Other Noncurrent Liabilities: Other$255 $2 $23 $8 $— $5 $— $107 
9. INVESTMENTS IN DEBT AND EQUITY SECURITIES
Duke Energy’s investments in debt and equity securities are primarily comprised of investments held in (i) the NDTF at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, (ii) the grantor trusts at Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana related to OPEB plans and (iii) Bison. The Duke Energy Registrants classify investments in debt securities as AFS and investments in equity securities as fair value through net income (FV-NI).
For investments in debt securities classified as AFS, the unrealized gains and losses are included in other comprehensive income until realized, at which time they are reported through net income. For investments in equity securities classified as FV-NI, both realized and unrealized gains and losses are reported through net income. Substantially all of Duke Energy’s investments in debt and equity securities qualify for regulatory accounting, and accordingly, all associated realized and unrealized gains and losses on these investments are deferred as a regulatory asset or liability.
Duke Energy classifies the majority of investments in debt and equity securities as long term, unless otherwise noted.
70
FINANCIAL STATEMENTSINVESTMENTS IN DEBT AND EQUITY SECURITIES

Investment Trusts
The investments within the Investment Trusts are managed by independent investment managers with discretion to buy, sell and invest pursuant to the objectives set forth by the investment manager agreements and trust agreements. The Duke Energy Registrants have limited oversight of the day-to-day management of these investments. As a result, the ability to hold investments in unrealized loss positions is outside the control of the Duke Energy Registrants. Accordingly, all unrealized losses associated with debt securities within the Investment Trusts are recognized immediately and deferred to regulatory accounts where appropriate.
Other AFS Securities
Unrealized gains and losses on all other AFS securities are included in other comprehensive income until realized, unless it is determined the carrying value of an investment has a credit loss. The Duke Energy Registrants analyze all investment holdings each reporting period to determine whether a decline in fair value is related to a credit loss. If a credit loss exists, the unrealized credit loss is included in earnings. There were no material credit losses as of September 30, 2021, and December 31, 2020.
Other Investments amounts are recorded in Other within Other Noncurrent Assets on the Condensed Consolidated Balance Sheets.
DUKE ENERGY
The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.
September 30, 2021December 31, 2020
GrossGrossGrossGross
UnrealizedUnrealizedEstimatedUnrealizedUnrealizedEstimated
HoldingHoldingFairHoldingHoldingFair
(in millions)GainsLossesValueGainsLossesValue
NDTF
Cash and cash equivalents$— $— $164 $— $— $177 
Equity securities4,700 35 6,754 4,138 54 6,235 
Corporate debt securities44 5 847 76 1 806 
Municipal bonds13 1 296 22 — 370 
U.S. government bonds34 8 1,605 51 — 1,361 
Other debt securities4 1 195 8 — 180 
Total NDTF Investments$4,795 $50 $9,861 $4,295 $55 $9,129 
Other Investments
Cash and cash equivalents$— $— $87 $— $— $127 
Equity securities83 — 145 79 — 146 
Corporate debt securities4 1 130 8 — 110 
Municipal bonds3 1 69 5 — 86 
U.S. government bonds— — 50 — — 42 
Other debt securities— — 34 — — 47 
Total Other Investments$90 $2 $515 $92 $— $558 
Total Investments$4,885 $52 $10,376 $4,387 $55 $9,687 
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, 2021, and 2020, were as follows.
Three Months EndedNine Months Ended
(in millions)September 30, 2021September 30, 2020September 30, 2021September 30, 2020
FV-NI:
 Realized gains $34 $13 $320 $338 
 Realized losses40 16 100 148 
AFS:
 Realized gains17 26 51 73 
 Realized losses15 19 46 38 
71
FINANCIAL STATEMENTSINVESTMENTS IN DEBT AND EQUITY SECURITIES

DUKE ENERGY CAROLINAS
The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.
September 30, 2021December 31, 2020
GrossGrossGrossGross
UnrealizedUnrealizedEstimatedUnrealizedUnrealizedEstimated
HoldingHoldingFairHoldingHoldingFair
(in millions)GainsLossesValueGainsLossesValue
NDTF
Cash and cash equivalents$— $— $60 $— $— $30 
Equity securities2,725 14 3,912 2,442 23 3,685 
Corporate debt securities27 3 495 49 1 510 
Municipal bonds1 — 24 6 — 91 
U.S. government bonds18 2 752 25 — 475 
Other debt securities4 1 190 7 — 174 
Total NDTF Investments$2,775 $20 $5,433 $2,529 $24 $4,965 
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, 2021, and 2020, were as follows.
Three Months EndedNine Months Ended
(in millions)September 30, 2021September 30, 2020September 30, 2021September 30, 2020
FV-NI:
 Realized gains$25 $10 $243 $46 
 Realized losses 29 12 68 82 
AFS:
 Realized gains10 20 35 50 
 Realized losses10 17 32 30 
PROGRESS ENERGY
The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.
September 30, 2021December 31, 2020
GrossGrossGrossGross
UnrealizedUnrealizedEstimatedUnrealizedUnrealizedEstimated
HoldingHoldingFairHoldingHoldingFair
(in millions)GainsLossesValueGainsLossesValue
NDTF
Cash and cash equivalents$— $— $104 $— $— $147 
Equity securities1,975 21 2,842 1,696 31 2,550 
Corporate debt securities17 2 352 27 — 296 
Municipal bonds12 1 272 16 — 279 
U.S. government bonds16 6 853 26 — 886 
Other debt securities— — 5 1 — 6 
Total NDTF Investments$2,020 $30 $4,428 $1,766 $31 $4,164 
Other Investments
Cash and cash equivalents$— $— $18 $— $— $106 
Municipal bonds2 — 26 3 — 26 
Total Other Investments$2 $— $44 $3 $— $132 
Total Investments$2,022 $30 $4,472 $1,769 $31 $4,296 
72
FINANCIAL STATEMENTSINVESTMENTS 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, 2021, and 2020, were as follows.
Three Months EndedNine Months Ended
(in millions)September 30, 2021September 30, 2020September 30, 2021September 30, 2020
FV-NI:
 Realized gains$9 $3 $77 $292 
 Realized losses11 4 32 66 
AFS:
 Realized gains7 6 14 17 
 Realized losses6 2 12 7 
DUKE ENERGY PROGRESS
The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.
September 30, 2021December 31, 2020
GrossGrossGrossGross
UnrealizedUnrealizedEstimatedUnrealizedUnrealizedEstimated
HoldingHoldingFairHoldingHoldingFair
(in millions)GainsLossesValueGainsLossesValue
NDTF
Cash and cash equivalents$— $— $92 $— $— $76 
Equity securities1,882 21 2,736 1,617 31 2,459 
Corporate debt securities17 2 287 27 — 296 
Municipal bonds12 1 272 16 — 279 
U.S. government bonds16 2 466 26 — 412 
Other debt securities— — 5 1 — 6 
Total NDTF Investments$1,927 $26 $3,858 $1,687 $31 $3,528 
Other Investments
Cash and cash equivalents$— $— $16 $— $— $1 
Total Other Investments$— $— $16 $— $— $1 
Total Investments$1,927 $26 $3,874 $1,687 $31 $3,529 
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, 2021, and 2020, were as follows.
Three Months EndedNine Months Ended
(in millions)September 30, 2021September 30, 2020September 30, 2021September 30, 2020
FV-NI:
 Realized gains$9 $3 $76 $43 
 Realized losses11 4 31 51 
AFS:
 Realized gains6 6 13 17 
 Realized losses5 2 11 7 
73
FINANCIAL STATEMENTSINVESTMENTS IN DEBT AND EQUITY SECURITIES

DUKE ENERGY FLORIDA
The following table presents the estimated fair value of investments in debt and equity securities; equity investments are classified as FV-NI and debt investments are classified as AFS.
September 30, 2021December 31, 2020
GrossGrossGrossGross
UnrealizedUnrealizedEstimatedUnrealizedUnrealizedEstimated
HoldingHoldingFairHoldingHoldingFair
(in millions)GainsLossesValueGainsLossesValue
NDTF
Cash and cash equivalents$— $— $12 $— $— $71 
Equity securities93 — 106 79 — 91 
Corporate debt securities— — 65 — — — 
U.S. government bonds— 4 387 — — 474 
Total NDTF Investments(a)
$93 $4 $570 $79 $— $636 
Other Investments
Cash and cash equivalents$— $— $1 $— $— $1 
Municipal bonds2 — 26 3 — 26 
Total Other Investments$2 $— $27 $3 $— $27 
Total Investments$95 $4 $597 $82 $— $663 
(a)During the nine months ended September 30, 2021, and the year ended December 31, 2020, Duke Energy Florida received reimbursements from the NDTF for costs related to ongoing decommissioning activity of Crystal River Unit 3.
Realized gains and losses, which were determined on a specific identification basis, from sales of FV-NI and AFS securities for the three and nine months ended September 30, 2021, and 2020, were as follows:
Three Months EndedNine Months Ended
(in millions)September 30, 2021September 30, 2020September 30, 2021September 30, 2020
FV-NI:
Realized gains$— $— $1 $249 
Realized losses— — 1 15 
AFS:
 Realized gains1 — 1 — 
 Realized losses1 — 1 — 
DUKE ENERGY INDIANA
The following table presents the estimated fair value of investments in debt and equity securities; equity investments are measured at FV-NI and debt investments are classified as AFS.
September 30, 2021December 31, 2020
GrossGrossGrossGross
UnrealizedUnrealizedEstimatedUnrealizedUnrealizedEstimated
HoldingHoldingFairHoldingHoldingFair
(in millions)GainsLossesValueGainsLossesValue
Investments
Cash and cash equivalents$— $— $19 $— $— $1 
Equity securities56 — 90 58 — 97 
Corporate debt securities— — 5 — — 3 
Municipal bonds1 1 36 1 — 38 
U.S. government bonds— — 5 — — 4 
Total Investments$57 $1 $155 $59 $— $143 
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, 2021, and 2020, were immaterial.
74
FINANCIAL STATEMENTSINVESTMENTS IN DEBT AND EQUITY SECURITIES

