Duke Energy (DUK) 10-K 2014 FY Annual report

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

(Mark One)

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

For the fiscal period ended December 31, 2014 or

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

For the transition period from________to________

Commission file number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, and Telephone Number	IRS Employer Identification No.
1-32853	DUKE ENERGY CORPORATION (a Delaware Corporation) 550 South Tryon Street Charlotte, NC 28202-1803 704-382-3853	20-2777218

Commission file number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, and Telephone Number	Commission file number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, and Telephone Number
1-4928	DUKE ENERGY CAROLINAS, LLC (a North Carolina limited liability company) 526 South Church Street Charlotte, North Carolina 28202-1803 704-382-3853 56-0205520	1-3274	DUKE ENERGY FLORIDA, INC. (a Florida corporation) 299 First Avenue North St. Petersburg, Florida 33701 704-382-3853 59-0247770
1-15929	PROGRESS ENERGY, INC. (a North Carolina corporation) 410 South Wilmington Street Raleigh, North Carolina 27601-1748 704-382-3853 56-2155481	1-1232	DUKE ENERGY OHIO, INC. (an Ohio corporation) 139 East Fourth Street Cincinnati, Ohio 45202 704-382-3853 31-0240030
1-3382	DUKE ENERGY PROGRESS, INC. (a North Carolina corporation) 410 South Wilmington Street Raleigh, North Carolina 27601-1748 704-382-3853 56-0165465	1-3543	DUKE ENERGY INDIANA, INC. (an Indiana corporation) 1000 East Main Street Plainfield, Indiana 46168 704-382-3853 35-0594457

SECURITIES REGISTERED PURSUANT TO SECTION 12(B) OF THE ACT:
Registrant	Title of each class	Name of each exchange on which registered
Duke Energy Corporation (Duke Energy)	Common Stock, $0.001 par value	New York Stock Exchange, Inc.
Duke Energy	5.125% Junior Subordinated Debentures due January 15, 2073	New York Stock Exchange, Inc.
Duke Energy Carolinas, LLC (Duke Energy Carolinas)	All of the registrant's limited liability company member interests are directly owned by Duke Energy.
Progress Energy, Inc. (Progress Energy)	All of the registrant's common stock is directly owned by Duke Energy.
Duke Energy Progress, Inc. (Duke Energy Progress)	All of the registrant's common stock is indirectly owned by Duke Energy.
Duke Energy Florida, Inc. (Duke Energy Florida)	All of the registrant's common stock is indirectly owned by Duke Energy.
Duke Energy Ohio, Inc. (Duke Energy Ohio)	All of the registrant's common stock is indirectly owned by Duke Energy.
Duke Energy Indiana, Inc. (Duke Energy Indiana)	All of the registrant's common stock is indirectly owned by Duke Energy.

SECURITIES REGISTERED PURSUANT TO SECTION 12(G) OF THE ACT:  None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act

Duke Energy	Yes x	No ¨	Duke Energy Florida	Yes x	No ¨
Duke Energy Carolinas	Yes x	No ¨	Duke Energy Ohio	Yes ¨	No x
Progress Energy	Yes ¨	No x	Duke Energy Indiana	Yes ¨	No x
Duke Energy Progress	Yes x	No ¨

Indicate by check mark if the registrant is not required to file reports to pursuant to Section 13 or Section 15(d) of the Exchange Act.

Yes ¨ No x (Response applicable to all registrants.)

Indicate by check mark whether the registrants (1) have 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. Yes x No ¨

Indicate by check mark whether the registrants have submitted electronically and posted on their corporate website, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes x No ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.

Duke Energy	Yes x	No ¨	Duke Energy Florida	Yes x	No ¨
Duke Energy Carolinas	Yes x	No ¨	Duke Energy Ohio	Yes x	No ¨
Progress Energy	Yes x	No ¨	Duke Energy Indiana	Yes x	No ¨
Duke Energy Progress	Yes x	No ¨

Indicate by check mark whether Duke Energy is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):  Large accelerated filer x  Accelerated filer ¨  Non-accelerated filer ¨  Smaller reporting company ¨

Indicate by check mark whether Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana are large accelerated filers, accelerated filers, non-accelerated filers, or smaller reporting companies. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):  Large accelerated filer ¨  Accelerated filer ¨  Non-accelerated filer x Smaller reporting company ¨

Indicate by check mark whether the registrants are a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x

Estimated aggregate market value of the common equity held by nonaffiliates of Duke Energy at June 30, 2014.	52,431,523,340
Number of shares of Common Stock, $0.001 par value, outstanding at February 24, 2015.	707,554,168

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the Duke Energy definitive proxy statement for the 2014 Annual Meeting of the Shareholders or an amendment to this Annual Report are incorporated by reference into PART III, Items 10, 11, 12, 13, and 14 hereof.

This combined Form 10-K is filed separately by seven registrants: Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana (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 and Duke Energy Indiana meet the conditions set forth in General Instructions I(1)(a) and (b) of Form 10-K and are, therefore, filing this form with the reduced disclosure format specified in General Instructions I(2) of Form 10-K. 

TABLE OF CONTENTS

FORM 10-K FOR THE YEAR ENDED December 31, 2014

Item		Page
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION
GLOSSARY OF TERMS
PART I.
1.	BUSINESS	9
	DUKE ENERGY	9
	GENERAL	9
	BUSINESS SEGMENTS	9
	GEOGRAPHIC REGIONS	17
	EMPLOYEES	17
	EXECUTIVE OFFICERS	17
	ENVIRONMENTAL MATTERS	18
	DUKE ENERGY CAROLINAS	18
	PROGRESS ENERGY	18
	DUKE ENERGY PROGRESS	18
	DUKE ENERGY FLORIDA	19
	DUKE ENERGY OHIO	19
	DUKE ENERGY INDIANA	19
1A.	RISK FACTORS	19
1B.	UNRESOLVED STAFF COMMENTS	25
2.	PROPERTIES	26
3.	LEGAL PROCEEDINGS	30
4.	MINE SAFETY DISCLOSURES	30
PART II.
5.	MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES	31
6.	SELECTED FINANCIAL DATA	33
7.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	34
7A.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	74
8.	FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA	75
9.	CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE	240
9A.	CONTROLS AND PROCEDURES	240
PART III.
10.	DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE	241
11.	EXECUTIVE COMPENSATION	241
12.	SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS	241
13.	CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE	241
14.	PRINCIPAL ACCOUNTING FEES AND SERVICES	241
PART IV.
15.	EXHIBITS AND FINANCIAL STATEMENT SCHEDULES	243
	SIGNATURES	245
	EXHIBIT INDEX	Exhibit-1

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. These forward-looking statements are identified by terms and phrases such as “anticipate,” “believe,” “intend,” “estimate,” “expect,” “continue,” “should,” “could,” “may,” “plan,” “project,” “predict,” “will,” “potential,” “forecast,” “target,” “guidance,” “outlook,” and similar expressions. Forward-looking statements involve risks and uncertainties that may cause actual results to be materially different from the results predicted. Factors that could cause actual results to differ materially from those indicated in any forward-looking statement include, but are not limited to:

• State, federal and foreign legislative and regulatory initiatives, including costs of compliance with existing and future environmental requirements or 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 the costs and liabilities relating to the Dan River ash basin release and compliance with current and any future regulatory changes related to the management of coal ash;

• The ability to recover eligible costs, including those associated with future significant weather events, and earn an adequate return on investment through the regulatory process;

• The costs of decommissioning nuclear facilities could prove to be more extensive than are currently identified and all costs may not be fully recoverable through the regulatory process;

• The risk that the credit ratings of the company or its subsidiaries may be different from what the companies expect;

• 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 customer usage patterns, including energy efficiency efforts and use of alternative energy sources, including self-generation and distributed generation technologies;

• Additional competition in electric markets and continued industry consolidation;

• Political and regulatory uncertainty in other countries in which Duke Energy conducts business;

• The influence of weather and other natural phenomena on operations, including the economic, operational and other effects of severe storms, hurricanes, droughts and tornadoes;

• The ability to successfully operate electric generating facilities and deliver electricity to customers;

• The impact on facilities and business from a terrorist attack, cybersecurity threats, data security breaches, and other catastrophic events;

• The inherent risks associated with the operation and potential construction of nuclear facilities, including environmental, health, safety, regulatory and financial risks;

• The timing and extent of changes in commodity prices, interest rates and foreign currency exchange 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 and general economic conditions;

• 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 Duke Energy Registrants’ capital investment projects in existing and new generation facilities, including risks related to financing, obtaining and complying with terms of permits, meeting construction budgets and schedules, and satisfying operating and environmental performance standards, as well as the ability to recover costs from customers in a timely manner or at all;

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

• The ability to control operation and maintenance costs;

• The level of creditworthiness of counterparties to transactions;

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

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

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

• The effect of accounting pronouncements issued periodically by accounting standard-setting bodies;

• The impact of potential goodwill impairments;

• The ability to reinvest prospective undistributed earnings of foreign subsidiaries or repatriate such earnings on a tax-efficient basis; and

• The ability to successfully complete future merger, acquisition or divestiture plans.

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; the Duke Energy Registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise that occur after that date.

Glossary of Terms

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

Term or Acronym	Definition
the 2010 Plan	Duke Energy’s 2010 Long-Term Incentive Plan
the 2012 Edwardsport settlement	Settlement agreement in 2012 among Duke Energy Indiana, the OUCC, the Duke Energy Indiana Industrial Group and Nucor Steel-Indiana
the 2012 Settlement	Settlement agreement in 2012 among Duke Energy Florida, the OPC and other customer advocates
the 2013 Settlement	Settlement agreement in 2013 among Duke Energy Florida, the OPC and other customer advocates
ACP	Atlantic Coast Pipeline
AFUDC	Allowance for Funds Used During Construction
Aguaytia	Aguaytia Integrated Energy Project
AHFS	Assets held for sale
ALJ	Administrative Law Judge
ANEEL	Brazilian electricity regulatory agency
AOCI	Accumulated Other Comprehensive Income
ASU	Accounting standard update
Board of Directors	Duke Energy Board of Directors
Bison	Bison Insurance Company Limited
Brunswick	Brunswick Nuclear Station
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
Calpine	Calpine Corporation
Catawba	Catawba Nuclear Station
Catawba Riverkeeper	Catawba Riverkeeper Foundation, Inc.
CCR	Coal Combustion Residuals
CCS	Carbon Capture and Storage
CECPCN	Certificate of Environmental Compatibility and Public Convenience and Necessity
CEO	Chief Executive Officer
Cinergy	Cinergy Corp. (collectively with its subsidiaries)
CO2	Carbon Dioxide
Coal Ash Act	North Carolina Coal Ash Management Act of 2014
Coal Ash Commission	Coal Ash Management Commission
COL	Combined Construction and Operating License
the Company	Duke Energy Corporation and its' subsidiaries
Consolidated Complaint	Corrected Verified Consolidated Shareholder Derivative Complaint
CPP	Clean Power Plan
CRC	Cinergy Receivables Company, LLC
CRES	Competitive Retail Electric Supplier
Crescent	Crescent Resources LLC
Crystal River Unit 3	Crystal River Unit 3 Nuclear Station
CSAPR	Cross-State Air Pollution Rule
CWA	Clean Water Act
DB	Defined Benefit (Pension Plan)
D.C. Circuit Court	U.S. Court of Appeals for the District of Columbia

DEBS	Duke Energy Business Services, LLC
DECAM	Duke Energy Commercial Asset Management, Inc.
DECS	Duke Energy Corporate Services
DEFR	Duke Energy Florida Receivables Company, LLC
DEGS	Duke Energy Generation Services, Inc.
DEIGP	Duke Energy International Geracao Paranapenema S.A.
Deloitte	Deloitte & Touche LLP, and the member firms of Deloitte Touche Tohmatsu and their respective affiliates
DENR	Department of Environment and Natural Resources
DEPR	Duke Energy Progress Receivables Company, LLC
DERF	Duke Energy Receivables Finance Company, LLC
Disposal Group	Duke Energy Ohio’s nonregulated Midwest generation business and Duke Energy Retail Sales, LLC
DOE	U.S. Department of Energy
Dominion	Dominion Resources
DSM	Demand Side Management
Duke Energy	Duke Energy Corporation (collectively with its subsidiaries)
Duke Energy Audit Committee	Audit Committee of the Board of Directors
Duke Energy Carolinas	Duke Energy Carolinas, LLC
Duke Energy Defendants	Several current and former Duke Energy officers and directors named as defendants in the Consolidated Complaint
Duke Energy Florida	Duke Energy Florida, Inc.
Duke Energy Indiana	Duke Energy Indiana, Inc.
Duke Energy Kentucky	Duke Energy Kentucky, Inc.
Duke Energy Ohio	Duke Energy Ohio, Inc.
Duke Energy Progress	Duke Energy Progress, Inc.
Duke Energy Registrants	Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana
Duke Energy Retail	Duke Energy Retail Sales, LLC
Duke Energy Vermillion	Duke Energy Vermillion II, LLC
DukeNet	DukeNet Communications Holdings, LLC
Dynegy	Dynegy Inc.
EE	Energy efficiency
EGU	Electric Generating Units
EIP	Progress Energy’s Equity Incentive Plan
Electric Settlement	Settlement agreement in 2013 among Duke Energy Ohio and all intervening parties
ELG	Effluent Limitation Guidelines
EMC	North Carolina Environmental Management Commission
EPA	U.S. Environmental Protection Agency
EPC	Engineering, Procurement and Construction agreement
EPS	Earnings Per Share
ESP	Electric Security Plan
ETR	Effective tax rate
Exchange Act	Exchange Act of 1934
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission

Fitch	Fitch Ratings, Inc.
Florida Global Case	Litigation case filed in the Circuit Court for Broward County, Florida by U.S. Global, LLC
Florida Municipal Joint Owners	Seminole Electric Cooperative, Inc., City of Ocala, Orlando Utilities Commission, City of Gainesville, City of Leesburg, Kissimmee Utility Authority, Utilities Commission of the City of New Smyrna Beach, City of Alachua and City of Bushnell
Form S-3	registration statement
FPSC	Florida Public Service Commission
FRR	Fixed Resource Requirement
FTR	Financial transmission rights
GAAP	Generally Accepted Accounting Principles in the United States
Gas Settlement	Settlement agreement in 2013 among Duke Energy Ohio, PUCO Staff and intervening parties
GBRA	Generation Base Rate Adjustment recovery mechanism
GHG	Greenhouse Gas
Global	U.S. Global, LLC
GPC	Georgia Power Company
GWh	Gigawatt-hours
Harris	Shearon Harris Nuclear Station
HB 998	North Carolina House Bill 998
Hines	Hines Energy Complex
IAP	State Environmental Agency of Parana
IBAMA	Brazil Institute of Environment and Renewable Natural Resources
Ibener	Iberoamericana de Energia Ibener, S.A.
IBNR	Incurred but not yet reported
IC	Internal combustion
IGCC	Integrated Gasification Combined Cycle
Interim FERC Mitigation	Interim firm power sale agreements mitigation plans related to the Progress Energy merger
IRP	Integrated Resource Plans
IRS	Internal Revenue Service
ISFSI	Independent Spent Fuel Storage Installation
ISO	Independent System Operator
ITC	Investment Tax Credit
IURC	Indiana Utility Regulatory Commission
Investment Trusts	Grantor trusts of Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana
JDA	Joint Dispatch Agreement
Joint Intervenors	Intervenors in matters related to the Edwardsport IGCC Plan, including the Citizens Action Coalition of Indiana, Inc., Sierra Club, Inc., Save the Valley, Inc., and Valley Watch, Inc.
KPSC	Kentucky Public Service Commission
kV	Kilovolt
kWh	Kilowatt-hour
Lee Nuclear Station	William States Lee III Nuclear Station
Levy	Duke Energy Florida’s proposed nuclear plant in Levy County, Florida
Legacy Duke Energy Directors	Members of the pre-merger Duke Energy Board of Directors
LIBOR	London Interbank Offered Rate
Long-Term FERC Mitigation	The revised market power mitigation plan related to the Progress Energy merger
MATS	Mercury and Air Toxics Standards (previously referred to as the Utility MACT Rule)

Mcf	Thousand cubic feet
McGuire	McGuire Nuclear Station
MGP	Manufactured gas plant
MISO	Midcontinent Independent System Operator, Inc.
MMBtu	Million British Thermal Unit
Moody’s	Moody’s Investor Service, Inc.
MTBE	Methyl tertiary butyl ether
MTEP	MISO Transmission Expansion Planning
MW	Megawatt
MVP	Multi Value Projects
MWh	Megawatt-hour
NASDAQ	Nasdaq Composite
NCAG	North Carolina Attorney General
NCEMC	North Carolina Electric Membership Corporation
NCEMPA	North Carolina Eastern Municipal Power Agency
NCRC	Florida’s Nuclear Cost Recovery Clause
NCSC	North Carolina Supreme Court
NCUC	North Carolina Utilities Commission
NC WARN	N.C. Waste Awareness and Reduction Network
NDTF	Nuclear decommissioning trust funds
NEIL	Nuclear Electric Insurance Limited
NMC	National Methanol Company
NOL	Net operating loss
NOx	Nitrogen oxide
NPNS	Normal purchase/normal sale
NRC	U.S. Nuclear Regulatory Commission
NSR	New Source Review
NWPA	Nuclear Waste Policy Act of 1982
NYSE	New York Stock Exchange
Oconee	Oconee Nuclear Station
Ohio EPA	Ohio Environmental Protection Agency
OPC	Florida Office of Public Counsel
OPEB	Other Post-Retirement Benefit Obligations
ORS	South Carolina Office of Regulatory Staff
Osprey Plant acquisition	Duke Energy Florida's proposed acquisition of Calpine Corporation's 599 MW combined cycle natural gas plant in Auburndale, FL
OUCC	Office of Utility Consumer Counselor
OVEC	Ohio Valley Electric Corporation
the Parent	Duke Energy Corporation Holding Company
PESC	Progress Energy Service Company
PJM	PJM Interconnection, LLC
Plea Agreements	Plea Agreements entered into by Duke Energy Carolinas and Duke Energy Progress in connection with a criminal investigation related to the Dan River ash basin release and the management of coal ash basins in North Carolina
Progress Energy	Progress Energy, Inc.

PSA	Purchase sale agreement
PSCSC	Public Service Commission of South Carolina
Public Staff	North Carolina Utilities Commission Public Staff
PUCO	Public Utilities Commission of Ohio
PURPA	Public Utility Regulatory Act of 1978
QF	Qualifying Facility
QUIPS	Quarterly Income Preferred Securities
RCA	Revolving Credit Agreement
RCRA	Resource Conservation and Recovery Act
Relative TSR	TSR of Duke Energy stock relative to a pre-defined peer group
the Resolutions	Proposed resolutions promulgated by the Brazilian electricity regulatory agency
Robinson	Robinson Nuclear Station
RTO	Regional Transmission Organization
SAFSTOR	A method of decommissioning in which a nuclear facility is placed and maintained in a condition that allows the facility to be safely stored and subsequently decontaminated to levels that permit release for unrestricted use.
SCDHEC	South Carolina Department of Health and Environmental Control
SEC	Securities and Exchange Commission
SELC	Southern Environmental Law Center
Segment Income	Income from continuing operations net of income attributable to noncontrolling interests
SO2	Sulfur dioxide
SOA	Society of actuaries
Spectra Energy	Spectra Energy Corp.
Spectra Capital	Spectra Energy Capital, LLC (formerly Duke Capital LLC)
S&P	Standard & Poor’s Rating Services
SSO	Standard Service Offer
State Utility Commissions	NCUC, PSCSC, FPSC, PUCO, IURC and KPSC (Collectively)
Subsidiary Registrants	Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana
Supreme Court	U.S. Supreme Court
Sutton	L.V. Sutton combined cycle facility
Suwannee project	Proposed 320 MW combustion turbine plant at Duke Energy Florida's Suwannee generating facility
TSR	Total shareholder return
U.S.	United States
USDOJ	United States Department of Justice Environmental Crimes Section and the United States Attorneys for the Eastern District of North Carolina, the Middle District of North Carolina and the Western District of North Carolina, collectively
VDEQ	Virginia Department of Environmental Quality
VEBA I	Duke Energy Corporation Employee Benefits Trust
Vermillion	Vermillion Generating Station
VIE	Variable Interest Entity
VSP	Voluntary Severance Plan
WACC	Weighted Average Cost of Capital
WVPA	Wabash Valley Power Association, Inc.

PART I

ITEM 1. BUSINESS

DUKE ENERGY

General

Duke Energy Corporation (collectively with its subsidiaries, Duke Energy) is an energy company headquartered in Charlotte, North Carolina, subject to regulation by the Federal Energy Regulatory Commission (FERC). Duke Energy operates in the United States (U.S.) and Latin America primarily through its direct and indirect subsidiaries. Duke Energy's subsidiaries include its subsidiary registrants (collectively referred to as the Subsidiary Registrants); Duke Energy Carolinas, LLC (Duke Energy Carolinas); Progress Energy, Inc. (Progress Energy); Duke Energy Progress, Inc. (Duke Energy Progress); Duke Energy Florida, Inc. (Duke Energy Florida); Duke Energy Ohio, Inc. (Duke Energy Ohio); and Duke Energy Indiana, Inc. (Duke Energy Indiana). When discussing Duke Energy’s consolidated financial information, it necessarily includes the results of its Subsidiary Registrants, which along with Duke Energy, are collectively referred to as the Duke Energy Registrants.

On August 21, 2014, Duke Energy entered into an agreement to sell its nonregulated Midwest generation business (Disposal Group) to Dynegy Inc. (Dynegy) for approximately $2.8 billion in cash subject to adjustments at closing for changes in working capital and capital expenditures. The Disposal Group primarily includes Duke Energy Ohio's coal-fired and gas-fired generation assets located in the Midwest region of the United States and dispatched into the PJM wholesale market. These assets earn energy and capacity revenue at market price. The Disposal Group also includes a retail sales subsidiary of Duke Energy, Duke Energy Retail Sales, LLC (Duke Energy Retail), which is certified as a Competitive Retail Electric Supplier (CRES) provider in Ohio. Duke Energy Retail serves retail electric and gas customers in Ohio with energy and provides other energy services at competitive rates. Completion of the transaction is conditioned on approval by FERC. The transaction is expected to close by the end of the second quarter of 2015. For additional information on the Midwest generation business disposition see Note 2 to the Consolidated Financial Statements, "Acquisitions, Dispositions and Sales of Other Assets."

The Duke Energy Registrants electronically file reports with the Securities and Exchange Commission (SEC), including annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, proxies and amendments to such reports.

The public may read and copy any materials the Duke Energy Registrants file with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. The SEC also maintains an Internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC at http://www.sec.gov. Additionally, information about the Duke Energy Registrants, including reports filed with the SEC, is available through Duke Energy’s website at http://www.duke-energy.com. Such reports are accessible at no charge and are made available as soon as reasonably practicable after such material is filed with or furnished to the SEC.

Business Segments

Duke Energy conducts its operations in three business segments; Regulated Utilities, International Energy and Commercial Power. The remainder of Duke Energy’s operations are presented as Other. Duke Energy’s chief operating decision maker regularly reviews financial information about each of these business segments in deciding how to allocate resources and evaluate performance. For additional information on each of these business segments, including financial and geographic information, see Note 3 to the Consolidated Financial Statements, “Business Segments.”

The following sections describe the business and operations of each of Duke Energy’s reportable business segments, as well as Other.

REGULATED UTILITIES

Regulated Utilities conducts operations primarily through Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida, Duke Energy Indiana, and Duke Energy Ohio. These electric and gas operations are subject to the rules and regulations of the FERC, the North Carolina Utilities Commission (NCUC), the Public Service Commission of South Carolina (PSCSC), the Florida Public Service Commission (FPSC), the Indiana Utility Regulatory Commission (IURC), the Public Utilities Commission of Ohio (PUCO), and the Kentucky Public Service Commission (KPSC).

Regulated Utilities serves 7.3 million retail electric customers in six states in the Southeast and Midwest regions of the U.S. Its service area covers approximately 95,000 square miles with an estimated population of 23 million people. Regulated Utilities serves 500,000 retail natural gas customers in southwestern Ohio and northern Kentucky. Electricity is also sold wholesale to incorporated municipalities, electric cooperative utilities and other load-serving entities.

The following table represents the distribution of billed sales by customer class for the year ended December 31, 2014.

	Duke Energy Carolinas(a)		Duke Energy Progress(a)		Duke Energy Florida(b)		Duke Energy Ohio(c)		Duke Energy Indiana(d)
Residential	32	%	29	%	49	%	36	%	28	%
General service	32	%	24	%	39	%	39	%	25	%
Industrial	25	%	16	%	8	%	24	%	32	%
Total retail sales	89	%	69	%	96	%	99	%	85	%
Wholesale and other sales	11	%	31	%	4	%	1	%	15	%
Total sales	100	%	100	%	100	%	100	%	100	%

(a) Primary general service sectors include health care, education, financial services, information technology and military buildings. Primary industrial sectors include textiles, chemicals, rubber and plastics, paper, food and beverage, and auto manufacturing.

9

PART I

(b) Primary general service sectors include tourism, health care and government facilities and schools. Primary industrial sectors include phosphate rock mining and processing and citrus and other food processing.

(c) Primary general service sectors include health care, education, real estate and rental leasing, financial and insurance services, water/wastewater services, and wholesale trade services. Primary industrial sectors include aerospace, primary metals, chemicals and food.

(d) Primary general service sectors include retail, financial, healthcare and education services. Primary industrial sectors include primary and fabricated metals, transportation equipment, building materials, food and beverage, stone/clay/glass, and chemicals.

The number of residential, general service and industrial customers within the Regulated Utilities service territory is expected to increase over time. However, growth in the near term has been hampered by current economic conditions. Average usage per residential customer is expected to remain flat or decline for the foreseeable future. While total industrial and general service sales increased in 2014 when compared to 2013, the growth rate was modest when compared to historical periods.

Seasonality and the Impact of Weather

Regulated Utilities’ costs and revenues are influenced by seasonal patterns. Peak sales of electricity occur during the summer and winter months, resulting in higher revenue and cash flows in these periods. By contrast, lower sales of electricity occur during the spring and fall, allowing for scheduled plant maintenance. Peak gas sales occur during the winter months. Residential and general service customers are most impacted by weather. Estimated weather impacts are based on actual current period weather compared to normal weather conditions. Normal weather conditions are defined as the long-term average of actual historical weather conditions.

The estimated impact of weather on earnings is based on the number of customers, temperature variances from a normal condition and customers’ historic usage levels and patterns. The methodology used to estimate the impact of weather does not and cannot consider all variables that may impact customer response to weather conditions such as humidity and relative temperature changes. The precision of this estimate may also be impacted by applying long-term weather trends to shorter-term periods.

Degree-day data are used to estimate energy required to maintain comfortable indoor temperatures based on each day’s average temperature. Heating-degree days measure the variation in weather based on the extent the average daily temperature falls below a base temperature. Cooling-degree days measure the variation in weather based on the extent the average daily temperature rises above the base temperature. Each degree of temperature below the base temperature counts as one heating-degree day and each degree of temperature above the base temperature counts as one cooling-degree day.

Competition

Retail

Regulated Utilities’ businesses operate as the sole supplier of electricity within their service territories, with the exception of Ohio, which has a competitive electricity supply market for generation service. Regulated Utilities owns and operates facilities necessary to transmit and distribute electricity and, except in Ohio, to generate electricity. Services are priced by state commission approved rates designed to include the costs of providing these services and a reasonable return on invested capital. This regulatory policy is intended to provide safe and reliable electricity at fair prices. Competition in the regulated electric distribution business is primarily from on-site generation of industrial customers and distributed generation, such as rooftop solar, at residential, general service and/or industrial customer sites.

Regulated Utilities is not aware of any proposed legislation in any jurisdiction that would give its retail customers the right to choose their electricity provider or otherwise restructure or deregulate the electric industry.

Although there is no pending legislation at this time, if the retail jurisdictions served by Regulated Utilities become subject to deregulation, the recovery of stranded costs could become a significant consideration. Stranded costs primarily include the generation assets of Regulated Utilities whose value in a competitive marketplace may be less than their current book value, as well as above-market purchased power commitments from qualifying facilities (QFs). The Public Utility Regulatory Policies Act of 1978 (PURPA) established a new class of generating facilities as QFs, typically small power production facilities that generate power within a utility company’s service territory for which the utility companies are legally obligated to purchase the energy at an avoided cost rate. Thus far, all states that have passed restructuring legislation have provided for the opportunity to recover a substantial portion of stranded costs.

Regulated Utilities’ largest stranded cost exposure is primarily related to Duke Energy Florida’s purchased power commitments with QFs, under which it has future minimum expected capacity payments through 2025 of $2.2 billion. Duke Energy Florida was obligated to enter into these contracts under provisions of PURPA. Duke Energy Florida continues to seek ways to address the impact of escalating payments under these contracts. However, the FPSC allows full recovery of the retail portion of the cost of power purchased from QFs. For additional information related to these purchased power commitments, see Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies.”

In Ohio, Regulated Utilities conducts competitive auctions for electricity supply. The cost of energy purchased through these auctions is recovered from retail customers. Regulated Utilities earns retail margin in Ohio on the transmission and distribution of electricity only and not on the cost of the underlying energy.

Wholesale

Regulated Utilities competes with other utilities and merchant generators for bulk power sales, sales to municipalities and cooperatives, and wholesale transactions. The principal factors in competing for these sales are price, availability of capacity and power, and reliability of service. Prices are influenced primarily by market conditions and fuel costs.

Increased competition in the wholesale electric utility industry and the availability of transmission access could affect Regulated Utilities’ load forecasts, plans for power supply and wholesale energy sales and related revenues. Wholesale energy sales will be impacted by the extent to which additional generation is available to sell to the wholesale market and the ability of Regulated Utilities to attract new customers and to retain existing customers.

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PART I

Energy Capacity and Resources

Regulated Utilities owns approximately 50,000 megawatts (MW) of generation capacity. For additional information on Regulated Utilities’ generation facilities, see Item 2, “Properties.”

Energy and capacity are also supplied through contracts with other generators and purchased on the open market. Factors that could cause Regulated Utilities to purchase power for its customers include generating plant outages, extreme weather conditions, generation reliability, growth, and price. Regulated Utilities has interconnections and arrangements with its neighboring utilities to facilitate planning, emergency assistance, sale and purchase of capacity and energy, and reliability of power supply.

Regulated Utilities’ generation portfolio is a balanced mix of energy resources having different operating characteristics and fuel sources designed to provide energy at the lowest possible cost to meet its obligation to serve retail customers. All options, including owned generation resources and purchased power opportunities, are continually evaluated on a real-time basis to select and dispatch the lowest-cost resources available to meet system load requirements.

Recently Completed Generation Projects

The additional capacity from recently completed generation projects allowed Regulated Utilities to retire or plan to retire older, less efficient capacity. The following table summarizes the generation projects constructed and placed in service during the past three years.

		Megawatts	Fuel	Commercial Operation	Cost (in millions)
Duke Energy Carolinas	Cliffside Unit 6	844	Coal	2012	$	2,100
Duke Energy Carolinas	Dan River Combined Cycle	637	Natural Gas	2012	675
Duke Energy Progress	H.F. Lee Combined Cycle	916	Natural Gas	2012	725
Duke Energy Progress	L.V. Sutton Combined Cycle	622	Natural Gas	2013	575
Duke Energy Indiana	Edwardsport IGCC	595	Coal	2013	3,550
Total		3,614			$	7,625

Potential Plant Retirements

The Subsidiary Registrants periodically file Integrated Resource Plans (IRP) with 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. Recent IRPs filed by the Subsidiary Registrants included planning assumptions to potentially retire certain coal-fired generating facilities earlier than their current estimated useful lives. These facilities do not have the requisite emission control equipment, primarily to meet United States Environmental Protection Agency (EPA) regulations recently approved or proposed. These facilities total approximately 1,704 MW at three sites. 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. For additional information related to potential plant retirements see Note 4 to the Consolidated Financial Statements, “Regulatory Matters.”

Sources of Electricity

Regulated Utilities relies principally on coal, natural gas and nuclear fuel for its generation of electricity. The following table lists sources of electricity and fuel costs for the three years ended December 31, 2014.

	Generation by Source(a)(e)						Cost of Delivered Fuel per Net Kilowatt-hour Generated (Cents)(a)(e)
	2014		2013		2012		2014	2013	2012
Coal(b)	36.5	%	35.7	%	39.1	%	3.54	3.67	3.55
Nuclear(b)	28.4	%	28.7	%	30.8	%	0.65	0.66	0.62
Gas and oil(b)	20.8	%	21.3	%	14.0	%	4.70	4.18	4.03
All fuels (cost-based on weighted average)(b)	85.7	%	85.7	%	83.9	%	2.86	2.79	2.55
Hydroelectric and solar(c)	0.9	%	1.5	%	0.8	%
Total generation	86.6	%	87.2	%	84.7	%
Purchased power and net interchange(d)	13.4	%	12.8	%	15.3	%
Total sources of energy	100.0	%	100.0	%	100.0	%

(a) Statistics include Duke Energy Progress and Duke Energy Florida beginning July 2, 2012.

(b) Statistics related to all fuels reflect Regulated Utilities' ownership interest in jointly owned generation facilities.

(c) Generating figures are net of output required to replenish pumped storage facilities during off-peak periods. 

(d) Purchased power includes renewable energy purchases. 

(e) Includes the effect of the Joint Dispatch Agreement (JDA) and Mitigation sales. Mitigation sales are excluded from the Regulated Utilities segment. 

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PART I

Coal

Regulated Utilities meets its coal demand through a portfolio of long-term purchase contracts and short-term spot market purchase agreements. Large amounts of coal are purchased under long-term contracts with mining operators who mine both underground and at the surface. Regulated Utilities uses spot-market purchases to meet coal requirements not met by long-term contracts. Expiration dates for its long-term contracts, which have various price adjustment provisions and market re-openers, range from 2015 to 2016 for Duke Energy Carolinas, 2015 to 2018 for Duke Energy Progress, 2015 to 2016 for Duke Energy Florida, and 2015 to 2025 for Duke Energy Indiana. Regulated Utilities expects to renew these contracts or enter into similar contracts with other suppliers as existing contracts expire, though prices will fluctuate over time as coal markets change. Coal purchased for the Carolinas is primarily produced from mines in Central Appalachia, Northern Appalachia and the Illinois Basin. Coal purchased for Florida is primarily produced from mines in Central Appalachia and the Illinois Basin. Coal purchased for Indiana is primarily produced in Indiana and Illinois. Regulated Utilities has an adequate supply of coal under contract to fuel its projected 2015 operations and a significant portion of supply to fuel its projected 2016 operations. Current coal inventory levels for Regulated Utilities are at adequate levels and are expected to remain at adequate levels for the remainder of 2015. Changing natural gas prices continue to influence the level of coal generation.

The current average sulfur content of coal purchased by Regulated Utilities is between 1.5 percent and 2 percent for Duke Energy Carolinas, between 1.5 percent and 2 percent for Duke Energy Progress, between 1 percent and 2.5 percent for Duke Energy Florida, and between 2 percent and 3 percent for Duke Energy Indiana. Regulated Utilities’ environmental controls, in combination with the use of sulfur dioxide (SO₂) emission allowances, enable Regulated Utilities to satisfy current SO₂ emission limitations for its existing facilities.

Nuclear

The industrial processes for producing nuclear generating fuel generally involve the mining and milling of uranium ore to produce uranium concentrates, and services to convert, enrich, and fabricate fuel assemblies.

Regulated Utilities has contracted for uranium materials and services to fuel its nuclear reactors. Uranium concentrates, conversion services and enrichment services are primarily met through a diversified portfolio of long-term supply contracts. The contracts are diversified by supplier, country of origin and pricing. Regulated Utilities staggers its contracting so that its portfolio of long-term contracts covers the majority of its fuel requirements in the near term and decreasing portions of its fuel requirements over time thereafter. Near-term requirements not met by long-term supply contracts have been and are expected to be fulfilled with spot market purchases. Due to the technical complexities of changing suppliers of fuel fabrication services, Regulated Utilities generally sources these services to a single domestic supplier on a plant-by-plant basis using multiyear contracts.