DEBT SECURITY MATURITIES
The table below summarizes the maturity date for debt securities.
September 30, 2021
DukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaIndiana
Due in one year or less$151 $3 $121 $22 $99 $5 
Due after one through five years954 343 548 244 304 18 
Due after five through 10 years639 268 286 247 39 8 
Due after 10 years1,482 847 553 517 36 15 
Total$3,226 $1,461 $1,508 $1,030 $478 $46 
10. FAIR VALUE MEASUREMENTS
Fair value is the exchange price to sell an asset or transfer a liability in an orderly transaction between market participants at the measurement date. The fair value definition focuses on an exit price versus the acquisition cost. Fair value measurements use market data or assumptions market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs may be readily observable, corroborated by market data or generally unobservable. Valuation techniques maximize the use of observable inputs and minimize use of unobservable inputs. A midmarket pricing convention (the midpoint price between bid and ask prices) is permitted for use as a practical expedient.
Fair value measurements are classified in three levels based on the fair value hierarchy as defined by GAAP. Certain investments are not categorized within the fair value hierarchy. These investments are measured at fair value using the net asset value (NAV) per share practical expedient. The NAV is derived based on the investment cost, less any impairment, plus or minus changes resulting from observable price changes for an identical or similar investment of the same issuer.
Fair value accounting guidance permits entities to elect to measure certain financial instruments that are not required to be accounted for at fair value, such as equity method investments or the company’s own debt, at fair value. The Duke Energy Registrants have not elected to record any of these items at fair value.
Valuation methods of the primary fair value measurements disclosed below are as follows.
Investments in equity securities
The majority of investments in equity securities are valued using Level 1 measurements. Investments in equity securities are typically valued at the closing price in the principal active market as of the last business day of the quarter. Principal active markets for equity prices include published exchanges such as the New York Stock Exchange and Nasdaq Stock Market. Foreign equity prices are translated from their trading currency using the currency exchange rate in effect at the close of the principal active market. There was no after-hours market activity that was required to be reflected in the reported fair value measurements.
Investments in debt securities
Most investments in debt securities are valued using Level 2 measurements because the valuations use interest rate curves and credit spreads applied to the terms of the debt instrument (maturity and coupon interest rate) and consider the counterparty credit rating. If the market for a particular fixed-income security is relatively inactive or illiquid, the measurement is Level 3.
Commodity derivatives
Commodity derivatives with clearinghouses are classified as Level 1. Commodity derivatives with observable forward curves are classified as Level 2. If forward price curves are not observable for the full term of the contract and the unobservable period had more than an insignificant impact on the valuation, the commodity derivative is classified as Level 3. In isolation, increases (decreases) in natural gas forward prices result in favorable (unfavorable) fair value adjustments for natural gas purchase contracts; and increases (decreases) in electricity forward prices result in unfavorable (favorable) fair value adjustments for electricity sales contracts. Duke Energy regularly evaluates and validates pricing inputs used to estimate the fair value of natural gas commodity contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.
Interest rate derivatives
Most over-the-counter interest rate contract derivatives are valued using financial models that utilize observable inputs for similar instruments and are classified as Level 2. Inputs include forward interest rate curves, notional amounts, interest rates and credit quality of the counterparties.
Other fair value considerations
See Note 11 in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2020, for a discussion of the valuation of goodwill and intangible assets.
75
FINANCIAL STATEMENTSFAIR VALUE MEASUREMENTS
DUKE ENERGY
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the tables below for all Duke Energy Registrants exclude cash collateral, which is disclosed in Note 8. See Note 9 for additional information related to investments by major security type for the Duke Energy Registrants.
September 30, 2021
(in millions)Total Fair ValueLevel 1Level 2Level 3Not Categorized
NDTF cash and cash equivalents$164 $164 $— $— $— 
NDTF equity securities6,754 6,705 — — 49 
NDTF debt securities2,943 998 1,945 — — 
Other equity securities145 145 — — — 
Other debt securities283 45 238 — — 
Other cash and cash equivalents87 87 — — — 
Derivative assets543 27 490 26 — 
Total assets10,919 8,171 2,673 26 49 
Derivative liabilities(415)(2)(256)(157)— 
Net assets (liabilities)$10,504 $8,169 $2,417 $(131)$49 
December 31, 2020
(in millions)Total Fair ValueLevel 1Level 2Level 3Not Categorized
NDTF cash and cash equivalents$177 $177 $— $— $— 
NDTF equity securities6,235 6,189 — — 46 
NDTF debt securities2,717 874 1,843 — — 
Other equity securities146 146 — — — 
Other debt securities285 37 248 — — 
Other cash and cash equivalents127 127 — — — 
Derivative assets61 1 53 7 — 
Total assets9,748 7,551 2,144 7 46 
Derivative liabilities(324)— (240)(84)— 
Net assets (liabilities)$9,424 $7,551 $1,904 $(77)$46 
The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.
Derivatives (net)
Three Months Ended September 30,Nine Months Ended September 30,
(in millions) 2021202020212020
Balance at beginning of period$(131)$(92)$(77)$(102)
Total pretax realized or unrealized losses included in comprehensive income(11)(102)(86)(102)
Purchases, sales, issuances and settlements:
Purchases— — 21 14 
Settlements4 (3)(4)(18)
Total gains (losses) included on the Condensed Consolidated Balance Sheet7 (6)15 5 
Balance at end of period$(131)$(203)$(131)$(203)
76
FINANCIAL STATEMENTSFAIR VALUE MEASUREMENTS
DUKE ENERGY CAROLINAS
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.
September 30, 2021
(in millions)Total Fair ValueLevel 1Level 2Not Categorized
NDTF cash and cash equivalents$60 $60 $— $— 
NDTF equity securities3,912 3,863 — 49 
NDTF debt securities1,461 359 1,102 — 
Derivative assets271 — 271 — 
Total assets5,704 4,282 1,373 49 
Derivative liabilities(18)— (18)— 
Net assets$5,686 $4,282 $1,355 $49 
December 31, 2020
(in millions)Total Fair ValueLevel 1Level 2Not Categorized
NDTF cash and cash equivalents$30 $30 $— $— 
NDTF equity securities3,685 3,639 — 46 
NDTF debt securities1,250 192 1,058 — 
Derivative assets20 — 20 — 
Total assets4,985 3,861 1,078 46 
Derivative liabilities(20)— (20)— 
Net assets$4,965 $3,861 $1,058 $46 
PROGRESS ENERGY
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.
September 30, 2021December 31, 2020
(in millions)Total Fair ValueLevel 1Level 2Total Fair ValueLevel 1Level 2
NDTF cash and cash equivalents$104 $104 $— $147 $147 $— 
NDTF equity securities2,842 2,842 — 2,550 2,550 — 
NDTF debt securities1,482 639 843 1,467 682 785 
Other debt securities26 — 26 26 — 26 
Other cash and cash equivalents18 18 — 106 106 — 
Derivative assets215 — 215 33 — 33 
Total assets4,687 3,603 1,084 4,329 3,485 844 
Derivative liabilities(12)— (12)(29)— (29)
Net assets$4,675 $3,603 $1,072 $4,300 $3,485 $815 
DUKE ENERGY PROGRESS
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.
September 30, 2021December 31, 2020
(in millions)Total Fair ValueLevel 1Level 2Total Fair ValueLevel 1Level 2
NDTF cash and cash equivalents$92 $92 $— $76 $76 $— 
NDTF equity securities2,736 2,736 — 2,459 2,459 — 
NDTF debt securities1,030 278 752 993 237 756 
Other cash and cash equivalents16 16 — 1 1 — 
Derivative assets215 — 215 33 — 33 
Total assets4,089 3,122 967 3,562 2,773 789 
Derivative liabilities— — — (14)— (14)
Net assets$4,089 $3,122 $967 $3,548 $2,773 $775 
77
FINANCIAL STATEMENTSFAIR VALUE MEASUREMENTS
DUKE ENERGY FLORIDA
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.
September 30, 2021December 31, 2020
(in millions)Total Fair ValueLevel 1Level 2Total Fair ValueLevel 1Level 2
NDTF cash and cash equivalents$12 $12 $— $71 $71 $— 
NDTF equity securities106 106 — 91 91 — 
NDTF debt securities452 361 91 474 445 29 
Other debt securities26 — 26 26 — 26 
Other cash and cash equivalents1 1 — 1 1 — 
Total assets597 480 117 663 608 55 
Derivative liabilities(12)— (12)— — — 
Net assets$585 $480 $105 $663 $608 $55 
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, 2021, and December 31, 2020.
DUKE ENERGY INDIANA
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.
September 30, 2021December 31, 2020
(in millions)Total Fair ValueLevel 1Level 2Level 3Total Fair ValueLevel 1Level 2Level 3
Other equity securities$90 $90 $— $— $97 $97 $— $— 
Other debt securities46 — 46 — 45 — 45 — 
Other cash and cash equivalents19 19 — — 1 1 — — 
Derivative assets36 12 — 24 6 — — 6 
Total assets191 121 46 24 149 98 45 6 
Derivative liabilities(2)(2)— — (1)(1)— — 
Net assets$189 $119 $46 $24 $148 $97 $45 $6 
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)2021202020212020
Balance at beginning of period$22 $10 $6 $11 
Purchases, sales, issuances and settlements:
Purchases— — 18 10 
Settlements(3)(3)(12)(13)
Total gains included on the Condensed Consolidated Balance Sheet5 1 12 — 
Balance at end of period$24 $8 $24 $8 
PIEDMONT
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.
September 30, 2021December 31, 2020
(in millions)Total Fair ValueLevel 1Level 2Total Fair ValueLevel 1Level 2
Derivative assets$12 $12 $— $1 $1 $— 
Derivative liabilities(148)— (148)(122)— (122)
Net (liabilities) assets$(136)$12 $(148)$(121)$1 $(122)
78
FINANCIAL STATEMENTSFAIR VALUE MEASUREMENTS
The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.
Derivatives (net)
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)2021202020212020
Balance at beginning of period$— $(105)$— $(117)
Total (losses) gains and settlements— (6)— 6 
Balance at end of period$— $(111)$— $(111)
QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS
The following tables include quantitative information about the Duke Energy Registrants' derivatives classified as Level 3.
September 30, 2021
Weighted
Fair ValueAverage
Investment Type(in millions)Valuation TechniqueUnobservable InputRangeRange
Duke Energy      
Electricity contracts$(157)RTO forward pricingForward electricity curves – price per MWh$18.02 -$143.85 $38.43 
Duke Energy Ohio 
FTRs2 RTO auction pricingFTR price – per MWh0.06 -1.27 0.71 
Duke Energy Indiana 
FTRs24 RTO auction pricingFTR price – per MWh(1.11)-8.55 1.61 
Duke Energy
Total Level 3 derivatives$(131)
December 31, 2020
Weighted
Fair ValueAverage
Investment Type(in millions)Valuation TechniqueUnobservable InputRangeRange
Duke Energy      
Electricity contracts$(84)Discounted cash flowForward electricity curves – price per MWh$14.68 -$151.84$28.84
Duke Energy Ohio   
FTRs1 RTO auction pricingFTR price – per MWh0.25 -1.68 0.79 
Duke Energy Indiana    
FTRs6 RTO auction pricingFTR price – per MWh(2.40)-7.41 1.05 
Duke Energy
Total Level 3 derivatives$(77)
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, 2021December 31, 2020
(in millions)Book ValueFair ValueBook ValueFair Value
Duke Energy(a)
$62,802 $69,381 $59,863 $69,292 
Duke Energy Carolinas12,975 14,964 12,218 14,917 
Progress Energy19,488 22,593 19,264 23,470 
Duke Energy Progress9,848 10,915 9,258 10,862 
Duke Energy Florida7,549 8,932 7,915 9,756 
Duke Energy Ohio3,092 3,517 3,089 3,650 
Duke Energy Indiana4,092 4,883 4,091 5,204 
Piedmont2,968 3,320 2,780 3,306 
(a)Book value of long-term debt includes $1.3 billion at September 30, 2021, and December 31, 2020, 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.
79
FINANCIAL STATEMENTSFAIR VALUE MEASUREMENTS
At both September 30, 2021, and December 31, 2020, fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper and nonrecourse notes payable of VIEs are not materially different from their carrying amounts because of the short-term nature of these instruments and/or because the stated rates approximate market rates.
11. VARIABLE INTEREST ENTITIES
CONSOLIDATED VIEs
The obligations of the consolidated VIEs discussed in the following paragraphs are nonrecourse to the Duke Energy Registrants. The registrants have no requirement to provide liquidity to, purchase assets of or guarantee performance of these VIEs unless noted in the following paragraphs.
No financial support was provided to any of the consolidated VIEs during the nine months ended September 30, 2021, and the year ended December 31, 2020, or is expected to be provided in the future that was not previously contractually required.
Receivables Financing – DERF/DEPR/DEFR
DERF, DEPR and DEFR are bankruptcy remote, special purpose subsidiaries of Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, respectively. DERF, DEPR and DEFR are wholly owned LLCs with separate legal existence from their parent companies, and their assets are not generally available to creditors of their parent companies. On a revolving basis, DERF, DEPR and DEFR buy certain accounts receivable arising from the sale of electricity and related services from their parent companies.
DERF, DEPR and DEFR borrow amounts under credit facilities to buy these receivables. Borrowing availability from the credit facilities is limited to the amount of qualified receivables purchased, which generally exclude receivables past due more than a predetermined number of days and reserves for expected past-due balances. The sole source of funds to satisfy the related debt obligations is cash collections from the receivables. Amounts borrowed under the credit facilities for DERF and DEPR are reflected on the Condensed Consolidated Balance Sheets as Long-Term Debt. Amounts borrowed under the credit facilities for DEFR are reflected on the Condensed Consolidated Balance Sheets as Current maturities of long-term debt.
The most significant activity that impacts the economic performance of DERF, DEPR and DEFR are the decisions made to manage delinquent receivables. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida are considered the primary beneficiaries and consolidate DERF, DEPR and DEFR, respectively, as they make those decisions.
Receivables Financing – CRC
CRC is a bankruptcy remote, special purpose entity indirectly owned by Duke Energy. On a revolving basis, CRC buys certain accounts receivable arising from the sale of electricity, natural gas and related services from Duke Energy Ohio and Duke Energy Indiana. CRC borrows amounts under a credit facility to buy the receivables from Duke Energy Ohio and Duke Energy Indiana. Borrowing availability from the credit facility is limited to the amount of qualified receivables sold to CRC, which generally exclude receivables past due more than a predetermined number of days and reserves for expected past-due balances. The sole source of funds to satisfy the related debt obligation is cash collections from the receivables. Amounts borrowed under the credit facility are reflected on Duke Energy's Condensed Consolidated Balance Sheets as Long-Term Debt.
The proceeds Duke Energy Ohio and Duke Energy Indiana receive from the sale of receivables to CRC are approximately 75% cash and 25% in the form of a subordinated note from CRC. The subordinated note is a retained interest in the receivables sold. Depending on collection experience, additional equity infusions to CRC may be required by Duke Energy to maintain a minimum equity balance of $3 million.
CRC is considered a VIE because (i) equity capitalization is insufficient to support its operations, (ii) power to direct the activities that most significantly impact the economic performance of the entity is not held by the equity holder and (iii) deficiencies in net worth of CRC are funded by Duke Energy. The most significant activities that impact the economic performance of CRC are decisions made to manage delinquent receivables. Duke Energy is considered the primary beneficiary and consolidates CRC as it makes these decisions. Neither Duke Energy Ohio nor Duke Energy Indiana consolidate CRC.
Receivables Financing – Credit Facilities
The following table summarizes the amounts and expiration dates of the credit facilities and associated restricted receivables described above.
Duke Energy
Duke EnergyDuke EnergyDuke Energy
CarolinasProgressFlorida
(in millions)CRCDERFDEPRDEFR
Expiration dateFebruary 2023December 2022April 2023April 2023
Credit facility amount$350 $475 $350 $250 
Amounts borrowed at September 30, 2021350 475 350 250 
Amounts borrowed at December 31, 2020350 364 250 250 
Restricted Receivables at September 30, 2021535 915 532 443 
Restricted Receivables at December 31, 2020547 696 500 397 
Nuclear Asset-Recovery Bonds – DEFPF
DEFPF is a bankruptcy remote, wholly owned special purpose subsidiary of Duke Energy Florida. DEFPF was formed in 2016 for the sole purpose of issuing nuclear asset-recovery bonds to finance Duke Energy Florida's unrecovered regulatory asset related to Crystal River Unit 3.
80
FINANCIAL STATEMENTSVARIABLE INTEREST ENTITIES

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, 2021December 31, 2020
Receivables of VIEs$6 $4 
Regulatory Assets: Current54 53 
Current Assets: Other17 39 
Other Noncurrent Assets: Regulatory assets896 937 
Current Liabilities: Other2 10 
Current maturities of long-term debt56 55 
Long-Term Debt946 1,002 
Commercial Renewables
Certain of Duke Energy’s renewable energy facilities are VIEs due to Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. Assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders. Additionally, Duke Energy has VIEs associated with tax equity arrangements entered into with third-party investors in order to finance the cost of renewable assets eligible for tax credits. The activities that most significantly impacted the economic performance of these renewable energy facilities were decisions associated with siting, negotiating PPAs and Engineering, Procurement and Construction agreements, and decisions associated with ongoing operations and maintenance-related activities. Duke Energy is considered the primary beneficiary and consolidates the entities as it is responsible for all of these decisions.
The table below presents material balances reported on Duke Energy's Condensed Consolidated Balance Sheets related to Commercial Renewables VIEs.
(in millions)September 30, 2021December 31, 2020
Current Assets: Other$330 $257 
Property, Plant and Equipment: Cost7,315 6,394 
Accumulated depreciation and amortization(1,414)(1,242)
Other Noncurrent Assets: Other110 67 
Current maturities of long-term debt165 167 
Long-Term Debt1,552 1,569 
Other Noncurrent Liabilities: AROs167 148 
Other Noncurrent Liabilities: Other341 316 
NON-CONSOLIDATED VIEs
The following tables summarize the impact of non-consolidated VIEs on the Condensed Consolidated Balance Sheets.
September 30, 2021
Duke EnergyDuke Duke
PipelineCommercialEnergyEnergy
(in millions)InvestmentsRenewablesTotalOhioIndiana
Receivables from affiliated companies$— $— $— $47 $77 
Investments in equity method unconsolidated affiliates15 465 480 — — 
Deferred tax asset58 — 58 — — 
Total assets$73 $465 $538 $47 $77 
Other current liabilities61 3 64 — — 
Other noncurrent liabilities63 3 66 — — 
Total liabilities$124 $6 $130 $— $— 
Net (liabilities) assets$(51)$459 $408 $47 $77 
81
FINANCIAL STATEMENTSVARIABLE INTEREST ENTITIES

December 31, 2020
Duke EnergyDuke Duke
PipelineCommercialEnergyEnergy
(in millions)InvestmentsRenewablesTotalOhioIndiana
Receivables from affiliated companies$— $— $— $83 $110 
Investments in equity method unconsolidated affiliates— 530 530 — — 
Other noncurrent assets31 — 31 — — 
Total assets$31 $530 $561 $83 $110 
Other current liabilities928 5 933 — — 
Other noncurrent liabilities8 10 18 — — 
Total liabilities$936 $15 $951 $— $— 
Net assets (liabilities)$(905)$515 $(390)$83 $110 
The Duke Energy Registrants are not aware of any situations where the maximum exposure to loss significantly exceeds the carrying values shown above except for certain renewable energy project entities guarantees for debt services and operations and maintenance, as discussed below.
Pipeline Investments
Duke Energy has investments in various joint ventures to construct and operate pipeline projects. These entities are considered VIEs due to having insufficient equity to finance their own activities without subordinated financial support. Duke Energy does not have the power to direct the activities that most significantly impact the economic performance, the obligation to absorb losses or the right to receive benefits of these VIEs and therefore does not consolidate these entities.
Duke Energy has a 47% ownership interest in ACP. For the three and nine months ended September 30, 2020, the ACP investment was considered a significant subsidiary because its loss exceeded 10% of Duke Energy’s income. ACP's net loss for the three and nine months ended September 30, 2020, was $163 million and $4,505 million, respectively.
In 2020, Duke Energy determined that it would no longer invest in the construction of the ACP pipeline. In February 2021, Duke Energy paid approximately $855 million to fund ACP's outstanding debt, relieving Duke Energy of its guarantee. See Notes 1 and 3 for further information regarding this transaction.
Commercial Renewables
Duke Energy has investments in various renewable energy project entities. Duke Energy has a 50% ownership in a VIE, which owns a portfolio of wind projects. This entity is a VIE as a result of Duke Energy issuing guarantees for debt service and operations and maintenance reserves in support of debt financings. Duke Energy does not consolidate this VIE because power to direct and control key activities is shared jointly by Duke Energy and the other owner. Duke Energy also has equity ownership in an entity, which owns a portfolio of fuel cell projects. Duke Energy does not consolidate the fuel cell portfolio as it does not have the power to direct the activities that most significantly impact the economic performance of the entity.
OVEC
Duke Energy Ohio’s 9% ownership interest in OVEC is considered a non-consolidated VIE due to OVEC having insufficient equity to finance its activities without subordinated financial support. The activities that most significantly impact OVEC's economic performance include fuel strategy and supply activities and decisions associated with ongoing operations and maintenance-related activities. Duke Energy Ohio does not have the unilateral power to direct these activities, and therefore, does not consolidate OVEC.
As a counterparty to an Inter-Company Power Agreement (ICPA), Duke Energy Ohio has a contractual arrangement to receive entitlements to capacity and energy from OVEC’s power plants through June 2040 commensurate with its power participation ratio, which is equivalent to Duke Energy Ohio's ownership interest. Costs, including fuel, operating expenses, fixed costs, debt amortization and interest expense, are allocated to counterparties to the ICPA based on their power participation ratio. The value of the ICPA is subject to variability due to fluctuation in power prices and changes in OVEC's cost of business. Duke Energy cannot predict the outcome in this matter. See Note 3 for additional information.
CRC
See discussion under Consolidated VIEs for additional information related to CRC.
Amounts included in Receivables from affiliated companies in the above table for Duke Energy Ohio and Duke Energy Indiana reflect their retained interest in receivables sold to CRC. These subordinated notes held by Duke Energy Ohio and Duke Energy Indiana are stated at fair value.
The following table shows the gross and net receivables sold.
Duke Energy OhioDuke Energy Indiana
(in millions)September 30, 2021December 31, 2020September 30, 2021December 31, 2020
Receivables sold$218 $270 $328 $344 
Less: Retained interests47 83 77 110 
Net receivables sold$171 $187 $251 $234 
82
FINANCIAL STATEMENTSVARIABLE INTEREST ENTITIES

The following table shows sales and cash flows related to receivables sold.
Duke Energy OhioDuke Energy Indiana
Three Months EndedNine Months EndedThree Months EndedNine Months Ended
September 30,September 30,September 30,September 30,
(in millions)20212020202120202021202020212020
Sales
Receivables sold$486 $462 $1,490 $1,428 $794 $717 $2,176 $1,947 
Loss recognized on sale2 2 7 8 4 3 10 9 
Cash flows
Cash proceeds from receivables sold$490 $449 $1,519 $1,439 $798 $689 $2,199 $1,941 
Collection fees received— 1 1 1 — — 1 1 
Return received on retained interests1 1 3 3 1 1 4 4 
Cash flows from sales of receivables are reflected within Cash Flows From Operating Activities and Cash Flows from Investing Activities on Duke Energy Ohio’s and Duke Energy Indiana’s Condensed Consolidated Statements of Cash Flows.
12. REVENUE
Duke Energy earns substantially all of its revenues through its reportable segments, Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables.
Electric Utilities and Infrastructure
Electric Utilities and Infrastructure earns the majority of its revenues through retail and wholesale electric service through the generation, transmission, distribution and sale of electricity. Duke Energy generally provides retail and wholesale electric service customers with their full electric load requirements or with supplemental load requirements when the customer has other sources of electricity.
The majority of wholesale revenues are full requirements contracts where the customers purchase the substantial majority of their energy needs and do not have a fixed quantity of contractually required energy or capacity. As such, related forecasted revenues are considered optional purchases. Supplemental requirements contracts that include contracted blocks of energy and capacity at contractually fixed prices have the following estimated remaining performance obligations:
Remaining Performance Obligations
(in millions)20212022202320242025ThereafterTotal
Progress Energy$24 $107 $44 $45 $7 $51 $278 
Duke Energy Progress2 8 8 8 — — 26 
Duke Energy Florida22 99 36 37 7 51 252 
Duke Energy Indiana— 1 9 14 15 25 64 
Revenues for block sales are recognized monthly as energy is delivered and stand-ready service is provided, consistent with invoiced amounts and unbilled estimates.
Gas Utilities and Infrastructure
Gas Utilities and Infrastructure earns its revenue through retail and wholesale natural gas service through the transportation, distribution and sale of natural gas. Duke Energy generally provides retail and wholesale natural gas service customers with all natural gas load requirements. Additionally, while natural gas can be stored, substantially all natural gas provided by Duke Energy is consumed by customers simultaneously with receipt of delivery.
Fixed-capacity payments under long-term contracts for the Gas Utilities and Infrastructure segment include minimum margin contracts and supply arrangements with municipalities and power generation facilities. Revenues for related sales are recognized monthly as natural gas is delivered and stand-ready service is provided, consistent with invoiced amounts and unbilled estimates. Estimated remaining performance obligations are as follows:
Remaining Performance Obligations
(in millions)20212022202320242025ThereafterTotal
Piedmont$17 $67 $64 $61 $60 $336 $605 
Commercial Renewables
Commercial Renewables earns the majority of its revenues through long-term PPAs and generally sells all of its wind and solar facility output, electricity and Renewable Energy Certificates (RECs) to customers. Some of these PPAs have been accounted for as leases. For PPAs that are not accounted for as leases, the delivery of electricity and the delivery of RECs are considered separate performance obligations.
Other
The remainder of Duke Energy’s operations is presented as Other, which does not include material revenues from contracts with customers.
83
FINANCIAL STATEMENTSREVENUE

Disaggregated Revenues
Disaggregated revenues are presented as follows:
Three Months Ended September 30, 2021
DukeDukeDukeDukeDuke
(in millions)DukeEnergyProgressEnergyEnergyEnergyEnergy
By market or type of customerEnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Electric Utilities and Infrastructure
   Residential$2,955 $892 $1,525 $619 $906 $223 $316 $— 
   General1,873 685 826 400 426 119 240 — 
   Industrial861 360 264 195 69 35 202 — 
   Wholesale619 111 399 324 75 19 89 — 
   Other revenues252 72 198 118 80 17 23 — 
Total Electric Utilities and Infrastructure revenue from contracts with customers$6,560 $2,120 $3,212 $1,656 $1,556 $413 $870 $— 
Gas Utilities and Infrastructure
   Residential$129 $— $— $— $— $62 $— $66 
   Commercial78 — — — — 24 — 58 
   Industrial30 — — — — 3 — 26 
   Power Generation— — — — — — — 23 
   Other revenues33 — — — — 4 — 9 
Total Gas Utilities and Infrastructure revenue from contracts with customers$270 $— $— $— $— $93 $— $182 
Commercial Renewables
Revenue from contracts with customers$56 $— $— $— $— $— $— $— 
Other
Revenue from contracts with customers$8 $— $— $— $— $— $— $— 
Total revenue from contracts with customers$6,894 $2,120 $3,212 $1,656 $1,556 $506 $870 $182 
Other revenue sources(a)
$57 $(16)$21 $11 $5 $— $16 $13 
Total revenues$6,951 $2,104 $3,233 $1,667 $1,561 $506 $886 $195 
(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.
84
FINANCIAL STATEMENTSREVENUE

Three Months Ended September 30, 2020
DukeDukeDukeDukeDuke
(in millions)DukeEnergyProgressEnergyEnergyEnergyEnergy
By market or type of customerEnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Electric Utilities and Infrastructure
   Residential$2,936 $883 $1,550 $616 $934 $213 $289 $— 
   General1,804 664 805 384 421 119 212 — 
   Industrial797 342 245 179 66 35 175 — 
   Wholesale603 117 412 358 54 10 64 — 
   Other revenues238 62 167 75 92 23 22 — 
Total Electric Utilities and Infrastructure revenue from contracts with customers$6,378 $2,068 $3,179 $1,612 $1,567 $400 $762 $— 
Gas Utilities and Infrastructure
   Residential$112 $— $— $— $— $55 $— $57 
   Commercial64 — — — — 20 — 44 
   Industrial24 — — — — 3 — 22 
   Power Generation— — — — — — — 10 
   Other revenues16 — — — — 3 — 11 
Total Gas Utilities and Infrastructure revenue from contracts with customers$216 $— $— $— $— $81 $— $144 
Commercial Renewables
Revenue from contracts with customers$57 $— $— $— $— $— $— $— 
Other
Revenue from contracts with customers$7 $— $— $— $— $— $— $— 
Total revenue from contracts with customers$6,658 $2,068 $3,179 $1,612 $1,567 $481 $762 $144 
Other revenue sources(a)
$63 $(10)$18 $14 $— $(8)$(1)$18 
Total revenues$6,721 $2,058 $3,197 $1,626 $1,567 $473 $761 $162 
(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 STATEMENTSREVENUE

Nine Months Ended September 30, 2021
DukeDukeDukeDukeDuke
(in millions)DukeEnergyProgressEnergyEnergyEnergyEnergy
By market or type of customerEnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Electric Utilities and Infrastructure
   Residential$7,753 $2,368 $3,903 $1,657 $2,246 $589 $894 $— 
   General4,805 1,685 2,170 1,036 1,134 329 619 — 
   Industrial2,228 872 700 500 200 99 558 — 
   Wholesale1,644 341 1,056 901 155 45 202 — 
   Other revenues712 208 509 272 237 61 64 — 
Total Electric Utilities and Infrastructure revenue from contracts with customers$17,142 $5,474 $8,338 $4,366 $3,972 $1,123 $2,337 $— 
Gas Utilities and Infrastructure
   Residential$747 $— $— $— $— $241 $— $505 
   Commercial373 — — — — 99 — 273 
   Industrial110 — — — — 14 — 96 
   Power Generation— — — — — — — 69 
   Other revenues100 — — — — 21 — 34 
Total Gas Utilities and Infrastructure revenue from contracts with customers$1,330 $— $— $— $— $375 $— $977 
Commercial Renewables
Revenue from contracts with customers$163 $— $— $— $— $— $— $— 
Other
Revenue from contracts with customers$20 $— $— $— $— $— $— $— 
Total Revenue from contracts with customers$18,655 $5,474 $8,338 $4,366 $3,972 $1,498 $2,337 $977 
Other revenue sources(a)
$204 $(44)$79 $51 $15 $(4)$29 $39 
Total revenues$18,859 $5,430 $8,417 $4,417 $3,987 $1,494 $2,366 $1,016 
(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.
86
FINANCIAL STATEMENTSREVENUE

Nine Months Ended September 30, 2020
DukeDukeDukeDukeDuke
(in millions)DukeEnergyProgressEnergyEnergyEnergyEnergy
By market or type of customerEnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Electric Utilities and Infrastructure
   Residential$7,451 $2,316 $3,792 $1,578 $2,214 $558 $785 $— 
   General4,691 1,720 2,080 1,001 1,079 336 554 — 
   Industrial2,148 871 673 487 186 103 502 — 
   Wholesale1,535 332 1,018 877 141 22 163 — 
   Other revenues713 184 476 208 268 62 63 — 
Total Electric Utilities and Infrastructure revenue from contracts with customers$16,538 $5,423 $8,039 $4,151 $3,888 $1,081 $2,067 $— 
Gas Utilities and Infrastructure
   Residential$631 $— $— $— $— $214 $— $417 
   Commercial308 — — — — 86 — 222 
   Industrial92 — — — — 12 — 80 
   Power Generation— — — — — — — 27 
   Other revenues58 — — — — 12 — 46 
Total Gas Utilities and Infrastructure revenue from contracts with customers$1,089 $— $— $— $— $324 $— $792 
Commercial Renewables
Revenue from contracts with customers$170 $— $— $— $— $— $— $— 
Other
Revenue from contracts with customers$20 $— $— $— $— $— $— $— 
Total Revenue from contracts with customers$17,817 $5,423 $8,039 $4,151 $3,888 $1,405 $2,067 $792 
Other revenue sources(a)
$274 $(7)$78 $56 $9 $(11)$3 $79 
Total revenues$18,091 $5,416 $8,117 $4,207 $3,897 $1,394 $2,070 $871 
(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 STATEMENTSREVENUE