Regulated Utilities has entered into fuel contracts that cover 100 percent of its uranium concentrates, conversion services, and enrichment services requirements through at least 2015 and cover fabrication services requirements for these plants through at least 2018. For future requirements not already covered under long-term contracts, Regulated Utilities believes it will be able to renew contracts as they expire, or enter into similar contractual arrangements with other suppliers of nuclear fuel materials and services.

Gas and Oil

Natural gas and oil supply for Regulated Utilities’ generation fleet is purchased under term and spot contracts from various suppliers. Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana use derivative instruments to limit a portion of their exposure to price fluctuations for natural gas. Regulated Utilities has certain dual-fuel generating facilities that can operate with both natural gas and oil. The cost of Regulated Utilities’ natural gas and oil is either at a fixed price or determined by market prices as reported in certain industry publications. Regulated Utilities believes it has access to an adequate supply of gas and oil for the reasonably foreseeable future. Regulated Utilities’ natural gas transportation for its gas generation is purchased under long-term firm transportation contracts with interstate and intrastate pipelines. Regulated Utilities may also purchase additional shorter-term transportation for its load requirements during peak periods. The Regulated Utilities natural gas plants are served by several supply zones and multiple pipelines.

Purchased Power

Regulated Utilities purchased approximately 14.3 million megawatt-hours (MWh), 11.7 million MWh and 19.8 million MWh of its system energy requirements during 2014, 2013, and 2012, respectively, under purchase obligations and leases and had 4,500 and 3,800 MW of firm purchased capacity under contract during 2014 and 2013, respectively. These amounts include MWh for Duke Energy Progress and Duke Energy Florida for all periods presented. These agreements include amounts contracted with certain QFs. Regulated Utilities may need to acquire additional purchased power capacity in the future to accommodate a portion of its system load needs. Regulated Utilities believes it can obtain adequate purchased power to meet these needs. However, during periods of high demand, the price and availability of purchased power may be significantly affected.

Gas for Retail Distribution

Regulated Utilities is responsible for the purchase and the subsequent delivery of natural gas to retail customers in its Ohio and Kentucky service territories. Regulated Utilities’ natural gas procurement strategy is to buy firm natural gas supplies and firm interstate pipeline transportation capacity during the winter season and during the non-heating season through a combination of firm supply and transportation capacity along with spot supply and interruptible transportation capacity. This strategy allows Regulated Utilities to assure reliable natural gas supply for its non-curtailable customers during peak winter conditions and provides Regulated Utilities the flexibility to reduce its contract commitments if firm customers choose alternate gas. In 2014, firm supply purchase commitment agreements provided approximately 97 percent of the natural gas supply.

Inventory

Generation of electricity is capital intensive. Regulated Utilities must maintain an adequate stock of fuel and materials and supplies in order to ensure continuous operation of generating facilities and reliable delivery to customers. As of December 31, 2014, the inventory balance for Regulated Utilities was $3,348 million. For additional information on inventory see Note 1 to the Consolidated Financial Statements, “Summary of Significant Accounting Policies.”

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PART I

North Carolina Ash Basin Management

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy Carolinas’ retired Dan River steam station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy Carolinas estimates 30,000 to 39,000 tons of ash and 24 million to 27 million gallons of basin water were released into the river during the incident. Duke Energy Carolinas incurred approximately $24 million of repairs and remediation expense related to this incident during the year ended December 31, 2014. Duke Energy Carolinas will not seek recovery of these costs from customers. In July 2014, Duke Energy completed remediation work identified by the EPA and continues to cooperate with the EPA's civil enforcement process.

As a result of separate Memoranda of Plea Agreement (Plea Agreements) entered into by Duke Energy Carolinas and Duke Energy Progress in connection with a criminal investigation related to the Dan River ash basin release and the management of coal ash basins at the 14 plants in North Carolina with coal ash basins, Duke Energy Carolinas and Duke Energy Progress recognized expense for the year ended December 31, 2014 of $72 million and $30 million, respectively. The Plea Agreements are subject to the approval of the U.S. District Court for the Eastern District of North Carolina and, if approved, will end the grand jury investigation related to the Dan River ash basin release and the management of coal ash basins at the 14 plants in North Carolina with coal ash basins.

The Plea Agreements do not cover pending civil claims related to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. Duke Energy Corporation will continue to defend against remaining civil actions associated with these matters. Other costs related to the Dan River release including state or federal civil enforcement proceedings, future regulatory directives, natural resources damages, pending litigation, future claims or litigation, and long-term environmental impact costs cannot be reasonably estimated at this time.

For additional information on the North Carolina Ash Basin Grand Jury Investigation and Plea Agreements, see Note 5 to the Consolidated Financial Statements, "Commitments and Contingencies."

Nuclear Matters

Regulated Utilities owns, wholly or partially, 12 nuclear reactors located at seven stations. Nuclear insurance includes: nuclear liability coverage; property, decontamination and premature decommissioning coverage; and replacement power expense coverage. Joint owners reimburse Regulated Utilities for certain expenses associated with nuclear insurance in accordance with joint owner agreements. The Price-Anderson Act requires plant owners to provide for public nuclear liability claims resulting from nuclear incidents to the maximum total financial protection liability, which currently is $13.6 billion. For additional information on nuclear insurance see Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies.”

Regulated Utilities has a significant future financial commitment to dispose of spent nuclear fuel and decommission and decontaminate each plant safely. The NCUC, PSCSC and FPSC require Regulated Utilities to update their cost estimates for decommissioning their nuclear plants every five years.

The following table summarizes the fair value of nuclear decommissioning trust fund (NDTF) balances and cost study results for Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida.

	NDTF
(in millions)	December 31, 2014		December 31, 2013		Decommissioning Costs(a)(b)		Year of Cost Study
Duke Energy Carolinas	$	3,042	$	2,840	$	3,420	2013
Duke Energy Progress	1,701		1,539		3,062		2014
Duke Energy Florida	803		753		1,083		2013

(a) Represents cost per the most recent site-specific nuclear decommissioning cost studies, including costs to decommission plant components not subject to radioactive contamination. Amounts are in dollars of the year of cost study.

(b) Includes the Subsidiary Registrants' ownership interest in jointly owned reactors. Other joint owners are responsible for decommissioning costs related to their interest in the reactors.

The NCUC, PSCSC and FPSC have allowed Regulated Utilities’ to recover estimated decommissioning costs through retail rates over the expected remaining service periods of their nuclear stations. Regulated Utilities believes the decommissioning costs being recovered through rates, when coupled with the existing fund balance and expected fund earnings, will be sufficient to provide for the cost of future decommissioning. For additional information see Note 9 to the Consolidated Financial Statements, “Asset Retirement Obligations.”

The Nuclear Waste Policy Act of 1982 (as amended) (NWPA) provides the framework for development by the federal government of interim storage and permanent disposal facilities for high-level radioactive waste materials. The NWPA promotes increased usage of interim storage of spent nuclear fuel at existing nuclear plants. Regulated Utilities will continue to maximize the use of spent fuel storage capability within its own facilities for as long as feasible.

Under federal law, the U.S. Department of Energy (DOE) is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. Delays have occurred in the DOE’s proposed permanent repository to be located at Yucca Mountain, Nevada.

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PART I

Until the DOE begins to accept the spent nuclear fuel, Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida will continue to safely manage their spent nuclear fuel. With certain modifications and additional approvals by the Nuclear Regulatory Commission (NRC), including the expansion of on-site dry cask storage facilities, spent nuclear fuel storage facilities will be sufficient to provide storage space for spent fuel through the expiration of the operating licenses, including any license renewals, for all sites except Shearon Harris Nuclear Station (Harris) and Crystal River Unit 3 Nuclear Station (Crystal River Unit 3). Under current regulatory guidelines, Harris has sufficient storage capacity in its spent fuel pools through the expiration of its renewed operating license. Crystal River Unit 3 was retired in 2013, with plans to place the facility in SAFSTOR prior to final decommissioning. An independent spent fuel storage installation will be installed to accommodate storage of all spent nuclear fuel until the DOE accepts the spent nuclear fuel.

The nuclear power industry faces uncertainties with respect to the cost and long-term availability of disposal sites for spent nuclear fuel and other radioactive waste, compliance with changing regulatory requirements, capital outlays for modifications and new plant construction, the technological and financial aspects of decommissioning plants at the end of their licensed lives, and requirements relating to nuclear insurance. Nuclear units are periodically removed from service to accommodate normal refueling and maintenance outages, repairs, uprates and certain other modifications.

Regulated Utilities is subject to the jurisdiction of the NRC for the design, construction and operation of its nuclear generating facilities. Nuclear operating licenses are potentially subject to extension. The following table includes the current expiration of nuclear operating licenses.

Unit	Year of Expiration
Duke Energy Carolinas
Catawba Unit 1	2043
Catawba Unit 2	2043
McGuire Unit 1	2041
McGuire Unit 2	2043
Oconee Unit 1	2033
Oconee Unit 2	2033
Oconee Unit 3	2034
Duke Energy Progress
Brunswick Unit 1	2036
Brunswick Unit 2	2034
Harris	2046
Robinson	2030
Duke Energy Florida
Crystal River Unit 3	(a)

(a) Duke Energy Florida has requested the NRC to terminate the Crystal River Unit 3 operating license as Crystal River Unit 3 permanently ceased operation in February 2013. For additional information on decommissioning activity and transition to SAFSTOR, see Note 4 "Regulatory Matters."

The NRC issues orders with regard to security at nuclear plants in response to new or emerging threats. The most recent orders include additional restrictions on nuclear plant access, increased security measures at nuclear facilities and closer coordination with intelligence, military, law enforcement and emergency response functions at the federal, state and local levels. As the NRC, other governmental entities and the industry continue to consider security issues, it is possible that more extensive security plans could be required.

Regulation

State

The NCUC, PSCSC, FPSC, PUCO, IURC and KPSC (collectively, the state utility commissions) approve rates for retail electric and gas service within their respective states. The state utility commissions, to varying degrees, have authority over the construction and operation of Regulated Utilities’ generating facilities. Certificates of Public Convenience and Necessity issued by the state utility commissions, as applicable, authorize Regulated Utilities to construct and operate its electric facilities, and to sell electricity to retail and wholesale customers. Prior approval from the relevant state utility commission is required for Regulated Utilities to issue securities. The underlying concept of utility ratemaking is to set rates at a level that allows the utility to collect revenues equal to its cost of providing service plus earn a reasonable rate of return on its invested capital, including equity.

Each of the state utility commissions allow recovery of certain costs through various cost-recovery clauses to the extent the respective commission determines in periodic hearings that such costs, including any past over or under-recovered costs, are prudent. The clauses are in addition to approved base rates.

Fuel, fuel-related costs and certain purchased power costs are eligible for recovery by Regulated Utilities. Regulated Utilities uses coal, hydroelectric, natural gas, oil and nuclear fuel to generate electricity, thereby maintaining a diverse fuel mix that helps mitigate the impact of cost increases in any one fuel. Due to the associated regulatory treatment and the method allowed for recovery, changes in fuel costs from year to year have no material impact on operating results of Regulated Utilities, unless a commission finds a portion of such costs to have been imprudent. However, delays between the expenditure for fuel costs and recovery from customers can adversely impact the timing of cash flows of Regulated Utilities.

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PART I

The following table summarizes base rate cases approved and effective in the past three years.

	Annual Increase (in millions)		Return on Equity		Equity Component of Capital Structure		Effective Date	Other
Duke Energy Carolinas 2013 North Carolina Rate Case(a)	$	234	10.2	%	53	%	September 2013	(b)
Duke Energy Carolinas 2013 South Carolina Rate Case(a)	118		10.2	%	53	%	September 2013	(c)
Duke Energy Carolinas 2011 North Carolina Rate Case	309		10.5	%	53	%	February 2012
Duke Energy Carolinas 2011 South Carolina Rate Case	93		10.5	%	53	%	February 2012
Duke Energy Progress 2012 North Carolina Rate Case(a)	178		10.2	%	53	%	June 2013	(d)
Duke Energy Ohio 2012 Electric Rate Case	49		9.84	%	53	%	May 2013
Duke Energy Ohio 2012 Natural Gas Rate Case	—		9.84	%	53	%	December 2013	(e)
Duke Energy Florida 2013 FPSC Settlement	—		10.5	%	49	%	October 2013	(f)(h)
Duke Energy Florida 2012 FPSC Settlement	150		10.5	%	49	%	January 2013	(g)(h)

(a) Rates increase over a two or three year period as approved by the NCUC and PSCSC. Annual increase amounts represent the total increase once effective.

(b) Terms of this rate case include (i) recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) a $10 million shareholder contribution to agencies providing energy assistance to low-income customers, (iii) an annual reduction in the regulatory liability for costs of removal of $30 million for each of the first two years, and (iv) no additional base rate increases to be effective before September 2015.

(c) Terms of this rate case include (i) recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) an approximate $4 million shareholder contribution to agencies providing energy assistance to low-income customers and for economic development, (iii) a reduction in the regulatory liability for costs of removal of $45 million for the first year, and (iv) no additional base rate increases to be effective before September 2015.

(d) Terms of this rate case include (i) recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) a $20 million shareholder contribution to agencies providing energy assistance to low-income customers, and (iii) a reduction in the regulatory liability for costs of removal of $20 million for the first year.

(e) Although the PUCO approved no increase in base rates, more than half of the revenue request was approved to be recovered in various riders, including recovery of costs related to former manufactured gas plants (MGP). Recovery of $56 million of MGP costs via a rider was approved in November 2013. The rider became effective in March 2014, was suspended in June 2014 and reinstated in January 2015. For additional information on MGP recovery see Note 4 to the Consolidated Financial Statements, “Regulatory Matters.”

(f) Terms of this settlement include (i) no additional base rate increases until 2019, (ii) partial recovery of Crystal River Unit 3 beginning in 2014, and (iii) full recovery of Crystal River Unit 3, not to exceed $1,466 million, plus the cost to build a dry cask storage facility, beginning no later than 2017.

(g) Terms of this settlement include the removal of Crystal River Unit 3 assets from rate base. 

(h) Capital structure includes deferred income tax, customer deposits and investment tax credits.

For more information on rate matters and other regulatory proceedings, see Note 4 to the Consolidated Financial Statements, “Regulatory Matters.”

Federal

The FERC approves Regulated Utilities’ cost-based rates for electric sales to certain wholesale customers, as well as sales of transmission service. Regulations of FERC and the state utility commissions govern access to regulated electric and gas customers and other data by nonregulated entities and services provided between regulated and nonregulated energy affiliates. These regulations affect the activities of nonregulated affiliates with Regulated Utilities.

Regional Transmission Organizations (RTO). PJM Interconnection, LLC (PJM) and Midcontinent Independent Transmission System Operator, Inc. (MISO) are the Independent System Operators (ISO) and FERC-approved RTOs for the regions in which Duke Energy Ohio and Duke Energy Indiana operate. PJM and MISO operate energy, capacity and other markets, and, through central dispatch, control the day-to-day operations of bulk power systems.

Duke Energy Ohio is a member of PJM and Duke Energy Indiana is a member of MISO. Transmission owners in these RTOs have turned over control of their transmission facilities, and their transmission systems are currently under the dispatch control of the RTOs. Transmission service is provided on a region-wide, open-access basis using the transmission facilities of the RTO members at rates based on the costs of transmission service.

Environmental. Regulated Utilities is subject to the jurisdiction of the EPA and state and local environmental agencies. For a discussion of environmental regulation, see “Environmental Matters” in this section.

See “Other Matters” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion about potential Global Climate Change legislation and other EPA regulations under development and the potential impacts such legislation and regulation could have on Duke Energy’s operations.

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PART I

INTERNATIONAL ENERGY

International Energy principally operates and manages power generation facilities and engages in sales and marketing of electric power, natural gas, and natural gas liquids outside the U.S. Its activities principally target power generation in Latin America. Additionally, International Energy owns a 25 percent interest in National Methanol Company (NMC), a large regional producer of methanol and methyl tertiary butyl ether (MTBE) located in Saudi Arabia. International Energy’s economic ownership interest will decrease to 17.5 percent upon successful startup of NMC's polyacetal production facility, which is expected to occur after June 2016. International Energy will retain 25 percent of the board representation and voting rights of NMC. The investment in NMC is accounted for under the equity method of accounting.

International Energy’s customers include retail distributors, electric utilities, independent power producers, marketers, and industrial and commercial companies. International Energy’s current strategy is focused on optimizing the value of its current Latin American portfolio and expanding the portfolio through investment in generation opportunities in Latin America.

During 2014, Duke Energy performed a strategic review of international Energy to evaluate a wide range of options and opportunities for growth of the business, including strategies for utilization of off-shore cash. Duke Energy determined it is in the shareholders' best interest, at the present time, to continue to own, operate and create value through portfolio optimization and efficiency of International Energy operations.

Duke Energy also declared a taxable dividend of historical foreign earnings in the form of notes payable that will result in the repatriation of approximately $2.7 billion in cash held and expected to be generated by International Energy over a period of up to eight years. Duke Energy’s intention is to indefinitely reinvest prospective undistributed foreign earnings generated by International Energy. For additional information see Note 22 to the Consolidated Financial Statements, “Income Taxes,” for additional information.

Competition and Regulation

International Energy’s sales and marketing of electric power and natural gas competes directly with other generators and marketers serving its market areas. Competitors are country and region-specific but include government-owned electric generating companies, local distribution companies with self-generation capability and other privately owned electric generating and marketing companies. The principal elements of competition are price and availability, terms of service, flexibility and reliability of service.

A high percentage of International Energy’s portfolio consists of baseload hydroelectric generation facilities, which compete with other forms of electric generation available to International Energy’s customers and end-users, including natural gas and fuel oils. Economic activity, conservation, legislation, governmental regulations, weather, including rainfall, additional generation capacities and other factors affect the supply and demand for electricity in the regions served by International Energy.

International Energy’s operations are subject to both country-specific and international laws and regulations. See “Environmental Matters” in this section.

COMMERCIAL POWER

Commercial Power builds, develops, and operates wind and solar renewable generation and energy transmission projects throughout the continental U.S. Long-term contracts are generally executed with load serving entities, which, in most instances, have obligations under state-mandated renewable energy portfolio standards or similar state or local renewable energy goals. Energy and renewable energy credits generated by wind and solar projects are generally sold at contractual prices. Commercial Power also builds, develops and operates high voltage power and natural gas transmission projects. These projects are designed to increase reliability, integrate renewables generation and relieve grid congestion.

Duke Energy, Dominion Resources (Dominion), Piedmont Natural Gas and AGL Resources announced the formation of a joint venture, Atlantic Coast Pipeline, LLC, to build and own the proposed Atlantic Coast Pipeline (ACP), a 550-mile interstate natural gas pipeline. The ACP is designed to meet the needs identified in requests for proposals by Duke Energy Carolinas, Duke Energy Progress and Piedmont Natural Gas. Dominion will build and operate the ACP and will own 45 percent. Duke Energy, will own 40 percent ownership of the pipeline through its Commercial Power segment. The remaining share will be owned by Piedmont Natural Gas and AGL Resources. Duke Energy Carolinas and Duke Energy Progress will be customers of the pipeline and enter into 20-year transportation contracts with ACP, subject to state regulatory approval. The project will require FERC approval, which the joint venture will seek to secure by summer 2016. The estimated in-service date of the pipeline is late 2018. For additional information on the ACP, see Note 4 to the Consolidated Financial Statements, “Regulatory Matters."

Commercial Power has three wind projects totaling approximately 510 MW under various stages of construction in Starr County, Texas. A 200 MW project is expected to commence operation in the second quarter of 2015, a 110 MW project is expected to commence commercial operations by the end of 2015 and a third 200 MW project is expected to commence operation in the third quarter of 2016. All three projects have entered into long-term power purchase agreements with third parties.

For additional information on Commercial Power’s generation facilities, see Item 2, “Properties.”

Other Matters

Commercial Power is subject to regulation at the federal level, primarily from the FERC. Regulations of the FERC govern access to regulated electric customer and other data by nonregulated entities, services provided between regulated and nonregulated energy affiliates, and Commercial Power’s investments in transmission projects. These regulations affect the activities of Commercial Power.

For more information on rate matters, see Note 4 to the Consolidated Financial Statements, “Regulatory Matters — Rate Related Information.”

Market Environment and Competition

The market price of commodities and services, along with the quality and reliability of services provided, drive competition in the wholesale energy business. Commercial Power’s main competitors include other nonregulated generators and wholesale power providers.

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Sources of Electricity

Commercial Power relies on wind and solar resources for its generation of electric energy.

OTHER

The remainder of Duke Energy’s operations is presented as Other. While it is not an operating segment, Other primarily includes unallocated corporate interest expense, certain unallocated corporate costs, Bison Insurance Company Limited (Bison), Duke Energy’s wholly owned, captive insurance subsidiary, contributions to the Duke Energy Foundation, and other investments in businesses the Company is in various stages of exiting or winding down. On December 31, 2013, Duke Energy sold its interest in DukeNet Communications Holdings, LLC (DukeNet) to Time Warner Cable, Inc. Following the repayment of existing DukeNet indebtedness at closing, transaction expenses and other purchase price adjustments, Duke Energy received cash proceeds of approximately $215 million.

Bison’s principal activities as a captive insurance entity include the indemnification of various business risks and losses, such as property, workers’ compensation and general liability of Duke Energy subsidiaries and affiliates.

Regulation

Certain entities within Other are subject to the jurisdiction of state and local agencies.

Geographic Regions

For a discussion of Duke Energy’s foreign operations see “Management’s Discussion and Analysis of Results of Operations” and Note 3 to the Consolidated Financial Statements, “Business Segments.”

Employees

On December 31, 2014, Duke Energy had 28,344 employees. A total of 6,267 operating and maintenance employees were represented by unions.

Executive Officers

Melissa H. Anderson	50	Senior Vice President and Chief Human Resources Officer. Ms. Anderson assumed her position in January 2015. Prior to joining Duke Energy, she served as Senior Vice President of Human Resources at Domtar Inc. since 2010.
Lynn J. Good	55	Vice Chairman, President and Chief Executive Officer.Ms. Good assumed her current position in July 2013. Prior to that, she served as Executive Vice President and Chief Financial Officer since 2009.
Dhiaa M. Jamil	58	Executive Vice President and President, Regulated Generation.Mr. Jamil assumed his current position in August 2014. He served as Executive Vice President and President of Duke Energy Nuclear from March 2013 and as Chief Nuclear Officer from February 2008 to August 2014. He also served as Chief Generation Officer for Duke Energy from July 2009 to June 2012.
Julia S. Janson	50	Executive Vice President, Chief Legal Officer and Corporate Secretary.Ms. Janson assumed her current position in December 2012. Prior to that, she had held the position of President of Duke Energy Ohio and Duke Energy Kentucky since 2008.
Marc E. Manly	62	Executive Vice President and President, Commercial Portfolio.Mr. Manly assumed his current position in August 2014. He served as Executive Vice President and President, Commercial Businesses from December 2012 until August 2014. He previously held the position of Chief Legal Officer from April 2006, upon the merger of Duke Energy and Cinergy, until December 2012.
A.R. Mullinax	60	Executive Vice President, Strategic Services. Mr. Mullinax assumed his current position in August 2014. Prior to that, he had held the position of Chief Information Officer since 2007.
Brian D. Savoy	39	Senior Vice President, Controller and Chief Accounting Officer.Mr. Savoy assumed his current position in September 2013. Prior to that, he had held the position of Director, Forecasting and Analysis since 2009.
B. Keith Trent	55	Executive Vice President, Grid Solutions and President, Midwest and Florida Regions.Mr. Trent assumed his current position in August 2014. He served as Executive Vice President and Chief Operating Officer, Regulated Utilities from December 2012 until August 2014. Prior to that, he held the position of Executive Vice President, Regulated Utilities upon the merger with Progress Energy in July 2012, and President, Commercial Businesses from July 2009 until July 2012.
Jennifer L. Weber	48	Executive Vice President, External Affairs and Strategic Policy.Ms. Weber assumed her current position in August 2014. Prior to that, she had served as Executive Vice President Chief Human Resources Officer since January 2011. She previously held the position of Senior Vice President and Chief Human Resources Officer from November 2008 until January 2011.
Lloyd M. Yates	54	Executive Vice President, Market Solutions and President, Carolinas Region.Mr. Yates assumed his current position in August 2014. He held the position of Executive Vice President, Regulated Utilities from December 2012 to August 2014, and prior to that, had served as Executive Vice President, Customer Operations since July 2012, upon the merger of Duke Energy and Progress Energy. Prior to the merger, Mr. Yates had served as Chief Executive Officer, Duke Energy Progress, Inc. since July 2007.
Steven K. Young	56	Executive Vice President and Chief Financial Officer.Mr. Young assumed his current position in August 2013. Prior to that, he had served as Vice President, Chief Accounting Officer and Controller since April 2006.

Executive officers serve until their successors are duly elected or appointed.

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There are no family relationships between any of the executive officers, nor any arrangement or understanding between any executive officer and any other person involved in officer selection.

Environmental Matters

The Duke Energy Registrants are subject to federal, state and local laws and regulations with regard to air and water quality, hazardous and solid waste disposal and other environmental matters. Duke Energy is also subject to international laws and regulations with regard to air and water quality, hazardous and solid waste disposal and other environmental matters. Environmental laws and regulations affecting the Duke Energy Registrants include, but are not limited to:

• The Clean Air Act (CAA), as well as state laws and regulations impacting air emissions, including State Implementation Plans related to existing and new national ambient air quality standards for ozone and particulate matter. Owners and/or operators of air emission sources are responsible for obtaining permits and for annual compliance and reporting.

• The Clean Water Act (CWA) which requires permits for facilities that discharge wastewaters into the environment.

• The Comprehensive Environmental Response, Compensation and Liability Act, which can require any individual or entity that currently owns or in the past may have owned or operated a disposal site, as well as transporters or generators of hazardous substances sent to a disposal site, to share in remediation costs.

• The Solid Waste Disposal Act, as amended by the Resource Conservation and Recovery Act (RCRA), which requires certain solid wastes, including hazardous wastes, to be managed pursuant to a comprehensive regulatory regime.

• The National Environmental Policy Act, which requires federal agencies to consider potential environmental impacts in their decisions, including siting approvals.

See “Other Matters” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations for a discussion about potential Global Climate Change legislation and the potential impacts such legislation could have on the Duke Energy Registrants’ operations. Additionally, other recently passed and potential future environmental laws and regulations could have a significant impact on the Duke Energy Registrants’ results of operations, cash flows or financial position. However, if and when such laws and regulations become effective, the Duke Energy Registrants will seek appropriate regulatory recovery of costs to comply within its regulated operations.

For more information on environmental matters involving the Duke Energy Registrants, including possible liability and capital costs, see Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies - Environmental.” Except to the extent discussed in Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” compliance with current international, federal, state and local provisions regulating the discharge of materials into the environment, or otherwise protecting the environment, is incorporated into the routine cost structure of our various business segments and is not expected to have a material adverse effect on the competitive position, consolidated results of operations, cash flows or financial position of the Duke Energy Registrants.

DUKE ENERGY CAROLINAS

Duke Energy Carolinas is a regulated public utility primarily engaged in the generation, transmission, distribution, and sale of electricity in portions of North Carolina and South Carolina. Duke Energy Carolinas’ service area covers approximately 24,000 square miles and supplies electric service to 2.5 million residential, commercial and industrial customers. For information about Duke Energy Carolinas’ generating plants, see Item 2, “Properties.” Duke Energy Carolinas is subject to the regulatory provisions of the NCUC, PSCSC, NRC and FERC.

Substantially all of Duke Energy Carolinas operations are regulated and qualify for regulatory accounting. Duke Energy Carolinas operates one reportable business segment, Regulated Utility. For additional information regarding this business segment, including financial information, see Note 3 to the Consolidated Financial Statements, “Business Segments.”

PROGRESS ENERGY

Progress Energy is a public utility holding company headquartered in Raleigh, North Carolina, primarily engaged in the regulated electric utility business and is subject to regulation by the FERC. Progress Energy conducts operations through its wholly owned subsidiaries, Duke Energy Progress and Duke Energy Florida. When discussing Progress Energy’s financial information, it necessarily includes the results of Duke Energy Progress and Duke Energy Florida.

Substantially all of Progress Energy’s operations are regulated and qualify for regulatory accounting. Progress Energy operates one reportable business segment, Regulated Utilities. For additional information regarding this business segment, including financial information, see Note 3 to the Consolidated Financial Statements, “Business Segments.”

DUKE ENERGY PROGRESS

Duke Energy Progress is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of North Carolina and South Carolina. Duke Energy Progress’ service area covers approximately 32,000 square miles, and supplies electric service to approximately 1.5 million residential, commercial and industrial customers. For information about Duke Energy Progress’ generating plants, see Item 2, “Properties.” Duke Energy Progress is subject to the regulatory provisions of the NCUC, PSCSC, NRC and FERC.

Substantially all of Duke Energy Progress’ operations are regulated and qualify for regulatory accounting. Duke Energy Progress operates one reportable business segment, Regulated Utility. For additional information regarding this business segment, including financial information, see Note 3 to the Consolidated Financial Statements, “Business Segments.”

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DUKE ENERGY FLORIDA

Duke Energy Florida is a regulated public utility primarily engaged in the generation, transmission, distribution, and sale of electricity in portions of Florida. Duke Energy Florida’s service area covers approximately 13,000 square miles and supplies electric service to approximately 1.7 million residential, commercial and industrial customers. For information about Duke Energy Florida’s generating plants, see Item 2, “Properties.” Duke Energy Florida is subject to the regulatory provisions of the FPSC, NRC and FERC.

Substantially all of Duke Energy Florida’s operations are regulated and qualify for regulatory accounting. Duke Energy Florida operates one reportable business segment, Regulated Utility. For additional information regarding this business segment, including financial information, see Note 3 to the Consolidated Financial Statements, “Business Segments.”

DUKE ENERGY OHIO

Duke Energy Ohio is a public utility that provides service in portions of Ohio and Kentucky. References herein to Duke Energy Ohio include Duke Energy Ohio and its subsidiaries. Duke Energy Ohio is subject to the regulatory provisions of the PUCO, KPSC and FERC.

Business Segments

Duke Energy Ohio operates two business segments: Regulated Utilities and Commercial Power. For additional information on each of these business segments, including financial information, see Note 3 to the Consolidated Financial Statements, “Business Segments.”

The following is a brief description of the nature of operations of each of Duke Energy Ohio’s reportable business segments.

REGULATED UTILITIES

Regulated Utilities transmits and distributes electricity in Ohio. Regulated Utilities also generates, transmits and distributes electricity in Kentucky. Regulated Utilities also transports and sells natural gas in Ohio and Kentucky. Duke Energy Ohio applies regulatory accounting to substantially all of the operations in its Regulated Utilities operating segment.

Duke Energy Ohio’s Regulated Utilities service area covers 3,000 square miles and supplies electric service to 840,000 residential, commercial and industrial customers and provides regulated transmission and distribution services for natural gas to 500,000 customers. See Item 2, “Properties” for further discussion of Duke Energy Ohio’s Regulated Utilities generating facilities.

See Note 4 to the Consolidated Financial Statements, “Regulatory Matters,” for further discussion related to regulatory filings.

COMMERCIAL POWER

On August 21, 2014, Duke Energy entered into an agreement to sell Commercial Power's Midwest generation business to Dynegy. The transaction is conditioned on approval by FERC, and is expected to close by the end of the second quarter of 2015. The results of these operations have been reclassified to Discontinued Operations on the Consolidated Statements of Operations and Comprehensive Income. For additional information on the Midwest generation business disposition see Note 2 to the Consolidated Financial Statements, "Acquisitions, Dispositions and Sales of Other Assets."

For additional information on Duke Energy Ohio’s Commercial Power generating facilities, see Item 2, “Properties,”

DUKE ENERGY INDIANA

Duke Energy Indiana is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Indiana. Duke Energy Indiana’s service area covers 23,000 square miles and supplies electric service to 810,000 residential, commercial and industrial customers. See Item 2, “Properties” for further discussion of Duke Energy Indiana’s generating facilities, transmission and distribution. Duke Energy Indiana is subject to the regulatory provisions of the IURC and FERC.

Substantially all of Duke Energy Indiana’s operations are regulated and qualify for regulatory accounting. Duke Energy Indiana operates one reportable business segment, Regulated Utility. For additional information regarding this business segment, including financial information, see Note 3 to the Consolidated Financial Statements, “Business Segments.”

ITEM 1A. RISK FACTORS

In addition to other disclosures within this Form 10-K, including Management’s Discussion and Analysis - Matters Impacting Future Results for each registrant in Item 7, and other documents filed with the SEC from time to time, the following factors should be considered in evaluating Duke Energy and its subsidiaries. Such factors could affect actual results of operations and cause results to differ substantially from those currently expected or sought. Unless otherwise indicated, risk factors discussed below generally relate to risks associated with all of the Duke Energy Registrants. Risks identified at the Subsidiary Registrant level are generally applicable to Duke Energy.

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Regulatory, Legislative and Legal Risks

The Duke Energy Registrants’ regulated electric revenues, earnings and results are dependent on state legislation and regulation that affect electric generation, transmission, distribution and related activities, which may limit their ability to recover costs.

The Duke Energy Registrants’ regulated utility businesses are regulated on a cost-of-service/rate-of-return basis subject to statutes and regulatory commission rules and procedures of North Carolina, South Carolina, Florida, Ohio, Indiana and Kentucky. If the Duke Energy Registrants’ regulated utility earnings exceed the returns established by the state utility commissions, retail electric rates may be subject to review and possible reduction by the commissions, which may decrease the Duke Energy Registrants’ future earnings. Additionally, if regulatory bodies do not allow recovery of costs incurred in providing service on a timely basis, the Duke Energy Registrants’ future earnings could be negatively impacted.

If legislative and regulatory structures were to evolve in such a way that the Duke Energy Registrants’ exclusive rights to serve their regulated customers were eroded, their future earnings could be negatively impacted.

Deregulation or restructuring in the electric industry may result in increased competition and unrecovered costs that could adversely affect the Duke Energy Registrants’ financial position, results of operations or cash flows and their utility businesses.

Increased competition resulting from deregulation or restructuring legislation could have a significant adverse impact on the Duke Energy Registrants’ results of operations, financial position, or cash flows. Retail competition and the unbundling of regulated electric service could have a significant adverse financial impact on the Duke Energy Registrants due to an impairment of assets, a loss of retail customers, lower profit margins or increased costs of capital. The Duke Energy Registrants cannot predict the extent and timing of entry by additional competitors into the electric markets. The Duke Energy Registrants cannot predict if or when they will be subject to changes in legislation or regulation, nor can they predict the impact of these changes on their financial position, results of operations or cash flows.

The Duke Energy Registrants’ businesses are subject to extensive federal regulation that will affect their operations and costs.

The Duke Energy Registrants are subject to regulation by FERC, NRC, EPA and various other federal agencies as well as the North American Electric Reliability Corporation. Regulation affects almost every aspect of the Duke Energy Registrants’ businesses, including, among other things, their ability to: take fundamental business management actions; determine the terms and rates of transmission and distribution services; make acquisitions; issue equity or debt securities; engage in transactions with other subsidiaries and affiliates; and pay dividends upstream to the Duke Energy Registrants. Changes to federal regulations are continuous and ongoing. The Duke Energy Registrants cannot predict the future course of regulatory changes or the ultimate effect those changes will have on their businesses. However, changes in regulation can cause delays in or affect business planning and transactions and can substantially increase the Duke Energy Registrants’ costs.

The Dan River ash basin release could impact the reputation and financial condition of the Duke Energy Registrants.

There is uncertainty regarding the extent and timing of future additional costs and liabilities related to the Dan River ash basin release, including the amount and extent of any pending or future civil or criminal penalties, and resulting litigation. These uncertainties are likely to continue for an extended period and may further increase costs. Thus, the Dan River ash basin release could have an adverse impact on the reputation of the Duke Energy Registrants and their financial position, results of operations and cash flows.

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

The Duke Energy Registrants are subject to numerous environmental laws and regulations affecting many aspects of their present and future operations, including coal combustion residuals (CCRs), air emissions, water quality, wastewater discharges, solid waste and hazardous waste. These laws and regulations can result in increased capital, operating and other costs. These laws and regulations generally require the Duke Energy Registrants to obtain and comply with a wide variety of environmental licenses, permits, inspections and other approvals. Compliance with environmental laws and regulations can require significant expenditures, including expenditures for cleanup costs and damages arising from contaminated properties. Failure to comply with environmental regulations may result in the imposition of fines, penalties and injunctive measures affecting operating assets. The steps the Duke Energy Registrants could be required to take to ensure their facilities are in compliance could be prohibitively expensive. As a result, the Duke Energy Registrants may be required to shut down or alter the operation of their facilities, which may cause the Duke Energy Registrants to incur losses. Further, the Duke Energy Registrants may not be successful in recovering capital and operating costs incurred to comply with new environmental regulations through existing regulatory rate structures and their contracts with customers. Also, the Duke Energy Registrants may not be able to obtain or maintain from time to time all required environmental regulatory approvals for their operating assets or development projects. Delays in obtaining any required environmental regulatory approvals, failure to obtain and comply with them or changes in environmental laws or regulations to more stringent compliance levels could result in additional costs of operation for existing facilities or development of new facilities being prevented, delayed or subject to additional costs. Although it is not expected that the costs to comply with current environmental regulations will have a material adverse effect on the Duke Energy Registrants’ financial position, results of operations or cash flows due to regulatory cost recovery, the Duke Energy Registrants are at risk that the costs of complying with environmental regulations in the future will have such an effect.

The EPA has recently enacted or proposed new federal regulations governing the management of cooling water intake structures, wastewater and carbon dioxide (CO₂) emissions. These regulations may require the Duke Energy Registrants to make additional capital expenditures and increase operating and maintenance costs.

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Duke Energy’s investments and projects located outside of the U.S. expose it to risks related to the laws, taxes, economic and political conditions, and policies of foreign governments. These risks may delay or reduce Duke Energy’s realization of value from its international projects.

Duke Energy currently owns and may acquire and/or dispose of material energy-related investments and projects outside the U.S. The economic, regulatory, market and political conditions in some of the countries where Duke Energy has interests may impact its ability to obtain financing on suitable terms. Other risks relate to its customers’ ability to honor their obligations with respect to projects and investments, delays in construction, limitations on its ability to enforce legal rights, and interruption of business, as well as risks of war, expropriation, nationalization, renegotiation, trade sanctions or nullification of existing contracts and changes in law, regulations, market rules or tax policy.

Operational Risks

The Duke Energy Registrants’ results of operations may be negatively affected by overall market, economic and other conditions that are beyond their control.

Sustained downturns or sluggishness in the economy generally affect the markets in which the Duke Energy Registrants operate and negatively influence electricity operations. Declines in demand for electricity as a result of economic downturns in the Duke Energy Registrants’ regulated electric service territories will reduce overall sales and lessen cash flows, especially as industrial customers reduce production and, therefore, consumption of electricity. Although the Duke Energy Registrants’ regulated electric business is subject to regulated allowable rates of return and recovery of certain costs, such as fuel, under periodic adjustment clauses, overall declines in electricity sold as a result of economic downturn or recession could reduce revenues and cash flows, thereby diminishing results of operations. Additionally, prolonged economic downturns that negatively impact the Duke Energy Registrants’ results of operations and cash flows could result in future material impairment charges to write-down the carrying value of certain assets, including goodwill, to their respective fair values.

The Duke Energy Registrants also sell electricity into the spot market or other competitive power markets on a contractual basis. With respect to such transactions, the Duke Energy Registrants are not guaranteed any rate of return on their capital investments through mandated rates, and revenues and results of operations are likely to depend, in large part, upon prevailing market prices. These market prices may fluctuate substantially over relatively short periods of time and could reduce the Duke Energy Registrants’ revenues and margins, thereby diminishing results of operations.

Factors that could impact sales volumes, generation of electricity and market prices at which the Duke Energy Registrants are able to sell electricity are as follows:

• weather conditions, including abnormally mild winter or summer weather that cause lower energy usage for heating or cooling purposes, respectively, and periods of low rainfall that decrease the ability to operate facilities in an economical manner;

• supply of and demand for energy commodities;

• transmission or transportation constraints or inefficiencies that impact nonregulated energy operations;

• availability of competitively priced alternative energy sources, which are preferred by some customers over electricity produced from coal, nuclear or gas plants, and customer usage of energy efficient equipment that reduces energy demand;

• natural gas, crude oil and refined products production levels and prices;

• ability to procure satisfactory levels of inventory, such as coal, gas and uranium; and

• capacity and transmission service into, or out of, the Duke Energy Registrants’ markets.

Natural disasters or operational accidents may adversely affect the Duke Energy Registrants’ operating results.

Natural disasters (such as electromagnetic events or the 2011 earthquake and tsunami in Japan) or other operational accidents within the company or industry (such as the San Bruno, California natural gas transmission pipeline failure) could have direct significant impacts on the Duke Energy Registrants as well as on key contractors and suppliers. Such events could indirectly impact the Duke Energy Registrants through changes to policies, laws and regulations whose compliance costs have a significant impact on the Duke Energy Registrants’ financial position, results of operations and cash flows.

Coal ash storage and management strategies to comply with CCR regulations could impact the reputation and financial condition of the Duke Energy Registrants.

As a result of electricity produced at coal-fired power plants Duke Energy Registrants manage large amounts of CCRs in dry storage in landfills or combined with water in ash basins. The potential exists for another coal ash pond failure or coal ash related incident, such as the one that occurred during the Dan River ash basin release, that could impact the environment or raise general public health concerns. Such an incident could have a material adverse impact to the reputation and financial condition of the Duke Energy Registrants.

Recent regulations for the disposal of CCRs from power plants by the EPA are expected to be effective in 2015. These regulations classify CCR as nonhazardous waste under the RCRA and apply to all new and existing landfills, new and existing surface impoundments, structural fills and CCR piles and establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. In addition to federal CCR regulations, CCR landfills and surface impoundments will continue to be independently regulated by most states and additional regulations by states may be imposed in the future. At this time, Duke Energy is evaluating the federal and state CCR regulations and developing cost estimates that will largely be dependent upon compliance alternatives selected to meet requirements of the regulations. These federal and state regulations may require additional capital expenditures, increased operating and maintenance costs, or closure of certain facilities which could affect the financial position, results of operations and cash flows of the Duke Energy Registrants. Although the Duke Energy Registrants intend to seek cost recovery for future expenditures through the normal ratemaking process with state utility

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commissions, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations, there is no guarantee that recovery of such costs will be granted.

The Duke Energy Registrants’ financial position, results of operations and cash flows may be negatively affected by a lack of growth or slower growth in the number of customers, or decline in customer demand or number of customers.

Growth in customer accounts and growth of customer usage each directly influence demand for electricity and the need for additional power generation and delivery facilities. Customer growth and customer usage are affected by a number of factors outside the control of the Duke Energy Registrants, such as mandated energy efficiency measures, demand-side management goals, distributed generation resources and economic and demographic conditions, such as population changes, job and income growth, housing starts, new business formation and the overall level of economic activity.

Certain regulatory and legislative bodies have introduced or are considering requirements and/or incentives to reduce energy consumption by certain dates. Additionally, technological advances driven by federal laws mandating new levels of energy efficiency in end-use electric devices or other improvements in or applications of technology could lead to declines in per capita energy consumption.

Advances in distributed generation technologies that produce power, including fuel cells, micro-turbines, wind turbines and solar cells, may reduce the cost of alternative methods of producing power to a level competitive with central power station electric production utilized by the Duke Energy Registrants.

Some or all of these factors, could result in a lack of growth or decline in customer demand for electricity or number of customers, and may cause the failure of the Duke Energy Registrants to fully realize anticipated benefits from significant capital investments and expenditures which could have a material adverse effect on their financial position, results of operations and cash flows.

Furthermore, the Duke Energy Registrants currently have energy efficiency riders in place to recover the cost of energy efficiency programs in North Carolina, South Carolina, Florida, Ohio and Kentucky. Should the Duke Energy Registrants be required to invest in conservation measures that result in reduced sales from effective conservation, regulatory lag in adjusting rates for the impact of these measures could have a negative financial impact.

The Duke Energy Registrants’ operating results may fluctuate on a seasonal and quarterly basis and can be negatively affected by changes in weather conditions and severe weather.

Electric power generation is generally a seasonal business. In most parts of the U.S., and other markets in which Duke Energy operates, demand for power peaks during the warmer summer months, with market prices typically peaking at that time. In other areas, demand for power peaks during the winter. Further, extreme weather conditions such as heat waves or winter storms could cause these seasonal fluctuations to be more pronounced. As a result, in the future, the overall operating results of the Duke Energy Registrants’ businesses may fluctuate substantially on a seasonal and quarterly basis and thus make period-to-period comparison less relevant.

Sustained severe drought conditions could impact generation by hydroelectric plants, as well as fossil and nuclear plant operations, as these facilities use water for cooling purposes and for the operation of environmental compliance equipment. Furthermore, destruction caused by severe weather events, such as hurricanes, tornadoes, severe thunderstorms, snow and ice storms, can result in lost operating revenues due to outages; property damage, including downed transmission and distribution lines; and additional and unexpected expenses to mitigate storm damage. The cost of storm restoration efforts may not be fully recoverable through the regulatory process.

The Duke Energy Registrants’ sales may decrease if they are unable to gain adequate, reliable and affordable access to transmission assets.

The Duke Energy Registrants depend on transmission and distribution facilities owned and operated by utilities and other energy companies to deliver electricity sold to the wholesale market. FERC’s power transmission regulations, as well as those of Duke Energy’s international markets, require wholesale electric transmission services to be offered on an open-access, non-discriminatory basis. If transmission is disrupted, or if transmission capacity is inadequate, the Duke Energy Registrants’ ability to sell and deliver products may be hindered.

The different regional power markets have changing regulatory structures, which could affect growth and performance in these regions. In addition, the ISOs who oversee the transmission systems in regional power markets have imposed in the past, and may impose in the future, price limitations and other mechanisms to address volatility in the power markets. These types of price limitations and other mechanisms may adversely impact the profitability of the Duke Energy Registrants’ wholesale power marketing business.

Fluctuations in commodity prices or availability may adversely affect various aspects of the Duke Energy Registrants’ operations as well as their financial condition, results of operations and cash flows.

The Duke Energy Registrants are exposed to the effects of market fluctuations in the price of natural gas, coal, fuel oil, nuclear fuel, electricity and other energy-related commodities as a result of their ownership of energy-related assets. Fuel costs are recovered primarily through cost-recovery clauses, subject to the approval of state utility commissions.

Additionally, the Duke Energy Registrants are exposed to risk that counterparties will not be able to fulfill their obligations. Disruption in the delivery of fuel, including disruptions as a result of, among other things, transportation delays, weather, labor relations,force majeure events, or environmental regulations affecting any of these fuel suppliers, could limit the Duke Energy Registrants to operate their facilities. Should counterparties fail to perform, the Duke Energy Registrants might be forced to replace the underlying commitment at prevailing market prices possibly resulting in losses in addition to the amounts, if any, already paid to the counterparties.

Certain of the Duke Energy Registrants’ hedge agreements may result in the receipt of, or posting of, derivative collateral with counterparties, depending on the daily derivative position. Fluctuations in commodity prices that lead to the return of collateral received and/or the posting of collateral with counterparties negatively impact liquidity. Downgrades in the Duke Energy Registrants’ credit ratings could lead to additional collateral posting requirements. The Duke Energy Registrants continually monitor derivative positions in relation to market price activity.

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Potential terrorist activities or military or other actions could adversely affect the Duke Energy Registrants’ businesses.

The continued threat of terrorism and the impact of retaliatory military and other action by the U.S. and its allies may lead to increased political, economic and financial market instability and volatility in prices for natural gas and oil, which may have material adverse effects in ways the Duke Energy Registrants cannot predict at this time. In addition, future acts of terrorism and possible reprisals as a consequence of action by the U.S. and its allies could be directed against companies operating in the U.S. or their international affiliates. Information technology systems, transmission and distribution and generation facilities such as nuclear plants could be potential targets of terrorist activities or harmful activities by individuals or groups. The potential for terrorism has subjected the Duke Energy Registrants’ operations to increased risks and could have a material adverse effect on their businesses. In particular, the Duke Energy Registrants may experience increased capital and operating costs to implement increased security for their information technology systems, transmission and distribution and generation facilities, including nuclear power plants under the NRC’s design basis threat requirements. These increased costs could include additional physical plant security and security personnel or additional capability following a terrorist incident.

Cyberattacks and data security breaches could adversely affect the Duke Energy Registrants' businesses.

Information security risks have generally increased in recent years as a result of the proliferation of new technologies and the increased sophistication and frequency of cyberattacks and data security breaches. The utility industry requires the continued operation of sophisticated information technology systems and network infrastructure, which are part of an interconnected regional grid. Additionally, connectivity to the Internet continues to increase through smart grid and other initiatives. Because of the critical nature of the infrastructure, increased connectivity to the Internet and technology systems’ inherent vulnerability to disability or failures due to hacking, viruses, acts of war or terrorism or other types of data security breaches, the Duke Energy Registrants face a heightened risk of cyberattack. In the event of such an attack, the Duke Energy Registrants could (i) have business operations disrupted, property damaged, customer information stolen and other private information accessed (ii) experience substantial loss of revenues, repair and restoration costs, implementation costs for additional security measures to avert future cyberattacks and other financial loss, and (iii) be subject to increased regulation, litigation and reputational damage.

Failure to attract and retain an appropriately qualified workforce could unfavorably impact the Duke Energy Registrants’ results of operations.

Certain events, such as an aging workforce, mismatch of skill set or complement to future needs, or unavailability of contract resources may lead to operating challenges and increased costs. The challenges include lack of resources, loss of knowledge base and the lengthy time required for skill development. In this case, costs, including costs for contractors to replace employees, productivity costs and safety costs, may rise. Failure to hire and adequately train replacement employees, including the transfer of significant internal historical knowledge and expertise to new employees, or future availability and cost of contract labor may adversely affect the ability to manage and operate the business, especially considering the workforce needs associated with nuclear generation facilities. If the Duke Energy Registrants are unable to successfully attract and retain an appropriately qualified workforce, their financial position or results of operations could be negatively affected.

Duke Energy’s investments and projects located outside of the U.S. expose it to risks related to fluctuations in currency rates. These risks, and Duke Energy’s activities to mitigate such risks, may adversely affect its cash flows and results of operations.

Duke Energy’s operations and investments outside the U.S. expose it to risks related to fluctuations in currency rates. As each local currency’s value changes relative to the U.S. dollar, the value in U.S. dollars of Duke Energy’s assets and liabilities in such locality and the cash flows generated in such locality, expressed in U.S. dollars, also change. Duke Energy’s primary foreign currency rate exposure is to the Brazilian Real.

Duke Energy selectively mitigates some risks associated with foreign currency fluctuations by, among other things, indexing contracts to the U.S. dollar and/or local inflation rates, hedging through debt denominated or issued in the foreign currency and hedging through foreign currency derivatives. These efforts, however, may not be effective and, in some cases, may expose Duke Energy to other risks that could negatively affect its cash flows and results of operations.

The costs of retiring Duke Energy Florida’s Crystal River Unit 3 could prove to be more extensive than is currently identified.

Costs to retire and decommission the plant could exceed estimates and, if not recoverable through the regulatory process, could adversely affect Duke Energy’s, Progress Energy’s and Duke Energy Florida’s financial condition, results of operations and cash flows.

Duke Energy Ohio’s and Duke Energy Indiana’s membership in an RTO presents risks that could have a material adverse effect on their results of operations, financial condition and cash flows.

The rules governing the various regional power markets may change, which could affect Duke Energy Ohio’s and Duke Energy Indiana’s costs and/or revenues. To the degree Duke Energy Ohio and Duke Energy Indiana incur significant additional fees and increased costs to participate in an RTO, their results of operations may be impacted. Duke Energy Ohio and Duke Energy Indiana may be allocated a portion of the cost of transmission facilities built by others due to changes in RTO transmission rate design. Duke Energy Ohio and Duke Energy Indiana may be required to expand their transmission system according to decisions made by an RTO rather than their own internal planning process. While RTO transmission rates were initially designed to be revenue neutral, various proposals and proceedings currently taking place by the FERC may cause transmission rates to change from time to time. In addition, RTOs have been developing rules associated with the allocation and methodology of assigning costs associated with improved transmission reliability, reduced transmission congestion and firm transmission rights that may have a financial impact on Duke Energy Ohio and Duke Energy Indiana.

As members of an RTO, Duke Energy Ohio and Duke Energy Indiana are subject to certain additional risks, including those associated with the allocation among RTO members, of losses caused by unreimbursed defaults of other participants in the RTO markets and those associated with complaint cases filed against an RTO that may seek refunds of revenues previously earned by RTO members.

Nuclear Generation Risks

Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida may incur substantial costs and liabilities due to their ownership and operation of nuclear generating facilities.

23

PART I

Ownership interest in and operation of nuclear stations by Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida subject them to various risks. These risks include, among other things: the potential harmful effects on the environment and human health resulting from the operation of nuclear facilities and the storage, handling and disposal of radioactive materials; limitations on the amounts and types of insurance commercially available to cover losses that might arise in connection with nuclear operations; and uncertainties with respect to the technological and financial aspects of decommissioning nuclear plants at the end of their licensed lives.

Ownership and operation of nuclear generation facilities requires compliance with licensing and safety-related requirements imposed by the NRC. In the event of non-compliance, the NRC may increase regulatory oversight, impose fines, and/or shut down a unit, depending upon its assessment of the severity of the situation. Revised security and safety requirements promulgated by the NRC, which could be prompted by, among other things, events within or outside of the control of Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, such as a serious nuclear incident at a facility owned by a third party, could necessitate substantial capital and other expenditures, as well as assessments to cover third-party losses. In addition, if a serious nuclear incident were to occur, it could have a material adverse effect on the results of operations and financial condition and reputation of Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida.

Liquidity, Capital Requirements and Common Stock Risks

The Duke Energy Registrants rely on access to short-term borrowings and longer-term capital markets to finance their capital requirements and support their liquidity needs. Access to those markets can be adversely affected by a number of conditions, many of which are beyond the Duke Energy Registrants’ control.

The Duke Energy Registrants’ businesses are financed to a large degree through debt. The maturity and repayment profile of debt used to finance investments often does not correlate to cash flows from their assets. Accordingly, as a source of liquidity for capital requirements not satisfied by the cash flow from their operations and to fund investments originally financed through debt instruments with disparate maturities, the Duke Energy Registrants rely on access to short-term money markets as well as longer-term capital markets. The Subsidiary Registrants also rely on access to short-term intercompany borrowings. If the Duke Energy Registrants are not able to access capital at competitive rates or at all, the ability to finance their operations and implement their strategy and business plan as scheduled could be adversely affected. An inability to access capital may limit the Duke Energy Registrants’ ability to pursue improvements or acquisitions that they may otherwise rely on for future growth.

Market disruptions may increase the cost of borrowing or adversely affect the ability to access one or more financial markets. Such disruptions could include: economic downturns, the bankruptcy of an unrelated energy company, capital market conditions generally, market prices for electricity and gas, actual or threatened terrorist attacks, or the overall health of the energy industry. The availability of credit under Duke Energy’s Master Credit Facility depends upon the ability of the banks providing commitments under the facility to provide funds when their obligations to do so arise. Systematic risk of the banking system and the financial markets could prevent a bank from meeting its obligations under the facility agreement.

Duke Energy maintains a revolving credit facility to provide backup for its commercial paper program and letters of credit to support variable rate demand tax-exempt bonds that may be put to the Duke Energy Registrant issuer at the option of the holder. The facility includes borrowing sublimits for the Duke Energy Registrants, each of whom is a party to the credit facility, and financial covenants that limit the amount of debt that can be outstanding as a percentage of the total capital for the specific entity. Failure to maintain these covenants at a particular entity could preclude Duke Energy from issuing commercial paper or the Duke Energy Registrants from issuing letters of credit or borrowing under the Master Credit Facility.

The Duke Energy Registrants must meet credit quality standards and there is no assurance they will maintain investment grade credit ratings. If the Duke Energy Registrants are unable to maintain investment grade credit ratings, they would be required under credit agreements to provide collateral in the form of letters of credit or cash, which may materially adversely affect their liquidity.

Each of the Duke Energy Registrants’ senior long-term debt issuances is currently rated investment grade by various rating agencies. The Duke Energy Registrants cannot ensure their senior long-term debt will be rated investment grade in the future.

If the rating agencies were to rate the Duke Energy Registrants below investment grade, borrowing costs would increase, perhaps significantly. In addition, the potential pool of investors and funding sources would likely decrease. Further, if the short-term debt rating were to fall, access to the commercial paper market could be significantly limited. A reduction in liquidity and borrowing availability could ultimately impact the ability to indefinitely reinvest prospective undistributed earnings generated by Duke Energy’s foreign subsidiaries, which could result in significant income taxes that would have a material effect on its results of operations.

A downgrade below investment grade could also require the posting of additional collateral in the form of letters of credit or cash under various credit, commodity and capacity agreements and trigger termination clauses in some interest rate derivative agreements, which would require cash payments. All of these events would likely reduce the Duke Energy Registrants’ liquidity and profitability and could have a material effect on their financial position, results of operations or cash flows.

Non-compliance with debt covenants or conditions could adversely affect the Duke Energy Registrants’ ability to execute future borrowings.

The Duke Energy Registrants’ debt and credit agreements contain various financial and other covenants. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements.

24

PART I

Market performance and other changes may decrease the value of the NDTF investments of Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, which then could require significant additional funding.

Ownership and operation of nuclear generation facilities also requires the maintenance of funded trusts that are intended to pay for the decommissioning costs of the respective nuclear power plants. The performance of the capital markets affects the values of the assets held in trust to satisfy these future obligations. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida have significant obligations in this area and hold significant assets in these trusts. These assets are subject to market fluctuations and will yield uncertain returns, which may fall below projected rates of return. Although a number of factors impact funding requirements, a decline in the market value of the assets may increase the funding requirements of the obligations for decommissioning nuclear plants. If Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida are unable to successfully manage their NDTF assets, their financial condition, results of operations and cash flows could be negatively affected.

Poor investment performance of the Duke Energy pension plan holdings and other factors impacting pension plan costs could unfavorably impact the Duke Energy Registrants’ liquidity and results of operations.

The costs of providing non-contributory defined benefit pension plans are dependent upon a number of factors, such as the rates of return on plan assets, discount rates, the level of interest rates used to measure the required minimum funding levels of the plans, future government regulation and required or voluntary contributions made to the plans. The Subsidiary Registrants are allocated their proportionate share of the cost and obligations related to these plans. Without sustained growth in the pension investments over time to increase the value of plan assets and, depending upon the other factors impacting costs as listed above, Duke Energy could be required to fund its plans with significant amounts of cash. Such cash funding obligations, and the Subsidiary Registrants’ proportionate share of such cash funding obligations, could have a material impact on the Duke Energy Registrants’ financial position, results of operations or cash flows.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

25

PART I

ITEM 2. PROPERTIES

REGULATED UTILITIES

The following table provides information related to Regulated Utilities' electric generation stations as of December 31, 2014. The MW displayed in the table below are based on summer capacity.

Facility	Plant Type	Primary Fuel	Location	Total MW Capacity	Owned MW Capacity	Ownership Interest
Duke Energy Carolinas
Oconee	Nuclear	Uranium	SC	2,554	2,554	100
Catawba(a)	Nuclear	Uranium	SC	2,290	441	19.25
McGuire	Nuclear	Uranium	NC	2,278	2,278	100
Belews Creek	Fossil Steam	Coal	NC	2,220	2,220	100
Marshall	Fossil Steam	Coal	NC	2,078	2,078	100
J.E. Rogers	Fossil Steam	Coal	NC	1,396	1,396	100
Bad Creek	Hydro	Water	SC	1,360	1,360	100
Lincoln	Combustion Turbine	Gas / Oil	NC	1,267	1,267	100
Allen	Fossil Steam	Coal	NC	1,127	1,127	100
Rockingham	Combustion Turbine	Gas / Oil	NC	825	825	100
Jocassee	Hydro	Water	SC	780	780	100
Dan River	Combined Cycle	Gas	NC	637	637	100
Buck	Combined Cycle	Gas	NC	631	631	100
Mill Creek	Combustion Turbine	Gas / Oil	SC	596	596	100
Cowans Ford	Hydro	Water	NC	325	325	100
W.S. Lee	Fossil Steam	Coal	SC	170	170	100
Keowee	Hydro	Water	SC	152	152	100
W.S. Lee	Combustion Turbine	Gas / Oil	SC	82	82	100
Distributed generation	Renewable	Solar	NC	4	4	100
Other small hydro (25 plants)	Hydro	Water	NC / SC	666	666	100
Total Duke Energy Carolinas				21,438	19,589
Duke Energy Progress
Roxboro(b) (c)	Fossil Steam	Coal	NC	2,433	2,343	96.30
Brunswick(c)	Nuclear	Uranium	NC	1,870	1,527	81.67
Smith	Combined Cycle	Gas / Oil	NC	1,088	1,088	100
Harris(c)	Nuclear	Uranium	NC	928	778	83.83
H.F. Lee	Combined Cycle	Gas / Oil	NC	916	916	100
Wayne County	Combustion Turbine	Gas / Oil	NC	863	863	100
Darlington	Combustion Turbine	Gas / Oil	SC	787	787	100
Smith	Combustion Turbine	Gas / Oil	NC	784	784	100
Robinson	Nuclear	Uranium	SC	741	741	100
Mayo(c)	Fossil Steam	Coal	NC	727	609	83.83
L.V. Sutton	Combined Cycle	Gas / Oil	NC	622	622	100
Asheville	Fossil Steam	Coal	NC	376	376	100
Asheville	Combustion Turbine	Gas / Oil	NC	324	324	100
Weatherspoon	Combustion Turbine	Gas / Oil	NC	128	128	100
Walters	Hydro	Water	NC	112	112	100
L.V. Sutton	Combustion Turbine	Gas / Oil	NC	61	61	100
Blewett	Combustion Turbine	Oil	NC	52	52	100
Other small hydro (3 plants)	Hydro	Water	NC	110	110	100
Total Duke Energy Progress				12,922	12,221
Duke Energy Florida
Crystal River	Fossil Steam	Coal	FL	2,291	2,291	100
Hines	Combined Cycle	Gas / Oil	FL	1,912	1,912	100
Bartow	Combined Cycle	Gas / Oil	FL	1,074	1,074	100
Anclote	Fossil Steam	Gas	FL	991	991	100
Intercession City(d)	Combustion Turbine	Gas / Oil	FL	986	986	(d)
DeBary	Combustion Turbine	Gas / Oil	FL	637	637	100
Tiger Bay	Combined Cycle	Gas / Oil	FL	205	205	100

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PART I

Facility	Plant Type	Primary Fuel	Location	Total MW Capacity	Owned MW Capacity	Ownership Interest
Bartow	Combustion Turbine	Gas / Oil	FL	177	177	100
Bayboro	Combustion Turbine	Oil	FL	174	174	100
Suwannee River	Combustion Turbine	Gas	FL	155	155	100
Turner	Combustion Turbine	Oil	FL	131	131	100
Suwannee River	Fossil Steam	Gas / Oil	FL	128	128	100
Higgins	Combustion Turbine	Gas / Oil	FL	105	105	100
Avon Park	Combustion Turbine	Gas / Oil	FL	48	48	100
University of Florida Cogeneration	Combustion Turbine	Gas	FL	46	46	100
Rio Pinar	Combustion Turbine	Oil	FL	12	12	100
Total Duke Energy Florida				9,072	9,072
Duke Energy Ohio
East Bend	Fossil Steam	Coal	KY	600	600	100
Woodsdale	Combustion Turbine	Gas / Propane	OH	462	462	100
Miami Fort (Unit 6)	Fossil Steam	Coal	OH	163	163	100
Total Duke Energy Ohio				1,225	1,225
Duke Energy Indiana
Gibson(e)	Fossil Steam	Coal	IN	3,132	2,822	90.10
Cayuga(f)	Fossil Steam	Coal / Oil	IN	1,005	1,005	100
Wabash River(g)	Fossil Steam	Coal / Oil	IN	676	676	100
Edwardsport	Fossil Steam	Coal	IN	595	595	100
Madison	Combustion Turbine	Gas	OH	576	576	100
Vermillion(h)	Combustion Turbine	Gas	IN	568	355	62.50
Wheatland	Combustion Turbine	Gas	IN	460	460	100
Noblesville	Combined Cycle	Gas / Oil	IN	285	285	100
Gallagher	Fossil Steam	Coal	IN	280	280	100
Henry County	Combustion Turbine	Gas / Oil	IN	129	129	100
Cayuga	Combustion Turbine	Gas / Oil	IN	99	99	100
Connersville	Combustion Turbine	Oil	IN	86	86	100
Miami Wabash	Combustion Turbine	Oil	IN	80	80	100
Markland	Hydro	Water	IN	45	45	100
Total Duke Energy Indiana				8,016	7,493
Total Regulated Utilities				52,673	49,600
Totals By Plant Type
Nuclear				10,661	8,319
Fossil Steam				20,388	19,870
Combined Cycle				7,370	7,370
Combustion Turbine				10,700	10,487
Hydro				3,550	3,550
Renewable				4	4
Total Regulated Utilities				52,673	49,600

(a) Jointly owned with North Carolina Municipal Power Agency Number 1, North Carolina Electric Membership Corporation and Piedmont Municipal Power Agency.

(b) Duke Energy Progress owns and operates Roxboro Station Units 1-3 and owns 87.06 percent of, and operates, Unit 4.

(c) Jointly owned with North Carolina Eastern Municipal Power Agency (NCEMPA). Duke Energy Progress executed an agreement in September 2014 to purchase NCEMPA's ownership interest in these facilities. For additional information see Note 2 to the Consolidated Financial Statements, "Acquisitions, Dispositions and Sales of Other Assets."

(d) Duke Energy Florida owns and operates Intercession City Station Units 1-10 and 12-14. Unit 11 is jointly owned with Georgia Power Company (GPC). GPC has the exclusive right to the output of this unit during the months of June through September. Duke Energy Florida has the exclusive right to the output of this unit for the remainder of the year.

(e) Duke Energy Indiana owns and operates Gibson Station Units 1-4 and owns 50.05 percent of, and operates, Unit 5. Unit 5 is jointly owned with Wabash Valley Power Association, Inc. and Indiana Municipal Power Agency.

(f) Includes Cayuga Internal Combustion (IC).

(g) Includes Wabash River IC.

(h) Jointly owned with Wabash Valley Power Association.

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PART I

The following table provides information related to Regulated Utilities' electric transmission and distribution properties as of December 31, 2014.

	Duke Energy Carolinas	Duke Energy Progress	Duke Energy Florida	Duke Energy Ohio	Duke Energy Indiana	Total Regulated Utilities
Electric Transmission Lines
Miles of 500 to 525 Kilovolt (kV)	600	300	200	—	—	1,100
Miles of 345 kV	—	—	—	1,000	700	1,700
Miles of 230 kV	2,600	3,400	1,700	—	700	8,400
Miles of 100 to 161 kV	6,800	2,600	1,000	700	1,400	12,500
Miles of 13 to 69 kV	3,100	—	2,300	800	2,500	8,700
Total conductor miles of electric transmission lines	13,100	6,300	5,200	2,500	5,300	32,400
Electric Distribution Lines
Miles of overhead lines	66,600	44,600	24,100	13,800	22,500	171,600
Miles of underground line	36,000	23,400	17,700	5,700	8,500	91,300
Total conductor miles of electric distribution lines	102,600	68,000	41,800	19,500	31,000	262,900
Number of electric transmission and distribution substations	1,500	500	500	300	500	3,300
Miles of gas mains	—	—	—	7,200	—	7,200
Miles of gas service lines	—	—	—	6,200	—	6,200

Substantially all of Regulated Utilities' electric plant in service is mortgaged under indentures relating to Duke Energy Carolinas’, Duke Energy Progress', Duke Energy Florida's, Duke Energy Ohio’s and Duke Energy Indiana’s various series of First Mortgage Bonds.

INTERNATIONAL ENERGY

The following table provides additional information related to International Energy’s electric generation stations as of December 31, 2014. The MW displayed in the table below are based on summer capacity.

Facility	Primary Fuel	Location	Total MW Capacity	Owned MW Capacity	Ownership Interest
DEI Brazil(a)	Water	Brazil	2,274	2,089	92
Egenor	Water	Peru	357	357	100
Cerros Colorados	Water / Gas	Argentina	576	524	91
DEI Chile	Water / Diesel	Chile	362	362	100
DEI El Salvador	Oil / Diesel	El Salvador	324	293	90
DEI Guatemala	Oil / Diesel / Coal	Guatemala	361	361	100
Electroquil	Diesel	Ecuador	192	163	85
Aguaytia	Gas	Peru	192	192	100
Total International Energy			4,638	4,341

(a) Includes Canoas I and II, which are jointly owned with Companhia Brasileira de Aluminio, as well as the wholly owned Palmeiras and Retiro small hydro plants.

International Energy also owns a 25 percent equity interest in NMC. In 2014, NMC produced approximately 921,000 metric tons of methanol and approximately 1.1 million metric tons of MTBE. Approximately 40 percent of methanol is normally used in the MTBE production.

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PART I

COMMERCIAL POWER

The following table provides information related to Commercial Power’s electric generation facilities as of December 31, 2014. The MW displayed in the table below are based on summer capacity.

Facility	Plant Type	Primary Fuel	Location	Total MW Capacity	Owned MW Capacity	Ownership Interest
Duke Energy Renewables
Los Vientos Windpower	Renewable	Wind	TX	402	402	100
Top of the World	Renewable	Wind	WY	200	200	100
Notrees	Renewable	Wind	TX	153	153	100
Campbell Hill	Renewable	Wind	WY	99	99	100
North Allegheny	Renewable	Wind	PA	70	70	100
Laurel Hill Wind Energy	Renewable	Wind	PA	69	69	100
Ocotillo	Renewable	Wind	TX	59	59	100
Kit Carson	Renewable	Wind	CO	51	51	100
Silver Sage	Renewable	Wind	WY	42	42	100
Happy Jack	Renewable	Wind	WY	29	29	100
Shirley	Renewable	Wind	WI	20	20	100
Highlander	Renewable	Solar	CA	21	21	100
Dogwood	Renewable	Solar	NC	20	20	100
Halifax Airport	Renewable	Solar	NC	20	20	100
Colonial Eagle - Pasquotank	Renewable	Solar	NC	20	20	100
Bagdad	Renewable	Solar	AZ	15	15	100
TX Solar	Renewable	Solar	TX	14	14	100
Washington White Post	Renewable	Solar	NC	12	12	100
Other small solar	Renewable	Solar	Various	54	54	100
Total Duke Energy Renewables				1,370	1,370
Duke Energy Ohio
Stuart(a)(b)	Fossil Steam	Coal	OH	2,308	900	39
Zimmer(a)	Fossil Steam	Coal	OH	1,300	605	46.5
Hanging Rock	Combined Cycle	Gas	OH	1,226	1,226	100
Miami Fort (Units 7 and 8)(a)	Fossil Steam	Coal	OH	1,020	652	64
Conesville(a)(b)	Fossil Steam	Coal	OH	780	312	40
Washington	Combined Cycle	Gas	OH	617	617	100
Fayette	Combined Cycle	Gas	PA	614	614	100
Killen(a)(b)	Fossil Steam	Coal	OH	600	198	33
Lee	Combustion Turbine	Gas	IL	568	568	100
Dick's Creek	Combustion Turbine	Gas	OH	136	136	100
Miami Fort	Combustion Turbine	Oil	OH	56	56	100
Total Duke Energy Ohio(c)				9,225	5,884
Totals By Facility Type
Renewable - Wind				1,194	1,194
Renewable - Solar				176	176
Fossil Steam				6,008	2,667
Combined Cycle				2,457	2,457
Combustion Turbine				760	760
Total Commercial Power				10,595	7,254

(a) Jointly owned with American Electric Power Generation Resources and/or The Dayton Power & Light Company.

(b) Facility operated by Duke Energy Ohio

(c) Duke Energy Ohio facilities are included in the Disposal Group as of December 31, 2014.

In addition to the above facilities, Commercial Power owns an equity interest in the 585 MW capacity Sweetwater wind projects located in Texas, the 299 MW capacity DS Cornerstone wind projects located in Kansas and the 17 MW capacity INDU Solar Holding Joint Venture. Commercial Power's ownership share is 442 MW of capacity in these projects.