As described in Note 1, Duke Energy adopted the new guidance for credit losses effective January 1, 2020, using the modified retrospective method of adoption, which does not require restatement of prior year reported results. The following table presents the reserve for credit losses for trade and other receivables based on adoption of the new standard.
Three Months Ended September 30, 2020 and 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Balance at June 30, 2020$102 $14 $29 $14 $14 $5 $3 $6 
Write-Offs12 (2)15 13 2 — — — 
Credit Loss Expense(9)— (16)(15)— — — 3 
Other Adjustments28 10 9 9 — — — — 
Balance at September 30, 2020$133 $22 $37 $21 $16 $5 $3 $9 
Balance at June 30, 2021$123 $42 $36 $21 $16 $4 $3 $13 
Write-Offs(13)(3)(6)(3)(3)— — (4)
Credit Loss Expense11 4 6 3 3 — — 2 
Other Adjustments2 (1)— — — — — 4 
Balance at September 30, 2021$123 $42 $36 $21 $16 $4 $3 $15 
Nine Months Ended September 30, 2020 and 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Balance at December 31, 2019$76 $10 $16 $8 $7 $4 $3 $6 
Cumulative Change in Accounting Principle5 1 2 1 1 — — 1 
Write-Offs(7)(8)8 8 — — — (5)
Credit Loss Expense24 9 2 (5)8 1 — 7 
Other Adjustments35 10 9 9 — — — — 
Balance at September 30, 2020$133 $22 $37 $21 $16 $5 $3 $9 
Balance at December 31, 2020$146 $23 $37 $23 $14 $4 $3 $12 
Write-Offs(39)(10)(20)(11)(9)— — (7)
Credit Loss Expense40 20 19 9 10 — — 6 
Other Adjustments(24)9 — — 1 — — 4 
Balance at September 30, 2021$123 $42 $36 $21 $16 $4 $3 $15 
Trade and other receivables are evaluated based on an estimate of the risk of loss over the life of the receivable and current and historical conditions using supportable assumptions. Management evaluates the risk of loss for trade and other receivables by comparing the historical write-off amounts to total revenue over a specified period. Historical loss rates are adjusted due to the impact of current conditions, as well as forecasted conditions over a reasonable time period. The calculated write-off rate can be applied to the receivable balance for which an established reserve does not already exist. Management reviews the assumptions and risk of loss periodically for trade and other receivables.
The aging of trade receivables is presented in the table below. Duke Energy considers receivables greater than 30 days outstanding past due.
September 30, 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Unbilled Revenue(a)(b)
$826 $308 $242 $125 $117 $5 $27 $7 
0-30 days2,201 689 910 521 388 65 41 80 
30-60 days194 74 63 37 26 7 5 6 
60-90 days57 30 14 6 8 1 1 3 
90+ days161 68 27 5 22 31 10 9 
Deferred Payment Arrangements(c)
113 66 29 21 8 2 — 6 
Trade and Other Receivables$3,552 $1,235 $1,285 $715 $569 $111 $84 $111 
88
FINANCIAL STATEMENTSREVENUE

December 31, 2020
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Unbilled Revenue(a)(b)
$969 $328 $283 $167 $116 $2 $16 $86 
0-30 days1,789 445 707 398 307 60 26 149 
30-60 days185 80 54 25 29 8 3 8 
60-90 days22 1 10 4 6 2 1 3 
90+ days119 16 32 9 23 30 12 9 
Deferred Payment Arrangements(c)
215 96 80 52 28 — — 7 
Trade and Other Receivables$3,299 $966 $1,166 $655 $509 $102 $58 $262 
(a)Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy or natural gas delivered but not yet billed and are included within Receivables and Receivables of VIEs on the Condensed Consolidated Balance Sheets.
(b)Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail accounts receivable, including receivables for unbilled revenues, to an affiliate, CRC, and account for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 11 for further information. These receivables for unbilled revenues are $64 million and $115 million for Duke Energy Ohio and Duke Energy Indiana, respectively, as of September 30, 2021, and $87 million and $134 million for Duke Energy Ohio and Duke Energy Indiana, respectively, as of December 31, 2020.
(c)Due to certain customer financial hardships created by the COVID-19 pandemic and resulting stay-at-home orders, Duke Energy permitted customers to defer payment of past-due amounts through an installment payment plan over a period of several months.
13. STOCKHOLDERS' EQUITY
Basic EPS is computed by dividing net income available to Duke Energy common stockholders, as adjusted for distributed and undistributed earnings allocated to participating securities and accumulated preferred dividends, by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income available to Duke Energy common stockholders, as adjusted for distributed and undistributed earnings allocated to participating securities and accumulated preferred dividends, by the diluted weighted average number of common shares outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as equity forward sale agreements, were exercised or settled. Duke Energy’s participating securities are restricted stock units that are entitled to dividends declared on Duke Energy common stock during the restricted stock unit’s vesting periods. Dividends declared on preferred stock are recorded on the Condensed Consolidated Statements of Operations as a reduction of net income to arrive at net income available to Duke Energy common stockholders. Dividends accumulated on preferred stock are an adjustment to net income used in the calculation of basic and diluted EPS.
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)2021202020212020
Net income available to Duke Energy common stockholders$1,366 $1,265 $3,070 $1,347 
Accumulated preferred stock dividends adjustment12 12 12 13 
Less: Impact of participating securities1 1 3 2 
Income from continuing operations available to Duke Energy common stockholders$1,377 $1,276 $3,079 $1,358 
Weighted average common shares outstanding – basic and diluted769 735 769 735 
EPS available to Duke Energy common stockholders
Basic and diluted$1.79 $1.74 $4.00 $1.85 
Potentially dilutive items excluded from the calculation(a)
2 2 2 2 
Dividends declared per common share$0.985 $0.965 $2.915 $2.855 
Dividends declared on Series A preferred stock per depositary share(b)
$0.359 $0.359 $1.078 $1.078 
Dividends declared on Series B preferred stock per share(c)
$24.375 $24.375 $48.750 $49.292 
(a)Performance stock awards were not included in the dilutive securities calculation because the performance measures related to the awards had not been met.
(b)5.75% Series A Cumulative Redeemable Perpetual Preferred Stock dividends are payable quarterly in arrears on the 16th day of March, June, September and December. The preferred stock has a $25 liquidation preference per depositary share.
(c)4.875% Series B Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock dividends are payable semiannually in arrears on the 16th day of March and September. The preferred stock has a $1,000 liquidation preference per share.
89
FINANCIAL STATEMENTSEMPLOYEE BENEFIT PLANS

14. EMPLOYEE BENEFIT PLANS
DEFINED BENEFIT RETIREMENT PLANS
Duke Energy and certain subsidiaries maintain, and the Subsidiary Registrants participate in, qualified and non-qualified, non-contributory defined benefit retirement plans. Duke Energy's policy is to fund amounts on an actuarial basis to provide assets sufficient to meet benefit payments to be paid to plan participants.
Duke Energy monitors lump-sum benefit payment activity associated with its defined benefit retirement plans. Duke Energy does not believe it is probable that total lump-sum benefit payments will exceed the settlement threshold, defined as the sum of service cost and interest cost on projected benefit obligation components of net periodic pension costs, for any of its defined benefit retirement plans in 2021. If Duke Energy believed it were probable that total lump-sum benefit payments would exceed the settlement threshold in 2021, then a settlement charge reflecting the recognition of a pro-rata portion of previously unrecognized actuarial losses, equal to the percentage of reduction in the projected benefit obligation resulting from total lump-sum benefit payments, would be recognized.
QUALIFIED PENSION PLANS
The following tables include the components of net periodic pension costs for qualified pension plans.
Three Months Ended September 30, 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Service cost$43 $14 $13 $7 $5 $2 $2 $1 
Interest cost on projected benefit obligation55 13 17 8 10 2 5 2 
Expected return on plan assets(139)(36)(47)(21)(25)(7)(10)(5)
Amortization of actuarial loss33 7 10 5 5 2 3 2 
Amortization of prior service credit(7)(2)(1)— (1)— — (1)
Amortization of settlement charges2 1 1 — — — — 1 
Net periodic pension costs$(13)$(3)$(7)$(1)$(6)$(1)$— $— 
Three Months Ended September 30, 2020
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Service cost$41 $12 $12 $6 $5 $1 $2 $1 
Interest cost on projected benefit obligation67 16 21 10 12 4 6 2 
Expected return on plan assets(143)(36)(48)(22)(25)(7)(11)(5)
Amortization of actuarial loss32 7 10 4 6 2 3 2 
Amortization of prior service credit(8)(2)— — — — — (2)
Amortization of settlement charges11 6 5 5 1 — 1 1 
Net periodic pension costs$— $3 $— $3 $(1)$— $1 $(1)
Nine Months Ended September 30, 2021
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Service cost$131 $42 $38 $22 $16 $4 $7 $4 
Interest cost on projected benefit obligation165 38 52 23 29 9 14 6 
Expected return on plan assets(418)(106)(141)(63)(76)(21)(30)(15)
Amortization of actuarial loss100 22 29 14 15 5 10 7 
Amortization of prior service credit(22)(6)(2)(1)(1)— (1)(6)
Amortization of settlement charges6 4 2 1 — — — 1 
Net periodic pension costs$(38)$(6)$(22)$(4)$(17)$(3)$— $(3)
90
FINANCIAL STATEMENTSEMPLOYEE BENEFIT PLANS

Nine Months Ended September 30, 2020
DukeDukeDukeDukeDuke
DukeEnergyProgressEnergyEnergyEnergyEnergy
(in millions)EnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
Service cost$124 $38 $36 $20 $16 $3 $6 $4 
Interest cost on projected benefit obligation202 47 64 29 35 12 17 7 
Expected return on plan assets(429)(108)(143)(66)(76)(21)(32)(16)
Amortization of actuarial loss96 21 30 13 17 5 9 7 
Amortization of prior service credit(24)(6)(2)(1)(1)— (1)(7)
Amortization of settlement charges16 8 6 6 1 — 1 1 
Net periodic pension costs$(15)$— $(9)$1 $(8)$(1)$— $(4)
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, 2021, and 2020.
OTHER POST-RETIREMENT BENEFIT PLANS
Net periodic costs for OPEB plans were not material for the three and nine months ended September 30, 2021, and 2020.
15. INCOME TAXES
EFFECTIVE TAX RATES
The ETRs from continuing operations for each of the Duke Energy Registrants are included in the following table.
Three Months EndedNine Months Ended
September 30,September 30,
2021202020212020
Duke Energy6.6 %7.8 %6.7 %(6.4)%
Duke Energy Carolinas2.9 %12.0 %3.6 %13.6 %
Progress Energy12.9 %10.4 %11.5 %13.4 %
Duke Energy Progress6.3 %3.1 %5.9 %10.0 %
Duke Energy Florida19.1 %21.4 %19.1 %20.3 %
Duke Energy Ohio13.4 %16.7 %15.3 %16.6 %
Duke Energy Indiana15.8 %19.6 %16.3 %19.4 %
Piedmont25.0 %16.7 %8.4 %3.7 %
The decrease in the ETR for Duke Energy for the three months ended September 30, 2021, was primarily due to an increase in the amortization of excess deferred taxes.
The increase in the ETR for Duke Energy for the nine months ended September 30, 2021, was primarily due to the cancellation of the ACP pipeline project recorded in the prior year, partially offset by an increase in the amortization of excess deferred taxes.
The decrease in the ETR for Duke Energy Carolinas for the three and nine months ended September 30, 2021, was primarily due to an increase in the amortization of excess deferred taxes.
The increase in the ETR for Progress Energy for the three months ended September 30, 2021, was primarily due to a decrease in the amortization of excess deferred taxes.
The decrease in the ETR for Progress Energy for the nine months ended September 30, 2021, was primarily due to an increase in the amortization of excess deferred taxes.
The increase in the ETR for Duke Energy Progress for the three months ended September 30, 2021, was primarily due to a decrease in the amortization of excess deferred taxes.
The decrease in the ETR for Duke Energy Progress for the nine months ended September 30, 2021, was primarily due to an increase in the amortization of excess deferred taxes.
The decrease in the ETR for Duke Energy Florida for the three and nine months ended September 30, 2021, was primarily due to unfavorable tax adjustments in the prior year.
The decrease in the ETR for Duke Energy Ohio for the three and nine months ended September 30, 2021, was primarily due to an increase in the amortization of excess deferred taxes.
The decrease in the ETR for Duke Energy Indiana for the three and nine months ended September 30, 2021, was primarily due to an increase in the amortization of excess deferred taxes.
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FINANCIAL STATEMENTSINCOME TAXES

The increase in the ETR for Piedmont for the three months ended September 30, 2021, was primarily due to a certain favorable tax credits.
The increase in the ETR for Piedmont for the nine months ended September 30, 2021, was primarily due to a decrease in AFUDC equity.
16. SUBSEQUENT EVENTS
For information on subsequent events related to regulatory matters, commitments and contingencies and debt and credit facilities, see Notes 3, 4 and 5.
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following combined Management’s Discussion and Analysis of Financial Condition and Results of Operations is separately filed by Duke Energy and Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont. However, none of the registrants make any representation as to information related solely to Duke Energy or the Subsidiary Registrants of Duke Energy other than itself.
DUKE ENERGY
Duke Energy is an energy company headquartered in Charlotte, North Carolina. Duke Energy operates in the U.S. primarily through its subsidiaries, Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, Duke Energy Indiana and Piedmont. When discussing Duke Energy’s consolidated financial information, it necessarily includes the results of the Subsidiary Registrants, which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants.
Management’s Discussion and Analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes for the nine months ended September 30, 2021, and with Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2020.
Executive Overview
Advancing Our Clean Energy Transformation
During the third quarter, we continued to execute on our clean energy transformation, delivering strong, sustainable value for shareholders, customers, communities and employees.
•In October 2021, North Carolina House Bill 951 was signed into law after legislative leaders announced bipartisan support for new state policy that would accelerate a clean energy transition for generation serving customers in the Carolinas, including providing a framework for a goal of 70% carbon reduction in electric generation from 2005 levels by 2030 and carbon neutrality by 2050 while continuing to prioritize affordability and reliability for our customers, who are located in both North and South Carolina. The legislation establishes a framework overseen by the NCUC to advance state CO2 emission reductions through the use of least cost planning, including stakeholder involvement, and also introduces modernized recovery mechanisms, including multi-year rate plans, that promote more efficient recovery of investments and align incentives between the company and the state’s energy policy objectives. The goals for a clean energy transition are generally consistent with Duke Energy Carolinas' and Duke Energy Progress' resource planning filings with the PSCSC.
•Also in October 2021, the Southeast Energy Exchange Market (SEEM) received clearance from the FERC. The new SEEM platform will facilitate sub-hourly, bilateral trading, allowing participants to buy and sell power close to the time the energy is consumed, utilizing available unreserved transmission. Southeastern electricity customers are expected to see cost, reliability and environmental benefits.
•In a significant move to support the company’s path to net-zero strategy, in September 2021 we completed the first phase of the investment of a 19.9% minority interest in Duke Energy Indiana by an affiliate of GIC, transferring 11.05% interest in exchange for approximately $1.025 billion. The proceeds from the $2.05 billion investment are expected to address common equity needs through 2025 to partially fund the company’s $59 billion capital and investment expenditure plan. This plan includes grid improvement, investments in clean energy and an improved customer experience – keys to our strategy to reduce carbon emissions from electricity generation to net-zero by 2050.
•In September 2021, we announced Ledyard Windpower, a 207-MW project and our first wind farm in Iowa. Once in operation next year, this project will increase the company’s U.S. wind capacity to over 3,100 MW.
•In August 2021, we announced a partnership with Accenture and Microsoft to develop a novel technology platform with the intent of measuring baseline methane emissions from natural gas distribution systems with a high level of accuracy in near real time. Once deployed, we expect the use of satellite technology and the new platform will increase the speed of a field response team’s ability to identify and repair methane leaks along distribution lines and systems.
Regulatory Activity. During the third quarter of 2021, we continued to move our regulatory strategy forward. See Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for additional information.
•In October 2021, Duke Energy Ohio filed a request to review the company’s electric distribution rates, seeking approval to increase current electric distribution rates by approximately $55 million. Duke Energy Ohio has invested more than $800 million in a variety of capital projects across southwest Ohio since it last requested a regulatory review of its electric distribution rates in 2017. Also, in October 2021, Duke Energy Kentucky reached a constructive natural gas rate case settlement with the Attorney General, subject to review and approval of the KPSC.
•In September 2021, Piedmont Natural Gas, the Public Staff of the NCUC, the Carolina Utility Customers Association, Inc., and the Carolina Industrial Group for Fair Utility Rates IV, filed a stipulation resolving all issues between these parties related to Piedmont’s rate case filed in March 2021. This constructive outcome provided for a return on equity of 9.60% and 51.60% equity component of the capital structure resulting in an overall rate of return of 6.90%, with an increase in pretax income (base rates) of approximately $67 million. The Stipulation is subject to the review and approval of the NCUC.
•We received approximately $418 million of coal ash insurance litigation proceeds from our settlements with insurer-defendants. Proceeds will be distributed in accordance with the terms of the CCR settlement agreement.
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.
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MD&AMATTERS IMPACTING FUTURE RESULTS