OTHER

Duke Energy owns approximately 5.2 million square feet and leases 2.9 million square feet of corporate, regional and district office space spread throughout its service territories and in Houston, Texas.

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PART I

ITEM 3. LEGAL PROCEEDINGS

For information regarding legal proceedings, including regulatory and environmental matters, see Note 4 to the Consolidated Financial Statements, “Regulatory Matters” and Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies - Litigation” and “Commitments and Contingencies - Environmental.”

Virginia Department of Environmental Quality Civil Enforcement

Duke Energy Carolinas and the Virginia Department of Environmental Quality are in negotiations regarding civil enforcement against Duke Energy Carolinas related to the February 2, 2014, coal ash release from Duke Energy Carolinas’ Dan River Steam Station. Monetary sanctions in excess of $100,000 appear likely.

Brazilian Transmission Fee Assessments

On July 16, 2008, Duke Energy International Geracao Paranapanema S.A. (DEIGP) filed a lawsuit in the Brazilian federal court challenging transmission fee assessments imposed under two new resolutions promulgated by the Brazilian electricity regulatory agency (ANEEL) (collectively, the Resolutions). The Resolutions purport to impose additional transmission fees on generation companies located in the State of Sao Paulo for utilization of the electric transmission system. The fees were retroactive to July 1, 2004, and effective through June 30, 2009. DEIGP's original assessment under these Resolutions amounts to approximately $56 million inclusive of interest through December 2014. Pending resolution of this dispute on the merits, DEIGP deposited the disputed portion, approximately $19 million, of the assessment into a court-monitored escrow, and paid the undisputed portion to the distribution companies. In a decision published on October 2, 2013, the trial court affirmed an additional fine imposed by ANEEL in the amount of $9 million for DEIGP’s failure to pay the disputed portion of the assessment. The $9 million was also deposited into a court-monitored escrow. In December 2014, the trial court ruled in favor of DEIGP on the merits of the original assessment. The merits of the original assessment and fine, as well as the contradiction between the trial court's ruling in favor of DEIGP on the original assessment but against DEIGP on its alleged failure to timely pay that assessment, will be addressed on appeal.

Brazilian Regulatory Citations

In September 2007, the State Environmental Agency of Parana (IAP) assessed seven fines against DEIGP, totaling $15 million for failure to comply with reforestation measures allegedly required by state regulations in Brazil. DEIGP has challenged the fines in administrative and judicial proceedings. Two of the seven fines have subsequently been dismissed or otherwise resolved in favor of DEIGP. A third fine was determined legitimate by the trial court, but is under appeal. The remaining fines are pending.

Additionally, DEIGP was assessed three fines by Brazil Institute of Environment and Renewable Natural Resources (IBAMA) for improper maintenance of existing reforested areas. One of these fines was determined legitimate by the trial court and is under appeal. The others are pending. The total current IBAMA assessment is approximately $500,000. DEIGP believes that it has properly maintained all reforested areas and has challenged the IBAMA assessments.

Gibson Notice of Violations

Pursuant to Notices of Violation dated June 23, 2011 and July 16, 2013, the EPA has asserted that, on several occasions between August 1, 2008 through March 31, 2013, Duke Energy Indiana’s Gibson steam station violated opacity limits contained in its Title V permit. Duke Energy Indiana entered into a settlement agreement with the EPA in the fourth quarter of 2014, which required payment of a civil penalty of $199,000.

ITEM 4. MINE SAFETY DISCLOSURES

This is not applicable for any of the Duke Energy Registrants.

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PART II

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

Duke Energy's common stock is listed for trading on the New York Stock Exchange (NYSE) (ticker symbol DUK). As of February 24, 2015, there were approximately 172,448 common stockholders of record.

Common Stock Data by Quarter

	2014					2013
		Stock Price Range(a)					Stock Price Range(a)
	Dividends Declared Per Share	High		Low		Dividends Declared Per Share	High		Low
First Quarter	0.780	$	72.67	$	67.05	0.765	$	72.68	$	64.44
Second Quarter(b)	0.780	75.13		68.81		1.545	75.46		64.62
Third Quarter	0.795	75.21		69.48		―	72.01		64.16
Fourth Quarter	0.795	87.29		74.33		0.780	73.53		66.05

(a) Stock prices represent the intra-day high and low stock price.

(b) Two dividends were declared in the second quarter of 2013. The first was $0.765 per share and the second was $0.78 per share. 

Duke Energy expects to continue its policy of paying regular cash dividends; however, there is no assurance as to the amount of future dividends as they depend on future earnings, capital requirements, and financial condition, and are subject to declaration by the Duke Energy Board of Directors.

Duke Energy’s operating subsidiaries have certain restrictions on their ability to transfer funds in the form of dividends or loans to Duke Energy. See Note 4 to the Consolidated Financial Statements, “Regulatory Matters” for further information regarding these restrictions.

Securities Authorized for Issuance Under Equity Compensation Plans

Duke Energy will provide information that is responsive to this Item 5 in its definitive proxy statement or in an amendment to this Annual Report not later than 120 days after the end of the fiscal year covered by this Annual Report, in either case under the caption “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters,” and possibly elsewhere therein. That information is incorporated in this Item 5 by reference.

Issuer Purchases of Equity Securities for Fourth Quarter of 2014

There were no repurchases of equity securities during the fourth quarter of 2014.

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PART II

Stock Performance Graph

The performance graph below illustrates a five year comparison of cumulative total returns of Duke Energy Corporation common stock, as compared with the S&P 500 Stock Index and the Philadelphia Utility Index for the five-year period 2009 through 2014.

This performance graph assumes an initial investment of $100 invested on December 31, 2009, in Duke Energy common stock, in the S&P 500 Stock Index and in the Philadelphia Utility Index and that all dividends are reinvested.

NYSE CEO Certification

Duke Energy has filed the certification of its Chief Executive Officer and Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 as exhibits to this Annual Report on Form 10-K for the year ended December 31, 2014.

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PART II

ITEM 6. SELECTED FINANCIAL DATA

(in millions, except per share amounts)	2014(c)			2013(c)		2012(c)		2011(c)		2010(c)
Statement of Operations(a)
Total operating revenues	$	23,925		$	22,756	$	17,912	$	12,412	$	12,220
Operating Income	5,258			4,854		2,911		2,475		2,444
Income From Continuing Operations	2,465			2,590		1,611		1,508		1,481
(Loss) Income From Discontinued Operations, net of tax	(576		)	86		171		206		(157		)
Net Income	1,889			2,676		1,782		1,714		1,324
Net Income Attributable to Duke Energy Corporation	1,883			2,665		1,768		1,706		1,320
Common Stock Data
Income from continuing operations attributable to Duke Energy Corporation common shareholders(b)
Basic	$	3.46		$	3.64	$	2.77	$	3.34	$	3.34
Diluted	3.46			3.63		2.77		3.34		3.33
(Loss) Income from discontinued operations attributable to Duke Energy Corporation common shareholders
Basic	$	(0.80	)	$	0.13	$	0.30	$	0.49	$	(0.34	)
Diluted	(0.80		)	0.13		0.30		0.49		(0.33		)
Net Income attributable to Duke Energy Corporation common shareholders(b)
Basic	$	2.66		$	3.77	$	3.07	$	3.83	$	3.00
Diluted	2.66			3.76		3.07		3.83		3.00
Dividends declared per common share(b)	3.15			3.09		3.03		2.97		2.91
Balance Sheet
Total Assets	$	120,709		$	114,779	$	113,856	$	62,526	$	59,090
Long-term Debt including capital leases and redeemable preferred stock of subsidiaries, less current maturities	37,213			38,152		36,444		18,679		17,935

(a) Significant transactions reflected in the results above include: (i) 2014 impairment of the Disposal Group (see Note 2 to the Consolidated Financial Statements, "Acquisitions, Dispositions and Sales of Other Assets"); (ii) 2014 incremental tax expense resulting from the decision to repatriate all cumulative historical undistributed foreign earnings (see Note 22 to the Consolidated Financial Statements, "Income Taxes"); (iii) 2014 increase in the litigation reserve related to the criminal investigation of the Dan River coal ash spill (see Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies”); (iv) 2013 charges related to Crystal River Unit 3 and nuclear development costs (see Notes 4 and 25 to the Consolidated Financial Statements, "Regulatory Matters" and "Quarterly Financial Data", respectively); (v) the 2012 merger with Progress Energy (see Note 2 to the Consolidated Financial Statements, "Acquisitions, Dispositions and Sales of Other Assets"); (vi) 2012 and 2011 pretax impairment and other charges related to the Edwardsport Integrated Gasification Combined Cycle (IGCC) project of $628 million and $222 million, respectively; and (vii) 2010 pretax impairment of goodwill and other assets of $660 million. 

(b) On July 2, 2012, immediately prior to the merger with Progress Energy, Duke Energy executed a one-for-three reverse stock split. All share and earnings per share amounts are presented as if the one-for-three reverse stock split had been effective at the beginning of the earliest period presented.

(c) Operating results reflect reclassifications due to the impact of discontinued operations (see Note 2 to the Consolidated Financial Statements, "Acquisitions, Dispositions and Sales of Other Assets").

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ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management’s Discussion and Analysis includes financial information prepared in accordance with generally accepted accounting principles (GAAP) in the United States (U.S.), as well as certain non-GAAP financial measures such as adjusted earnings, adjusted earnings per share and adjusted segment income, 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. The 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 as presented herein may not be comparable to similarly titled measures used by other companies.

The following combined Management’s Discussion and Analysis of Financial Condition and Results of Operations is separately filed by Duke Energy Corporation (collectively with its subsidiaries, Duke Energy) and its subsidiaries Duke Energy Carolinas, LLC (Duke Energy Carolinas), Progress Energy, Inc. (Progress Energy), Duke Energy Progress, Inc. (Duke Energy Progress), Duke Energy Florida, Inc. (Duke Energy Florida), Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, Inc. (Duke Energy Indiana) (collectively referred to as the Subsidiary Registrants). However, none of the registrants makes any representation as to information related solely to Duke Energy or the Subsidiary Registrants of Duke Energy other than itself.

DUKE ENERGY

Duke Energy is an energy company headquartered in Charlotte, North Carolina. Duke Energy operates in the U.S. primarily through its wholly owned subsidiaries, Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, as well as in Latin America.

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 Consolidated Financial Statements and Notes for the years ended December 31, 2014, 2013 and 2012.

Executive Overview

Merger with Progress Energy

On July 2, 2012, Duke Energy merged with Progress Energy, with Duke Energy continuing as the surviving corporation, and Progress Energy becoming a wholly owned subsidiary of Duke Energy. Duke Energy Progress and Duke Energy Florida, Progress Energy’s regulated utility subsidiaries, are now indirect wholly owned subsidiaries of Duke Energy. Duke Energy’s consolidated financial statements include Progress Energy, Duke Energy Progress and Duke Energy Florida activity beginning July 2, 2012.

Immediately preceding the merger, Duke Energy completed a one-for-three reverse stock split with respect to the issued and outstanding shares of Duke Energy common stock. All share and per share amounts presented herein reflect the impact of the one-for-three reverse stock split.

For additional information on the details of this transaction including regulatory conditions and accounting implications, see Note 2 to the Consolidated Financial Statements, “Acquisitions, Dispositions and Sales of Other Assets.”

Disposition of the Nonregulated Midwest Generation Business

On August 21, 2014, Duke Energy entered into a purchase sale agreement (PSA) to sell its nonregulated Midwest generation business and Duke Energy Retail Sales LLC (Disposal Group) to Dynegy Inc. (Dynegy) for approximately $2.8 billion in cash subject to adjustments at closing for changes in working capital and capital expenditures. The completion of the transaction, conditioned on approval by Federal Energy Regulatory Commissions (FERC), is expected by the end of the second quarter of 2015.

For additional information on the details of this transaction including regulatory conditions and accounting implications, see Note 2 to the Consolidated Financial Statements, “Acquisitions, Dispositions and Sales of Other Assets.”

2014 Financial Results

The following table summarizes adjusted earnings and net income attributable to Duke Energy.

	Years Ended December 31,
	2014				2013				2012
(in millions, except per share amounts)	Amount		Per diluted share		Amount		Per diluted share		Amount		Per diluted share
Adjusted earnings(a)	$	3,218	$	4.55	$	3,080	$	4.36	$	2,489	$	4.33
Net income attributable to Duke Energy	1,883		2.66		2,665		3.76		1,768		3.07

(a) See Results of Operations below for Duke Energy’s definition of adjusted earnings and adjusted earnings per diluted share as well as a reconciliation of this non-GAAP financial measure to net income attributable to Duke Energy and net income attributable to Duke Energy per diluted share.

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Adjusted earnings increased from 2013 to 2014 primarily due to the impact of the revised rates and favorable weather, partially offset by higher depreciation and amortization expense. Adjusted earnings increased from 2012 to 2013 primarily due to the inclusion of a full year of Progress Energy results in 2013, the impact of the revised rates, net of higher depreciation and amortization expense and lower allowance for funds used during construction (AFUDC).

See “Results of Operations” below for a detailed discussion of the consolidated results of operations, as well as a detailed discussion of financial results for each of Duke Energy’s reportable business segments, as well as Other.

2014 Areas of Focus and Accomplishments

In 2014, Duke Energy focused on achieving financial objectives, completing important strategic initiatives, including the agreement to sell the non-regulated Midwest Generation business and completion of a strategic review of the international business, advancing a platform of growth initiatives, operational excellence, and the strengthening of coal ash management practices and plans to accelerate basin closure strategies resulting from the Dan River coal ash spill.

Sale of the Midwest Generation Business. In 2014, Duke Energy entered into a PSA to sell the Disposal Group to Dynegy for approximately $2.8 billion. This decision supports Duke Energy’s strategy to focus investments on businesses with more predictable and less volatile earnings.

International Energy Operations. Duke Energy completed the strategic review of the international operations. As a result of the review, Duke Energy determined it is in the shareholders’ best interest, at the present time, to continue to own, operate and create value through portfolio optimization and efficiency in the International operations. In addition, Duke Energy declared a taxable dividend of historical foreign earnings in the form of notes payable that will result in the repatriation of approximately $2.7 billion of cash held and expected to be generated by International Energy over a period of up to eight years. The cash will help support the dividend and growth in the investment portfolio of the domestic businesses.

Growth Initiatives. In 2014, Duke Energy announced new growth initiatives representing a total investment of approximately $8 billion. These initiatives include:

• Duke Energy Indiana proposed transmission and distribution infrastructure improvement totaling $1.9 billion.

• Duke Energy Florida proposed approximately $1.8 billion investment in three new generation projects, a combined-cycle plant in Citrus County, an uprate plan at the Hines Energy Complex (Hines) facility and acquisition of the Osprey plant from Calpine Corporation (Calpine).

• Duke Energy Progress proposed the acquisition of North Carolina Eastern Municipal Power Agency's (NCEMPA) ownership interest in some of Duke Energy Progress’s existing nuclear and coal generation and the acquisition of solar projects in eastern North Carolinas for a total amount of approximately $1.2 billion.

• Duke Energy Carolinas proposed construction of a combined-cycle natural gas plant at the William States Lee generation facility at a cost of approximately $600 million.

• Commercial Power proposed construction of the Atlantic Coast Pipeline for a total investment of approximately $2 billion

Operational Excellence of the Nuclear Fleet. Duke Energy’s nuclear fleet set a company record for total electricity production and demonstrated a combined capacity factor at approximately 93 percent, the 16th consecutive year above 90 percent on this plant reliability measure.

Deliver Merger Benefits. Duke Energy continues to focus on realizing benefits of the merger with Progress Energy. Duke Energy is on-track to achieve the $687 million of guaranteed savings for customers in the Carolinas over five years. After two and a half years, Duke Energy Carolinas and Duke Energy Progress have generated over 60 percent of the guaranteed fuel and joint dispatch savings. In total 85 percent of the guaranteed benefit has been locked-in or delivered to Duke Energy’s customers in the Carolinas.

Dan River Coal Ash Spill and Other Coal Ash Management. Duke Energy has improved coal ash practices and accelerated plans to close its ash basins. Comprehensive engineering reviews were completed at each of the ash basins, and a central internal organization was formed to manage all coal combustion products. Duke Energy also established an independent national Coal Ash Management Advisory Board to help guide company strategy. Excavation plans have been filed for four high priority sites identified in connection with North Carolina coal ash management enacted in 2014 - Dan River, Asheville, Riverbend, and L.V. Sutton combined cycle facility (Sutton). Excavation plans have also been filed for the W.S. Lee site in South Carolina, and work is progressing on closure plans for the other ten North Carolina sites.

On February 20, 2015, Duke Energy Carolinas, Duke Energy Progress and Duke Energy Business Services LLC (DEBS), a wholly owned subsidiary of Duke Energy, each entered into a Memorandum of Plea Agreement (Plea Agreements) in connection with an investigation initiated by the USDOJ. The Plea Agreements are subject to the approval of the United States District Court for the Eastern District of North Carolina and, if approved, will end the grand jury investigation related to the Dan River ash basin release and the management of coal ash basins at 14 plants in North Carolina with coal ash basins.

Under the Plea Agreements, the USDOJ charged DEBS and Duke Energy Progress with four misdemeanor CWA violations related to violations at Duke Energy Progress’ H.F. Lee Steam Electric Plant, Cape Fear Steam Electric Plant and Asheville Steam Electric Generating Plant. The United States Department Of Justice charged Duke Energy Carolinas and DEBS with five misdemeanor Clean Water Act violations related to violations at Duke Energy Carolinas’ Dan River Steam Station and Riverbend Steam Station. DEBS, Duke Energy Carolinas and Duke Energy Progress also agreed (i) to a five-year probation period, (ii) to pay a total of approximately $68 million in fines and restitution and $34 million for community service and mitigation (the Payments), and (iii) to establish environmental compliance plans subject to the oversight of a court-appointed monitor paid for by the companies for the duration of the probation period (iii) for Duke Energy Carolinas and Duke Energy Progress each to maintain $250 million under their Master Credit Facility as security to meet their obligations under the Pleas Agreements, in addition to certain other conditions set out in the Plea Agreements. Payments under the Plea Agreements will be borne by shareholders and are not tax deductible. Duke Energy Corporation has agreed to issue a guarantee of all payments and performance due from the Companies, including but not limited to payments for fines, restitution, community service, mitigation and the funding of, and obligations under, the environmental compliance plans. As a result of the Plea Agreements, Duke Energy Carolinas and Duke Energy Progress recognized charges of $72 million and $30 million, respectively, in the fourth quarter of 2014. The amounts are recorded in Operation, maintenance and other on the Consolidated Statements of Operations and Comprehensive Income.

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Duke Energy Objectives - 2015 and Beyond

Duke Energy is committed to creating value and trust, while transforming our energy future. Primary objectives for 2015 are:

• Growing and adapting the business and achieving financial objectives, including delivering on the 2015 adjusted diluted earnings per share (EPS) guidance range of $4.55 to $4.75, and advancing viable future growth opportunities for regulated and nonregulated businesses

• Excelling in safety, operational performance and environmental stewardship

• Developing and engaging employees, while strengthening leadership

• Improving the lives of our customers and the vitality of our communities

Complete the Sale of the Nonregulated Midwest Generation Business.In January 2015, FERC requested additional information regarding the proposed sale of the nonregulated Midwest Generation business. The parties to the transaction responded to FERC on February 6, 2015, and the comment period expired on February 23, 2015. FERC approval is the final regulatory approval required to close the transaction, which is expected by the end of the second quarter of 2015.

Proceeds from the sale are expected to be deployed to recapitalize Duke Energy in a balanced manner, with a combination of an accelerated share repurchase and reductions in holding company debt. However, this plan could change depending on circumstances at the time of closing.

Growth Initiatives. Duke Energy will continue to pursue regulatory, state and federal approval of the growth projects. These projects will support long-term adjusted earnings growth of four to six percent and support Duke Energy’s ability to continue providing its customers affordable, reliable energy from an increasingly diverse generation portfolio.

In the Regulated Utilities business, Duke Energy does not anticipate any significant base rate cases through 2017. Growth is expected to be supported by retail and wholesale load growth and significant investments. Duke Energy expects to invest between $4 billion and $5 billion annually in Regulated business growth projects. Many of these projects will be recovered through riders such as transmission and distribution expenditures in Indiana and Ohio, as well as the Crystal River 3 rider in Florida and energy efficiency riders in the Carolinas. The regulated wholesale business is expected to grow in 2015.

The Commercial Power renewables business is a significant component of the Duke Energy growth strategy. Renewable projects enable Duke Energy to respond to customer interest in clean tech while increasing diversity in the generation portfolio. The portfolio of wind and solar is expected to continue growing as between $1 billion and $2 billion is deployed over the next three years .Additionally, investments in the Atlantic Coast pipeline adds approximately $1 billion of capital spending through 2017.

Continue the Coal Ash Management Strategy. In December 2014, U.S. Environmental Protection Agency (EPA) finalized the Resource Conservation and Recovery Act (RCRA) related to coal combustion residuals (CCR) associated with the generation of electricity from coal. The rules classify coal ash as non-hazardous waste and provide guidelines related to the disposal of coal ash. Duke Energy will continue the compliance strategy with the North Carolina Coal Ash Management Act of 2014 (Coal Ash Act) and complete an evaluation of the provisions for this rule. Duke Energy will update ash management plans to comply with all state and federal regulations and begin excavation or other compliance work once plans and permits are approved.

Results of Operations

In this section, Duke Energy provides analysis and discussion of earnings and factors affecting earnings on both a GAAP and non-GAAP basis.

Management evaluates financial performance in part based on the non-GAAP financial measures, adjusted earnings and adjusted diluted EPS. These items are measured as income from continuing operations net of income (loss) attributable to noncontrolling interests, adjusted for the dollar and per share impact of mark-to-market impacts of economic hedges in the Commercial Power segment and special items including the operating results of the Disposal Group classified as discontinued operations for GAAP purposes. Special items represent certain charges and credits, which management believes will not be recurring on a regular basis, although it is reasonably possible such charges and credits could recur. As result of the agreement in August 2014 to sell the Disposal Group to Dynegy, the operating results of the Disposal Group are classified as discontinued operations, including a portion of the mark-to-market adjustments associated with derivative contracts. Management believes that including the operating results of the Disposal Group classified as discontinued operations better reflects its financial performance and therefore has included these results in adjusted earnings and adjusted diluted EPS. Derivative contracts are used in Duke Energy’s hedging of a portion of the economic value of its generation assets in the Commercial Power segment. The mark-to-market impact of derivative contracts is recognized in GAAP earnings immediately and, if associated with the Disposal Group, classified as discontinued operations, as such derivative contracts do not qualify for hedge accounting or regulatory treatment. The economic value of generation assets is subject to fluctuations in fair value due to market price volatility of input and output commodities (e.g., coal, electricity, natural gas). Economic hedging involves both purchases and sales of those input and output commodities related to generation assets. Operations of the generation assets are accounted for under the accrual method. Management believes excluding impacts of mark-to-market changes of the derivative contracts from adjusted earnings until settlement better matches the financial impacts of the derivative contract with the portion of economic value of the underlying hedged asset. Management believes the presentation of adjusted earnings and adjusted diluted EPS provides useful information to investors, as it provides them an additional relevant comparison of Duke Energy’s performance across periods. Management uses these non-GAAP financial measures for planning and forecasting and for reporting results to the Duke Energy Board of Directors (Board of Directors), employees, shareholders, analysts and investors concerning Duke Energy’s financial performance. Adjusted diluted EPS is also used as a basis for employee incentive bonuses. The most directly comparable GAAP measures for adjusted earnings and adjusted diluted EPS are Net Income Attributable to Duke Energy Corporation and Diluted EPS Attributable to Duke Energy Corporation common shareholders, which include the dollar and per share impact of special items, mark-to-market impacts of economic hedges in the Commercial Power segment and discontinued operations.

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Management evaluates segment performance based on segment income. Segment income is defined as income from continuing operations net of income (loss) attributable to noncontrolling interests. Segment income, as discussed below, includes intercompany revenues and expenses that are eliminated in the Consolidated Financial Statements. Management also uses adjusted segment income as a measure of historical and anticipated future segment performance. Adjusted segment income is a non-GAAP financial measure, as it is based upon segment income adjusted for the mark-to-market impacts of economic hedges in the Commercial Power segment and special items. Management believes the presentation of adjusted segment income as presented provides useful information to investors, as it provides them with an additional relevant comparison of a segment’s performance across periods. The most directly comparable GAAP measure for adjusted segment income is segment income, which represents segment income from continuing operations, including any special items and the mark-to-market impacts of economic hedges in the Commercial Power segment.

Duke Energy’s adjusted earnings, adjusted diluted EPS, and adjusted segment income may not be comparable to similarly titled measures of another company because other entities may not calculate the measures in the same manner.

See Note 3 to the Consolidated Financial Statements, “Business Segments,” for a discussion of Duke Energy’s segment structure.

Overview

The following table reconciles non-GAAP measures to the most directly comparable GAAP measure.

	Year Ended December 31, 2014
(in millions, except per share amounts)	Regulated Utilities			International Energy			Commercial Power			Total Reportable Segments			Other			Eliminations/ Discontinued Operations			Duke Energy			Per Diluted Share
Adjusted segment income/Adjusted earnings	$	2,897		$	428		$	109		$	3,434		$	(216	)	$	—		$	3,218		$	4.55
International tax adjustment	—			(373		)	—			$	(373	)	—			—			(373		)	(0.53		)
Costs to achieve Progress Energy merger	—			—			—			—			(127		)	—			(127		)	(0.18		)
Midwest generation operations	—			—			(114		)	(114		)	—			114			—			—
Coal ash Plea Agreements reserve	(102		)	—			—			(102		)	—			—			(102		)	(0.14		)
Asset impairment	—			—			(59		)	(59		)	—			—			(59		)	(0.08		)
Asset sales	—			—			—			—			9			—			9			0.01
Economic hedges (mark-to-market)	—			—			(6		)	(6		)	—			—			(6		)	(0.01		)
Discontinued operations	—			—			15			15			—			(692		)	(677		)	(0.96		)
Segment income (loss)/Net Income Attributable to Duke Energy Corporation	$	2,795		$	55		$	(55	)	$	2,795		$	(334	)	$	(578	)	$	1,883		$	2.66

	Year Ended December 31, 2013
(in millions, except per share amounts)	Regulated Utilities			International Energy		Commercial Power			Total Reportable Segments			Other			Eliminations/ Discontinued Operations		Duke Energy			Per Diluted Share
Adjusted segment income/Adjusted earnings	$	2,776		$	408	$	15		$	3,199		$	(119	)	$	—	$	3,080		$	4.36
Crystal River Unit 3 charges	(215		)	—		—			(215		)	—			—		(215		)	(0.31		)
Costs to achieve Progress Energy merger	—			—		—			—			(184		)	—		(184		)	(0.26		)
Midwest generation operations	—			—		(88		)	(88		)	14			74		—			—
Nuclear development charges	(57		)	—		—			(57		)	—			—		(57		)	(0.08		)
Litigation reserve	—			—		—			—			(14		)	—		(14		)	(0.02		)
Asset sales	—			—		(15		)	(15		)	65			—		50			0.07
Discontinued operations	—			—		—			—			—			5		5			—
Segment income (loss)/Net Income Attributable to Duke Energy Corporation	$	2,504		$	408	$	(88	)	$	2,824		$	(238	)	$	79	$	2,665		$	3.76

	Year Ended December 31, 2012
(in millions, except per share amounts)	Regulated Utilities			International Energy		Commercial Power			Total Reportable Segments			Other			Eliminations/ Discontinued Operations		Duke Energy			Per Diluted Share
Adjusted segment income/Adjusted earnings	$	2,086		$	439	$	93		$	2,618		$	(129	)	$	—	$	2,489		$	4.33
Edwardsport impairment and other charges	(402		)	—		—			(402		)	—			—		(402		)	(0.70		)
Costs to achieve Progress Energy merger	—			—		—			—			(397		)	—		(397		)	(0.70		)
Midwest generation operations	—			—		(149		)	(149		)	9			140		—			—
Economic hedges (mark-to-market)	—			—		(3		)	(3		)	—			—		(3		)	(0.01		)
Democratic National Convention Host Committee support	—			—		—			—			(6		)	—		(6		)	(0.01		)
Employee severance and office consolidation	60			—		—			60			—			—		60			0.11
Discontinued operations	—			—		—			—			—			27		27			0.05
Segment income (loss)/Net Income Attributable to Duke Energy Corporation	$	1,744		$	439	$	(59	)	$	2,124		$	(523	)	$	167	$	1,768		$	3.07

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The variance in adjusted earnings for the year ended December 31, 2014, compared to 2013, was primarily due to:

• Increased retail pricing and riders primarily resulting from the implementation of revised rates in most jurisdictions;

• Favorable weather in 2014 compared to 2013;

• Higher PJM capacity revenues for the nonregulated Midwest generation business due to higher prices; and

• Higher results of the renewables business due to higher production from the wind and solar portfolios, lower costs and additional renewables investments.

Partially offset by:

• Higher depreciation and amortization expense primarily due to higher depreciable asset base and lower reductions to cost of removal reserves;

• Higher operations and maintenance expense due to higher storm costs, the timing of fossil plant outages and the impact of nuclear outage cost levelization;

• Lower post in-service debt returns due to projects added to customer rates; and

• Higher property and other non-income taxes.

The variance in adjusted earnings for the year ended December 31, 2013, compared to 2012, was primarily due to:

• The inclusion of Progress Energy results for the first six months of 2013;

• Increased retail pricing and riders resulting primarily from the implementation of revised rates in all jurisdictions; and

• Lower operating and maintenance expense resulting primarily from the adoption of nuclear outage cost levelization in the Carolinas, lower benefit costs and merger synergies.

Partially offsetting these increases was:

• Higher depreciation and amortization expense;

• Lower AFUDC;

• Lower nonregulated Midwest gas generation results; and

• Incremental shares issued to complete the Progress Energy merger (impacts per diluted share amounts only).

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Segment Results

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

Regulated Utilities

	Years Ended December 31,
(in millions)	2014		2013		Variance 2014 vs. 2013			2012		Variance 2013 vs. 2012
Operating Revenues	$	22,271	$	20,910	$	1,361		$	16,080	$	4,830
Operating Expenses	17,026		16,126		900			12,943		3,183
Gains on Sales of Other Assets and Other, net	4		7		(3		)	15		(8		)
Operating Income	5,249		4,791		458			3,152		1,639
Other Income and Expense, net	267		221		46			341		(120		)
Interest Expense	1,093		986		107			806		180
Income Before Income Taxes	4,423		4,026		397			2,687		1,339
Income Tax Expense	1,628		1,522		106			941		581
Less: Income Attributable to Noncontrolling Interest	—		—		—			2		(2		)
Segment Income	$	2,795	$	2,504	$	291		$	1,744	$	760
Duke Energy Carolinas' GWh sales	87,645		85,790		1,855			81,362		4,428
Duke Energy Progress' GWh sales(a)	62,871		60,204		2,667			58,390		1,814
Duke Energy Florida GWh sales(b)	38,703		37,974		729			38,443		(469		)
Duke Energy Ohio GWh sales	24,735		24,557		178			24,344		213
Duke Energy Indiana GWh sales	33,433		33,715		(282		)	33,577		138
Total Regulated Utilities GWh sales	247,387		242,240		5,147			236,116		6,124
Net proportional MW capacity in operation	49,600		49,607		(7		)	49,654		(47		)

(a) For Duke Energy Progress, 26,634 Gigawatt-hours (GWh) sales for the year ended December 31, 2012, occurred prior to the merger between Duke Energy and Progress Energy.

(b) For Duke Energy Florida, 18,348 GWh sales for the year ended December 31, 2012, occurred prior to the merger between Duke Energy and Progress Energy.

Year Ended December 31, 2014 as Compared to 2013

Regulated Utilities’ results were positively impacted by higher retail pricing and rate riders, favorable weather, an increase in wholesale power margins, higher weather-normal sales volumes, and 2013 impairments and other charges. These impacts were partially offset by higher depreciation and amortization expense, higher operation and maintenance costs, higher interest expense, and higher income tax expense. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• A $614 million increase in fuel revenues driven primarily by increased demand from electric retail customers resulting from favorable weather conditions, and higher fuel rates for electric retail customers for all jurisdictions, except North Carolina. Fuel revenues represent sales to retail and wholesale customers;

• A $556 million net increase in retail pricing primarily due to retail rate changes and updated rate riders;

• A $216 million increase in electric sales (net of fuel revenue) to retail customers due to more favorable weather conditions. (i) For the year ended December 31, 2014 in the Carolinas, cooling degree days were 4 percent below normal as compared with 15 percent below normal during the same period in 2013, and heating degree days were 11 percent above normal as compared with 4 percent above normal during the same period in 2013. (ii) For the year ended December 31, 2014 in the Midwest, cooling degree days were 21 percent below normal as compared with 8 percent below normal during the same period in 2013, and heating degree days were 18 percent above normal as compared with 7 percent above normal during the same period in 2013. (iii) For the year ended December 31, 2014 in Florida, cooling degree days were 3 percent below normal as compared with 2 percent above normal during the same period in 2013, and heating degree days were 4 percent above normal as compared with 35 percent below normal during the same period in 2013;

• A $63 million increase in wholesale power revenues, net of sharing, primarily due to additional volumes and capacity charges for customers served under long-term contracts; and

• A $21 million increase in weather-normal sales volumes to retail customers (net of fuel revenue) reflecting increased demand.

Partially offset by:

• A $139 milliondecrease in gross receipts tax revenue due to the NC Tax Simplification and Rate Reduction Act which terminated the collection of the North Carolina gross receipts tax effective July 1, 2014.

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Operating Expenses. The variance was driven primarily by:

• A $611 million increase in fuel expense (including purchased power and natural gas purchases for resale) primarily related to (i) higher volumes of coal, and oilused in electric generation due primarily to increased generation resulting from favorable weather conditions, (ii) higher natural gasprices, and (iii) the application of the Nuclear Electric Insurance Limited (NEIL) settlement proceeds in 2013 for Duke Energy Florida;

• A $436 million increase in depreciation and amortization expense primarily due to increases in depreciation as a result of additional plant in service and amortization of regulatory assets, and higher 2013 reductions to cost of removal reserves in accordance with regulatory orders; and

• A $292 million increase in operating and maintenance expense primarily due to a litigation reserve related to the criminal investigation of the Dan River coal ash spill (See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information), higher storm costs, repairs and remediation expenses associated with the Dan River coal ash discharge and other ash basin related assessment costs, and higher nuclear costs, including nuclear outage levelization costs, and higher environmental and operational costs that are recoverable in rates; partially offset by a 2013 Crystal River Unit 3 Nuclear Station (Crystal River Unit 3) related settlement matter, decreased benefits costsand 2013 donations for low-income customers and job training in accordance with 2013 North Carolina Utilities Commission (NCUC) and Public Service Commission of South Carolina (PSCSC) rate case orders.

Partially offset by:

• A $346 million decrease due to the 2013 impairment and other charges primarily related to Crystal River Unit 3 and the proposed Levy Nuclear Station (Levy). See Note 4 to the Consolidated Financial Statements, “Regulatory Matters,” for additional information;

• A $42 million decrease in property and other taxes primarily due to the termination of the collection of the North Carolina gross receipts tax as mentioned above; partially offset by a sales tax reserve as a result of an Indiana sales tax audit, and higher property taxes; and

• A $22 million decrease due to the 2013 impairment resulting from the decision to suspend the application for two proposed nuclear units at Shearon Harris Nuclear Station (Harris).

Other Income and Expenses, net. The varianceis primarily due to recognition of post in-service equity returns for projects that had been completed prior to being reflected in customer rates, partially offset by lower AFUDC – equity, primarily due to placing the Sutton plant into service in late 2013.

Interest Expense. The variancewas primarily due to no longer recording post in-service debt returns on projects now reflected in customer ratesand a reduction in debt return on the Crystal River 3 regulatory asset now recovered through fuel revenues.

Income Tax Expense. The variance was primarily due to higher pretax income and partially offset by a lower effective tax rate of 36.8 percent compared to 37.8 percent, respectively, for the years ended December 31, 2014 and 2013. The decrease in effective tax rate is primarily due to favorable audit settlements, a higher manufacturing deduction due to prior year limitations based on taxable income, and changes in income apportionment for state income tax, partially offset by the non-deductible litigation reserve related to the criminal investigation of the Dan River coal ash spill.