Regulatory Matters
Coal Ash Costs
As a result of the NCDEQ settlement on December 31, 2019, Duke Energy Carolinas and Duke Energy Progress agreed to excavate seven of the nine remaining coal ash basins in North Carolina with ash moved to on-site lined landfills. At the two remaining basins, uncapped basin ash will be excavated and moved to off-site lined landfills. The majority of spend is expected to occur over the next 15-20 years. In January 2021, Duke Energy Carolinas and Duke Energy Progress reached a settlement agreement on recovery of coal ash costs as outlined in Note 3, "Regulatory Matters." The company agreed not to seek recovery of approximately $1 billion of deferred coal ash expenditures and Duke Energy Carolinas and Duke Energy Progress took a charge of approximately $500 million each in 2020. On March 31, 2021, and April 16, 2021, the NCUC approved the coal ash settlement for Duke Energy Carolinas and Duke Energy Progress, respectively.
Duke Energy Indiana has interpreted the CCR rule to identify the coal ash basin sites impacted and has assessed the amounts of coal ash subject to the rule and a method of compliance. In 2020, the Hoosier Environmental Council filed a petition challenging the Indiana Department of Environmental Management's (IDEM) partial approval of five of Duke Energy Indiana’s ash pond site closure plans at Gallagher Station. The petition does not challenge the other 13 basin closures approved by IDEM at other Indiana stations. Interpretation of the requirements of the CCR rule is subject to further legal challenges and regulatory approvals, which could result in additional ash basin closure requirements, higher costs of compliance and greater AROs. Additionally, Duke Energy Indiana has retired facilities that are not subject to the CCR rule. Duke Energy Indiana may incur costs at these facilities to comply with environmental regulations or to mitigate risks associated with on-site storage of coal ash.
MGP
Duke Energy Ohio and other parties have filed with the PUCO a Stipulation and Recommendation that would resolve all open issues regarding manufactured gas plant remediation costs incurred between 2013 and 2019, including Duke Energy Ohio's request for additional deferral authority beyond 2019, and the pending issues related to the Tax Act as it relates to Duke Energy Ohio's natural gas operations. These impacts, if approved by the PUCO, are not expected to have a material impact on Duke Energy Ohio's financial statements. Failure to approve the Stipulation and Recommendation, disallowance of costs incurred, failure to complete the work by the deadline or failure to obtain an extension from the PUCO could result in an adverse impact.
For additional information, see Notes 3 and 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and "Commitments and Contingencies," respectively.
Commercial Renewables
Duke Energy continues to monitor recoverability of renewable merchant plants located in the Electric Reliability Council of Texas West market and in the PJM West market, due to fluctuating market pricing and long-term forecasted energy prices. Based on the most recent recoverability test, the carrying value approximated the aggregate estimated future undiscounted cash flows for the assets under review. A continued decline in energy market pricing or other factors unfavorably impacting the economics would likely result in a future impairment. Impairment of these assets could result in adverse impacts. For additional information, see Note 2 to the Condensed Consolidated Financial Statements, "Business Segments."
In February 2021, a severe winter storm impacted certain Commercial Renewables assets in Texas. Extreme weather conditions limited the ability for these solar and wind facilities to generate and sell electricity into the Electric Reliability Council of Texas market. Lost revenues and higher than expected purchased power costs have negatively impacted the operating results of these generating units. The financial impact of the storm is expected to be material to the Commercial Renewables segment's 2021 operating results. In addition, Duke Energy has been named in multiple lawsuits arising out of this winter storm. For more information, see Notes 2 and 4 to the Condensed Consolidated Financial Statements, "Business Segments" and "Commitments and Contingencies," respectively.
COVID-19
Duke Energy continues to monitor the impacts of the COVID-19 pandemic on its results of operations, financial position and cash flows as a result of the economic slowdown caused by reduced operations of businesses and governmental agencies and the corresponding reduction in the demand for energy. Duke Energy has experienced improvement in energy sales, aging of receivables and operating results in recent periods and continues efforts to partially offset these impacts. Additionally, in light of learnings from COVID-19 regarding workforce deployment and technology capabilities, the company has reviewed the long-term real estate and future workforce strategy. The review has resulted in an initiative that will reduce physical workspace and includes reassessments of lease terms and lease modifications, termination penalties, as well as, asset impairments on property, plant and equipment and a change in workforce roles and responsibilities. For more information, see Notes 1 and 3 to the Condensed Consolidated Financial Statements, "Organization and Basis of Presentation" and "Regulatory Matters," respectively.
Activist Investor
On May 17, 2021, Elliott, who has indicated it holds an economic interest in outstanding Duke Energy common stock, publicly released a letter it had sent to the Board, which advocated for consideration of certain governance and strategic proposals. On May 17, 2021, management issued a response to Elliott. On July 19, 2021, Elliott publicly released a second letter to the Board and Duke Energy issued a response. Duke Energy is unable to predict the outcome of this matter.
Other Matters
See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Duke Energy Registrants' Annual Reports on Form 10-K for the year ended December 31, 2020, for discussion of risks associated with the Tax Act.
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MD&ADUKE ENERGY

Results of Operations
Non-GAAP Measures
Management’s Discussion and Analysis includes financial information prepared in accordance with GAAP in the U.S., as well as certain non-GAAP financial measures such as adjusted earnings and adjusted EPS discussed below. Generally, a non-GAAP financial measure is a numerical measure of financial performance, financial position or cash flows that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable measure calculated and presented in accordance with GAAP. Non-GAAP financial measures should be viewed as a supplement to, and not a substitute for, financial measures presented in accordance with GAAP. Non-GAAP measures presented may not be comparable to similarly titled measures used by other companies because other companies may not calculate the measures in the same manner.
Management evaluates financial performance in part based on non-GAAP financial measures, including adjusted earnings and adjusted EPS. Adjusted earnings and adjusted EPS represent income from continuing operations available to Duke Energy Corporation common stockholders in dollar and per share amounts, adjusted for the dollar and per share impact of special items. As discussed below, special items represent certain charges and credits, which management believes are not indicative of Duke Energy's ongoing performance. The most directly comparable GAAP measures for adjusted earnings and adjusted EPS are GAAP Reported Earnings (Loss) and GAAP Reported Earnings (Loss) Per Share, respectively.
Special items included in the periods presented below include the following, which management believes do not reflect ongoing costs:
•Workplace and workforce realignment represents costs attributable to business transformation, including long-term real estate strategy changes and workforce realignment.
•Regulatory Settlements represents an impairment charge related to the 2018 South Carolina rate cases, charges related to the CCR settlement and insurance proceeds distributed in accordance with that agreement and Duke Energy Carolinas and Duke Energy Progress partial settlements in the 2019 North Carolina rate cases.
•Gas Pipeline Investments represents costs related to the cancellation of the ACP pipeline and additional exit obligations.
•Severance represents the reversal of 2018 severance charges, which were deferred as a result of partial settlements in the Duke Energy Carolinas and the Duke Energy Progress 2019 North Carolina rate cases.
Three Months Ended September 30, 2021, as compared to September 30, 2020
GAAP reported EPS was $1.79 for the third quarter of 2021 compared to a $1.74 in the third quarter of 2020. In addition to the drivers below, GAAP reported EPS increased due to the cancellation of the ACP pipeline in the prior year and partial settlements in the 2019 North Carolina rate cases in the prior year. This was partially offset by an impairment charge related to the 2018 South Carolina rate cases and charges related to the CCR settlement and insurance proceeds distributed in accordance with that agreement.
As discussed above, management also evaluates financial performance based on adjusted EPS. Duke Energy’s third quarter 2021 adjusted EPS was $1.88 compared to $1.87 for the third quarter of 2020. The increase in adjusted EPS was primarily due to positive rate case contributions and higher volumes. This was partially offset by higher operation and maintenance expenses, higher income tax expense and share dilution from equity issuances.
The following table reconciles non-GAAP measures, including adjusted EPS, to their most directly comparable GAAP measures.
 Three Months Ended September 30,
20212020
(in millions, except per share amounts)EarningsEPS EarningsEPS
GAAP Reported Earnings/GAAP Reported EPS$1,366 $1.79 $1,265 $1.74 
Adjustments:
Workplace and Workforce Realignment(a)
7 — — — 
Regulatory Settlements(b)
64 0.09 27 0.04 
Gas Pipeline Investments(c)
(2)— 69 0.09 
Adjusted Earnings/Adjusted EPS$1,435 $1.88 $1,361 $1.87 
(a)Net of tax benefit of $2 million.
(b)Net of tax benefit of $19 million and $8 million for the three months ended September 30, 2021, and 2020, respectively.
(c)Net of tax expense of $1 million and tax benefit of $21 million for the three months ended September 30, 2021, and 2020, respectively.
Nine Months Ended September 30, 2021, as compared to September 30, 2020
GAAP Reported EPS was $4.00 for the nine months ended September 30, 2021, compared to $1.85 for the nine months ended September 30, 2020. In addition to the drivers below, GAAP reported EPS increased due to the cancellation of the ACP pipeline in the prior year, partially offset by workplace and workforce realignment costs.
As discussed above, management also evaluates financial performance based on adjusted EPS. Duke Energy’s adjusted EPS was $4.30 for the nine months ended September 30, 2021, compared to $4.09 for the nine months ended September 30, 2020. The increase in adjusted EPS was primarily due to positive rate case contributions and higher volumes, partially offset by higher income tax expense and share dilution from equity issuances.
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MD&ADUKE ENERGY

The following table reconciles non-GAAP measures, including adjusted EPS, to their most directly comparable GAAP measures.
 Nine Months Ended September 30,
20212020
(in millions, except per share amounts)EarningsEPSEarningsEPS
GAAP Reported Earnings/GAAP Reported EPS$3,070 $4.00 $1,347 $1.85 
Adjustments:
Workplace and Workforce Realignment(a)
142 0.19 — — 
Regulatory Settlements(b)
64 0.09 27 0.04 
Gas Pipeline Investments(c)
15 0.02 1,695 2.30 
Severance(d)
— — (75)(0.10)
Adjusted Earnings/Adjusted EPS$3,291 $4.30 $2,994 $4.09 
(a)Net of tax benefit of $42 million.
(b)Net of tax benefit of $19 million and $8 million for the nine months ended September 30, 2021, and 2020, respectively.
(c)Net of tax benefit of $4 million and $395 million for the nine months ended September 30, 2021, and 2020, respectively.
(d)Net of tax expense of $23 million.
SEGMENT RESULTS
The remaining information presented in this discussion of results of operations is on a GAAP basis. Management evaluates segment performance based on segment income. Segment income is defined as income from continuing operations net of income attributable to noncontrolling interests and preferred stock dividends. Segment income includes intercompany revenues and expenses that are eliminated in the Condensed Consolidated Financial Statements.
Duke Energy's segment structure includes the following segments: Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables. The remainder of Duke Energy’s operations is presented as Other. See Note 2 to the Condensed Consolidated Financial Statements, “Business Segments,” for additional information on Duke Energy’s segment structure.
Electric Utilities and Infrastructure
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)20212020Variance20212020Variance
Operating Revenues$6,569 $6,379 $190 $17,185 $16,596 $589 
Operating Expenses
Fuel used in electric generation and purchased power1,864 1,869 (5)4,760 4,703 57 
Operation, maintenance and other1,363 1,326 37 3,907 3,891 16 
Depreciation and amortization1,084 1,053 31 3,154 3,023 131 
Property and other taxes330 286 44 949 885 64 
Impairment of assets and other charges202 20 182 203 23 180 
Total operating expenses4,843 4,554 289 12,973 12,525 448 
Gains on Sales of Other Assets and Other, net9 3 6 11 11 — 
Operating Income1,735 1,828 (93)4,223 4,082 141 
Other Income and Expenses, net220 67 153 421 241 180 
Interest Expense365 308 57 1,066 991 75 
Income Before Income Taxes1,590 1,587 3 3,578 3,332 246 
Income Tax Expense160 206 (46)393 493 (100)
Less: Income Attributable to Noncontrolling Interest5 — 5 5 — 5 
Segment Income$1,425 $1,381 $44 $3,180 $2,839 $341 
Duke Energy Carolinas GWh sales25,033 23,726 1,307 67,357 64,045 3,312 
Duke Energy Progress GWh sales19,219 19,035 184 51,555 49,512 2,043 
Duke Energy Florida GWh sales12,983 12,973 10 32,731 32,390 341 
Duke Energy Ohio GWh sales6,844 6,678 166 18,586 17,763 823 
Duke Energy Indiana GWh sales8,788 8,463 325 23,880 22,842 1,038 
Total Electric Utilities and Infrastructure GWh sales72,867 70,875 1,992 194,109 186,552 7,557 
Net proportional MW capacity in operation49,749 50,371 (622)
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MD&ASEGMENT RESULTS — ELECTRIC UTILITIES AND INFRASTRUCTURE