Year Ended December 31, 2013 as Compared to 2012

Regulated Utilities’ results were positively impacted by 2012 impairment and other charges related to the Edwardsport Integrated Gasification Combined Cycle (IGCC) plant, higher retail pricing and rate riders, the inclusion of Progress Energy results for the first six months of 2013, a net increase in wholesale power revenues, and higher weather-normal sales volumes. These impacts were partially offset by higher income tax expense, Crystal River Unit 3 charges, lower AFUDC – equity and higher depreciation and amortization expense. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• A $4,339 million increase due to the inclusion of Progress Energy for the first six months of 2013,

• A $434 million net increase in retail pricing primarily due to revised rates approved in all jurisdictions;

• A $76 million net increase in wholesale power revenues, net of sharing, primarily due to additional volumes and charges for capacity for customers served under long-term contracts; and

• A $72 million increase in weather-normal sales volumes to retail customers (net of fuel revenue) reflecting increased demand.

Partially offset by:

• A $132 million decrease in fuel revenues (including emission allowances) driven primarily by (i) the impact of lower Florida residential fuel rates, including amortization associated with the settlement agreement approved by the Florida Public Service Commission (FPSC) in 2012 (2012 Settlement), (ii) lower fuel rates for electric retail customers in the Carolinas, Florida and Ohio, and (iii) lower revenues for purchased power, partially offset by (iv) increased demand from electric retail customers. Fuel revenues represent sales to retail and wholesale customers.

Operating Expenses. The variance was driven primarily by:

• A $3,393 million increase due to the inclusion of Progress Energy for the first six months of 2013,

• A $346 million increase in impairment and other charges in 2013 primarily related to Crystal River Unit 3 and Levy, and

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• A $102 million increase in depreciation and amortization expense primarily due to a decrease in the reduction of the cost of removal component of amortization expense as allowed under the 2012 Settlement.

Partially offset by:

• A $600 million decrease due to 2012 impairment and other charges related to the Edwardsport IGCC plant. See Note 4 to the Consolidated Financial Statements, "Regulatory Matters," for additional information, and

• A $120 million decrease in fuel expense (including purchased power and natural gas purchases for resale) primarily related to (i) the application of the NEIL settlement proceeds in Florida, including amortization associated with the 2012 Settlement; (ii) lower purchased power costs in (a) the Carolinas, primarily due to additional generating capacity placed in service in late 2012 and market conditions, (b) Ohio, primarily due to reduced sales volumes, and (c) Indiana, reflective of market conditions; partially offset by (iii) higher volumes of natural gas used in electric generation due primarily to additional generating capacity placed in service; (iv) higher prices for natural gas and coal used in electric generation; and (v) higher volumes of coal used in electric generation primarily due to generation mix.

Other Income and Expenses, net. The decrease is primarily due to lower AFUDC equity, resulting from major projects that were placed into service in late 2012 and the implementation of new customer rates related to the IGCC rider, partially offset by the inclusion of Progress Energy for the first six months of 2013.

Interest Expense. The variance was primarily driven by the inclusion of Progress Energy for the first six months of 2013.

Income Tax Expense. The variance was primarily due to an increase in pretax income. The effective tax rates for the years ended December 31, 2013 and 2012 were 37.8 percent and 35 percent, respectively. The increase in the effective tax rate was primarily due to an increase in pretax income and a reduction in AFUDC equity.

Matters Impacting Future Regulated Utilities Results

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at the retired Dan River steam station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy is a party to multiple lawsuits filed in regards to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. The outcome of these lawsuits could have an adverse impact to Regulated Utilities’ financial position, results of operations and cash flows. See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact to the Regulated Utilities' financial position, results of operations and cash flows. See Notes 5 and 9 to the Consolidated Financial Statements, “Commitments and Contingencies” and "Asset Retirement Obligations," respectively, for additional information.

In 2015, the Indiana Utility Regulatory Commission (IURC) is examining intervenors' allegations that the Edwardsport IGCC was not properly placed in commercial operation in June 2013 and intervenors’ allegations regarding plant performance. In addition, the Indiana Court of Appeals remanded the IURC order in the ninth IGCC rider proceeding back to the IURC for further findings concerning approximately $61 million of financing charges Joint Intervenors claimed were caused by construction delay and a ratemaking issue concerning the in-service date determination for tax purposes. The outcome of these proceedings could have an adverse impact to Regulated Utilities' financial position, results of operations and cash flows. Duke Energy cannot predict on the outcome of these proceedings. See Note 4 to the Consolidated Financial Statements, “Regulatory Matters,” for additional information.

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International Energy

	Years Ended December 31,
(in millions)	2014		2013		Variance 2014 vs. 2013			2012		Variance 2013 vs. 2012
Operating Revenues	$	1,417	$	1,546	$	(129	)	$	1,549	$	(3	)
Operating Expenses	1,007		1,000		7			1,043		(43		)
Gains (Losses) on Sales of Other Assets and Other, net	6		3		3			—		3
Operating Income	416		549		(133		)	506		43
Other Income and Expense, net	190		125		65			171		(46		)
Interest Expense	93		86		7			76		10
Income Before Income Taxes	513		588		(75		)	601		(13		)
Income Tax Expense	449		166		283			149		17
Less: Income Attributable to Noncontrolling Interests	9		14		(5		)	13		1
Segment Income	$	55	$	408	$	(353	)	$	439	$	(31	)
Sales, GWh	18,629		20,306		(1,677		)	20,132		174
Net proportional MW capacity in operation	4,340		4,600		(260		)	4,584		16

Year Ended December 31, 2014 as Compared to 2013

International Energy’s results were negatively impacted by higher tax expense resulting from the decision to repatriate historical undistributed foreign earnings, unfavorable hydrology and exchange rates in Brazil and an unplanned outage in Chile, partially offset by higher equity earnings in National Methanol Company (NMC) and a 2013 net currency remeasurement loss in Latin America. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• A $44 million decrease in Peru as a result of lower sales volumes and unfavorable exchange rates;

• A $35 million decrease in Brazil due to unfavorable exchange rates and lower sales volumes partially offset by higher average prices;

• A $27 million decrease in Chile as a result of lower sales volumes due to an unplanned outage, and lower average prices; and

• A $25 million decrease in Argentina due to unfavorable exchange rates and lower average prices.

Operating Expenses. The variance was driven primarily by:

• A $75 million increase in Brazil due to higher purchased power as a result of unfavorable hydrology, partially offset by favorable exchange rates.

Partially offset by:

• A $38 million decrease in Peru as a result of lower purchased power, transmission, and royalty costs; and

• A $26 million decrease in Argentina due to favorable exchange rates and lower purchased power and fuel consumption.

Other Income and Expenses, net. The variance is primarily due to a 2013 net currency remeasurement loss in Latin America, higher interest income in Brazil, and higher equity earnings in NMC as a result of increased methyl tertiary butyl ether (MTBE) and methanol sales volumes, partially offset by lower average prices and higher butane costs.

Income Tax Expense. The variance was primarily due to approximately $373 million of incremental tax expense resulting from the decision to repatriate all cumulative historical undistributed foreign earnings at that time. The effective tax rate for the years ended December 31, 2014 and 2013 was 87.3 percent and 28.3 percent, respectively. The increase in the effective tax rate was also primarily due to the tax expense associated with the repatriation decision.

Year Ended December 31, 2013 as Compared to 2012

International Energy’s results were negatively impacted by an extended outage at NMC and unfavorable exchange rates in Latin America, partially offset by the acquisition of Iberoamericana de Energía Ibener, S.A. (Ibener) in 2012 and higher average prices and lower purchased power costs in Brazil. The following is a detailed discussion of the variance drivers by line item.

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Operating Revenues. The variance was driven primarily by:

• A $67 million decrease in Brazil due to weakening of the Real to the U.S. dollar,

• A $53 million decrease in Central America due to lower average prices and volumes, and

• An $18 million decrease in Argentina as a result of unfavorable exchange rates.

Partially offset by:

• A $67 million increase in Brazil due to higher average prices, net of lower volumes, and

• A $65 million increase in Chile as a result of asset acquisitions in 2012.

Operating Expenses. The variance was driven primarily by:

• A $65 million decrease in Central America due to lower fuel costs, partially offset by higher purchased power and coal consumption, and

• A $20 million decrease in Brazil due to weakening of the Real to the U.S. dollar and lower purchased power partially offset by higher variable costs.

Partially offset by:

• A $36 million increase in Chile as a result of acquisitions in 2012.

Other Income and Expenses, net. The decrease was primarily driven by a net currency remeasurement loss in Latin America due to strengthening of the dollar, and lower equity earnings at NMC as a result of lower MTBE average prices and lower volumes due to extended maintenance, partially offset by lower butane costs.

Interest Expense. The variance was primarily due to the Chile acquisitions in 2012, partially offset by favorable exchange rates and lower inflation in Brazil.

Income Tax Expense. The variance was primarily due to a decrease in pretax income. The effective tax rates for the years ended December 31, 2013 and 2012 were 28.3 percent and 24.8 percent, respectively. The increase in the effective tax rate is primarily due to a higher proportion of earnings in countries with higher tax rates.

Matters Impacting Future International Energy Results

International Energy's operations include conventional hydroelectric power generation facilities located in Brazil where water reservoirs are currently at abnormally low levels due to a lack of rainfall.  In addition, International Energy’s equity earnings from NMC reflect sales of methanol and MTBEs, which generates margins that are directionally correlated with crude oil prices. International Energy's earnings and future cash flows could be adversely impacted by either a sustained period of low reservoir levels, especially if the government of Brazil were to implement rationing or some other mandatory conservation program, or a significant decrease in crude oil prices.

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Commercial Power

	Years Ended December 31,
(in millions)	2014			2013			Variance 2014 vs. 2013			2012			Variance 2013 vs. 2012
Operating Revenues	$	255		$	260		$	(5	)	$	307		$	(47	)
Operating Expenses	441			425			16			419			6
(Losses) Gains on Sales of Other Assets and Other, net	—			(23		)	23			2			(25		)
Operating Loss	(186		)	(188		)	2			(110		)	(78		)
Other Income and Expense, net	18			13			5			33			(20		)
Interest Expense	58			61			(3		)	63			(2		)
Loss Before Income Taxes	(226		)	(236		)	10			(140		)	(96		)
Income Tax Benefit	(171		)	(148		)	(23		)	(82		)	(66		)
Less: Income Attributable to Noncontrolling Interests	—			—			—			1			(1		)
Segment Loss	$	(55	)	$	(88	)	$	33		$	(59	)	$	(29	)
Coal-fired plant production, GWh	867			1,644			(777		)	2,096			(452		)
Renewable plant production, GWh	5,462			5,111			351			3,452			1,659
Total Commercial Power production, GWh	6,329			6,755			(426		)	5,548			1,207
Net proportional MW capacity in operation	1,370			2,031			(661		)	2,222			(191		)

Year Ended December 31, 2014 as Compared to 2013

Commercial Power’s results were impacted by higher production tax credits generation, higher production and lower operating costs by the renewables business and a prior-year loss recognized on certain renewables projects, partially offset by an impairment recorded for an intangible asset. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• An $8 million decrease in electric revenues for the Beckjord station, which is not included in the Disposal Group, driven from lower production as units have been retired;

• A $7 million decrease in net mark-to-market revenues on non-qualifying power hedge contracts.

Partially offset by:

• A $16 million increase in electric revenues from higher production in the renewables portfolio.

Operating Expenses. The variance was driven primarily by:

• A $94 million increase driven by an impairment taken related to Ohio Valley Electric Corporation (OVEC). See Note 11 to the Consolidated Financial Statements, “Goodwill and Intangible Assets” for additional information.

Partially offset by:

• An $18 million decrease in depreciation driven by discontinued amortization of an intangible asset that was impaired and written off in 2014 and extensions on the projected useful lives of assets in the renewable portfolio;

• A $17 million decrease in fuel expense for the Beckjord station driven by lower cost of coal from decreased production as units have been retired;

• A $16 million decrease related to a 2013 legal settlement reserve related to previously disposed businesses;

• A $10 million decrease in general and administrative costs;

• A $9 million decrease in operations and maintenance expense for the renewables portfolio driven primarily by development cost reductions; and

• A $6 million decrease in property tax expense driven by cost reductions in the renewables portfolio resulting from a property tax abatement that went into effect in the current year.

Losses on Sales of Other Assets and Other, net. The variance is attributable to a loss recognized on the sale of certain renewable development projects in 2013.

Other Income and Expense. The variance was primarily due to a net gain recognized for the sale of certain renewable development assets and increased equity earnings from higher production in the renewable wind portfolio.

Income Tax Benefit. The variance was primarily due to changes in state deferred taxes and higher production tax credits in 2014 for the Renewables portfolio. The effective tax rate for the years ended December 31, 2014 and 2013 was 75.5 percent and 62.8 percent, respectively.

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Year Ended December 31, 2013 as Compared to 2012

Commercial Power’s results were negatively impacted by the sale of non-core business operations and lower income from the renewables portfolio and Beckjord generating station. These impacts are partially offset by higher income tax benefits. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

• An $81 million decrease due primarily to the sale of non-core businesses in 2012; and

• A $35 million decrease in electric revenues for the Beckjord station driven from lower production as units were prepared for retirement;

Partially offset by:

• A $67 million increase due to higher volumes in the renewables portfolio.

Operating Expenses. The variance was driven primarily by:

• A $34 million increase in operations and maintenance expense for the renewables portfolio driven primarily by commercial operation of certain assets and costs to run the renewables services company acquired in 2012;

• A $25 million increase in depreciation driven by renewable portfolio assets put in service;

• A $17 million increase related to Midcontinent Independent System Operator, Inc. (MISO) and PJM Transmission System Enhancement obligations; and

• A $16 million increase related to a 2013 legal settlement reserve related to previously disposed businesses.

Partially offset by:

• A $56 million decrease due primarily to the sale of non-core businesses in 2012;

• A $17 million decrease in general and administrative costs; and

• A $16 million decrease in fuel expense for the Beckjord station, which is not included in the Disposal Group, driven by lower cost of coal from decreased production as units were prepared for retirement;

(Losses) Gains on Sales of Other Assets and Other, net. The variance is attributable to a loss recognized on the sale of certain renewable development projects in 2013 and a gain on the 2012 contribution of certain renewable assets to a joint venture.

Other Income and Expense, net. The variance is primarily due to the sale of non-core businesses in 2012, lower equity earnings from the renewables portfolio, and lower interest income.

Income Tax Benefit. The variance was primarily due to an increase in pretax loss and a decrease in manufacturing deductions combined with higher production tax credits in 2013. The effective tax rates for the years ended December 31, 2013 and 2012 were 62.8 percent and 58.4 percent, respectively. The increase in the effective tax rate for the period was primarily due to higher production tax credits in 2013 for the Renewable portfolio.

Other

	Years Ended December 31,
(in millions)	2014			2013			Variance 2014 vs. 2013			2012			Variance 2013 vs. 2012
Operating Revenues	$	105		$	175		$	(70	)	$	84		$	91
Operating Expenses	322			457			(135		)	704			(247		)
Gains (Losses) on Sales of Other Assets and Other, net	6			(3		)	9			(7		)	4
Operating Loss	(211		)	(285		)	74			(627		)	342
Other Income and Expense, net	45			131			(86		)	19			112
Interest Expense	400			416			(16		)	299			117
Loss Before Income Taxes	(566		)	(570		)	4			(907		)	337
Income Tax Benefit	(237		)	(335		)	98			(386		)	51
Less: Income (Loss) Attributable to Noncontrolling Interests	5			3			2			2			1
Net Expense	$	(334	)	$	(238	)	$	(96	)	$	(523	)	$	285

Year Ended December 31, 2014 as Compared to 2013

Other’s results were negatively impacted by a decrease in income tax benefit. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The decrease was primarily due to mark-to-market activity of mitigation sales related to the Progress Energy merger.

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Operating Expenses. The decrease was primarily due to lower charges related to the Progress Energy merger and prior year Crescent Resources LLC (Crescent) litigation reserve, partially offset by unfavorable loss experience at Bison.

Other Income and Expenses. The decrease was primarily due to a gain on the sale of Duke Energy’s 50 percent ownership in DukeNet Communications Holdings, LLC (DukeNet) in 2013, partially offset by a current year investment sale gain and higher investment income at Bison Insurance Company Limited (Bison).

Interest Expense. The variance was due primarily to lower interest on long-term debt resulting from debt maturities and new debt issued at lower rates.

Income Tax Benefit. The variance was primarily due to a state tax benefit recognized in 2013. The effective tax rate for the years ended December 31, 2014 and 2013 was 41.9 percent and 58.6 percent, respectively.

Year Ended December 31, 2013 as Compared to 2012

Other’s results were positively impacted by lower charges related to the Progress Energy merger, the sale of DukeNet, and increased current year activity from mitigation sales related to the Progress Energy merger. These impacts were partially offset by increased interest expense, lower income tax benefit and the Crescent litigation reserve in 2013. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by increased activity from mitigation sales related to the Progress Energy merger and higher premiums earned at Bison as a result of the addition of Progress Energy.

Operating Expenses. The variance was driven primarily by lower charges related to the Progress Energy merger, and prior year donations, partially offset by the Crescent litigation reserve in 2013 and unfavorable loss experience at Bison as a result of the addition of Progress Energy.

Other Income and Expense, net. The variance was driven primarily by a gain on the sale of Duke Energy’s 50 percent ownership in DukeNet in 2013.

Interest Expense. The variance was due primarily to the inclusion of Progress Energy for the first six months of 2013 and additional debt issuances.

Income Tax Benefit. The variance was primarily due to a decrease in pretax loss. The effective tax rates for the years ended December 31, 2013 and 2012 were 58.6 percent and 42.5 percent, respectively.

Matters Impacting Future Other Results

Duke Energy previously held an effective 50 percent interest in Crescent Resources, LLC (Crescent). Crescent was a real estate joint venture formed by Duke Energy in 2006 that filed for Chapter 11 bankruptcy protection in June 2009. On June 9, 2010, Crescent restructured and emerged from bankruptcy and Duke Energy forfeited its entire 50 percent ownership interest to Crescent debt holders. This forfeiture caused Duke Energy to recognize a loss, for tax purposes, on its interest in the second quarter of 2010. Although Crescent has reorganized and emerged from bankruptcy with creditors owning all Crescent interest, there remains uncertainty as to the tax treatment associated with the restructuring. Based on this uncertainty, it is possible that Duke Energy could incur a future tax liability related to the tax losses associated with its partnership interest in Crescent and the resolution of issues associated with Crescent’s emergence from bankruptcy.

In 2013, a FERC Administrative Law Judge issued an initial decision holding that Duke Energy is responsible for costs associated with Multi Value Projects (MVP), a type of Transmission Expansion Planning (MTEP) cost, approved by MISO prior to the date of Duke Energy’s withdrawal. The initial decision will be reviewed by FERC. If FERC upholds the initial decision, Duke Energy intends to file an appeal in federal court. If Duke Energy is deemed responsible for these costs, and if a portion of these costs are not eligible for recovery, there may be an adverse impact to its financial position, results of operations and cash flows. See Note 4 to the Consolidated Financial Statements, “Regulatory Matters,” for additional information.

INCOME (LOSS) FROM DISCONTINUED OPERATIONS, NET OF TAX

Discontinued Operations decreased $662 million for the year ended December 31, 2014, compared to the same period in the prior year, primarily due to a $929 million pretax write-down of the carrying amount of the assets to the estimated fair value of the Disposal Group, based on the transaction price included in the PSA, less estimated costs to sell and a $134 million pretax mark-to-market loss on economic hedges for the Disposal Group. Included in the variance is the $117 million impact of ceasing depreciation on the assets of the Disposal Group beginning in the second quarter of 2014.

Discontinued Operations decreased $85 million for the year ended December 31, 2013 compared to the same period in the prior year, primarily due to a reduction in PJM capacity revenues related to lower average cleared capacity auction pricing for the Disposal Group.

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DUKE ENERGY CAROLINAS

Introduction

Management’s Discussion and Analysis should be read in conjunction with the accompanying Consolidated Financial Statements and Notes for the years ended December 31, 2014, 2013 and 2012.

Basis of Presentation

The results of operations and variance discussion for Duke Energy Carolinas is presented in a reduced disclosure format in accordance with General Instruction (I)(2)(a) of Form 10-K.

Results of Operations

	Years Ended December 31,
(in millions)	2014		2013		Variance
Operating Revenues	$	7,351	$	6,954	$	397
Operating Expenses	5,456		5,145		311
Operating Income	1,895		1,809		86
Other Income and Expense, net	172		120		52
Interest Expense	407		359		48
Income Before Income Taxes	1,660		1,570		90
Income Tax Expense	588		594		(6		)
Net Income	$	1,072	$	976	$	96

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

Increase (decrease) over prior year	2014		2013
Residential sales	4.0	%	2.3	%
General service sales	2.4	%	1.0	%
Industrial sales	2.4	%	0.4	%
Wholesale and other	(4.7	)%	62.1	%
Total sales	2.2	%	5.4	%
Average number of customers	1.0	%	0.7	%

Year Ended December 31, 2014 as Compared to 2013

Operating Revenues. The variance was driven primarily by:

• A $180 million increase in retail pricing and updated rate riders, which primarily reflects the impact of the 2013 North Carolina and South Carolina retail rate cases;

• A $151 million increase in fuel revenues driven primarily by increased demand from retail customers, mainly due to favorable weather conditions. Fuel revenues represent sales to retail and wholesale customers;

• A $99 million increase in electric sales (net of fuel revenues) to retail customers due to favorable weather conditions. Heating degree days in 2014 were 11 percent above normal compared to 5 percent above normal during the same period in 2013 and cooling degree days were 6 percent below normal as compared to 17 percent below normal in 2013;

• A $19 million increase in wholesale power revenues, net of sharing, primarily due to new customers; and

• An $18 million increase in weather-normal sales volumes to retail customers reflecting increased demand.

Partially offset by:

• A $79 million decrease in gross receipts tax revenue due to the NC Tax Simplification and Rate Reduction Act which terminated the collection of the North Carolina gross receipts tax effective July 1, 2014.

Operating Expenses. The variance was driven primarily by:

• A $151 million increase in fuel expense (including purchased power) primarily due to increased retail demand resulting from favorable weather conditions;

• A $127 million increase in operating and maintenance expenses primarily due to a litigation reserve related to the criminal investigation of the Dan River coal ash spill (See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information), repairs and remediation expenses associated with the Dan River coal ash discharge and other ash basin related assessment costs, higher non-outage costs at generation plants, higher storm costs, higher distribution costs, higher nuclear outage expense including the impacts of nuclear levelization, and higher energy efficiency program costs, partially offset by decreased corporate costs and lower costs associated with the Progress Energy merger; and

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• An $88 million increase in depreciation and amortization primarily due to higher depreciation as a result of additional plant in service and amortization of certain regulatory assets, partially offset by lower depreciation expense due to reductions for costs of removal in accordance with the 2013 North Carolina and South Carolina rate case orders.

Partially offset by:

• A $58 million decrease in property and other tax expenses primarily due to lower revenue related taxes driven by the elimination of North Carolina gross receipts tax effective July 1, 2014, partially offset by higher property tax expense.

Other Income and Expenses, net. The variance was primarily due to the recognition of post in-service equity returns for projects that had been completed prior to being reflected in customer rates.

Interest Expense. The variance was primarily due to no longer recording post in-service debt returns on projects now reflected in customer rates, partially offset by lower interest on bonds.

Income Tax Expense. The effective tax rate for the years ended December 31, 2014 and 2013 was 35.4 percent and 37.8 percent, respectively. The decrease in the effective tax rate is primarily due to favorable audit settlements, changes in apportionment related to state income tax and the tax benefit related to the manufacturing deduction in 2014 as the prior year deduction was limited by taxable income, partially offset by the non-deductible litigation reserve related to the criminal investigation of the Dan River coal ash spill.

Matters Impacting Future Results

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at the retired Dan River steam station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy is a party to multiple lawsuits filed in regards to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. The outcome of these lawsuits could have an adverse impact to Duke Energy Carolinas’ financial position, results of operations and cash flows. See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact to Duke Energy Carolinas' financial position, results of operations and cash flows. See Notes 5 and 9 to the Consolidated Financial Statements, “Commitments and Contingencies” and "Asset Retirement Obligations," respectively, for additional information.

PROGRESS ENERGY

Introduction

Management’s Discussion and Analysis should be read in conjunction with the accompanying Consolidated Financial Statements and Notes for the years ended December 31, 2014, 2013 and 2012.

Basis of Presentation

The results of operations and variance discussion for Progress Energy is presented in a reduced disclosure format in accordance with General Instruction (I)(2)(a) of Form 10-K.

Results of Operations

	Years Ended December 31,
(in millions)	2014			2013		Variance
Operating Revenues	$	10,166		$	9,533	$	633
Operating Expenses	8,159			7,918		241
Gains (Losses) on Sales of Other Assets and Other, net	11			3		8
Operating Income	2,018			1,618		400
Other Income and Expense, net	77			94		(17		)
Interest Expense	675			680		(5		)
Income Before Income Taxes	1,420			1,032		388
Income Tax Expense	540			373		167
Income from Continuing Operations	880			659		221
Discontinued Operations, net of tax	(6		)	16		(22		)
Net Income	874			675		199
Less: Net Income Attributable to Noncontrolling Interests	5			3		2
Net Income Attributable to Parent	$	869		$	672	$	197

Year Ended December 31, 2014 as Compared to 2013

Operating Revenues. The variance was driven primarily by:

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• A $341 million increase in fuel revenues (including emission allowances) driven primarily by increased demand from wholesale and retail customers, partially resulting from favorable weather conditions, and higher fuel rates for wholesale customers reflective of higher fuel costs for Duke Energy Progress; and to a higher fuel rate in the current year related to lower NEIL insurance reimbursements and accelerated Crystal River Unit 3 regulatory asset cost recovery in 2014 as allowed by the 2013 Settlement for Duke Energy Florida. Fuel revenues represent sales to retail and wholesale customers;

• A $149 million increase in retail pricing, which primarily reflects the impact of the 2013 North Carolina retail rate case in North Carolina and the 2014 base rate increase in Florida; and

• A $114 million increase (net of fuel revenue) in GWh sales to retail customers due to favorable weather conditions. For Duke Energy Progress, heating degree days in 2014 were 11 percent above normal compared to 2 percent above normal in 2013 and cooling degree days were 2 percent below normal compared to 13 percent below normal in 2013. For Duke Energy Florida, heating degree days in 2014 were 51 percent higher and cooling degree days were 4 percent lower compared to the same period in 2013

Operating Expenses. The variance was driven primarily by:

• A $344 million increase in fuel expenses (including purchased power). For Duke Energy Florida the increase is due to the application of the NEIL settlement proceeds in 2013 and higher sales volumes driven by increased demand and higher fuel prices in the current year. For Duke Energy Progress the increase is primarily due to increased sales volumes;

• A $245 million increase in depreciation and amortization. For Duke Energy Florida the increase is primarily due to a reduction of the cost of removal component of amortization expense in 2013 as allowed under the 2012 Settlement, increased environmental cost recovery clause amortization related to prior year under-recovery and nuclear cost recovery clause amortization due to an increase in recoverable nuclear assets in the current year. For Duke Energy Progress the increase is primarily due to higher depreciation as a result of additional plant in service and amortization of certain regulatory assets and a prior year reversal of a portion of cost of removal reserves in accordance with the 2013 NCUC rate case order; and

• An $88 million increase in operations, maintenance and other expense primarily due to a litigation reserve related to the criminal investigation of the management of North Carolina coal ash basins (See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information).

Partially offset by:

• A $346 million decrease due to 2013 impairment and other charges at Duke Energy Florida primarily related to Crystal River Unit 3 and Levy; and

• A $49 million decrease at Duke Energy Progress due to a current year $18 million reduction to a 2012 impairment charge related to the disallowance of transmission project costs, which are a portion of the Long-Term FERC Mitigation and a $22 million prior-year impairment charge resulting from the decision to suspend the application for two proposed nuclear units at the Harris nuclear station.

Other Income and Expense, net. The variance was primarily due to lower AFUDC – equity as a result of assets placed into service, partially offset by post in-service equity returns for projects that had been completed prior to being reflected in customer rates.

Income Tax Expense. The variance was primarily due to an increase in pretax income. The effective tax rate for the 12 months ended December 31, 2014 and 2013 was 38.0 percent and 36.2 percent, respectively. The increase in the effective tax rate is primarily due to a decrease in AFUDC – equity and the non-deductible litigation reserve related to the criminal investigation of the management of North Carolina coal ash basins.

Matters Impacting Future Results

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy Carolinas' retired Dan River steam station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy is a party to multiple lawsuits filed in regards to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. The outcome of these lawsuits could have an adverse impact to Progress Energy's financial position, results of operations and cash flows. See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information. 

An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact to Progress Energy's financial position, results of operations and cash flows. See Notes 5 and 9 to the Consolidated Financial Statements, “Commitments and Contingencies” and "Asset Retirement Obligations," respectively, for additional information.

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DUKE ENERGY PROGRESS

Introduction

Management’s Discussion and Analysis should be read in conjunction with the accompanying Consolidated Financial Statements and Notes for the years ended December 31, 2014, 2013 and 2012.

Basis of Presentation

The results of operations and variance discussion for Duke Energy Progress is presented in a reduced disclosure format in accordance with General Instruction (I)(2)(a) of Form 10-K.

Results of Operations

	Years Ended December 31,
(in millions)	2014		2013		Variance
Operating Revenues	$	5,176	$	4,992	$	184
Operating Expenses	4,244		4,061		183
Gains on Sales of Other Asset and Other, net	3		1		2
Operating Income	935		932		3
Other Income and Expense, net	51		57		(6		)
Interest Expense	234		201		33
Income Before Income Taxes	752		788		(36		)
Income Tax Expense	285		288		(3		)
Net Income	$	467	$	500	$	(33	)

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

Increase (decrease) over prior year	2014		2013
Residential sales	5.1	%	4.0	%
General service sales	2.1	%	—	%
Industrial sales	(2.9	)%	1.1	%
Wholesale and other	10.1	%	7.6	%
Total sales	4.4	%	3.1	%
Average number of customers	1.1	%	0.9	%

Year Ended December 31, 2014 as Compared to 2013

Operating Revenues. The variance was driven primarily by:

• A $104 million increase in fuel revenues (including emission allowances) driven primarily by increased demand from wholesale and retail customers, partially resulting from favorable weather conditions, and higher fuel rates for wholesale customers reflective of higher fuel costs. Fuel revenues represent sales to retail and wholesale customers;

• An $82 million increase (net of fuel revenue) in electric sales to retail customers due to favorable weather conditions. Heating degree days in 2014 were 11 percent above normal compared to 2 percent above normal in 2013 and cooling degree days were 2 percent below normal compared to 13 percent below normal in 2013; and

• An $80 million increase in retail pricing, which primarily reflects the impact of the 2013 North Carolina retail rate case.

Partially offset by:

• A $60 million decrease in gross receipts tax revenue due to the NC Tax Simplification and Rate Reduction Act which terminated the collection of the North Carolina gross receipts tax effective July 1, 2014; and

• A $19 million decrease in weather-normal sales volumes to retail customers reflecting decreased demand.

Operating Expenses. The variance was driven primarily by:

• A $111 million increase in fuel expenses (including purchased power) primarily due to increased sales volumes;

• A $113 million increase in operations and maintenance expenses primarily due to a litigation reserve related to the criminal investigation of the management of North Carolina coal ash basins (See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information), the impacts of amortization on nuclear levelization outage deferrals and higher storm costs, partially offset by prior year donations for low-income customers and job training in accordance with the 2013 NCUC rate case order and lower costs to achieve the merger with Duke Energy including severance and employee relocation expenses; and

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• A $48 million increase in depreciation and amortization expenses primarily due to higher depreciation as a result of additional plant in service and amortization of certain regulatory assets and a prior year reversal of a portion of cost of removal reserves in accordance with the 2013 NCUC rate case order.

Partially offset by:

• A $49 million decrease in property and other tax expenses primarily due to lower revenue related taxes driven by the elimination of North Carolina gross receipts tax effective July 1, 2014, partially offset by higher property tax expense; and

• A $40 million decrease due to a current year $18 million reduction to a 2012 impairment charge related to the disallowance of transmission project costs, which are a portion of the Long-Term FERC Mitigation and a $22 million prior-year impairment charge resulting from the decision to suspend the application for two proposed nuclear units at the Harris nuclear station.

Interest Expense. The variance was primarily due to a new debt issuance, no longer recording post in-service debt returns on projects now reflected in customer rates and lower AFUDC – debt due to projects placed in service.

Income Tax Expense. The variance was primarily due to a decrease in pretax income. The effective tax rate for the years ended December 31, 2014 and 2013 was 37.9 percent and 36.5 percent, respectively. The increase in the effective tax rate is primarily due to the non-deductible litigation reserve related to the criminal investigation of the management of North Carolina coal ash basins.

Matters Impacting Future Results

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy Carolinas' retired Dan River steam station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy is a party to multiple lawsuits filed in regards to the Dan River coal ash release and operations at other North Carolina facilities with ash basins. The outcome of these lawsuits could have an adverse impact to Duke Energy Progress’ financial position, results of operations and cash flows. See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact to Duke Energy Progress' financial position, results of operations and cash flows. See Notes 5 and 9 to the Consolidated Financial Statements, “Commitments and Contingencies” and "Asset Retirement Obligations," respectively, for additional information.

DUKE ENERGY FLORIDA

Introduction

Management’s Discussion and Analysis should be read in conjunction with the accompanying Consolidated Financial Statements and Notes for the years ended December 31, 2014, 2013 and 2012.

Basis of Presentation

The results of operations and variance discussion for Duke Energy Florida is presented in a reduced disclosure format in accordance with General Instruction (I)(2)(a) of Form 10-K.

Results of Operations

	Years Ended December 31,
(in millions)	2014		2013		Variance
Operating Revenues	$	4,975	$	4,527	$	448
Operating Expenses	3,898		3,840		58
Gains on Sales of Other Asset and Other, net	1		1		—
Operating Income	1,078		688		390
Other Income and Expense, net	20		30		(10		)
Interest Expense	201		180		21
Income Before Income Taxes	897		538		359
Income Tax Expense	349		213		136
Net Income	$	548	$	325	$	223

The following table shows the percent changes in GWh sales and average number of customers for Duke Energy Florida. The below 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 and to public and private utilities and power marketers. Amounts are not weather normalized.

Increase (decrease) over prior year	2014		2013
Residential sales	2.7	%	1.4	%
General service sales	0.5	%	(0.5	)%
Industrial sales	1.9	%	1.5	%
Wholesale and other	(5.9	)%	(13.8	)%
Total sales	1.9	%	(1.2	)%
Average number of customers	1.5	%	1.1	%

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Year Ended December 31, 2014 as Compared to 2013

Operating Revenues. The variance was driven primarily by:

• A $237 million increase in fuel and capacity revenues primarily due to a higher fuel rate in the current year related to lower NEIL insurance reimbursements and accelerated Crystal River Unit 3 regulatory asset cost recovery in 2014 as allowed by the 2013 Settlement. Fuel revenues represent sales to retail and wholesale customers;

• A $69 million net increase in base revenues due primarily to the 2014 base rate increase;

• A $63 million increase in nuclear cost recovery clause and energy conservation cost recovery clause revenues due to higher recovery rates in the current year;

• A $32 million increase in electric sales (net of fuel revenue) to retail customers due to favorable weather conditions. Heating degree days in 2014 were 51 percent higher and cooling degree days were 4 percent lower compared to the same period in 2013; and

• A $29 million increase in wholesale power revenues primarily driven by increased capacity rates partially offset by the impact of contracts that expired in 2013.

Operating Expenses. The variance was driven primarily by:

• A $231 million increase in fuel used in electric generation and purchased power due to the application of the NEIL settlement proceeds in 2013 and higher sales volumes driven by increased demand and higher fuel prices in the current year;

• A $215 million increase in depreciation and amortization primarily due to a reduction of the cost of removal component of amortization expense in 2013 as allowed under the 2012 Settlement, increased environmental cost recovery clause amortization related to prior year under-recovery and nuclear cost recovery clause amortization due to an increase in recoverable nuclear assets in the current year; and

• A $16 million increase in property and other taxes primarily driven by higher revenue-related taxes in 2014 due to the higher revenues.