Three Months Ended September 30, 2021, as compared to September 30, 2020
Electric Utilities and Infrastructure’s higher segment income is due to higher revenues from rate cases in various jurisdictions, weather-normal sales volumes, and coal ash insurance litigation proceeds partially offset by an impairment charge related to the South Carolina rate cases and higher operating expenses. The following is a detailed discussion of the variance drivers by line item.
Operating Revenues. The variance was driven primarily by:
•a $144 million increase in retail base rate pricing due to general rate cases in North Carolina and Indiana net of rider impacts as well as multiyear rate adjustments in Florida; and
•a $114 million increase in weather-normal retail sales volumes.
Partially offset by
•a $48 million decrease in storm revenues at Duke Energy Florida due to full recovery of Hurricane Dorian costs in the prior year; and
•a $17 million decrease in retail sales due to less favorable weather in the current year.
Operating Expenses. The variance was driven primarily by:
•a $182 million increase in impairment of assets and other charges primarily due to the 2018 South Carolina rate case settlements at Duke Energy Carolinas and Duke Energy Progress, partially offset by a prior year impairment of Duke Energy Carolina's Clemson assets;
•a $44 million increase in property and other taxes primarily due to higher property taxes at Duke Energy Carolinas and Duke Energy Ohio and a prior year sales and use tax refund at Duke Energy Carolinas;
•a $37 million increase in operation, maintenance and other primarily driven by higher employee-related costs, partially offset by lower storm and outage costs; and
•a $31 million increase in depreciation and amortization primarily due to resolution of rate cases and higher plant in service, partially offset by lower depreciation related to the extension of the lives of nuclear facilities.
Other Income and Expense, net. The increase is primarily due to coal ash insurance litigation proceeds at Duke Energy Carolinas and Duke Energy Progress and lower non-service pension costs.
Interest Expense. The variance was primarily due to lower debt return on coal ash at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Indiana.
Income Tax Expense. The decrease in tax expense was primarily due to an increase in the amortization of excess deferred taxes. The ETRs for the three months ended September 30, 2021, and 2020, were 10.1% and 13.0%, respectively. The decrease in the ETR was primarily due to an increase in the amortization of excess deferred taxes.
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Electric Utilities and Infrastructure’s variance is due to higher revenues from rate cases in various jurisdictions, higher retail sales volumes, and coal ash insurance litigation proceeds, partially offset by an impairment charge related to the South Carolina rate cases, higher depreciation and amortization and interest expense. The following is a detailed discussion of the variance drivers by line item.
Operating Revenues. The variance was driven primarily by:
•a $297 million increase in retail base rate pricing due to general rate cases in Indiana and North Carolina net of rider impacts as well as multiyear settlement rate adjustments in Florida;
•a $188 million increase in weather-normal retail sales volumes;
•an $86 million increase in retail sales, net of fuel revenues, due to favorable weather;
•a $61 million increase in fuel revenues primarily driven by higher sales volumes; and
•a $21 million increase in wholesale revenues primarily due to higher rates at Duke Energy Indiana and higher volumes at Duke Energy Progress, partially offset by a restructured capacity contract at Duke Energy Florida.
Partially offset by:
•a $103 million decrease in storm revenues due to full recovery of Hurricane Dorian costs in the prior year.
97
MD&ASEGMENT RESULTS — ELECTRIC UTILITIES AND INFRASTRUCTURE

Operating Expenses. The variance was driven primarily by:
•a $180 million increase in impairment of assets and other charges primarily due to the 2018 South Carolina rate case settlements at Duke Energy Carolinas and Duke Energy Progress, partially offset by a prior year impairment of Duke Energy Carolinas' Clemson assets;
•a $131 million increase in depreciation and amortization primarily due to resolution of rate cases and higher plant in service, partially offset by lower depreciation related to the extension of the lives of nuclear facilities;
•a $64 million increase in property and other taxes primarily due to higher property taxes at Duke Energy Carolinas and Duke Energy Ohio, and a prior year sales and use tax refund at Duke Energy Carolinas;
•a $57 million increase in fuel used in electric generation and purchased power primarily due to higher sales volumes; and
•a $16 million increase in operations, maintenance and other driven by higher employee-related expenses, partially offset by decreased storm amortization at Duke Energy Florida and lower COVID-19 costs.
Other Income and Expenses, net. The increase is primarily due to coal ash insurance litigation proceeds at Duke Energy Carolinas and Duke Energy Progress and lower non-service pension costs.
Interest Expense. The variance was primarily due to lower debt return on coal ash at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Indiana.
Income Tax Expense. The decrease in tax expense was primarily due to an increase in the amortization of excess deferred taxes, partially offset by an increase in pretax income. The ETRs for the nine months ended September 30, 2021, and 2020, were 11.0% and 14.8%, respectively. The decrease in the ETR was primarily due to an increase in the amortization of excess deferred taxes.
Gas Utilities and Infrastructure
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)20212020Variance20212020Variance
Operating Revenues$289 $241 $48 $1,391 $1,194 $197 
Operating Expenses
Cost of natural gas75 41 34 430 300 130 
Operation, maintenance and other102 103 (1)302 312 (10)
Depreciation and amortization74 65 9 216 193 23 
Property and other taxes30 26 4 92 82 10 
Impairment of assets and other charges— 7 (7)— 7 (7)
Total operating expenses281 242 39 1,040 894 146 
Operating Income (Loss)8 (1)9 351 300 51 
Other Income and Expenses
Equity in earnings (losses) of unconsolidated affiliates10 (71)81 2 (2,004)2,006 
Other income and expenses, net15 16 (1)50 42 8 
           Total other income and expenses25 (55)80 52 (1,962)2,014 
Interest Expense37 35 2 105 103 2 
(Loss) Income Before Income Taxes(4)(91)87 298 (1,765)2,063 
Income Tax (Benefit) Expense(1)(18)17 39 (365)404 
Segment (Loss) Income$(3)$(73)$70 $259 $(1,400)$1,659 
Piedmont LDC throughput (dekatherms)134,549,588 115,549,371 19,000,217 390,210,785 360,861,306 29,349,479 
Duke Energy Midwest LDC throughput (Mcf)10,268,918 9,678,342 590,576 62,220,827 58,570,583 3,650,244 
Three Months Ended September 30, 2021, as compared to September 30, 2020
Gas Utilities and Infrastructure’s results were impacted primarily by the cancellation of the ACP pipeline in the prior year. The following is a detailed discussion of the variance drivers by line item.
Operating Revenues. The variance was driven primarily by:
•a $34 million increase due to higher natural gas costs passed through to customers, higher volumes, and higher off-system sales natural gas costs; and
•a $12 million increase due to growth in base rates and riders at Piedmont and growth in riders in the Midwest.
98
MD&ASEGMENT RESULTS — GAS UTILITIES AND INFRASTRUCTURE

Operating Expenses. The variance was driven primarily by:
•a $34 million increase in cost of natural gas due to higher natural gas prices, higher volumes, and increased off-system sales natural gas costs; and
•a $9 million increase in depreciation due to additional plant in service.
Equity in earnings (losses) of unconsolidated affiliates. The variance was primarily driven by the cancellation of the ACP pipeline in the prior year.
Income Tax Benefit. The decrease in tax benefit was primarily due to a decrease in pretax losses. The ETRs for the three months ended September 30, 2021, and 2020, were 25.0% and 19.8%, respectively. The increase in the ETR was primarily due to certain favorable tax credits.
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Gas Utilities and Infrastructure’s results were impacted primarily by the cancellation of the ACP pipeline in the prior year and margin growth. The following is a detailed discussion of the variance drivers by line item.
Operating Revenues. The variance was driven primarily by:
•a $130 million increase due to higher natural gas costs passed through to customers, higher volumes, and increased off-system sales natural gas costs;
•a $15 million increase due to Tennessee base rate case increases;
•an $11 million increase due to North Carolina IMR; and
•a $10 million increase due to revenue from the Capital Expenditure Program (CEP) rider related to 2019 and 2020 activity.
Operating Expenses. The variance was driven primarily by:
•a $130 million increase in cost of natural gas due to higher natural gas prices, higher volumes, and increased off-system sales natural gas costs; and
•a $23 million increase in depreciation due to additional plant in service.
Equity in earnings (losses) of unconsolidated affiliates. The variance was driven primarily by the cancellation of the ACP pipeline in the prior year.
Income Tax Expense. The increase in tax expense was primarily due to the cancellation of the ACP pipeline project recorded in the prior year. The ETRs for the nine months ended September 30, 2021, and 2020, were 13.1% and 20.7%, respectively. The decrease in the ETR was primarily due to the cancellation of the ACP pipeline project recorded in the prior year.
Commercial Renewables
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)20212020Variance20212020Variance
Operating Revenues$117 $126 $(9)$355 $378 $(23)
Operating Expenses
Operation, maintenance and other90 72 18 240 204 36 
Depreciation and amortization58 52 6 167 148 19 
Property and other taxes10 8 2 28 24 4 
Impairment of assets and other charges— — — — 6 (6)
Total operating expenses158 132 26 435 382 53 
Operating Loss(41)(6)(35)(80)(4)(76)
Other Income and Expenses, net(2)(1)(1)(24)— (24)
Interest Expense20 18 2 53 49 4 
Loss Before Income Taxes(63)(25)(38)(157)(53)(104)
Income Tax Benefit(6)(15)9 (56)(52)(4)
Add: Loss Attributable to Noncontrolling Interests135 70 65 253 208 45 
Segment Income$78 $60 $18 $152 $207 $(55)
Renewable plant production, GWh2,567 2,563 4 7,942 7,660 282 
Net proportional MW capacity in operation(a)
4,630 3,984 646 
(a)Certain projects are included in tax equity structures where investors have differing interests in the project's economic attributes. One hundred percent of the tax equity project's capacity is included in the table above.
99
MD&ASEGMENT RESULTS — COMMERCIAL RENEWABLES

Three Months Ended September 30, 2021, as compared to September 30, 2020
Commercial Renewables' results were favorable to prior year primarily driven by the growth of new project investments. Since the prior year period, Commercial Renewables has placed in service approximately 650 MW.
Operating Revenues. The variance was primarily driven by an $8 million decrease due to lower wind resource and operating downtime.
Operating Expenses. The variance was primarily driven by a $12 million increase in operating expenses, depreciation expense and property tax expense associated with the growth of new project investments placed in service, $8 million increase for higher engineering and construction costs within the distributed energy portfolio and $3 million increase attributed to maintenance at several facilities.
Income Tax Benefit. The decrease in the tax benefit was primarily driven by an increase in taxes associated with tax equity investments and a decrease in production tax credits generated partially offset by an increase in pretax losses.
Loss Attributable to Noncontrolling Interests. The increase was primarily driven by the growth of new wind and solar project investments financed with tax equity.
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Commercial Renewables' results were unfavorable to prior year primarily driven by the impacts from Texas Storm Uri, which resulted in a $35 million pretax loss, as well as unfavorable wind resource and fewer projects being placed in service in the current year.
Operating Revenues. The variance was primarily driven by a $20 million decrease due to lower wind resource and operating downtime and a $15 million decrease for lower market prices in the current year impacting the wind portfolio. This was partially offset by an $8 million increase for market sales in excess of market purchases during Texas Storm Uri and a $4 million increase due to growth of new projects.
Operating Expenses. The increase was primarily due to $33 million for higher operating expenses, depreciation expense and property tax expense as a result of the growth in new projects placed in service since prior year, $11 million increase for higher operating expenses attributed to maintenance at several wind and solar facilities, an $11 million increase for higher engineering and construction costs within the distributed energy portfolio and a $2 million increase associated with Texas Storm Uri. This was partially offset by a $6 million decrease related to an impairment charge in the prior year for a non-contracted wind project.
Other Income and Expenses, net. The variance was primarily driven by a $29 million loss in equity earnings due to the impacts of Texas Storm Uri, partially offset by $4 million in equity earnings from the wind and distributed asset portfolios.
Income Tax Benefit. The increase in the tax benefit was primarily driven by an increase in pretax losses partially offset by an increase in taxes associated with tax equity investments and a decrease in production tax credits generated.
Loss Attributable to Noncontrolling Interests. The variance was primarily driven by a $57 million net increase from the growth of new project investments financed with tax equity, partially offset by a $12 million loss resulting from Texas Storm Uri.
Other
Three Months Ended September 30,Nine Months Ended September 30,
(in millions)20212020Variance20212020Variance
Operating Revenues$28 $24 $4 $81 $73 $8 
Operating Expenses46 37 9 282 (15)297 
Losses on Sales of Other Assets and Other, net(1)— (1)(1)— (1)
Operating (Loss) Income(19)(13)(6)(202)88 (290)
Other Income and Expenses, net25 43 (18)78 55 23 
Interest Expense163 160 3 470 498 (28)
Loss Before Income Taxes(157)(130)(27)(594)(355)(239)
Income Tax Benefit(63)(66)3 (166)(149)(17)
Less: Income Attributable to Noncontrolling Interests1 — 1 1 — 1 
Less: Preferred Dividends39 39 — 92 93 (1)
Net Loss$(134)$(103)$(31)$(521)$(299)$(222)
Three Months Ended September 30, 2021, as compared to September 30, 2020
The higher net loss was driven by interest income related to a tax refund recorded in the prior year, impairments to optimize the company’s real estate portfolio and reduce office space as parts of the business move to a hybrid and remote workforce strategy and a lower income tax benefit due to higher tax optimization achieved in the prior year partially offset by higher pretax loss.
Operating Expenses. The increase was primarily driven by asset impairments to optimize the company's real estate portfolio and reduce office space as parts of the business move to a hybrid and remote workforce strategy.
Other Income and Expenses, net. The variance was primarily due to higher interest income in the prior year related to a tax refund of AMT credit carryforwards.
Interest Expense. The variance was primarily due to higher outstanding long-term debt.
100