Partially offset by:

• A $346 million decrease due to 2013 impairment and other charges primarily related to Crystal River Unit 3 and Levy; and

• A $48 million decrease in operations and maintenance costs primarily due to prior year Crystal River Unit 3 related settlement matters and lower costs associated with Progress Energy’s merger with Duke Energy. These costs were partially offset by increased expenses that are recoverable under the energy conservation and environmental cost recovery clauses.

Other Income and Expense, net. The variance is driven by lower AFUDC return on the Levy projects in the current year.

Interest Expense. The increase is due to a lower debt return in 2014 driven by the Crystal River Unit 3 regulatory asset impairment in 2013 and accelerated Crystal River Unit 3 regulatory asset cost recovery in 2014 as allowed by the 2013 Settlement.

Income Tax Expense. The variance was primarily due to an increase in pretax income. The effective tax rate for the years ended December 31, 2014 and 2013 was 38.9 percent and 39.6 percent, respectively.

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DUKE ENERGY OHIO

Introduction

Management’s Discussion and Analysis should be read in conjunction with the accompanying Consolidated Financial Statements and Notes for the years ended December 31, 2014, 2013 and 2012.

Basis of Presentation

The results of operations and variance discussion for Duke Energy Ohio is presented in a reduced disclosure format in accordance with General Instruction (I)(2)(a) of Form 10-K.

Results of Operations

	Years Ended December 31,
(in millions)	2014			2013		Variance
Operating Revenues	$	1,913		$	1,805	$	108
Operating Expenses	1,727			1,627		100
Gains on Sales of Other Assets and Other, net	1			4		(3		)
Operating Income	187			182		5
Other Income and Expense, net	10			2		8
Interest Expense	86			74		12
Income from Continuing Operations Before Income Taxes	111			110		1
Income Tax Expense from Continuing Operations	43			43		—
Income from Continuing Operations	68			67		1
(Loss) Income from Discontinued Operations, net of tax	(563		)	35		(598		)
Net (Loss) Income	$	(495	)	$	102	$	(597	)

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

Increase (decrease) over prior year	2014		2013
Residential sales	1.3	%	1.5	%
General service sales	0.8	%	0.8	%
Industrial sales	3.3	%	0.2	%
Wholesale power sales	(24.9	)%	20.9	%
Total sales	0.7	%	0.9	%
Average number of customers	0.6	%	0.4	%

Year Ended December 31, 2014 as Compared to 2013

Operating Revenues. The variance was driven primarily by:

• A $56 million increase in regulated fuel revenues primarily driven by higher fuel costs and increased sales volumes;

• A $51 million increase in retail pricing and rate riders primarily due to 2013 rate increases; and

• A $9 million increase in volumes to retail customers.

Partially offset by:

• An $8 million decrease in electric revenues for the Beckjord station driven from lower production as units have been retired; and

• A $7 million decrease in net mark-to-market revenue on non-qualifying power hedge contracts.

Operating Expenses. The variance was driven primarily by:

• A $94 million impairment taken related to OVEC. See Note 11 to the Consolidated Financial Statements, “Goodwill and Intangible Assets” for additional information; and

• A $64 million increase in regulated fuel expense driven primarily by higher fuel costs and increased volumes.

Partially offset by:

• A $30 million decrease in operating and maintenance expenses primarily due to lower corporate governance costs;

• A $16 million decrease in nonregulated fuel expense for the Beckjord station driven by lower cost of coal from decreased production as units have been retired; and

• An $8 million decrease in property and other taxes driven primarily by an Ohio gas excise tax settlement in 2014.

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Interest Expense. The increase was primarily due to higher regulated average debt balances in 2014 compared to 2013 and higher intercompany interest expense related to the funds loaned from Cinergy to Duke Energy Commercial Asset Management, Inc. (DECAM).

Income Tax Expense. The effective tax rate for the years ended December 31, 2014 and 2013 was 38.9 percent and 39.1 percent, respectively.

Discontinued Operations, Net of Tax. The variance was primarily due to the impairment recognized for the nonregulated Midwest generation business.

Matters Impacting Future Results

On February 17, 2014, Duke Energy Ohio announced it had initiated a process to exit its nonregulated Midwest generation business. Duke Energy Ohio expects to dispose of the nonregulated Midwest generation business in the second quarter of 2015. Duke Energy Ohio recognized a pretax impairment charge of $886 million for the year ended December 31, 2014, which represents the excess of the carrying value over the estimated fair value of the business based on the transaction price included in the PSA, less estimated costs to sell. The transaction is expected to close by the end of the second quarter of 2015 and the impairment will be updated, if necessary, based on the final sales price, after any adjustments at closing for working capital and capital expenditures.

In 2013, a FERC Administrative Law Judge issued an initial decision that Duke Energy Ohio is responsible for costs associated with certain MVP costs, a type of MTEP cost, approved by MISO prior to the date of Duke Energy Ohio’s withdrawal. The initial decision will be reviewed by FERC. If FERC upholds the initial decision, Duke Energy Ohio intends to file an appeal in federal court. If Duke Energy Ohio is deemed responsible for these costs, and if a portion of these costs are not eligible for recovery, there may be an adverse impact to its financial position, results of operations and cash flows. See Note 4 to the Consolidated Financial Statements, “Regulatory Matters,” for additional information.

DUKE ENERGY INDIANA

Introduction

Management’s Discussion and Analysis should be read in conjunction with the accompanying Consolidated Financial Statements and Notes for the years ended December 31, 2014, 2013 and 2012.

Basis of Presentation

The results of operations and variance discussion for Duke Energy Indiana is presented in a reduced disclosure format in accordance with General Instruction (I)(2)(a) of Form 10-K.

Results of Operations

	Years Ended December 31,
(in millions)	2014		2013		Variance
Operating Revenues	$	3,175	$	2,926	$	249
Operating Expenses	2,470		2,193		277
Operating Income (Loss)	705		733		(28		)
Other Income and Expense, net	22		18		4
Interest Expense	171		170		1
Income (Loss) Before Income Taxes	556		581		(25		)
Income Tax Expense (Benefit)	197		223		(26		)
Net Income (Loss)	$	359	$	358	$	1

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

Increase (decrease) over prior year	2014		2013
Residential sales	2.1	%	3.2	%
General service sales	—	%	0.5	%
Industrial sales	2.5	%	(0.3	)%
Wholesale power sales	(8.8	)%	(1.4	)%
Total sales	(0.8	)%	0.4	%
Average number of customers	0.6	%	0.7	%

Year Ended December 31, 2014 as Compared to 2013

Operating Revenues. The variance was driven primarily by:

• A $138 million increase in fuel revenues (including emission allowances) due to an increase in fuel rates as a result of higher fuel and purchased power costs;

• An $86 million net increase in rate riders primarily due to updates to the IGCC rider; and

• A $17 million increase in wholesale power revenues primarily due to higher customer rates.

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Operating Expenses. The variance was driven primarily by:

• A $128 million increase in fuel costs primarily driven by higher fuel and purchased power costs;

• A $71 million increase in depreciation and amortization primarily as a result of the Edwardsport IGCC plant being placed into service in the second quarter of 2013;

• A $57 million increase in property and other taxes, primarily as a result of amounts recorded related to an Indiana sales tax audit; and

• A $21 million increase in operation and maintenance primarily due to higher operation and maintenance costs, higher outage costs at generation plants, partially offset by decreased corporate costs.

Income Tax Expense. The effective tax rate for the years ended December 31, 2014 and 2013 was 35.5 percent and 38.4 percent, respectively. The decrease in the effective tax rate was primarily due to a reduction in the Indiana statutory corporate state income tax rate, a more favorable state tax credit, and a prior period adjustment.

Matters Impacting Future Results

Duke Energy Indiana is evaluating converting Wabash River Unit 6 to a natural gas-fired unit or retiring the unit earlier than its current estimated useful life. If Duke Energy Indiana elects early retirement of the unit, recovery of remaining book values and associated carrying costs totaling approximately $40 million could be subject to future regulatory approvals and therefore cannot be assured.

In 2015, the IURC is examining intervenors' allegations that the Edwardsport IGCC was not properly placed in commercial operation in June 2013 and intervenors’ allegations regarding plant performance. In addition, the Indiana Court of Appeals remanded the IURC order in the ninth IGCC rider proceeding back to the IURC for further findings concerning approximately $61 million of financing charges Joint Intervenors claimed were caused by construction delay and a ratemaking issue concerning the in-service date determination for tax purposes. The outcome of these proceedings could have an adverse impact to Duke Energy Indiana’s financial position, results of operations and cash flows. Duke Energy cannot predict on the outcome of these proceedings. See Note 4 to the Consolidated Financial Statements, “Regulatory Matters,” for additional information.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

Preparation of financial statements requires the application of accounting policies, judgments, assumptions and estimates that can significantly affect the reported results of operations and the amounts of assets and liabilities reported in the financial statements. Judgments made include the likelihood of success of particular projects, possible legal and regulatory challenges, earnings assumptions on pension and other benefit fund investments and anticipated recovery of costs. 

Management discusses these policies, estimates and assumptions with senior members of management on a regular basis and provides periodic updates on management decisions to the Audit Committee of the Board of Directors. Management believes the areas described below require significant judgment in the application of accounting policy or in making estimates and assumptions that are inherently uncertain and that may change in subsequent periods.

Regulatory Accounting

A substantial majority of Regulated Utilities, Duke Energy’s regulated operations, meet the criteria for application of regulatory accounting treatment. As a result, Duke Energy records assets and liabilities that would not be recorded for nonregulated entities. Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in customer rates. Regulatory liabilities generally represent obligations to make refunds or reduce rates to customers for previous collections or for costs that have yet to be incurred.

Management continually assesses whether recorded regulatory assets are probable of future recovery by considering factors such as applicable regulatory environment changes, historical regulatory treatment for similar costs in Duke Energy’s jurisdictions, litigation of rate orders, recent rate orders to other regulated entities, and the status of any pending or potential deregulation legislation. If future recovery of costs ceases to be probable, asset write-offs would be recognized in operating income. Additionally, regulatory agencies can provide flexibility in the manner and timing of the depreciation of property, plant and equipment, recognition of nuclear decommissioning costs and amortization of regulatory assets or may disallow recovery of all or a portion of certain assets. For further information on regulatory assets and liabilities, see Note 4 to the Consolidated Financial Statements, “Regulatory Matters.”

As required by regulated operations accounting, significant judgment can be required to determine if an otherwise recognizable cost is considered to be an entity specific cost recoverable in future rates and therefore a regulatory asset. Significant judgment can also be required to determine if revenues previously recognized are for entity specific costs that are no longer expected to be incurred and are therefore a regulatory liability.

Regulatory accounting rules also require recognition of a loss if it becomes probable that part of the cost of a plant under construction (or a recently completed plant or an abandoned plant) will be disallowed for ratemaking purposes and a reasonable estimate of the amount of the disallowance can be made. For example, if a cost cap is set for a plant still under construction, the amount of the disallowance is a result of a judgment as to the ultimate cost of the plant. Other disallowances can require judgments on allowed future rate recovery. See Note 4 to the Consolidated Financial Statements, “Regulatory Matters,” for a discussion of disallowances recorded related to the Edwardsport IGCC plant and the retired Crystal River Unit 3 Nuclear Station.

When it becomes probable that regulated generation, transmission or distribution assets will be abandoned, the cost of the asset is removed from plant in service. The value that may be retained as an asset on the balance sheet for the abandoned property is dependent upon amounts that may be recovered through regulated rates, including any return. As such, an impairment charge could be offset by the establishment of a regulatory asset if rate recovery is probable. The impairment for a disallowance of costs for regulated plants under construction, recently completed or abandoned is based on discounted cash flows.

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As discussed in Note 2 to the Consolidated Financial Statements, “Acquisitions, Dispositions and Sales of Other Assets,” Duke Energy Carolinas and Duke Energy Progress recorded disallowance charges in 2012 in order to gain FERC approval of the merger between Duke Energy and Progress Energy. In addition to the disallowances, Duke Energy Carolinas and Duke Energy Progress guaranteed total fuel savings to customers in North Carolina and South Carolina of $687 million over the five years in order to gain NCUC and PSCSC approval of the merger between Duke Energy and Progress Energy. Based on current estimates of future fuel costs, Duke Energy anticipates that it will meet the guaranteed fuel savings. However, if actual fuel costs are higher than expected, Duke Energy could record a charge for the unmet guaranteed savings.

Goodwill Impairment Assessments

Duke Energy allocates goodwill to reporting units, which are determined to be an operating segment or one level below based on how the segment is managed. Duke Energy is required to test goodwill for impairment at the reporting unit level at least annually and more frequently if it is more likely than not that the fair value of a reporting unit is less than its carrying value. Duke Energy performs its annual impairment test as of August 31.

Application of the goodwill impairment test requires management judgment, including determining the fair value of the reporting unit, which management estimates using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market approach, which estimates fair value based on market comparables within the utility and energy industries. Significant assumptions used in these fair value analyses include discount and growth rates, future rates of return expected to result from ongoing rate regulation, utility sector market performance and transactions, projected operating and capital cash flows for Duke Energy’s business and the fair value of debt.

Estimated future cash flows under the income approach are based to a large extent on Duke Energy’s internal business plan, and adjusted as appropriate for Duke Energy’s views of market participant assumptions. Duke Energy’s internal business plan reflects management’s assumptions related to customer usage and attrition based on internal data and economic data obtained from third-party sources, projected commodity pricing data and potential changes in environmental regulations. The business plan assumes the occurrence of certain events in the future, such as the outcome of future rate filings, future approved rates of returns on equity, anticipated earnings/returns related to significant future capital investments, continued recovery of cost of service, the renewal of certain contracts and the future of renewable tax credits. Management also makes assumptions regarding operation, maintenance and general and administrative costs based on the expected outcome of the aforementioned events. In estimating cash flows, Duke Energy incorporates expected growth rates, regulatory and economic stability, the ability to renew contracts and other factors, into its revenue and expense forecasts.

One of the most significant assumptions that Duke Energy utilizes in determining the fair value of its reporting units under the income approach is the discount rate applied to the estimated future cash flows. Management determines the appropriate discount rate for each of its reporting units based on the weighted average cost of capital (WACC) for each individual reporting unit. The WACC takes into account both the after-tax cost of debt and cost of equity. A major component of the cost of equity is the current risk-free rate on 20-year U.S. Treasury bonds. In the 2014 impairment tests, Duke Energy considered implied WACCs for certain peer companies in determining the appropriate WACC rates to use in its analysis. As each reporting unit has a different risk profile based on the nature of its operations, including factors such as regulation, the WACC for each reporting unit may differ. Accordingly, the WACCs were adjusted, as appropriate, to account for company specific risk premiums. The discount rates used for calculating the fair values as of August 31, 2014, for each of Duke Energy’s domestic reporting units ranged from 5.3 percent to 6.9 percent.

For Duke Energy’s international operations, a country-specific risk adder based on the average risk premium for each separate country in which International Energy operates was added to the base discount rate to reflect the differing risk profiles. This resulted in a discount rate for the August 31, 2014 goodwill impairment test for the international operations of 10.5 percent.

The underlying assumptions and estimates are made as of a point in time. Subsequent changes, particularly changes in the discount rates, authorized regulated rates of return or growth rates inherent in management’s estimates of future cash flows, could result in future impairment charges.

The majority of Duke Energy’s business is in environments that are either fully or partially rate-regulated. In such environments, revenue requirements are adjusted periodically by regulators based on factors including levels of costs, sales volumes and costs of capital. Accordingly, Duke Energy’s regulated utilities operate to some degree with a buffer from the direct effects, positive or negative, of significant swings in market or economic conditions. However, changes in discount rates may have a significant impact on the fair value of equity.

As of August 31, 2014, all of the reporting units’ estimated fair value of equity exceeded the carrying value of equity by more than 10 percent.

Long-Lived Asset Impairment Assessments, Excluding Regulated Operations

Property, plant and equipment, excluding plant held for sale, is stated at the lower of carrying value (historical cost less accumulated depreciation and previously recorded impairments) or fair value, if impaired. Duke Energy evaluates property, plant and equipment for impairment when events or changes in circumstances (such as a significant change in cash flow projections, the determination that it is more likely than not an asset or asset group will be sold) indicate the carrying value of such assets may not be recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted future cash flows attributable to the assets, as compared with their carrying value.

Performing an impairment evaluation involves a significant degree of estimation and judgment in areas such as identifying circumstances that indicate an impairment may exist, identifying and grouping affected assets, and developing the undiscounted future cash flows associated with the asset. If an impairment has occurred, the amount of the impairment recognized is determined by estimating the fair value of the asset and recording a loss if the carrying value is greater than the fair value. Additionally, determining fair value of the asset requires probability weighting future cash flows to reflect expectations about possible variations in their amounts or timing and the selection of an appropriate discount rate. Although cash flow estimates are based on relevant information available at the time the estimates are made, estimates of future cash flows are, by nature, highly uncertain and may vary significantly from actual results. For assets identified as held for sale, the carrying value is compared to the estimated fair value less cost to sell to determine if an impairment loss is required. Until the assets are disposed of, their estimated fair value is re-evaluated when circumstances or events change.

When determining whether an asset or asset group has been impaired, management groups assets at the lowest level that has discrete cash flows.

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For further information related to the impairment recorded in conjunction with planned sale of Duke Energy's Disposal Group to Dynegy, see Note 2 to the Consolidated Financial Statements, "Acquisition, Disposals and Sales of Other Assets,"

Accounting for Loss Contingencies

Preparation of financial statements and related disclosures require judgments regarding the future outcome of contingent events. Duke Energy is involved in certain legal and environmental matters arising in the normal course of business. Estimating probable losses requires analysis of multiple forecasts and scenarios that often depend on judgments about potential actions by third parties, such as federal, state and local courts and other regulators. Contingent liabilities are often resolved over long periods of time. Amounts recorded in the consolidated financial statements may differ from the actual outcome once the contingency is resolved, which could have a material impact on future results of operations, financial position and cash flows of Duke Energy.

For further information, see Notes 4 and 5 to the Consolidated Financial Statements, "Regulatory Matters" and “Commitments and Contingencies.”

Revenue Recognition

Revenues on sales of electricity and gas are recognized when either the service is provided or the product is delivered. Operating revenues include unbilled electric and gas revenues earned when service has been delivered but not billed by the end of the accounting period. Unbilled retail revenues are estimated by applying an average revenue per kilowatt-hour (kWh) or per thousand cubic feet (Mcf) for all customer classes to the number of estimated kWh or Mcf delivered but not billed. Unbilled wholesale energy revenues are calculated by applying the contractual rate per megawatt-hour (MWh) to the number of estimated MWh delivered but not yet billed. Unbilled wholesale demand revenues are calculated by applying the contractual rate per megawatt (MW) to the MW volume delivered but not yet billed. The amount of unbilled revenues can vary significantly from period to period as a result of numerous factors, including seasonality, weather, customer usage patterns, customer mix and the average price in effect for customer classes.

Pension and Other Post-Retirement Benefits

The calculation of pension expense, other post-retirement benefit expense and net pension and other post-retirement assets or liabilities require the use of assumptions and election of permissible accounting alternatives. Changes in assumptions can result in different expense and reported asset or liability amounts, and future actual experience can differ from the assumptions. Duke Energy believes the most critical assumptions for pension and other post-retirement benefits are the expected long-term rate of return on plan assets and the assumed discount rate. Additionally, the health care cost trend rate assumption is critical to Duke Energy’s estimate of other post-retirement benefits.

Duke Energy has historically utilized the Society of Actuaries’ (SOA) published mortality data in developing a best estimate of mortality as part of the calculation of the pension obligation (qualified and non-qualified) and other post-retirement benefit obligation. On October 27, 2014, the SOA published updated mortality tables for U.S. plans (RP-2014) and an updated improvement scale, which both reflect improved longevity. Based on an evaluation of the mortality experience of Duke Energy's pension plan participants, the updated SOA study of mortality tables and recent additional studies of mortality improvement, Duke Energy adopted an adjusted version of the SOA's new RP-2014 mortality tables with an updated generational improvement scale (BB-2D) previously published by the SOA for purposes of measuring its U.S. pension (qualified and non-qualified) and other post-retirement benefit obligations as of December 31, 2014. The change to the mortality assumption increased Duke Energy's pension obligation (qualified and non-qualified) and other post-retirement benefit obligation by $201 million and $7 million, respectively, as of December 31, 2014.

Duke Energy elects to amortize net actuarial gains or losses in excess of the corridor of 10 percent of the greater of the market-related value of plan assets or plan projected benefit obligation, into net pension or other post-retirement benefit expense over the average remaining service period of active covered employees. Prior service cost or credit, which represents the effect on plan liabilities due to plan amendments, is amortized over the average remaining service period of active covered employees.

Duke Energy maintains non-contributory defined benefit retirement plans. The plans cover most U.S. employees using a cash balance formula. Under a cash balance formula, a plan participant accumulates a retirement benefit consisting of pay credits based upon a percentage of current eligible earnings based on age and years of service and current interest credits. Certain employees are covered under plans that use a final average earnings formula.

Duke Energy provides some health care and life insurance benefits for retired employees on a contributory and non-contributory basis. Certain employees are eligible for these benefits if they have met age and service requirements at retirement, as defined in the plans.

As of December 31, 2014, Duke Energy assumes pension and other post-retirement plan assets will generate a long-term rate of return of 6.50 percent. The expected long-term rate of return was developed using a weighted average calculation of expected returns based primarily on future expected returns across asset classes considering the use of active asset managers, where applicable. Equity securities are held for their higher expected returns. Debt securities are primarily held to hedge the pension liability. Hedge funds, real estate and other global securities are held for diversification. Investments within asset classes are to be diversified to achieve broad market participation and reduce the impact of individual managers on investments. In 2013, Duke Energy adopted a de-risking investment strategy for its pension assets. As the funded status of the plans increase, over time the targeted allocation to return seeking assets will be reduced and the targeted allocation to fixed-income assets will be increased to better manage Duke Energy's pension liability and reduced funded status volatility. Based on the current funded status of the plans, the asset allocation for the Duke Energy pension plans has been adjusted to 65 percent fixed-income assets and 35 percent return-seeking assets and the asset allocation for the Progress Energy pension plans has been adjusted to 60 percent fixed-income assets and 40 percent return-seeking assets. Duke Energy regularly reviews its actual asset allocation and periodically rebalances its investments to the targeted allocations when considered appropriate.

The assets for Duke Energy’s pension and other post-retirement plans are maintained in a master trust. Duke Energy also invests other post-retirement assets in the Duke Energy Corporation Employee Benefits Trust (VEBA I). The investment objective of VEBA I is to achieve sufficient returns, subject to a prudent level of portfolio risk, for the purpose of promoting the security of plan benefits for participants. VEBA I is passively managed.

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Duke Energy discounted its future U.S. pension and other post-retirement obligations using a rate of 4.1 percent as of December 31, 2014. Discount rates used to measure benefit plan obligations for financial reporting purposes reflect rates at which pension benefits could be effectively settled. As of December 31, 2014, Duke Energy determined its discount rate for U.S. pension and other post-retirement obligations using a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flow to match the timing of projected benefit payments. The selected bond portfolio is derived from a universe of non-callable corporate bonds rated Aa quality or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plan’s projected benefit payments discounted at this rate with the market value of the bonds selected.

Future changes in plan asset returns, assumed discount rates and various other factors related to the participants in Duke Energy’s pension and post-retirement plans will impact future pension expense and liabilities. Duke Energy cannot predict with certainty what these factors will be in the future. The following table presents the approximate effect on Duke Energy’s 2014 pretax pension expense, pretax other post-retirement expense, pension obligation and other post-retirement benefit obligation if a 0.25 percent change in rates were to occur.

	Qualified and Non-Qualified Pension Plans						Other Post-Retirement Plans
(in millions)	0.25		%	(0.25		)%	0.25		%	(0.25		)%
Effect on 2014 pretax pension and other post-retirement expense
Expected long-term rate of return	$	(19	)	$	19		$	(1	)	$	1
Discount rate	(17		)	16			(2		)	2
Effect on pension and other post-retirement benefit obligation at December 31, 2014
Discount rate	(198		)	203			(20		)	21

Duke Energy’s U.S. other post-retirement plan uses a health care trend rate covering both pre- and post-age 65 retired plan participants, which is comprised of a medical care trend rate, which reflects the near- and long-term expectation of increases in medical costs, and a prescription drug trend rate, which reflects the near and long-term expectation of increases in prescription drug costs. As of December 31, 2014, the health care trend rate was 6.75 percent, trending down to 4.75 percent by 2023. The following table presents the approximate effect on Duke Energy’s 2014 pretax other post-retirement expense and other post-retirement benefit obligation if a 1 percentage point change in the health care trend rate were to occur.

	Other Post-Retirement Plans
(in millions)	1		%	(1		)%
Effect on 2014 other post-retirement expense	$	7		$	(6	)
Effect on other post-retirement benefit obligation at December 31, 2014	36			(31		)

For further information, see Note 21 to the Consolidated Financial Statements, “Employee Benefit Plans.”

LIQUIDITY AND CAPITAL RESOURCES

Sources and Uses of Cash

Duke Energy relies primarily upon cash flows from operations, debt issuances and its existing cash and cash equivalents to fund its domestic 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 projected primary sources and uses for the next three fiscal years are included in the table below.

(in millions)	2015		2016		2017
Uses:
Capital expenditures	$7,025-7,425		$8,600-9,375		$7,050-7,825
Debt maturities and reduction in short-term debt(a)	3,300		1,850		2,150
Dividend payments	2,250		2,300		2,350
Share repurchases	1,400		—		—
Sources:
Cash flows from operations(b)	$	7,115	$	7,525	$	8,100
Debt issuances	3,100		6,000		4,000
Proceeds from the sale of the Disposal Group	2,800		—		—

(a) Excludes capital leases and securitized receivables maturities in 2016 and 2017 expected to be renewed. Amounts represent Duke Energy's financing plan, which accelerates certain contractual maturities.

(b) Cash flows from operations includes expenditures related to ash basin closures.

Duke Energy expects the sale of the Disposal group to Dynegy to be completed by the end of the second quarter of 2015. The sale price is $2.8 billion in cash subject to adjustments at closing for changes in working capital and capital expenditures. Upon closing of the transaction, Duke Energy intends to execute a balanced recapitalization strategy with the proceeds. The recapitalization is expected to include a combination of an accelerated share repurchase and debt reduction through avoidance of holding company debt issuances in 2015. The ultimate use of proceeds will depend on facts and circumstances at the time of the closing. For further information on the Midwest Generation Exit, refer to Note 2 to the Consolidated Financial Statements, “Acquisitions, Dispositions and Sales of Other Assets."

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In December 2014, Duke Energy declared a taxable dividend of historical foreign earnings in the form of notes payable that will result in the repatriation of approximately $2.7 billion of cash held and expected to be generated by International Energy over a period of up to eight years. Between $1.2 billion and $1.4 billion will be remitted in 2015, with the remaining amount remitted by 2022. The proceeds of the dividend will principally be used to support Duke Energy's dividend and growth in the domestic business.

The Subsidiary Registrants generally maintain minimal cash balances and use short-term borrowings to meet their working capital needs and other cash requirements. The Subsidiary Registrants, excluding Progress Energy, support their short-term borrowing needs through participation with Duke Energy and certain of its other subsidiaries in a money pool arrangement. The companies with short-term funds may provide short-term loans to affiliates participating under this arrangement. See Note 6 to the Consolidated Financial Statements, “Debt and Credit Facilities,” for additional discussion of the money pool arrangement.

Duke Energy and the Subsidiary Registrants, excluding Progress Energy, may also use short-term debt, including commercial paper and the money pool, as a bridge to long-term debt financings. The levels of borrowing may vary significantly over the course of the year due to the timing of long-term debt financings and the impact of fluctuations in cash flows from operations. From time to time, Duke Energy’s current liabilities exceed current assets resulting from the use of short-term debt as a funding source to meet scheduled maturities of long-term debt, as well as cash needs, which can fluctuate due to the seasonality of its business.

Credit Facilities and Registration Statements

Master Credit Facility Summary

At December 31, 2014, Duke Energy had a Master Credit Facility with a capacity of $6 billion. In January 2015, Duke Energy amended the Master Credit Facility to increase its capacity to $7.5 billion through January 2020. The Duke Energy Registrants, excluding Progress Energy, each have borrowing capacity under the Master Credit Facility up to specified sublimits 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 the 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 the Master Credit Facility.

	December 31, 2014
(in millions)	Duke Energy			Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Facility size(a)	$	6,000		$	2,250		$	1,000		$	750		$	650		$	650		$	700
Reduction to backstop issuances
Commercial paper(b)	(2,021		)	(1,479		)	(300		)	—			(29		)	(38		)	(175		)
Outstanding letters of credit	(70		)	(62		)	(4		)	(2		)	(1		)	—			(1		)
Tax-exempt bonds	(116		)	—			(35		)	—			—			—			(81		)
Available capacity	$	3,793		$	709		$	661		$	748		$	620		$	612		$	443

(a) Represents the sublimit of each borrower at December 31, 2014. The Duke Energy Ohio sublimit includes $100 million for Duke Energy Kentucky.

(b) Duke Energy issued $475 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana. The balances are included within Long-Term Debt Payable to Affiliated Companies in the Consolidated Balance Sheets.

On February 20, 2015, Duke Energy Carolinas, Duke Energy Progress and Duke Energy Business Services LLC (DEBS), a wholly owned subsidiary of Duke Energy, each entered into a Memorandum of Plea Agreement (Plea Agreements) in connection with the investigation initiated by the United States Department of Justice Environmental Crimes Section and the United States Attorneys for the Eastern District of North Carolina, the Middle District of North Carolina and the Western District of North Carolina (collectively, the USDOJ). Under the terms of the Plea Agreements, Duke Energy Carolinas and Duke Energy Progress are required to each maintain $250 million of available capacity under the Master Credit Facility as security to meet their obligations under the Plea Agreements, in addition to certain other conditions set out in the Plea Agreements. The Plea Agreements are subject to court approval. See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

PremierNotes

Duke Energy has an effective registration statement (Form S-3) with the Securities and Exchange Commission (SEC) to sell up to $3 billion of variable denomination floating rate demand notes, called PremierNotes. The Form S-3 states that no more than $1.5 billion of the notes will be outstanding at any particular time. The notes are offered on a continuous basis and bear interest at a floating rate per annum determined by the Duke Energy PremierNotes Committee, or its designee, on a weekly basis. The interest rate payable on notes held by an investor may vary based on the principal amount of the investment. The notes have no stated maturity date, are non-transferable and may be redeemed in whole or in part by Duke Energy or at the investor’s option at any time. The balance as of December 31, 2014 and December 31, 2013, was $968 million and $836 million, respectively. The notes are short-term debt obligations and are reflected as Notes payable and commercial paper on Duke Energy’s Consolidated Balance Sheets.

Shelf Registration

In September 2013, Duke Energy filed a Form S-3 with the SEC. Under this Form S-3, which is uncapped, the Duke Energy Registrants, excluding Progress Energy may issue debt and other securities in the future at amounts, prices and with terms to be determined at the time of future offerings. The registration statement also allows for the issuance of common stock by Duke Energy.

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CAPITAL EXPENDITURES

Duke Energy continues to focus on reducing risk and positioning its business for future success and will invest principally in its strongest business sectors. Based on this goal, the majority of Duke Energy’s total projected capital expenditures are allocated to the Regulated Utilities segment. Duke Energy’s projected capital and investment expenditures for the next three fiscal years are included in the table below.

(in millions)	2015		2016		2017
New generation	$	825	$	2,200	$	850
Environmental	275		300		450
Nuclear fuel	450		475		425
Major nuclear	300		175		150
Customer additions	500		525		550
Grid modernization and other transmission and distribution projects	1,050		1,375		1,525
Maintenance	2,550		2,775		2,300
Total Regulated Utilities	5,950		7,825		6,250
Commercial Power, International Energy and Other	1,075		775		800
Total committed expenditures	7,025		8,600		7,050
Discretionary expenditures	400		775		775
Total projected capital and investment expenditures	$	7,425	$	9,375	$	7,825

DEBT MATURITIES

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

(in millions)	Maturity Date	Interest Rate		December 31, 2014
Unsecured Debt
Duke Energy (Parent)	April 2015	3.350	%	$	450
First Mortgage Bonds
Duke Energy Ohio	March 2015	0.375	%	150
Duke Energy Progress	April 2015	5.150	%	300
Duke Energy Carolinas	October 2015	5.300	%	500
Duke Energy Florida	November 2015	0.650	%	250
Duke Energy Florida	December 2015	5.100	%	300
Duke Energy Progress	December 2015	5.250	%	400
Tax-exempt Bonds
Duke Energy Progress	January 2015	0.108	%	243
Other				214
Current maturities of long-term debt				$	2,807

DIVIDEND PAYMENTS

In 2014, Duke Energy paid quarterly cash dividends for the 88th consecutive year and expects to continue its policy of paying regular cash dividends in the future. There is no assurance as to the amount of future dividends because they depend on future earnings, capital requirements, financial condition and are subject to the discretion of the Board of Directors.

The Board of Directors continues to target a payout ratio of 65 percent to 70 percent, based upon adjusted diluted EPS. Over the past several years, Duke Energy’s dividend has grown at approximately 2 percent annually, slower than overall adjusted earnings growth. Duke Energy has now achieved the targeted payout range and believes it has the flexibility to grow the dividend at a pace more consistent with adjusted earnings growth.

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Dividend and Other Funding Restrictions of Duke Energy Subsidiaries

As discussed in Note 4 to the Consolidated Financial Statements “Regulatory Matters,” Duke Energy’s wholly owned public utility operating companies have restrictions on the amount of funds that can be transferred to Duke Energy via dividend, advance or loan as a result of conditions imposed by various regulators in conjunction with merger transactions. Duke Energy Progress and Duke Energy Florida also have restrictions imposed by their first mortgage bond indentures and Articles of Incorporation which, in certain circumstances, limit their ability to make cash dividends or distributions on common stock. Additionally, certain other Duke Energy subsidiaries have other restrictions, such as minimum working capital and tangible net worth requirements pursuant to debt and other agreements that limit the amount of funds that can be transferred to Duke Energy. At December 31, 2014, the amount of restricted net assets of wholly owned subsidiaries of Duke Energy that may not be distributed to Duke Energy in the form of a loan or dividend is less than 25 percent of Duke Energy’s net assets. Duke Energy does not have any legal or other restrictions on paying common stock dividends to shareholders out of its consolidated equity accounts. Although these restrictions cap the amount of funding the various operating subsidiaries can provide to Duke Energy, management does not believe these restrictions will have a significant impact on Duke Energy’s ability to access cash to meet its payment of dividends on common stock and other future funding obligations.

CASH FLOWS FROM OPERATING ACTIVITIES

The relatively stable operating cash flows of Regulated Utilities compose a substantial portion of Duke Energy’s cash flows from operations. Regulated Utilities’ cash flows from operations are primarily driven by sales of electricity and natural gas and costs of operations. Weather conditions, working capital and commodity price fluctuations, and unanticipated expenses, including unplanned plant outages and storms can affect the timing and level of cash flows from operations.

Duke Energy believes it has sufficient liquidity resources through the commercial paper markets, and ultimately, the Master Credit Facility, to support these operations. Cash flows from operations are subject to a number of other factors, including, but not limited to, regulatory constraints, economic trends and market volatility (see Item 1A, “Risk Factors,” for additional information).

At December 31, 2014, Duke Energy had cash and cash equivalents and short-term investments of $2.0 billion, of which approximately $1.7 billion is held by entities domiciled in foreign jurisdictions. During 2014, Duke Energy declared a taxable dividend of historical foreign earnings in the form of notes payable that will result in the repatriation of approximately $2.7 billion of cash held and expected to be generated by International Energy over a period of up to eight years. As a result of the decision to repatriate all cumulative historic undistributed foreign earnings, during the fourth quarter of 2014, Duke Energy recorded U. S. income tax expense of approximately $373 million. Duke Energy’s intention is to indefinitely reinvest prospective undistributed earnings generated by Duke Energy's foreign subsidiaries. See Note 22 to the Consolidated Financial Statements, “Income Taxes,” for additional information.