MD&ASEGMENT RESULTS - OTHER

Nine Months Ended September 30, 2021, as compared to September 30, 2020
The higher net loss was driven by asset impairments to optimize the company's real estate portfolio and reduce office space as parts of the business move to a hybrid and remote workforce strategy as well as a reversal of severance costs in the prior year.
Operating Expenses. The increase was primarily due to asset impairments to optimize the company's real estate portfolio and reduce office space as parts of the business move to a hybrid and remote workforce strategy as well as a reversal of severance costs in the prior year.
Other Income and Expenses, net. The variance was primarily due to higher equity earnings from the NMC investment and market returns on investments that fund certain employee benefit obligations, partially offset by lower interest income in the prior year related to a tax refund of AMT credit carryforwards.
Interest Expense. The variance was primarily due to lower interest rates.
Income Tax Benefit. The increase in the tax benefit was primarily driven by an increase in pretax losses, partially offset by lower state tax expense in the prior year. The ETRs for the nine months ended September 30, 2021, and 2020, were 27.9% and 42.0%, respectively. The decrease in the ETR was primarily due to lower state tax expense in the prior year.
DUKE ENERGY CAROLINAS
Results of Operations
Nine Months Ended September 30,
(in millions)20212020Variance
Operating Revenues$5,430 $5,416 $14 
Operating Expenses
Fuel used in electric generation and purchased power1,218 1,326 (108)
Operation, maintenance and other1,347 1,218 129 
Depreciation and amortization1,088 1,090 (2)
Property and other taxes248 213 35 
Impairment of assets and other charges238 22 216 
Total operating expenses4,139 3,869 270 
Gains on Sales of Other Assets and Other, net1 1 — 
Operating Income1,292 1,548 (256)
Other Income and Expenses, net218 128 90 
Interest Expense400 370 30 
Income Before Income Taxes1,110 1,306 (196)
Income Tax Expense40 178 (138)
Net Income$1,070 $1,128 $(58)
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 year2021
Residential sales4.9 %
General service sales2.0 %
Industrial sales5.8 %
Wholesale power sales6.0 %
Joint dispatch sales23.0 %
Total sales5.2 %
Average number of customers2.4 %
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Operating Revenues. The variance was driven primarily by:
•an $88 million increase in weather-normal retail sales volumes;
•a $57 million increase in retail sales due to more favorable weather; and
•a $22 million increase due to higher pricing from the North Carolina retail rate case, net of a return of EDIT to customers.
Partially offset by:
•a $115 million decrease in fuel revenues due to lower prices, partially offset by higher retail sales volumes; and
•a $40 million decrease in rider revenues primarily due to energy efficiency programs.
101
MD&ADUKE ENERGY CAROLINAS

Operating Expenses. The variance was driven primarily by:
•a $216 million increase in impairment of assets and other charges due to the 2018 South Carolina rate case settlement and optimization of the company's real estate portfolio and reduction of office space as parts of the business move to a hybrid and remote workforce strategy, partially offset by a prior year Clemson University Combined Heat and Power Plant impairment;
•a $129 million increase in operation, maintenance and other expense primarily due to higher employee-related expenses and a severance cost adjustment in the prior year related to the 2019 North Carolina retail rate case, and higher costs associated with the implementation of Customer Connect; and
•a $35 million increase in property and other taxes primarily due to property tax valuation adjustments and a prior year sales and use tax refund.
Partially offset by:
•a $108 million decrease in fuel used in electric generation and purchased power primarily associated with the recovery of fuel expenses, partially offset by higher natural gas prices and changes in the generation mix.
Other Income and Expense, net. The variance was primarily due to coal ash insurance proceeds and lower non-service pension costs.
Interest Expense. The variance was driven by amortization of carrying costs related to excess deferred taxes, and lower debt return on coal ash projects.
Income Tax Expense. The decrease in tax expense was primarily due to an increase in the amortization of excess deferred taxes and a decrease in pretax income.
PROGRESS ENERGY
Results of Operations
Nine Months Ended September 30,
(in millions)20212020Variance
Operating Revenues$8,417 $8,117 $300 
Operating Expenses
Fuel used in electric generation and purchased power2,702 2,628 74 
Operation, maintenance and other1,863 1,789 74 
Depreciation and amortization1,430 1,356 74 
Property and other taxes419 419 — 
Impairment of assets and other charges79 1 78 
Total operating expenses6,493 6,193 300 
Gains on Sales of Other Assets and Other, net9 9 — 
Operating Income1,933 1,933 — 
Other Income and Expenses, net167 89 78 
Interest Expense592 599 (7)
Income Before Income Taxes1,508 1,423 85 
Income Tax Expense174 190 (16)
Net Income1,334 1,233 101 
Less: Net Income Attributable to Noncontrolling Interests1 1 — 
Net Income Attributable to Parent$1,333 $1,232 $101 
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Operating Revenues. The variance was driven primarily by:
•a $146 million increase in fuel cost recovery driven by higher fuel prices, higher volumes in the current year and accelerated recovery of retired Crystal River coal units;
•a $136 million increase in retail pricing due to the North Carolina rate case and base rate adjustments at Duke Energy Florida related to annual increases from the 2017 Settlement Agreement and the solar base rate adjustment;
•a $73 million increase in weather-normal retail sales volumes;
•a $32 million increase in other revenues at Duke Energy Florida primarily due to higher transmission revenues and higher customer charges that were waived due to COVID-19 in the prior year; and
•a $19 million increase in rider revenues at Duke Energy Florida primarily due to increased retail sales volumes.
102
MD&APROGRESS ENERGY

Partially offset by:
•a $103 million decrease in storm revenues at Duke Energy Florida due to full recovery of Hurricane Dorian costs in the prior year.
Operating Expenses. The variance was driven primarily by:
•a $78 million increase in impairment of assets and other charges primarily due to the 2018 South Carolina rate case settlement at Duke Energy Progress and optimization of the company's real estate portfolio and reduction of office space as parts of the business move to a hybrid and remote workforce strategy;
•a $74 million increase in fuel used in electric generation and purchased power primarily due to higher demand, changes in generation mix and recognition of RECs used for compliance at Duke Energy Progress, and outside fuel purchases during a major plant outage;
•a $74 million increase in operation, maintenance and other expense driven by a prior year severance cost adjustment related to the 2019 North Carolina retail rate case, outage costs and other employee-related costs, partially offset by reduced storm amortization at Duke Energy Florida; and
•a $74 million increase in depreciation and amortization primarily due to accelerated depreciation of retired Crystal River coal units and an increase in plant base at Duke Energy Florida, partially offset by the extension of the lives at nuclear facilities at Duke Energy Progress.
Other Income and Expenses, net. The increase is primarily due to coal ash insurance litigation proceeds at Duke Energy Progress, lower non-service pension costs and unrealized gains on the nuclear decommissioning trust fund at Duke Energy Florida.
Income Tax Expense. The decrease in tax expense was primarily due to an increase in the amortization of excess deferred taxes, partially offset by an increase in pretax income.
DUKE ENERGY PROGRESS
Results of Operations
Nine Months Ended September 30,
(in millions)20212020Variance
Operating Revenues$4,417 $4,207 $210 
Operating Expenses
Fuel used in electric generation and purchased power1,368 1,337 31 
Operation, maintenance and other1,092 970 122 
Depreciation and amortization811 833 (22)
Property and other taxes129 129 — 
Impairment of assets and other charges60 5 55 
Total operating expenses3,460 3,274 186 
Gains on Sales of Other Assets and Other, net8 8 — 
Operating Income965 941 24 
Other Income and Expenses, net111 52 59 
Interest Expense226 203 23 
Income Before Income Taxes850 790 60 
Income Tax Expense50 79 (29)
Net Income
$800 $711 $89 
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 period2021
Residential sales6.5 %
General service sales3.9 %
Industrial sales2.7 %
Wholesale power sales5.2 %
Joint dispatch sales(2.6)%
Total sales4.1 %
Average number of customers0.4 %
103
MD&ADUKE ENERGY PROGRESS

Nine Months Ended September 30, 2021, as compared to September 30, 2020
Operating Revenues. The variance was driven primarily by:
•a $72 million increase due to higher pricing from the North Carolina retail rate case, net of a return of EDIT to customers;
•a $54 million increase in weather-normal retail sales volumes in the current year;
•a $46 million increase in retail sales due to more favorable weather;
•a $24 million increase in fuel cost recovery driven by higher fuel prices and volumes in the current year; and
•a $15 million increase in wholesale revenues due to higher capacity volumes, partially offset by lower recovery of coal ash costs.
Operating Expenses. The variance was driven primarily by:
•a $122 million increase in operation, maintenance and other expense primarily due to higher employee-related costs and a severance cost adjustment in the prior year related to the 2019 North Carolina retail rate case, increased outage costs and energy efficiency program costs;
•a $55 million increase in impairment of assets and other charges primarily due to the 2018 South Carolina rate case settlement at Duke Energy Progress and optimization of the company's real estate portfolio and reduction of office space as parts of the business move to a hybrid and remote workforce strategy; and
•a $31 million increase in fuel used in electric generation and purchased power primarily due to higher demand and changes in generation mix as well as recognition of RECs used for compliance.
Partially offset by:
•a $22 million decrease in depreciation and amortization expense, primarily driven by the extension of the lives of nuclear facilities.
Other Income and Expense, net. The increase is primarily due to coal ash insurance litigation proceeds and lower non-service pension costs.
Interest Expense. The variance was driven primarily by lower debt return on coal ash projects.
Income Tax Expense. The decrease in tax expense was primarily due to an increase in the amortization of excess deferred taxes, partially offset by an increase in pretax income.
DUKE ENERGY FLORIDA
Results of Operations
Nine Months Ended September 30,
(in millions)20212020Variance
Operating Revenues$3,987 $3,897 $90 
Operating Expenses
Fuel used in electric generation and purchased power1,335 1,291 44 
Operation, maintenance and other760 806 (46)
Depreciation and amortization619 523 96 
Property and other taxes290 290 — 
Impairment of assets and other charges19 (4)23 
Total operating expenses3,023 2,906 117 
Gains on Sales of Other Assets and Other, net1 — 1 
Operating Income965 991 (26)
Other Income and Expenses, net54 36 18 
Interest Expense239 245 (6)
Income Before Income Taxes780 782 (2)
Income Tax Expense149 159 (10)
Net Income$631 $623 $8 
104
MD&ADUKE ENERGY FLORIDA

The following table shows the percent changes in GWh sales and average number of customers. The percentages for retail customer classes represent billed sales only. Wholesale power sales include both billed and unbilled sales. Total sales includes billed and unbilled retail sales and wholesale sales to incorporated municipalities, public and private utilities and power marketers. Amounts are not weather-normalized.
Increase (Decrease) over prior period2021
Residential sales(0.5)%
General service sales3.1 %
Industrial sales8.1 %
Wholesale and other20.1 %
Total sales1.1 %
Average number of customers1.9 %
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Operating Revenues. The variance was driven primarily by:
•a $122 million increase in fuel and capacity revenues primarily due to higher retail sales volumes and accelerated recovery of the retired coal units Crystal River 1 and 2;
•a $64 million increase in retail pricing due to base rate adjustments related to annual increases from the 2017 Settlement Agreement and the solar base rate adjustment;
•a $32 million increase in other revenues primarily due to lower revenues in the prior year due to the moratorium on customer late payments and service charges in response to the COVID-19 pandemic, lower outdoor lighting equipment rentals in the prior year, and higher transmission revenues due to prior year customer settlement and the increased network billing rates;
•a $19 million increase in rider revenues primarily due to increased volumes; and
•a $16 million increase in weather-normal retail sales volumes.
Partially offset by:
•a $103 million decrease in storm revenues due to full recovery of Hurricane Dorian costs in the prior year;
•a $37 million decrease in retail sales, net of fuel revenues, due to unfavorable weather in the current year; and
•an $18 million decrease in wholesale power revenues, net of fuel, primarily due to a restructured capacity contract.
Operating Expenses. The variance was driven primarily by:
•a $96 million increase in depreciation and amortization primarily due to accelerated depreciation of retired coal units Crystal River 1 and 2 and an increase in plant base;
•a $44 million increase in fuel used in electric generation and purchased power primarily due to higher natural gas prices, and outside fuel purchases during a major plant outage at the Hines facility; and
•a $23 million increase in impairment of assets and other charges to optimize the company's real estate portfolio and reduce office space as parts of the business move to a hybrid and remote workforce strategy.
Partially offset by:
•a $46 million decrease in operation, maintenance and other expense primarily due to decreased storm amortization costs, partially offset by outage maintenance costs at Hines.
Other Income and Expense, net. The increase is primarily due to lower non-service pension costs and gains on the nuclear decommissioning trust fund.
Income Tax Expense. The decrease in tax expense was primarily due to unfavorable tax adjustments in the prior year.
105
MD&ADUKE ENERGY OHIO

DUKE ENERGY OHIO
Results of Operations
Nine Months Ended September 30,
(in millions)20212020Variance
Operating Revenues
Regulated electric$1,119 $1,070 $49 
Regulated natural gas375 324 51 
Total operating revenues1,494 1,394 100 
Operating Expenses
Fuel used in electric generation and purchased power294 258 36 
Cost of natural gas76 46 30 
Operation, maintenance and other335 333 2 
Depreciation and amortization228 208 20 
Property and other taxes266 244 22 
Impairment of assets and other charges5 — 5 
Total operating expenses 1,204 1,089 115 
Operating Income290 305 (15)
Other Income and Expenses, net14 11 3 
Interest Expense82 75 7 
Income Before Income Taxes222 241 (19)
Income Tax Expense34 40 (6)
Net Income$188 $201 $(13)
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.
ElectricNatural Gas
Increase (Decrease) over prior year20212021
Residential sales2.6 %6.8 %
General service sales3.8 %9.8 %
Industrial sales5.5 %4.2 %
Wholesale electric power sales104.7 %n/a
Other natural gas salesn/a2.5 %
Total sales4.6 %6.2 %
Average number of customers0.5 %0.8 %
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Operating Revenues. The variance was driven primarily by:
•a $31 million increase in fuel related revenues primarily due to higher natural gas prices and increased volumes;
•a $27 million increase in revenues related to OVEC collections and OVEC sales into PJM;
•a $16 million increase in PJM transmission revenues as a result of increased capital spend;
•an $11 million increase in retail pricing primarily due to the Duke Energy Kentucky general rate case; and
•a $6 million increase in revenues due to favorable weather.
Operating Expenses. The variance was driven primarily by:
•a $66 million increase in fuel expense primarily driven by higher retail prices and increased volumes for natural gas and purchased power;
•a $22 million increase in property and other taxes primarily due to increased plant in service, higher kilowatt and natural gas distribution taxes due to increased usage and a lower Network Integration Transmission Service tax deferral;
•a $20 million increase in depreciation and amortization primarily driven by an increase in distribution plant in service; and
•a $5 million increase in impairment of assets and other charges to optimize the company's real estate portfolio and reduce office space as parts of the business moves to a hybrid and remote workforce strategy.
Income Tax Expense. The decrease in tax expense was primarily due to a decrease in pretax income.
106
MD&ADUKE ENERGY INDIANA