DEBT ISSUANCES

Depending on availability based on the issuing entity, the credit rating of the issuing entity, and market conditions, the Subsidiary Registrants prefer to issue first mortgage bonds and secured debt, followed by unsecured debt. This preference is the result of generally higher credit ratings for first mortgage bonds and secured debt, which typically result in lower interest costs. Duke Energy Corporation primarily issues unsecured debt.

Duke Energy’s capitalization is balanced between debt and equity as shown in the table below. The 2015 projected capitalization percentages exclude purchase accounting adjustments of approximately $2.9 billion related to the merger with Progress Energy, while the 2014 and 2013 percentages include all debt-related purchase accounting amounts.

	Projected 2015		Actual 2014		Actual 2013
Equity	50	%	49	%	50	%
Debt	50	%	51	%	50	%

Duke Energy’s fixed charges coverage ratio, calculated using SEC guidelines, was 3.2 times for 2014, 3.0 times for 2013, and 2.4 times for 2012.

Restrictive Debt Covenants

Duke Energy’s debt and credit agreements contain various financial and other covenants. The Master Credit Facility contains a covenant requiring the debt-to-total capitalization ratio to not exceed 65 percent for each borrower. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements or sublimits thereto. As of December 31, 2014, Duke Energy was in compliance with all covenants related to its significant debt agreements. In addition, some credit agreements may allow for acceleration of payments or termination of the agreements due to nonpayment, or to the acceleration of other significant indebtedness of the borrower or some of its subsidiaries. None of the debt or credit agreements contain material adverse change clauses.

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Credit Ratings

The Duke Energy Registrants each hold credit ratings by Fitch Ratings, Inc. (Fitch), Moody’s Investors Service, Inc. (Moody’s) and Standard & Poor’s Rating Services (S&P). The following table includes Duke Energy and certain subsidiaries’ credit ratings and ratings outlook as of February 2015.

	Fitch	Moody's	S&P
Duke Energy Corporation	Stable	Stable	Positive
Issuer Credit Rating	BBB+	A3	BBB+
Senior Unsecured Debt	BBB+	A3	BBB
Commercial Paper	F-2	P-2	A-2
Duke Energy Carolinas	Positive	Stable	Positive
Senior Secured Debt	A+	Aa2	A
Senior Unsecured Debt	A	A1	BBB+
Progress Energy	Stable	Stable	Positive
Senior Unsecured Debt	BBB	Baa1	BBB
Duke Energy Progress	Stable	Stable	Positive
Senior Secured Debt	A+	Aa2	A
Senior Unsecured Debt	A	A1	BBB+
Duke Energy Florida	Stable	Stable	Positive
Senior Secured Debt	A	A1	A
Senior Unsecured Debt	A-	A3	BBB+
Duke Energy Ohio	Stable	Stable	Positive
Senior Secured Debt	A	A2	A
Senior Unsecured Debt	A-	Baa1	BBB+
Duke Energy Indiana	Stable	Stable	Positive
Senior Secured Debt	A	Aa3	A
Senior Unsecured Debt	A-	A2	BBB+

Credit ratings are intended to provide credit lenders a framework for comparing the credit quality of securities and are not a recommendation to buy, sell or hold. The Duke Energy Registrants’ credit ratings are dependent on the rating agencies’ assessments of their ability to meet their debt principal and interest obligations when they come due. If, as a result of market conditions or other factors, the Duke Energy Registrants are unable to maintain current balance sheet strength, or if earnings and cash flow outlook materially deteriorates, credit ratings could be negatively impacted.

Cash Flow Information

The following table summarizes Duke Energy’s cash flows for the three most recently completed fiscal years.

	Years Ended December 31,
(in millions)	2014			2013			2012
Cash flows provided by (used in):
Operating activities	$	6,586		$	6,382		$	5,244
Investing activities	(5,373		)	(4,978		)	(6,197		)
Financing activities	(678		)	(1,327		)	267
Net increase (decrease) in cash and cash equivalents	535			77			(686		)
Cash and cash equivalents at beginning of period	1,501			1,424			2,110
Cash and cash equivalents at end of period	$	2,036		$	1,501		$	1,424

OPERATING CASH FLOWS

The following table summarizes key components of Duke Energy’s operating cash flows for the three most recently completed fiscal year.

	Years Ended December 31,
(in millions)	2014			2013			2012
Net income	$	1,889		$	2,676		$	1,782
Non-cash adjustments to net income	5,366			4,876			3,769
Contributions to qualified pension plans	—			(250		)	(304		)
Working capital	(669		)	(920		)	(3		)
Net cash provided by operating activities	$	6,586		$	6,382		$	5,244

For the year ended December 31, 2014 compared to 2013, the variance was driven primarily by:

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* A $204 million increase due to prior year contributions to qualified pension plans, favorable retail pricing and rate riders and favorable weather, partially offset by current year under collection of fuel and purchased power costs and timing of cash payments for operations and maintenance expenses.

For the year ended December 31, 2013 compared to 2012, the variance was driven primarily by:

* A $2,001 million increase in net income after non-cash adjustments, mainly due to the inclusion of Progress Energy's results for first six months of 2013 and the impact of revised rates and lower operation and maintenance expenses, partially offset by;

* A $917 million decrease in operating cash flows from increased investments in traditional working capital, mainly due to the timing of receivables and accruals, lower incentive accruals, net of current year payments and reserve reductions and the prior year overallocation of the Carolinas' fuels costs. These decreases were partially offset by the NEIL proceeds.

INVESTING CASH FLOWS

The following table summarizes key components of Duke Energy’s investing cash flows for the three most recently completed fiscal years.

	Years Ended December 31,
(in millions)	2014			2013			2012
Capital, investment and acquisition expenditures	$	(5,528	)	$	(5,607	)	$	(5,958	)
Available for sale securities, net	23			173			(182		)
Proceeds from sales of equity investments and other assets, and sales of and collections on notes receivable	179			277			212
Other investing items	(47		)	179			(269		)
Net cash used in investing activities	$	(5,373	)	$	(4,978	)	$	(6,197	)

The primary use of cash related to investing activities is capital, investment and acquisition expenditures, detailed by reportable business segment in the following table.

	Years Ended December 31,
(in millions)	2014		2013		2012
Regulated Utilities	$	4,744	$	5,049	$	4,220
Commercial Power	67		268		1,038
International Energy	555		67		551
Other	162		223		149
Total capital, investment and acquisition expenditures	$	5,528	$	5,607	$	5,958

For the year ended December 31, 2014 compared to 2013, the variance was driven primarily by:

* A $192 million return of collateral related to the Chilean hydro acquisition in 2013 and

* A $150 million decrease in net proceeds from sales and maturities of available for sale securities, net of purchases.

For the year ended December 31, 2013 compared to 2012, the variance was driven primarily by:

* A $581 million variance in restricted cash due to posting collateral on a secured debt issuance related to the Chilean hydro acquisition in 2012 and the return of a portion of this collateral in 2013,

* A $355 million increase in proceeds from the sales of available-for-sale securities, net of purchases due to the investment of excess cash held in foreign jurisdictions and

* A $351 million decrease in capital, investment and acquisition expenditures primarily due to lower spending on Duke Energy's renewable energy projects and ongoing infrastructure modernization program as these projects were completed, net of expenditures on Progress Energy's maintenance projects.

FINANCING CASH FLOWS

The following table summarizes key components of Duke Energy’s financing cash flows for the three most recently completed fiscal years.

	Years Ended December 31,
(in millions)	2014			2013			2012
Issuance of common stock related to employee benefit plans	$	25		$	9		$	23
Issuance of long-term debt, net	(123		)	840			1,672
Notes payable and commercial paper	1,688			93			278
Dividends paid	(2,234		)	(2,188		)	(1,752		)
Other financing items	(34		)	(81		)	46
Net cash (used in) provided by financing activities	$	(678	)	$	(1,327	)	$	267

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For the year ended December 31, 2014 compared to 2013, the variance was driven primarily by:

* A $1,595 million increase in proceeds from net issuances of notes payable and commercial paper, primarily due to funding a larger proportion of total financing needs with short-term debt in anticipation of the receipt in 2015 of proceeds from the sale of the Midwest Generation business, the proceeds from which will partially be used for debt reduction, partially offset by;

* A $963 million decrease in net issuances of long-term debt, primarily due to funding a larger proportion of total financing needs with short-term debt in 2014 than in 2013.

For the year ended December 31, 2013 compared to 2012, the variance was driven primarily by:

* An $832 million decrease in net issuances of long-term debt, primarily due to the timing of issuances and redemptions between years, resulting from the completion of major construction projects,

* A $436 million increase in quarterly dividends primarily due to an increase in common shares outstanding, resulting from the merger with Progress Energy and an increase in dividends per share from $0.765 to $0.78 in the third quarter of 2013. The total annual dividend per share was $3.09 in 2013 compared to $3.03 in 2012 and

* A $185 million decrease in proceeds from net issuances of notes payable and commercial paper, primarily due to changes in short-term working capital needs.

Summary of Significant Debt Issuances

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

				Year Ended December 31, 2014
Issuance Date	Maturity Date	Interest Rate		Duke Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy
Unsecured Debt
April 2014(a)	April 2024	3.750	%	$	600	$	—	$	—	$	600
April 2014(a)(b)	April 2017	0.613	%	400		—		—		400
June 2014(c)	May 2019	11.970	%	—		—		—		108
June 2014(c)	May 2021	13.680	%	—		—		—		110
Secured Debt
March 2014(d)	March 2017	0.863	%	—		—		225		225
July 2014(e)	July 2036	5.340	%	—		—		—		129
First Mortgage Bonds
March 2014(f)	March 2044	4.375	%	—		400		—		400
March 2014(f)(g)	March 2017	0.435	%	—		250		—		250
November 2014(h)	December 2044	4.150	%	—		500		—		500
November 2014(g)(h)	November 2017	0.432	%	—		200		—		200
Total issuances				$	1,000	$	1,350	$	225	$	2,922

(a) Proceeds were used to redeem $402 million of tax-exempt bonds at Duke Energy Ohio, the repayment of outstanding commercial paper and for general corporate purposes. See Note 13 to the Consolidated Financial Statements, "Related Party Transactions" for additional information related to the redemption of Duke Energy Ohio's tax-exempt bonds.

(b) The debt is floating rate based on three-month London Interbank Offered Rate (LIBOR) plus a fixed credit spread of 38 basis points.

(c) Proceeds were used to repay $196 million of debt for International Energy and for general corporate purposes.

(d) Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Florida. Proceeds were used to repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes. See Note 17 to the Consolidated Financial Statements, "Variable Interest Entities" for further details.

(e) Proceeds were used to fund a portion of Duke Energy's prior investment in the existing Wind Star renewables portfolio.

(f) Proceeds were used to repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes.

(g) The debt is floating rate based on three-month LIBOR plus a fixed credit spread of 20 basis points.

(h) Proceeds will be used to repay to redeem $450 million of tax-exempt bonds, repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes.

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				Year Ended December 31, 2013
Issuance Date	Maturity Date	Interest Rate		Duke Energy (Parent)		Duke Energy Progress		Duke Energy Ohio		Duke Energy Indiana		Duke Energy
Unsecured Debt
January 2013(a)	January 2073	5.125	%	$	500	$	—	$	—	$	—	$	500
June 2013(b)	June 2018	2.100	%	500		—		—		—		500
August 2013(c)(d)	August 2023	11.000	%	―		—		—		—		220
October 2013(e)	October 2023	3.950	%	400		—		—		—		400
Secured Debt
February 2013(f)(g)	December 2030	2.043	%	—		—		—		—		203
February 2013(f)	June 2037	4.740	%	—		—		—		—		220
April 2013(h)	April 2026	5.456	%	—		—		—		—		230
December 2013(i)	December 2016	0.852	%	—		300		—		—		300
First Mortgage Bonds
March 2013(j)	March 2043	4.100	%	—		500		—		—		500
July 2013(k)	July 2043	4.900	%	—		—		—		350		350
July 2013(k)(l)	July 2016	0.619	%	—		—		—		150		150
September 2013(m)	September 2023	3.800	%	—		—		300		—		300
September 2013(m)(n)	March 2015	0.400	%	—		—		150		—		150
Total issuances				$	1,400	$	800	$	450	$	500	$	4,023

(a) Callable after January 2018 at par. Proceeds were used to redeem the $300 million 7.10 percent Cumulative Quarterly Income Preferred Securities (QUIPS) and to repay a portion of outstanding commercial paper and for general corporate purposes.

(b) Proceeds were used to repay $250 million of current maturities and for general corporate purposes, including the repayment of outstanding commercial paper.

(c) Proceeds were used to repay $200 million of current maturities. The maturity date included above applies to half of the instrument. The remaining half matures in August 2018.

(d) The debt is floating rate based on a consumer price index and an overnight funds rate in Brazil. The debt is denominated in Brazilian Real.

(e) Proceeds were used to repay commercial paper as well as for general corporate purposes.

(f) Represents the conversion of construction loans related to a renewable energy project issued in December 2012 to term loans. No cash proceeds were received in conjunction with the conversion. The term loans have varying maturity dates. The maturity date presented represents the latest date for all components of the respective loans.

(g) The debt is floating rate. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 95 percent of the loans.

(h) Represents the conversion of a $190 million bridge loan issued in conjunction with the acquisition of Ibener in December 2012. Duke Energy received incremental proceeds of $40 million upon conversion of the bridge loan. The debt is floating rate and is denominated in U.S. dollars. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 75 percent of the loan.

(i) Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Progress; the proceeds were used to repay short-term debt. See Note 17 to the Consolidated Financial Statements, "Variable Interest Entities" for further details.

(j) Proceeds were used to repay notes payable to affiliated companies as well as for general corporate purposes.

(k) Proceeds were used to repay $400 million of current maturities.

(l) The debt is floating rate based on 3-month LIBOR and a fixed credit spread of 35 basis points.

(m) Proceeds were used for general corporate purposes including the repayment of short-term notes payable, a portion of which was incurred to fund the retirement of $250 million of first mortgage bonds that matured in the first half of 2013.

(n) The debt is floating rate based on 3-month LIBOR plus a fixed credit spread of 14 basis points.

Off-Balance Sheet Arrangements

Duke Energy and certain of its subsidiaries enter into guarantee arrangements in the normal course of business to facilitate commercial transactions with third parties. These arrangements include performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and indemnifications.

Most of the guarantee arrangements entered into by Duke Energy enhance the credit standing of certain subsidiaries, non-consolidated entities or less than wholly owned entities, enabling them to conduct business. As such, these guarantee arrangements involve elements of performance and credit risk, which are not always included on the Consolidated Balance Sheets. The possibility of Duke Energy, either on its own or on behalf of Spectra Energy Capital, LLC (Spectra Capital) through indemnification agreements entered into as part of the January 2, 2007 spin-off of Spectra Energy Corp (Spectra Energy), having to honor its contingencies is largely dependent upon the future operations of the subsidiaries, investees and other third parties, or the occurrence of certain future events.

Duke Energy performs ongoing assessments of their respective guarantee obligations to determine whether any liabilities have been incurred as a result of potential increased non-performance risk by third parties for which Duke Energy has issued guarantees.

See Note 7 to the Consolidated Financial Statements, “Guarantees and Indemnifications,” for further details of the guarantee arrangements.

Issuance of these guarantee arrangements is not required for the majority of Duke Energy’s operations. Thus, if Duke Energy discontinued issuing these guarantees, there would not be a material impact to the consolidated results of operations, cash flows or financial position.

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Other than the guarantee arrangements discussed above and normal operating lease arrangements, Duke Energy does not have any material off-balance sheet financing entities or structures. For additional information on these commitments, see Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies.”

Contractual Obligations

Duke Energy enters into contracts that require payment of cash at certain specified periods, based on certain specified minimum quantities and prices. The following table summarizes Duke Energy’s contractual cash obligations as of December 31, 2014.

	Payments Due By Period
(in millions)	Total		Less than 1 year (2015)		2-3 years (2016 & 2017)		4-5 years (2018 & 2019)		More than 5 years (2020 & beyond)
Long-Term debt(a)	$	36,617	$	2,691	$	5,204	$	5,761	$	22,961
Interest payments on long-term debt(b)	24,064		1,603		2,926		2,614		16,921
Capital leases(c)	2,733		178		378		406		1,771
Operating leases(c)	1,818		205		370		305		938
Purchase obligations:(d)
Fuel and purchased power(e)	21,128		4,778		5,838		3,171		7,341
Other purchase obligations(f)	7,418		4,074		1,269		519		1,556
Nuclear decommissioning trust annual funding(g)	345		33		67		29		216
Total contractual cash obligations(h)(i)	$	94,123	$	13,562	$	16,052	$	12,805	$	51,704

(a) See Note 6 to the Consolidated Financial Statements, “Debt and Credit Facilities.”

(b) Interest payments on variable rate debt instruments were calculated using December 31, 2014 interest rates and holding them constant for the life of the instruments.

(c) See Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies.” Amounts in the table above include the interest component of capital leases based on the interest rates stated in the lease agreements and exclude certain related executory costs.

(d) Current liabilities, except for current maturities of long-term debt, and purchase obligations reflected in the Consolidated Balance Sheets, have been excluded from the above table.

(e) Includes firm capacity payments that provide Duke Energy with uninterrupted firm access to electricity transmission capacity and natural gas transportation contracts, as well as undesignated contracts and contracts that qualify as normal purchase/normal sale (NPNS). For contracts where the price paid is based on an index, the amount is based on market prices at December 31, 2014, or the best projections of the index. For certain of these amounts, Duke Energy may settle on a net cash basis since Duke Energy has entered into payment netting arrangements with counterparties that permit Duke Energy to offset receivables and payables with such counterparties.

(f) Includes contracts for software, telephone, data and consulting or advisory services. Amount also includes contractual obligations for engineering, procurement and construction costs for new generation plants and nuclear plant refurbishments, environmental projects on fossil facilities, major maintenance of certain nonregulated plants, maintenance and day to day contract work at certain wind facilities and commitments to buy wind and combustion turbines. Amount excludes certain open purchase orders for services that are provided on demand, for which the timing of the purchase cannot be determined.

(g) Related to future annual funding obligations to nuclear decommissioning trust fund (NDTF) through nuclear power stations' re-licensing dates. Amounts through 2017 include North Carolina jurisdictional amounts that Duke Energy Progress retained internally and is transitioning to its external decommissioning funds per a 2008 NCUC order. The transition of the original $131 million must be complete by December 31, 2017, and at least 10 percent must be transitioned each year. See Note 9 to the Consolidated Financial Statements, "Asset Retirement Obligations."

(h) Uncertain tax positions of $213 million are not reflected in this table as Duke Energy cannot predict when open income tax years will close with completed examinations. See Note 22 to the Consolidated Financial Statements, "Income Taxes."

(i) The table above excludes reserves for litigation, environmental remediation, asbestos-related injuries and damages claims and self-insurance claims (see Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies”) because Duke Energy is uncertain as to the timing and amount of cash payments that will be required. Additionally, the table above excludes annual insurance premiums that are necessary to operate the business, including nuclear insurance (see Note 5 to the Consolidated Financial Statements, “Commitments and Contingencies”), funding of pension and other post-retirement benefit plans (see Note 21 to the Consolidated Financial Statements, "Employee Benefit Plans"), asset retirement obligations, including ash management expenditures (see Note 9 to the Consolidated Financial Statements, "Asset Retirement Obligations") and regulatory liabilities (see Note 4 to the Consolidated Financial Statements, “Regulatory Matters”) because the amount and timing of the cash payments are uncertain. Also excluded are Deferred Income Taxes and Investment Tax Credits recorded on the Consolidated Balance Sheets since cash payments for income taxes are determined based primarily on taxable income for each discrete fiscal year.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Risk Management Policies

Duke Energy is exposed to market risks associated with commodity prices, interest rates, equity prices and foreign currency exchange rates. Duke Energy has established comprehensive risk management policies to monitor and manage these market risks. Duke Energy’s Chief Executive Officer and Chief Financial Officer are responsible for the overall approval of market risk management policies and the delegation of approval and authorization levels. The Finance and Risk Management Committee of the Board of Directors receives periodic updates from the Chief Risk Officer and other members of management on market risk positions, corporate exposures, and overall risk management activities. The Chief Risk Officer is responsible for the overall governance of managing commodity price risk, including monitoring exposure limits.

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The following disclosures about market risk contain forward-looking statements that involve estimates, projections, goals, forecasts, assumptions, risks and uncertainties that could cause actual results or outcomes to differ materially from those expressed in the forward-looking statements. Please review Item 1A, “Risk Factors,” and “Cautionary Statement Regarding Forward-Looking Information” for a discussion of the factors that may impact any such forward-looking statements made herein.

Commodity Price Risk

Duke Energy is exposed to the impact of market fluctuations in the prices of electricity, coal, natural gas and other energy-related products marketed and purchased as a result of its ownership of energy related assets. Duke Energy’s exposure to these fluctuations is limited by the cost-based regulation of its operations in its Regulated Utilities segment as these operations are typically allowed to recover substantially all of these costs through various cost-recovery clauses, including fuel clauses. While there may be a delay in timing between when these costs are incurred and when these costs are recovered through rates, changes from year to year generally do not have a material impact on operating results of these regulated operations.

Price risk represents the potential risk of loss from adverse changes in the market price of electricity or other energy commodities. Duke Energy’s exposure to commodity price risk is influenced by a number of factors, including contract size, length, market liquidity, location and unique or specific contract terms. Duke Energy employs established policies and procedures to manage risks associated with these market fluctuations, which may include using various commodity derivatives, such as swaps, futures, forwards and options. For additional information, see Note 14 to the Consolidated Financial Statements, “Derivatives and Hedging.”

Validation of a contract’s fair value is performed by an internal group separate from Duke Energy’s deal origination function. While Duke Energy uses common industry practices to develop its valuation techniques, changes in its pricing methodologies or the underlying assumptions could result in significantly different fair values and income recognition.

Hedging Strategies

Duke Energy closely monitors risks associated with commodity price changes on its future operations and, where appropriate, uses various commodity instruments such as electricity, coal and natural gas forward contracts to mitigate the effect of such fluctuations on operations. These instruments are also used to optimize the value of the nonregulated generation portfolio. Duke Energy’s primary use of energy commodity derivatives is to hedge the generation portfolio against exposure to the prices of power and fuel.

The majority of instruments used to manage Duke Energy’s commodity price exposure are either not designated as hedges or do not qualify for hedge accounting. These instruments are referred to as undesignated contracts. Mark-to-market changes for undesignated contracts entered into by regulated businesses are reflected as regulatory assets or liabilities on the Consolidated Balance Sheets. Undesignated contracts entered into by unregulated businesses are marked-to-market each period, with changes in the fair value of the derivative instruments reflected in earnings.

Duke Energy may also enter into other contracts that qualify for the NPNS exception. When a contract meets the criteria to qualify as an NPNS, Duke Energy applies such exception. Income recognition and realization related to NPNS contracts generally coincide with the physical delivery of the commodity. For contracts qualifying for the NPNS exception, no recognition of the contract’s fair value in the Consolidated Financial Statements is required until settlement of the contract as long as the transaction remains probable of occurring.

Generation Portfolio Risks 

Duke Energy is primarily exposed to market price fluctuations of wholesale power, natural gas, and coal prices in the Regulated Utilities segment. The Duke Energy Registrants optimize the value of their wholesale and nonregulated generation portfolios. The portfolios include generation assets, fuel, and emission allowances. Modeled forecasts of future generation output and fuel requirements are based on forward power and fuel markets. The component pieces of the portfolio are bought and sold based on models and forecasts of generation in order to manage the economic value of the portfolio in accordance with the strategies of the business units.

For the Regulated Utilities segment, the generation portfolio not utilized to serve retail operations or committed load is subject to commodity price fluctuations. However, the impact on the Consolidated Statements of Operations is partially offset by mechanisms in these regulated jurisdictions that result in the sharing of net profits from these activities with retail customers.

International Energy and Commercial Power generally hedge their expected generation using long-term bilateral power sales contracts when favorable market conditions exist and are subject to wholesale commodity price risks for electricity not sold under such contracts. International Energy dispatches electricity not sold under long-term bilateral contracts into unregulated markets and receives wholesale energy margins and capacity revenues from national system operators. Derivative contracts executed to manage generation portfolio risks for delivery periods beyond 2015 are also exposed to changes in fair value due to market price fluctuations of wholesale power, fuel oil and coal.

See “Sensitivity Analysis for Generation Portfolio and Derivative Price Risks” below, for more information regarding the effect of changes in commodity prices on Duke Energy’s net income.

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SENSITIVITY ANALYSIS FOR GENERATION PORTFOLIO AND DERIVATIVE PRICE RISKS

The table below summarizes the estimated effect of commodity price changes on Duke Energy’s pretax net income, based on a sensitivity analysis performed for the nonregulated generation portfolio. Forecasted exposure to commodity price risk for the Regulated Utilities segment is not anticipated to have a material adverse effect on Duke Energy’s results of operations in 2015. The following commodity price sensitivity calculations consider existing hedge positions and estimated production levels, as indicated in the table below, but do not consider other potential effects that might result from such changes in commodity prices.

Summary of Sensitivity Analysis for Generation Portfolio and Derivative Price Risks (in millions)

	Generation Portfolio Risks for 2015 As of December 31,(a)				Sensitivities for Derivatives Beyond 2015 As of December 31,(b)
Potential effect on pretax net income assuming a 10 percent price change in	2014		2013		2014		2013
Forward wholesale power prices (based on price per MWh)	$	4	$	1	$	—	$	—

(a)    Amounts related to forward wholesale prices represent the potential impact of commodity price changes on forecasted

economic generation which has not been contracted or hedged. Amounts related to forward coal prices and forward gas prices represent the potential impact of commodity price changes on fuel needed to achieve such economic generation. Amounts exclude the impact of mark-to-market changes on undesignated contracts relating to periods in excess of one year from the respective date.

(b) Amounts represent sensitivities related to derivative contracts executed to manage generation portfolio risks for periods beyond 2014. Amounts exclude the potential impact of commodity price changes on forecasted economic generation and fuel needed to achieve such forecasted generation.  

Interest Rate Risk

Duke Energy is exposed to risk resulting from changes in interest rates as a result of its issuance of variable and fixed-rate debt and commercial paper. Duke Energy manages interest rate exposure by limiting variable-rate exposures to a percentage of total debt and by monitoring the effects of market changes in interest rates. Duke Energy also enters into financial derivative instruments, which may include instruments such as, but not limited to, interest rate swaps, swaptions and U.S. Treasury lock agreements to manage and mitigate interest rate risk exposure. See Notes 1, 6, 14, and 16 to the Consolidated Financial Statements, “Summary of Significant Accounting Policies,” “Debt and Credit Facilities,” “Derivatives and Hedging,” and “Fair Value Measurements.”

At December 31, 2014, Duke Energy had $250 million notional amount of fixed-to-floating swaps outstanding and no pre-issuance hedges outstanding. In the first quarter of 2015, Duke Energy entered into an additional $250 million notional amount of fixed-to-floating swaps. Duke Energy had $6.9 billion of unhedged long- and short-term floating interest rate exposure at December 31, 2014. The impact of a 100 basis point change in interest rates on pretax income is approximately $72 million at December 31, 2014.

This amount was estimated by considering the impact of the hypothetical interest rates on variable-rate securities outstanding, adjusted for interest rate hedges as of December 31, 2014.

Credit Risk

Credit risk represents the loss that the Duke Energy Registrants would incur if a counterparty fails to perform under its contractual obligations. To reduce credit exposure, the Duke Energy Registrants seek to enter into netting agreements with counterparties that permit them to offset receivables and payables with such counterparties. The Duke Energy Registrants attempt to further reduce credit risk with certain counterparties by entering into agreements that enable obtaining collateral or terminating or resetting the terms of transactions after specified time periods or upon the occurrence of credit-related events. The Duke Energy Registrants may, at times, use credit derivatives or other structures and techniques to provide for third-party credit enhancement of their counterparties’ obligations. The Duke Energy Registrants also obtain cash or letters of credit from customers to provide credit support outside of collateral agreements, where appropriate, based on a financial analysis of the customer and the regulatory or contractual terms and conditions applicable to each transaction. See Note 14 to the Consolidated Financial Statements, “Derivatives and Hedging,” for additional information regarding credit risk related to derivative instruments.

The Duke Energy Registrants’ industry has historically operated under negotiated credit lines for physical delivery contracts. The Duke Energy Registrants frequently use master collateral agreements to mitigate certain credit exposures. The collateral agreements provide for a counterparty to post cash or letters of credit to the exposed party for exposure in excess of an established threshold. The threshold amount represents a negotiated unsecured credit limit for each party to the agreement, determined in accordance with the Duke Energy Registrants’ internal corporate credit practices and standards. Collateral agreements generally also provide that the inability to post collateral is sufficient cause to terminate contracts and liquidate all positions.

The Duke Energy Registrants’ principal customers for its electric and gas businesses are commodity clearinghouses, regional transmission organizations, industrial, commercial and residential end-users, marketers, distribution companies, municipalities, electric cooperatives and utilities located throughout the U.S. and Latin America. The Duke Energy Registrants have concentrations of receivables from such entities throughout these regions. These concentrations of customers may affect the Duke Energy Registrants’ overall credit risk in that risk factors can negatively impact the credit quality of the entire sector. Where exposed to credit risk, the Duke Energy Registrants analyze the counterparties’ financial condition prior to entering into an agreement, establish credit limits and monitor the appropriateness of those limits on an ongoing basis.

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Duke Energy Carolinas has a third-party insurance policy to cover certain losses related to its asbestos-related injuries and damages above an aggregate self-insured retention of $476 million. Duke Energy Carolinas’ cumulative payments began to exceed the self-insurance retention on its insurance policy during the second quarter of 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 for indemnification and medical cost claim payments is $864 million in excess of the self-insured retention. Insurance recoveries of $616 million and $649 million related to this policy are classified in the Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables as of December 31, 2014 and 2013, respectively. Duke Energy Carolinas is not aware of any uncertainties regarding the legal sufficiency of insurance claims. Management believes the insurance recovery asset is probable of recovery as the insurance carrier continues to have a strong financial strength rating.

The Duke Energy Registrants also have credit risk exposure through issuance of performance guarantees, letters of credit and surety bonds on behalf of less than wholly owned entities and third parties. Where the Duke Energy Registrants have issued these guarantees, it is possible that they could be required to perform under these guarantee obligations in the event the obligor under the guarantee fails to perform. Where the Duke Energy Registrants have issued guarantees related to assets or operations that have been disposed of via sale, they attempt to secure indemnification from the buyer against all future performance obligations under the guarantees. See Note 7 to the Consolidated Financial Statements, “Guarantees and Indemnifications,” for further information on guarantees issued by the Duke Energy Registrants.

The Duke Energy Registrants are also subject to credit risk of their vendors and suppliers in the form of performance risk on contracts including, but not limited to, outsourcing arrangements, major construction projects and commodity purchases. The Duke Energy Registrants’ credit exposure to such vendors and suppliers may take the form of increased costs or project delays in the event of non-performance.

Credit risk associated with the Duke Energy Registrants’ service to residential, commercial and industrial customers is generally limited to outstanding accounts receivable. The Duke Energy Registrants mitigate this credit risk by requiring customers to provide a cash deposit or letter of credit until a satisfactory payment history is established, subject to the rules and regulations in effect in each retail jurisdiction, at which time the deposit is typically refunded. Charge-offs for retail customers have historically been insignificant to the operations of the Duke Energy Registrants and are typically recovered through the retail rates. Management continually monitors customer charge-offs and payment patterns to ensure the adequacy of bad debt reserves. Duke Energy Ohio and Duke Energy Indiana sell certain of their accounts receivable and related collections through CRC, a Duke Energy consolidated variable interest entity. Losses on collection are first absorbed by the equity of CRC and next by the subordinated retained interests held by Duke Energy Ohio, Duke Energy Kentucky and Duke Energy Indiana. See Note 17 to the Consolidated Financial Statements, “Variable Interest Entities.”

Based on the Duke Energy Registrants’ policies for managing credit risk, their exposures and their credit and other reserves, the Duke Energy Registrants do not currently anticipate a materially adverse effect on their consolidated financial position or results of operations as a result of non-performance by any counterparty.

Marketable Securities Price Risk

As described further in Note 15 to the Consolidated Financial Statements, “Investments in Debt and Equity Securities,” Duke Energy invests in debt and equity securities as part of various investment portfolios to fund certain obligations. The vast majority of investments in equity securities are within the NDTF and assets of the various pension and other post-retirement benefit plans.

Pension Plan Assets

Duke Energy maintains investments to help fund the costs of providing non-contributory defined benefit retirement and other post-retirement benefit plans. These investments are exposed to price fluctuations in equity markets and changes in interest rates. The equity securities held in these pension plans are diversified to achieve broad market participation and reduce the impact of any single investment, sector or geographic region. Duke Energy has established asset allocation targets for its pension plan holdings, which take into consideration the investment objectives and the risk profile with respect to the trust in which the assets are held.

A significant decline in the value of plan asset holdings could require Duke Energy to increase funding of its pension plans in future periods, which could adversely affect cash flows in those periods. Additionally, a decline in the fair value of plan assets, absent additional cash contributions to the plan, could increase the amount of pension cost required to be recorded in future periods, which could adversely affect Duke Energy’s results of operations in those periods.

Nuclear Decommissioning Trust Funds

As required by the Nuclear Regulatory Commission (NRC), NCUC, PSCSC and FPSC, subsidiaries of Duke Energy maintain trust funds to fund the costs of nuclear decommissioning. As of December 31, 2014, these funds were invested primarily in domestic and international equity securities, debt securities, cash and cash equivalents and short-term investments. Per the NRC, Internal Revenue Code, NCUC, PSCSC and FPSC requirements, these funds may be used only for activities related to nuclear decommissioning. The investments in equity securities are exposed to price fluctuations in equity markets. Duke Energy actively monitors its portfolios by benchmarking the performance of its investments against certain indices and by maintaining, and periodically reviewing, target allocation percentages for various asset classes. Accounting for nuclear decommissioning recognizes that costs are recovered through retail rates; therefore, fluctuations in equity prices do not affect their Consolidated Statements of Operations as changes in the fair value of these investments are deferred as regulatory assets or regulatory liabilities pursuant to an Order by the NCUC, PSCSC and FPSC. Earnings or losses of the fund will ultimately impact the amount of costs recovered through retail rates. See Note 9 to the Consolidated Financial Statements, “Asset Retirement Obligations” for additional information regarding nuclear decommissioning costs. See Note 15 to the Consolidated Financial Statements, “Investments in Debt and Equity Securities” for additional information regarding NDTF assets.

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Foreign Currency Risk

Duke Energy is exposed to foreign currency risk from investments in international businesses owned and operated in foreign countries and from certain commodity-related transactions within domestic operations that are denominated in foreign currencies. To mitigate risks associated with foreign currency fluctuations, contracts may be denominated in or indexed to the U.S. dollar and/or local inflation rates, or investments may be naturally hedged through debt denominated or issued in the foreign currency. Duke Energy may also use foreign currency derivatives, where possible, to manage its risk related to foreign currency fluctuations. To monitor its currency exchange rate risks, Duke Energy uses sensitivity analysis, which measures the impact of devaluation of the foreign currencies to which it has exposure.

Duke Energy’s primary foreign currency rate exposure is to the Brazilian Real. The table below summarizes the potential effect of foreign currency devaluations on Duke Energy’s Consolidated Statement of Operations and Consolidated Balance Sheets, based on a sensitivity analysis performed as of December 31, 2014 and December 31, 2013.

Summary of Sensitivity Analysis for Foreign Currency Risks

	Assuming 10 percent devaluation in the currency exchange rates in all exposure currencies
	As of December 31,
(in millions)	2014			2013
Income Statement impact(a)	$	(20	)	$	(20	)
Balance Sheet impact(b)	(98		)	(140		)

(a)    Amounts represent the potential annual net pretax loss on the translation of local currency earnings to the U.S. dollar in

2014 and 2013, respectively.

(b) Amounts represent the potential impact to the currency translation through Accumulated Other Comprehensive Income (AOCI) on the Consolidated Balance Sheets.

OTHER MATTERS

Ratios of Earnings to Fixed Charges

The Duke Energy Registrants’ ratios of earnings to fixed charges, as calculated using SEC guidelines, are included in the table below.