DUKE ENERGY INDIANA
Results of Operations
Nine Months Ended September 30,
(in millions)20212020Variance
Operating Revenues$2,366 $2,070 $296 
Operating Expenses
Fuel used in electric generation and purchased power710 577 133 
Operation, maintenance and other543 564 (21)
Depreciation and amortization458 415 43 
Property and other taxes57 57 — 
Impairment of assets and other charges8 — 8 
Total operating expenses1,776 1,613 163 
Operating Income590 457 133 
Other Income and Expenses, net31 28 3 
Interest Expense148 114 34 
Income Before Income Taxes473 371 102 
Income Tax Expense77 72 5 
Net Income$396 $299 $97 
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 year2021
Residential sales3.0 %
General service sales4.6 %
Industrial sales5.5 %
Wholesale power sales7.8 %
Total sales4.5 %
Average number of customers1.0 %
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Operating Revenues. The variance was driven primarily by:
•a $128 million increase primarily due to higher base rate pricing from the Indiana retail rate case, net of lower rider revenues;
•a $109 million increase in fuel revenues primarily due to higher fuel cost recovery driven by customer demand and fuel prices;
•a $29 million increase in weather-normal retail sales volumes driven by higher nonresidential customer demand; and
•a $24 million increase in wholesale revenues primarily related to the true up of wholesale transmission revenues and higher rates in the current year.
Operating Expenses. The variance was driven primarily by:
•a $133 million increase in fuel used in electric generation and purchased power expense primarily due to higher purchased power expense, higher coal and natural gas costs and higher amortization of deferred fuel costs;
•a $43 million increase in depreciation and amortization primarily due to a change in depreciation rates from the Indiana retail rate case, amortization of deferred coal ash pond ARO and additional plant in service; and
•an $8 million increase in impairment of assets and other charges to optimize the company’s real estate portfolio and reduce office space as parts of the business move to a hybrid workforce strategy.
Partially offset by:
•a $21 million decrease in operation, maintenance and other primarily due to major outage costs incurred in the prior year and outage delays in the current year.
Interest Expense. The variance is primarily due to higher post-in-service carrying costs interest resulting from the Indiana retail rate case and higher prior year coal ash spend debt returns on the Indiana Department of Environmental Management's approved ash basin closure projects.
107
MD&ADUKE ENERGY INDIANA

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 excess deferred taxes.
PIEDMONT
Results of Operations
Nine Months Ended September 30,
(in millions)20212020Variance
Operating Revenues$1,016 $871 $145 
Operating Expenses
Cost of natural gas354 254 100 
Operation, maintenance and other231 234 (3)
Depreciation and amortization150 133 17 
Property and other taxes44 37 7 
Impairment of assets and other charges9 7 2 
Total operating expenses788 665 123 
Operating Income228 206 22 
Other Income and Expenses, net51 44 7 
Interest Expense88 89 (1)
Income Before Income Taxes191 161 30 
Income Tax Expense16 6 10 
Net Income$175 $155 $20 
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 year2021
Residential deliveries16.0 %
Commercial deliveries14.3 %
Industrial deliveries5.4 %
Power generation deliveries6.7 %
For resale20.0 %
Total throughput deliveries8.1 %
Secondary market volumes(0.9)%
Average number of customers2.0 %
The margin decoupling mechanism adjusts for variations in residential and commercial use per customer, including those due to weather and conservation. The weather normalization adjustment mechanisms mostly offset the impact of weather on bills rendered, but do not ensure full recovery of approved margin during periods when winter weather is significantly warmer or colder than normal.
Nine Months Ended September 30, 2021, as compared to September 30, 2020
Operating Revenues. The variance was driven primarily by:
•a $100 million increase due to higher natural gas costs passed through to customers and increased off-system sales natural gas costs;
•a $15 million increase due to Tennessee base rate case increases; and
•an $11 million increase due to North Carolina IMR.
Operating Expenses. The variance was driven primarily by:
•a $100 million increase due to higher natural gas costs passed through to customers and increased off-system sales natural gas costs;
•a $17 million increase in depreciation expense due to additional plant in service and software projects in service; and
•a $7 million increase in property and other taxes due to higher current year property taxes in North Carolina and South Carolina.
Other Income and Expense, net. The variance is primarily driven by favorable AFUDC equity and intercompany interest income.
Income Tax Expense. The increase in tax expense was primarily due to an increase in pretax income.
108
MD&ALIQUIDITY AND CAPITAL RESOURCES

LIQUIDITY AND CAPITAL RESOURCES
Sources and Uses of Cash
Duke Energy relies primarily upon cash flows from operations, debt and equity issuances and its existing cash and cash equivalents to fund its liquidity and capital requirements. Duke Energy’s capital requirements arise primarily from capital and investment expenditures, repaying long-term debt and paying dividends to shareholders. Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2020, included a summary and detailed discussion of projected primary sources and uses of cash for 2021 to 2023.
In January 2021, Duke Energy entered into a definitive agreement with an affiliate of GIC, for GIC to make an indirect minority interest investment of 19.9% in Duke Energy Indiana. The investment will be completed following two closings for an aggregate purchase price of approximately $2 billion. The first closing occurred on September 8, 2021, and Duke Energy Indiana Holdco, LLC, the holding company for Duke Energy Indiana, issued 11.05% of its membership interests in exchange for 50% of the total investment amount. Duke Energy has the discretion to determine the timing of the second closing, but the closing will occur no later than January 2023. At the second closing, Duke Energy Indiana Holdco, LLC will issue additional membership interests for the remaining 50% of the total investment amount, and GIC's minority interest ownership in Duke Energy Indiana Holdco, LLC will be 19.9%. Proceeds from the minority interest investment are expected to address common equity needs through 2025 to partially fund Duke Energy's $59 billion capital and investment expenditure plan.
As of September 30, 2021, Duke Energy had approximately $548 million of cash on hand, $6.3 billion available under its $8 billion Master Credit Facility and $500 million available under the $1 billion Three-Year Revolving Credit Facility. Duke Energy expects to have sufficient liquidity in the form of cash on hand, cash from operations and available credit capacity to support its funding needs. Refer to Note 5 to the Condensed Consolidated Financial Statements, "Debt and Credit Facilities," for information regarding Duke Energy's debt issuances and maturities, and available credit facilities including the Master Credit Facility.
Credit Ratings
In March 2021, Moody's Investors Services, Inc. (Moody's) downgraded by one notch the long-term credit ratings for Duke Energy (Parent) and Duke Energy Carolinas. The downgrade reflects Duke Energy's balance sheet objectives. The downgrade for Duke Energy (Parent) and Duke Energy Carolinas also considers the impact for Duke Energy Carolinas and Duke Energy Progress as a result of the 2019 rate case orders and approval of the CCR Settlement Agreement. While these agreements are indicative of a regulatory environment that remains broadly supportive of utility credit quality, their financial terms resulted in current impairment charges and lowered the amount of future cash flow Duke Energy Carolinas and Duke Energy Progress will receive in conjunction with their coal ash remediation spending. As part of the credit rating action, Moody's affirmed Duke Energy's (Parent) short-term and commercial paper credit ratings and confirmed the credit ratings for Duke Energy Progress. Following a January 2021, credit rating downgrade of Duke Energy (Parent) and its subsidiaries, Standard & Poor's Rating Services continues to maintain a stable outlook on Duke Energy Corporation and its subsidiaries as of September 30, 2021.
Cash Flow Information
The following table summarizes Duke Energy’s cash flows.
Nine Months Ended
September 30,
(in millions)20212020
Cash flows provided by (used in):
Operating activities$7,227 $6,766 
Investing activities(8,200)(7,964)
Financing activities1,160 1,225 
Net increase in cash, cash equivalents and restricted cash187 27 
Cash, cash equivalents and restricted cash at beginning of period556 573 
Cash, cash equivalents and restricted cash at end of period$743 $600 
OPERATING CASH FLOWS
The following table summarizes key components of Duke Energy’s operating cash flows.
Nine Months Ended
September 30,
(in millions)20212020Variance
Net income$2,915 $1,232 $1,683 
Non-cash adjustments to net income4,556 6,204 (1,648)
Payments for asset retirement obligations(389)(463)74 
Refund of AMT credit carryforwards— 572 (572)
Working capital145 (779)924 
Net cash provided by operating activities$7,227 $6,766 $461 
The variance was primarily due to timing of accruals and payments in working capital accounts, partially offset by prior year $572 million refund of AMT credit carryforwards.
109
MD&ALIQUIDITY 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)20212020Variance
Capital, investment and acquisition expenditures$(7,119)$(7,684)$565 
Other investing items(1,081)(280)(801)
Net cash used in investing activities$(8,200)$(7,964)$(236)
The variance relates primarily to payment made to fund ACP's outstanding debt, partially offset by decreases in capital expenditures due to lower overall investments in the Electric Utilities and Infrastructure, Gas Utilities and Infrastructure and Commercial Renewables segments.
FINANCING CASH FLOWS
The following table summarizes key components of Duke Energy’s financing cash flows.
Nine Months Ended
September 30,
(in millions)20212020Variance
Issuances of long-term debt, net$2,683 $2,694 $(11)
Issuances of common stock5 75 (70)
Notes payable, commercial paper and other short-term borrowings(723)260 (983)
Dividends paid(2,340)(2,113)(227)
Contributions from noncontrolling interests1,556 402 1,154 
Other financing items(21)(93)72 
Net cash provided by financing activities$1,160 $1,225 $(65)
The variance was primarily due to:
•a $983 million decrease in net proceeds from issuances of notes payable and commercial paper; and
•a $227 million increase in dividends paid.
Partially offset by:
•a $1.154 billion increase in contributions from noncontrolling interests, primarily due to the $1 billion receipt from GIC to make an indirect minority interest investment of 11.05% in Duke Energy Indiana.
OTHER MATTERS
Environmental Regulations
The Duke Energy Registrants are subject to federal, state and local regulations regarding air and water quality, hazardous and solid waste disposal, coal ash and other environmental matters. These regulations can be changed from time to time and result in new obligations of the Duke Energy Registrants. Refer to Note 3 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for further information regarding potential plant retirements and regulatory filings related to the Duke Energy Registrants.
Off-Balance Sheet Arrangements
During the three and nine months ended September 30, 2021, there were no material changes to Duke Energy’s off-balance sheet arrangements. For additional information on Duke Energy’s off-balance sheet arrangements, see “Off-Balance Sheet Arrangements” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2020.
Contractual Obligations
Duke Energy enters into contracts that require payment of cash at certain specified periods, based on certain specified minimum quantities and prices. During the three and nine months ended September 30, 2021, there were no material changes in Duke Energy's contractual obligations. For an in-depth discussion of Duke Energy’s contractual obligations, see “Contractual Obligations” and “Quantitative and Qualitative Disclosures about Market Risk” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2020.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
For an in-depth discussion of the Duke Energy Registrants' market risks, see “Quantitative and Qualitative Disclosures about Market Risk” in Item 7 of the Annual Report on Form 10-K for the Duke Energy Registrants. During the three and nine months ended September 30, 2021, there were no material changes to the Duke Energy Registrants' disclosures about market risk.
110

ITEM 4.CONTROLS AND PROCEDURES

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, 2021, and, based upon this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these controls and procedures are effective in providing reasonable assurance of compliance.
Changes in Internal Control over Financial Reporting
Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, the Duke Energy Registrants have evaluated changes in internal control over financial reporting (as such term is defined in Rules 13a-15 and 15d-15 under the Exchange Act) that occurred during the fiscal quarter ended September 30, 2021, and have concluded no change has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.
111
OTHER INFORMATION


ITEM 1. LEGAL PROCEEDINGS
For information regarding material legal proceedings, including regulatory and environmental matters, see Note 3, "Regulatory Matters," and Note 4, "Commitments and Contingencies," to the Condensed Consolidated Financial Statements. For additional information, see Item 3, "Legal Proceedings," in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2020.
ITEM 1A. RISK FACTORS
In addition to the other information set forth in this report, careful consideration should be given to the factors discussed in Part I, “Item 1A. Risk Factors” in the Duke Energy Registrants' Annual Report on Form 10-K for the year ended December 31, 2020, 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 the Annual Report on Form 10-K for the year ended December 31, 2020.
Our business could be negatively affected as a result of actions of activist shareholders.
On May 17, 2021, Elliott who has indicated it holds an economic interest in our outstanding common stock, publicly released a letter it had sent to our Board. On July 19, 2021, Elliott issued a follow-up letter to our Board.
While we strive to maintain constructive communications with our shareholders, activist shareholders may, from time to time, engage in proxy solicitations or advance shareholder proposals, or otherwise attempt to affect changes and assert influence on our Board and management. Perceived uncertainties as to the future direction or governance of the company may cause concern to our current or potential regulators, vendors or strategic partners, or make it more difficult to execute on our strategy or to attract and retain qualified personnel, which may have a material impact on our business and operating results.
In addition, actions such as those described above could cause fluctuations in the trading price of our common stock, based on temporary or speculative market perceptions or other factors that do not necessarily reflect the underlying fundamentals and prospects of our business.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
None.
112
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 (***).
DukeDukeDukeDukeDuke
ExhibitDukeEnergyProgressEnergyEnergyEnergyEnergy
NumberEnergyCarolinasEnergyProgressFloridaOhioIndianaPiedmont
*3.1X
4.1X
4.2X
10.1XX
10.2X
*31.1.1X
*31.1.2X
*31.1.3X
*31.1.4X
*31.1.5X
*31.1.6X
*31.1.7X
*31.1.8X
*31.2.1X
*31.2.2X
113
EXHIBITS

*31.2.3X
*31.2.4X
*31.2.5X
*31.2.6X
*31.2.7X
*31.2.8X
*32.1.1X
*32.1.2X
*32.1.3X
*32.1.4X
*32.1.5X
*32.1.6X
*32.1.7X
*32.1.8X
*32.2.1X
*32.2.2X
*32.2.3X
*32.2.4X
*32.2.5X
*32.2.6X
114
EXHIBITS

*32.2.7X
*32.2.8X
*101.INSXBRL Instance Document (this does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document).XXXXXXXX
*101.SCHXBRL Taxonomy Extension Schema Document.XXXXXXXX
*101.CALXBRL Taxonomy Calculation Linkbase Document.XXXXXXXX
*101.LABXBRL Taxonomy Label Linkbase Document.XXXXXXXX
*101.PREXBRL Taxonomy Presentation Linkbase Document.XXXXXXXX
*101.DEFXBRL Taxonomy Definition Linkbase Document.XXXXXXXX
*104Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibit 101).XXXXXXXX
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.
115
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 4, 2021/s/ STEVEN K. YOUNG
Steven K. Young
Executive Vice President and Chief Financial Officer (Principal Financial Officer)
Date:November 4, 2021/s/ CYNTHIA S. LEE
Cynthia S. Lee
Vice President, Chief Accounting Officer
and Controller
(Principal Accounting Officer)
116

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