	Years Ended December 31,
	2014	2013	2012
Duke Energy(a)	3.2	3.0	2.4
Duke Energy Carolinas	4.6	4.4	3.8
Progress Energy	2.7	2.2	1.6
Duke Energy Progress	3.5	3.7	2.3
Duke Energy Florida	4.1	2.9	2.3
Duke Energy Ohio	2.1	2.2	1.7
Duke Energy Indiana	4.1	4.1	0.3

(a) Includes the results of Progress Energy beginning on July 2, 2012.

Midwest Generation Exit

Merchant power plants have, in the recent past, delivered volatile returns in the competitive energy markets in the Midwest. In Ohio, the Public Utilities Commission of Ohio (PUCO) had granted revenue support from regulated retail markets to help stabilize returns during the transition to competitive markets. However, in early 2014, a request for continued revenue support was denied by the PUCO. This decision made it clear the energy markets in Ohio were to be fully unregulated. Although the undiscounted cash flows recover the carrying value of the Midwest Generation assets, the recovery period is over a long period of time, with risks inherent in operating these assets in competitive energy markets and in an ever changing landscape of environmental regulations related to fossil fuel based generation sources. Management concluded in early 2014 that the projected risk and earnings profile of these assets was no longer consistent with Duke Energy’s strategy and initiated a plan to sell these assets and realize the fair value over a shorter period while reducing the risk and volatility associated with these assets.

On August 21, 2014, Duke Energy Commercial Enterprises, Inc., an indirect wholly owned subsidiary of Duke Energy Corporation, and Duke Energy SAM, LLC, a wholly owned subsidiary of Duke Energy Ohio, entered into a PSA with a subsidiary of Dynegy whereby Dynegy will acquire Duke Energy’s Disposal Group for approximately $2.8 billion in cash subject to adjustments at closing for changes in working capital and capital expenditures. The completion of the transaction is conditioned on approval by FERC and the release of certain credit support obligations. The transaction is expected to close by the end of the second quarter of 2015. For additional information on the Midwest generation business disposition see Note 2 to the Consolidated Financial Statements, "Acquisitions, Dispositions and Sales of Other Assets."

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North Carolina Ash Basins

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy Carolinas’ retired Dan River steam station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe, stopping the release of materials into the river. Duke Energy Carolinas estimates 30,000 to 39,000 tons of ash and 24 million to 27 million gallons of basin water were released into the river during the incident. For additional information see Note 5 to the Condensed Consolidated Financial Statements, "Commitments and Contingencies."

Environmental Regulations

Duke Energy is subject to international, federal, state, and local regulations regarding air and water quality, hazardous and solid waste disposal, and other environmental matters. The Subsidiary Registrants are subject to federal, state, and local regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These regulations can be changed from time to time and result in new obligations of the Duke Energy Registrants.

The following sections outline various proposed and recently enacted regulations that may impact the Duke Energy Registrants. The Duke Energy Registrants also expect to incur increased fuel, purchased power, operation and maintenance, and other costs for replacement generation for potential coal-fired power plant retirements as a result of these proposed and final regulations. The actual compliance costs may be materially different from these estimates based on the timing and requirements of the final EPA regulations. Refer to Note 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters," for further information regarding potential plant retirements and regulatory filings related to the Duke Energy Registrants.

Coal Ash Management Act of 2014

On September 20, 2014, the Coal Ash Act became law. The Coal Ash Act (i) establishes a Coal Ash Management Commission (Coal Ash Commission) to oversee handling of coal ash within the state; (ii) prohibits construction of new and expansion of existing ash impoundments and use of existing impoundments at retired facilities, effective October 1, 2014; (iii) requires closure of ash impoundments at Duke Energy Progress' Asheville and Sutton stations and Duke Energy Carolinas' Riverbend and Dan River stations no later than August 1, 2019; (iv) requires dry disposal of fly ash at active plants not retired by December 31, 2018; (v) requires dry disposal of bottom ash at active plants by December 31, 2019, or retirement of active plants; (vi) requires all remaining ash impoundments in North Carolina to be categorized as high-risk, intermediate-risk, or low-risk no later than December 31, 2015 by The North Carolina Department of Environment and Natural Resources (DENR) with the method of closure and timing to be based upon the assigned risk, with closure no later than December 31, 2029; (vii) establishes requirements to deal with groundwater and surface water impacts from impoundments and (viii) enhances the level of regulation for structural fills utilizing coal ash. The Coal Ash Act includes a variance procedure for compliance deadlines and modification of requirements regarding structural fills and compliance boundaries. Provisions of the Coal Ash Act prohibit cost recovery for unlawful discharge of ash basin waters occurring after January 1, 2014. The Coal Ash Act included a moratorium for any NCUC ordered rate changes to effectuate the legislation, which ended January 15, 2015. The Coal Ash Act leaves the decision on cost recovery determinations related to closure of CCR surface impoundments (ash basins or impoundments) to the normal ratemaking processes before utility regulatory commissions. In November 2014, Duke Energy submitted to DENR site specific coal ash excavation plans for the four high priority stations required to be closed no later than August 1, 2019. These plans and all associated permits must be approved by DENR before any excavation work can begin.

In September 2014, Duke Energy Carolinas executed a consent agreement with the South Carolina Department of Health and Environmental Control (SCDHEC) requiring the excavation of an inactive ash basin and ash fill area at the W.S. Lee Steam Station. As part of this agreement, in December 2014, Duke Energy Carolinas filed an ash removal plan and schedule with SCDHEC.

For further information, refer to Note 5 of the Condensed Consolidated Financial Statements, “Commitments and Contingencies.”

Mercury and Air Toxics Standards

The final Mercury and Air Toxics Standards (MATS) rule, previously referred to as the Utility MACT Rule, was issued on February 16, 2012. The final rule establishes emission limits for hazardous air pollutants from new and existing coal-fired and oil-fired steam electric generating units. The rule requires sources to comply with emission limits by April 16, 2015. Under the Clean Air Act (CAA), permitting authorities have the discretion to grant up to a one-year compliance extension, on a case-by-case basis, to sources that are unable to complete the installation of emission controls before the compliance deadline. The Duke Energy Registrants have requested and received a number of compliance extensions. Strategies to achieve compliance with the final rule will include installation of new air emission control equipment, development of monitoring processes, fuel switching, and acceleration of retirement for some coal-fired electric-generation units. For additional information, refer to Note 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters," regarding potential plant retirements.

In April 2014, several petitions for review of the final rule were denied by the U.S. Court of Appeals for the District of Columbia (D.C. Circuit Court). On November 25, 2014, the Supreme Court granted a petition for review based on the issue of whether the EPA unreasonably refused to consider costs in determining whether it is appropriate to regulate hazardous air pollutants from coal-fired and oil-fired steam electric generating units. Oral arguments are scheduled for March 25, 2015. The Duke Energy Registrants cannot predict the outcome of the Supreme Court review of the D.C. Circuit Court decision and are planning for the rule to be implemented as promulgated given the imminent compliance deadline.

Clean Water Act 316(b)

The EPA published the final 316(b) cooling water intake structure rule on August 15, 2014, with an effective date of October 14, 2014. The rule applies to 27 of the electric generating facilities the Duke Energy Registrants own and operate depending on unit retirement dates, excluding stations included in the Disposal Group. The rule allows several options for demonstrating compliance and provides flexibility to the state environmental permitting agencies to make determinations on controls, if any, that will be required for cooling water intake structures. Any required intake structure modifications and/or retrofits are expected to be installed in the 2019 to 2022 timeframe. Petitions challenging the rule have been filed by several groups. It is unknown at this time when the courts will rule on the petitions.

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Steam Electric Effluent Limitation Guidelines

On June 7, 2013, the EPA proposed Steam Electric Effluent Limitations Guidelines. The EPA is under a revised court order to finalize the rule by September 30, 2015. The EPA has proposed eight options for the rule, which vary in stringency and cost. The proposed regulation applies to seven waste streams, including wastewater from air pollution control equipment and ash transport water. Most, if not all, of the steam electric generating facilities the Duke Energy Registrants own are likely affected sources. Requirements to comply with the final rule may begin as early as late 2018 for some facilities.

Estimated Cost and Impacts of Rulemakings

The ultimate compliance requirements for currently proposed environmental regulations will not be known until all the rules have been finalized. The Duke Energy Registrants also expect to incur increased fuel, purchased power, operation and maintenance, and other expenses, in addition to costs for replacement generation for potential coal-fired power plant retirements as a result of these regulations. The actual compliance costs incurred may be materially different from these estimates based on the timing and requirements of the final regulations. The Duke Energy Registrants intend to seek rate recovery of appropriate amounts incurred associated with regulated operations in complying with these regulations. Refer to Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters," for further information regarding potential plant retirements and regulatory filings related to the Duke Energy Registrants.

The following table provides estimated costs, excluding AFUDC, of new control equipment that may need to be installed on existing power plants, including conversion of plants to dry disposal of bottom ash and fly ash, to comply with the above regulations over the five years ended December 31, 2019. The table excludes amounts related to the Disposal Group and ash basin closure costs recorded as asset retirement obligations, for additional information refer to Note 9 of the Condensed Consolidated Financial Statements, "Asset Retirement Obligations." The table also does not include estimated ash basin closure costs to comply with the recently issued EPA regulations for the disposal of CCR from power plants.

(in millions)	Estimated 5 Year Cost
Duke Energy	$	1,850
Duke Energy Carolinas	675
Progress Energy	525
Duke Energy Progress	475
Duke Energy Florida	50
Duke Energy Ohio	75
Duke Energy Indiana	575

Coal Combustion Residuals

On December 19, 2014, the EPA signed the first federal regulation for the disposal of CCR from power plants. The federal regulation classifies CCR as nonhazardous waste under the Resource Conservation and Recovery Act. The regulation applies to all new and existing landfills, new and existing surface impoundments, structural fills and CCR piles. The rule establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. In addition to the requirements of the federal CCR regulation, CCR landfills and surface impoundments will continue to be independently regulated by most states. Duke Energy records an asset retirement obligation when it has a legal obligation to incur retirement costs associated with the retirement of a long-lived asset and the obligation can be reasonably estimated. Once the rule is effective in 2015, additional asset retirement obligation amounts will be recorded at all Duke registrants. Cost recovery for future expenditures will be pursued through the normal ratemaking process with state utility commissions, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations. At this time, Duke Energy is evaluating the CCR regulation and developing cost estimates that will largely be dependent upon compliance alternatives selected to meet requirements of the regulations. For more information, see Note 5 to the Condensed Consolidated Financial Statements, "Commitments and Contingencies."

Cross-State Air Pollution Rule

On August 8, 2011, the final Cross-State Air Pollution Rule (CSAPR) was published in the Federal Register. The CSAPR established state-level annual sulfur dioxide (SO₂₎ budgets and annual and seasonal nitrogen oxide (NO_x) budgets that were to take effect on January 1, 2012.

On August 21, 2012, the D.C. Circuit Court vacated the CSAPR. The court also directed the EPA to continue administering the Clean Air Interstate Rule (CAIR), which required additional reductions in SO₂ and NO_x emissions beginning in 2015. On April 29, 2014, the U.S. Supreme Court (Supreme Court) reversed the D.C. Circuit Court’s decision, finding that with CSAPR the EPA reasonably interpreted the good neighbor provision of the CAA. The case was remanded to the D.C. Circuit Court for further proceedings consistent with the Supreme Court’s opinion. On October 23, 2014, the D.C. Circuit Court lifted the CSAPR stay, which allowed Phase 1 of the rule to take effect on January 1, 2015, terminating the CAIR. Where the CSAPR requirements are constraining, actions to meet the requirements could include purchasing emission allowances, power purchases, curtailing generation and utilizing low sulfur fuel. The CSAPR will not result in Duke Energy Registrants adding new emission controls.

Additional challenges to the CSAPR filed in 2012, not addressed by the D.C. Circuit Court decision to vacate the CSAPR, are still ongoing. Oral arguments were held February 25, 2015. The Duke Energy Registrants cannot predict the outcome of these proceedings or how the requirements of the CSAPR may be impacted going forward.

Carbon Dioxide New Source Performance Standards

On January 8, 2014, the EPA proposed a rule to establish carbon dioxide (CO₂) emissions standards for new pulverized coal, IGCC, natural gas combined cycle, and simple cycle electric generating units commencing construction on or after that date. Based on the proposal, future coal and IGCC units will be required to employ carbon capture and storage technology to meet the proposed standard.

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In January 2015, the EPA announced that it would finalize the rule for new power plants in the summer of 2015. The Duke Energy Registrants do not expect a material impact on their future results of operations or cash flows based on the EPA’s proposal. The final rule, however, could be significantly different from the proposal.

CO₂ Existing Source Performance Standards and Standards for Reconstructed and Modified Units

On June 18, 2014, the EPA’s proposed Clean Power Plan (CPP) for regulating CO₂ emissions from existing fossil fuel-fired electric generating units (EGUs) was published in the Federal Register. On the same date the EPA proposed carbon pollution standards for reconstructed and modified EGUs. The comment period ended October 16, 2014 for the reconstructed and modified proposal and December 1, 2014 for the CPP. Duke Energy submitted comments on both proposals. In January 2015 the EPA announced that it would finalize both proposals in the summer of 2015.

Once the CPP is finalized, states will be required to develop plans to implement its requirements. The CPP will not directly impose any regulatory requirements on Duke Energy Registrants. State implementation plans will include the regulatory requirements that will apply to Duke Energy Registrants. Based on the EPA’s June 18, 2014 proposal, states will have from one to three years after the CPP is finalized to submit a plan for EPA’s review. In January 2015 the EPA announced that it would also propose a federal implementation plan for public comment in the summer of 2015. A federal plan would be EPA’s plan for meeting the requirements of the CPP and could take the place of a state plan if a state either fails to submit a plan or submits a plan that is not approved by the EPA.

The EPA has proposed to phase CO₂ emission reductions in over the period 2020 to 2030. The final requirements of the CPP, however, including the implementation schedule are uncertain and could be significantly different from the proposal. In addition, it will be several years before the requirements of the subsequent state plans are known. Also unknown at this time are the requirements of any federal plan that might be imposed on states in which the Duke Energy Registrants operate should a state fail to submit a plan or have their plan disapproved by the EPA. The Duke Energy Registrants are therefore unable to predict the outcome of this rulemaking, or how it might impact them, but the impact could be significant.

Global Climate Change

The Duke Energy Registrants’ greenhouse gas (GHG) emissions consist primarily of CO₂ with most coming from their fleet of coal-fired power plants in the U.S. In 2014, the Duke Energy Registrants’ U.S. power plants emitted approximately 135 million tons of CO₂. CO₂ emissions from Duke Energy’s international operations were approximately 2 million tons. The Duke Energy Registrants’ future CO₂ emissions will be influenced by variables including new regulations, economic conditions that affect electricity demand, and the Duke Energy Registrants’ decisions regarding generation technologies deployed to meet customer electricity needs.

The Duke Energy Registrants are taking actions that will result in reduced GHG emissions over time. These actions will lower the Duke Energy Registrants’ exposure to any future mandatory GHG emission reduction requirements or carbon tax, whether a result of federal legislation or EPA regulation. Under any future scenario involving mandatory GHG limitations, the Duke Energy Registrants would plan to seek recovery of compliance costs associated with their regulated operations through appropriate regulatory mechanisms.

The Duke Energy Registrants recognize certain groups associate severe weather events with climate change, and forecast the possibility these weather events could have a material impact on future results of operations should they occur more frequently and with greater severity. However, the uncertain nature of potential changes of extreme weather events (such as increased frequency, duration, and severity), the long period of time over which any potential changes might take place, and the inability to predict these with any degree of accuracy, make estimating any potential future financial risk to the Duke Energy Registrants’ impossible. Currently, the Duke Energy Registrants plan and prepare for extreme weather events they experience from time to time, such as ice storms, tornadoes, hurricanes, severe thunderstorms, high winds and droughts.

The Duke Energy Registrants routinely take steps to reduce the potential impact of severe weather events on their electric distribution systems. The Duke Energy Registrants’ electric generating facilities are designed to withstand extreme weather events without significant damage. The Duke Energy Registrants maintain an inventory of coal and oil on site to mitigate the effects of any potential short-term disruption in fuel supply so they can continue to provide customers with an uninterrupted supply of electricity. The Duke Energy Registrants have a program in place to effectively manage the impact of future droughts on their operations.

Nuclear Matters

Following the events at the Fukushima Daiichi nuclear power station in Japan, Duke Energy conducted thorough inspections at each of its seven nuclear sites during 2011. The initial inspections did not identify any significant vulnerabilities, however, Duke Energy is reviewing designs to evaluate safety margins to external events. Emergency-response capabilities, written procedures and engineering specifications were reviewed to verify each site’s ability to respond in the unlikely event of station blackout. Duke Energy is working within the nuclear industry to improve safety standards and margin using the three layers of safety approach used in the U.S.: protection, mitigation and emergency response. Emergency equipment is currently being added at each station to perform key safety functions in the event that backup power sources are lost permanently. These improvements are in addition to the numerous layers of safety measures and systems previously in place.

In March 2011, the NRC formed a task force to conduct a comprehensive review of processes and regulations to determine whether the agency should make additional improvements to the nuclear regulatory system. On July 13, 2011, the task force proposed a set of improvements designed to ensure protection, enhance accident mitigation, strengthen emergency preparedness and improve efficiency of NRC programs. The recommendations were further prioritized into three tiers based on the safety enhancement level. On March 12, 2012, the NRC issued three regulatory orders requiring safety enhancements related to mitigation strategies to respond to extreme natural events resulting in the loss of power at a plant, ensuring reliable hardened containment vents and enhancing spent fuel pool instrumentation.

On August 30, 2012, the NRC issued implementation guidance to enable power plants to achieve compliance with the orders issued in March 2012. Plants were required to submit implementation plans to the NRC by February 28, 2013, and complete implementation of the safety enhancements within two refueling outages or by December 31, 2016, whichever comes first. Each plant is also required to reassess their seismic and flooding hazards using present-day methods and information, conduct inspections to ensure protection against hazards in the current design basis, and re-evaluate emergency communications systems and staffing levels.

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Duke Energy is committed to compliance with all safety enhancements ordered by the NRC in connection with the March 12, 2012, regulatory orders noted above, the cost of which could be material. Until such time as the NRC-mandated reassessment of flooding and seismic hazards is complete the exact scope and cost of compliance modifications to Duke Energy’s sites will not be known. With the NRC’s continuing review of the remaining recommendations, Duke Energy cannot predict to what extent the NRC will impose additional licensing and safety-related requirements, or the costs of complying with such requirements. Upon receipt of additional guidance from the NRC and a collaborative industry review, Duke Energy will be able to determine an implementation plan and associated costs. See Item 1A, “Risk Factors,” for further discussion of applicable risk factors.

New Accounting Standards

See Note 1 to the Consolidated Financial Statements, “Summary of Significant Accounting Policies” for a discussion of the impact of new accounting standards.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

See “Management’s Discussion and Analysis of Results of Operations and Financial Condition - Quantitative and Qualitative Disclosures About Market Risk.”

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Duke Energy Corporation (Duke Energy)
Report of Independent Registered Public Accounting Firm	77
Consolidated Statements of Operations	78
Consolidated Statements of Comprehensive Income	79
Consolidated Balance Sheets	80
Consolidated Statements of Cash Flows	81
Consolidated Statements of Changes in Equity	82
Duke Energy Carolinas, LLC (Duke Energy Carolinas)
Report of Independent Registered Public Accounting Firm	83
Consolidated Statements of Operations and Comprehensive Income	84
Consolidated Balance Sheets	85
Consolidated Statements of Cash Flows	86
Consolidated Statements of Changes in Member’s Equity	87
Progress Energy, Inc. (Progress Energy)
Report of Independent Registered Public Accounting Firm	88
Consolidated Statements of Operations and Comprehensive Income	89
Consolidated Balance Sheets	90
Consolidated Statements of Cash Flows	91
Consolidated Statements of Changes in Common Stockholder’s Equity	92
Duke Energy Progress, Inc. (Duke Energy Progress)
Report of Independent Registered Public Accounting Firm	93
Consolidated Statements of Operations and Comprehensive Income	94
Consolidated Balance Sheets	95
Consolidated Statements of Cash Flows	96
Consolidated Statements of Changes in Common Stockholder’s Equity	97
Duke Energy Florida, Inc. (Duke Energy Florida)
Report of Independent Registered Public Accounting Firm	98
Consolidated Statements of Operations and Comprehensive Income	99
Consolidated Balance Sheets	100
Consolidated Statements of Cash Flows	101
Consolidated Statements of Changes in Common Stockholder’s Equity	102
Duke Energy Ohio, Inc. (Duke Energy Ohio)
Report of Independent Registered Public Accounting Firm	103
Consolidated Statements of Operations and Comprehensive Income	104
Consolidated Balance Sheets	105
Consolidated Statements of Cash Flows	106
Consolidated Statements of Changes in Common Stockholder’s Equity	107
Duke Energy Indiana, Inc. (Duke Energy Indiana)
Report of Independent Registered Public Accounting Firm	108
Consolidated Statements of Operations and Comprehensive Income	109
Consolidated Balance Sheets	110
Consolidated Statements of Cash Flows	111
Consolidated Statements of Changes in Common Stockholder’s Equity	112
Combined Notes to Consolidated Financial Statements
Note 1 – Summary of Significant Accounting Policies	113
Note 2 – Acquisitions, Dispositions and Sales of Other Assets	122

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Note 3 – Business Segments	127
Note 4 – Regulatory Matters	132
Note 5 – Commitments and Contingencies	143
Note 6 – Debt and Credit Facilities	154
Note 7 – Guarantees and Indemnifications	159
Note 8 – Joint Ownership of Generating and Transmission Facilities	160
Note 9 – Asset Retirement Obligations	161
Note 10 – Property, Plant and Equipment	164
Note 11 – Goodwill and Intangible Assets	166
Note 12 – Investments in Unconsolidated Affiliates	168
Note 13 – Related Party Transactions	169
Note 14 – Derivatives and Hedging	170
Note 15 – Investments in Debt and Equity Securities	185
Note 16 – Fair Value Measurements	192
Note 17 – Variable Interest Entities	201
Note 18 – Common Stock	206
Note 19 – Severance	207
Note 20 – Stock-Based Compensation	208
Note 21 – Employee Benefit Plans	210
Note 22 – Income Taxes	227
Note 23 – Other Income and Expenses, Net	234
Note 24 – Subsequent Events	234
Note 25 – Quarterly Financial Data (Unaudited)	235

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of

Duke Energy Corporation

Charlotte, North Carolina

We have audited the accompanying consolidated balance sheets of Duke Energy Corporation and subsidiaries (the "Company") as of December 31, 2014 and 2013, and the related consolidated statements of operations, comprehensive income, changes in equity, and cash flows for each of the three years in the period ended December 31, 2014. We also have audited the Company's internal control over financial reporting as of December 31, 2014, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company's management is responsible for these financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Annual Report On Internal Control Over Financial Reporting. Our responsibility is to express an opinion on these financial statements and an opinion on the Company's internal control over financial reporting based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

A company's internal control over financial reporting is a process designed by, or under the supervision of, the company's principal executive and principal financial officers, or persons performing similar functions, and effected by the company's board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Duke Energy Corporation and subsidiaries as of December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2014, based on the criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

/s/ Deloitte & Touche LLP 

Charlotte, North Carolina

February 27, 2015

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DUKE ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF OPERATIONS

	Years Ended December 31,
(in millions, except per share amounts)	2014			2013			2012
Operating Revenues
Regulated electric	$	21,550		$	20,329		$	15,515
Nonregulated electric, natural gas, and other	1,802			1,916			1,928
Regulated natural gas	573			511			469
Total operating revenues	23,925			22,756			17,912
Operating Expenses
Fuel used in electric generation and purchased power - regulated	7,686			7,108			5,582
Fuel used in electric generation and purchased power - nonregulated	533			540			651
Cost of natural gas and other	248			224			215
Operation, maintenance and other	5,856			5,673			4,787
Depreciation and amortization	3,066			2,668			2,145
Property and other taxes	1,213			1,274			965
Impairment charges	81			399			666
Total operating expenses	18,683			17,886			15,011
Gains (Losses) on Sales of Other Assets and Other, net	16			(16		)	10
Operating Income	5,258			4,854			2,911
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	130			122			148
Gains on sales of unconsolidated affiliates	17			100			22
Other income and expenses, net	351			262			397
Total other income and expenses	498			484			567
Interest Expense	1,622			1,543			1,244
Income From Continuing Operations Before Income Taxes	4,134			3,795			2,234
Income Tax Expense from Continuing Operations	1,669			1,205			623
Income From Continuing Operations	2,465			2,590			1,611
(Loss) Income From Discontinued Operations, net of tax	(576		)	86			171
Net Income	1,889			2,676			1,782
Less: Net Income Attributable to Noncontrolling Interests	6			11			14
Net Income Attributable to Duke Energy Corporation	$	1,883		$	2,665		$	1,768
Earnings Per Share - Basic and Diluted
Income from continuing operations attributable to Duke Energy Corporation common shareholders
Basic	$	3.46		$	3.64		$	2.77
Diluted	$	3.46		$	3.63		$	2.77
(Loss) Income from discontinued operations attributable to Duke Energy Corporation common shareholders
Basic	$	(0.80	)	$	0.13		$	0.30
Diluted	$	(0.80	)	$	0.13		$	0.30
Net Income attributable to Duke Energy Corporation common shareholders
Basic	$	2.66		$	3.77		$	3.07
Diluted	$	2.66		$	3.76		$	3.07
Weighted-average shares outstanding
Basic	707			706			574
Diluted	707			706			575

See Notes to Consolidated Financial Statements

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DUKE ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Years Ended December 31,
(in millions)	2014			2013			2012
Net Income	$	1,889		$	2,676		$	1,782
Other Comprehensive Loss, net of tax
Foreign currency translation adjustments	(124		)	(197		)	(75		)
Pension and OPEB adjustments(a)	4			38			19
Net unrealized (losses) gains on cash flow hedges(b)	(26		)	59			(28		)
Reclassification into earnings from cash flow hedges	7			1			(1		)
Unrealized gains (losses) on investments in available-for-sale securities	3			(4		)	14
Reclassification into earnings from available-for-sale securities	—			4			(5		)
Other Comprehensive Loss, net of tax	(136		)	(99		)	(76		)
Comprehensive Income	1,753			2,577			1,706
Less: Comprehensive Income Attributable to Noncontrolling Interests	14			5			10
Comprehensive Income Attributable to Duke Energy Corporation	$	1,739		$	2,572		$	1,696

(a) Net of insignificant tax expense in 2014, $17 million tax expense in 2013 and $9 million tax expense in 2012. See Note 21 for additional information.

(b) Net of $13 million tax benefit in 2014, $20 million tax expense in 2013 and $6 million tax expense in 2012.

See Notes to Consolidated Financial Statements

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DUKE ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

	December 31,
(in millions)	2014			2013
ASSETS
Current Assets
Cash and cash equivalents	$	2,036		$	1,501
Short-term investments	—			44
Receivables (net of allowance for doubtful accounts of $17 at December 31, 2014 and $30 at December 31, 2013)	791			1,286
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $51 at December 31, 2014 and $43 at December 31, 2013)	1,973			1,719
Inventory	3,459			3,250
Assets held for sale	364			—
Regulatory assets	1,115			895
Other	1,837			1,821
Total current assets	11,575			10,516
Investments and Other Assets
Investments in equity method unconsolidated affiliates	358			390
Nuclear decommissioning trust funds	5,546			5,132
Goodwill	16,321			16,340
Assets held for sale	2,642			107
Other	3,008			3,432
Total investments and other assets	27,875			25,401
Property, Plant and Equipment
Cost	104,861			103,115
Accumulated depreciation and amortization	(34,824		)	(33,625		)
Generation facilities to be retired, net	9			—
Net property, plant and equipment	70,046			69,490
Regulatory Assets and Deferred Debits
Regulatory assets	11,042			9,191
Other	171			181
Total regulatory assets and deferred debits	11,213			9,372
Total Assets	$	120,709		$	114,779
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	2,271		$	2,391
Notes payable and commercial paper	2,514			839
Taxes accrued	569			551
Interest accrued	418			440
Current maturities of long-term debt	2,807			2,104
Liabilities associated with assets held for sale	262			7
Regulatory liabilities	204			316
Other	2,188			1,996
Total current liabilities	11,233			8,644
Long-Term Debt	37,213			38,152
Deferred Credits and Other Liabilities
Deferred income taxes	13,423			12,097
Investment tax credits	427			442
Accrued pension and other post-retirement benefit costs	1,145			1,322
Liabilities associated with assets held for sale	35			66
Asset retirement obligations	8,466			4,950
Regulatory liabilities	6,193			5,949
Other	1,675			1,749
Total deferred credits and other liabilities	31,364			26,575
Commitments and Contingencies
Equity
Common stock, $0.001 par value, 2 billion shares authorized; 707 million and 706 million shares outstanding at December 31, 2014 and 2013, respectively	1			1
Additional paid-in capital	39,405			39,365
Retained earnings	2,012			2,363
Accumulated other comprehensive loss	(543		)	(399		)
Total Duke Energy Corporation shareholders' equity	40,875			41,330
Noncontrolling interests	24			78
Total equity	40,899			41,408
Total Liabilities and Equity	$	120,709		$	114,779

See Notes to Consolidated Financial Statements

80

PART II

DUKE ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Years Ended December 31,
(in millions)	2014			2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,889		$	2,676		$	1,782
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	3,507			3,229			2,652
Equity component of AFUDC	(135		)	(157		)	(300		)
Severance expense	—			—			92
FERC mitigation costs	(15		)	—			117
Community support and charitable contributions expense	—			34			92
Gains on sales of other assets	(33		)	(79		)	(44		)
Impairment charges	915			400			586
Deferred income taxes	1,149			1,264			584
Equity in earnings of unconsolidated affiliates	(130		)	(122		)	(148		)
Voluntary opportunity cost deferral	—			—			(101		)
Accrued pension and other post-retirement benefit costs	108			307			239
Contributions to qualified pension plans	—			(250		)	(304		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	44			1			60
Receivables	58			(281		)	39
Inventory	(269		)	(31		)	(258		)
Other current assets	(414		)	(35		)	140
Increase (decrease) in
Accounts payable	(30		)	73			131
Taxes accrued	(14		)	77			(142		)
Other current liabilities	(201		)	24			295
Other assets	16			(384		)	(129		)
Other liabilities	141			(364		)	(139		)
Net cash provided by operating activities	6,586			6,382			5,244
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(5,384		)	(5,526		)	(5,501		)
Investment expenditures	(90		)	(81		)	(6		)
Acquisitions	(54		)	—			(451		)
Cash acquired from the merger with Progress Energy	—			—			71
Purchases of available-for-sale securities	(4,110		)	(6,142		)	(4,719		)
Proceeds from sales and maturities of available-for-sale securities	4,133			6,315			4,537
Net proceeds from the sales of equity investments and other assets, and sales of and collections on notes receivable	179			277			212
Change in restricted cash	9			167			(414		)
Other	(56		)	12			74
Net cash used in investing activities	(5,373		)	(4,978		)	(6,197		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	2,914			3,601			4,170
Issuance of common stock related to employee benefit plans	25			9			23
Payments for the:
Redemption of long-term debt	(3,037		)	(2,761		)	(2,498		)
Redemption of preferred stock of a subsidiary	—			(96		)	—
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	1,066			—			—
Payments for the redemption of short-term debt with original maturities greater than 90 days	(564		)	—			—
Notes payable and commercial paper	1,186			93			278
Distributions to noncontrolling interests	(65		)	(15		)	(25		)
Contributions from noncontrolling interests	—			9			76
Dividends paid	(2,234		)	(2,188		)	(1,752		)
Other	31			21			(5		)
Net cash (used in) provided by financing activities	(678		)	(1,327		)	267
Net increase (decrease) in cash and cash equivalents	535			77			(686		)
Cash and cash equivalents at beginning of period	1,501			1,424			2,110
Cash and cash equivalents at end of period	$	2,036		$	1,501		$	1,424
Supplemental Disclosures:
Cash paid for interest, net of amount capitalized	$	1,659		$	1,665		$	1,032
Cash paid for (received from) income taxes	158			(202		)	72
Merger with Progress Energy
Fair value of assets acquired	—			—			48,944
Fair value of liabilities assumed	—			—			30,873
Issuance of common stock	—			—			18,071
Significant non-cash transactions:
Accrued capital expenditures	664			594			684

See Notes to Consolidated Financial Statements

81

PART II

DUKE ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

						Duke Energy Corporation Shareholders Accumulated Other Comprehensive Loss
(in millions)	Common Stock Shares	Common Stock	Additional Paid-in Capital	Retained Earnings		Foreign Currency Adjustments		Net Losses on Cash Flow Hedges		Unrealized (Losses) Gains on Available-for-Sale Securities		Pension and OPEB Related Adjustments		Common Stockholders' Equity		Noncontrolling Interests		Total Equity
Balance at December 31, 2011	445	1	21,132	1,873		(45	)	(71	)	(9	)	(109	)	22,772		93		22,865
Net income(a)	—	—	—	1,768		—		—		—		—		1,768		12		1,780
Other comprehensive (loss) income	—	—	—	—		(71	)	(29	)	9		19		(72	)	(4	)	(76	)
Common stock issued in connection with the   Progress Energy Merger	258	—	18,071	—		—		—		—		—		18,071		—		18,071
Common stock issuances, including dividend   reinvestment and employee benefits	1	—	76	—		—		—		—		—		76		—		76
Common stock dividends	—	—	—	(1,752	)	—		—		—		—		(1,752	)	—		(1,752	)
Contribution from noncontrolling interest in   DS Cornerstone, LLC	—	—	—	—		—		—		—		—		—		76		76
Deconsolidation of DS Cornerstone, LLC	—	—	—	—		—		—		—		—		—		(82	)	(82	)
Changes in noncontrolling interest in  subsidiaries(b)	—	—	—	—		—		—		—		—		—		(17	)	(17	)
Balance at December 31, 2012	704	1	39,279	1,889		(116	)	(100	)	—		(90	)	40,863		78		40,941
Net income	—	—	—	2,665		—		—		—		—		2,665		11		2,676
Other comprehensive (loss) income	—	—	—	—		(191	)	60		—		38		(93	)	(6	)	(99	)
Common stock issuances, including dividend   reinvestment and employee benefits	2	—	86	—		—		—		—		—		86		—		86
Common stock dividends	—	—	—	(2,188	)	—		—		—		—		(2,188	)	—		(2,188	)
Premium on the redemption of preferred stock of subsidiaries	—	—	—	(3	)	—		—		—		—		(3	)	—		(3	)
Contribution from noncontrolling interest	—	—	—	—		—		—		—		—		—		9		9
Changes in noncontrolling interest in subsidiaries(b)	—	—	—	—		—		—		—		—		—		(14	)	(14	)
Balance at December 31, 2013	706	1	39,365	2,363		(307	)	(40	)	—		(52	)	41,330		78		41,408
Net income	—	—	—	1,883		—		—		—		—		1,883		6		1,889
Other comprehensive (loss) income	—	—	—	—		(132	)	(19	)	3		4		(144	)	8		(136	)
Common stock issuances, including dividend   reinvestment and employee benefits	1	—	40	—		—		—		—		—		40		—		40
Common stock dividends	—	—	—	(2,234	)	—		—		—		—		(2,234	)	—		(2,234	)
Changes in noncontrolling interest in subsidiaries(b)	—	—	—	—		—		—		—		—		—		(65	)	(65	)
Other	—	—	—	—		—		—		—		—		—		(3	)	(3	)
Balance at December 31, 2014	707	1	39,405	2,012		(439	)	(59	)	3		(48	)	40,875		24		40,899

(a) For the year ended December 31, 2012, consolidated net income of $1,782 million includes $2 million attributable to preferred shareholders of subsidiaries. Income attributable to preferred shareholders of subsidiaries is not a component of total equity and is excluded from the table above.

(b) This decrease primarily relates to cash distributions to noncontrolling interests.

See Notes to Consolidated Financial Statements

82

PART II

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Duke Energy Carolinas, LLC

Charlotte, North Carolina

We have audited the accompanying consolidated balance sheets of Duke Energy Carolinas, LLC and subsidiaries (the "Company") as of December 31, 2014 and 2013, and the related consolidated statements of operations and comprehensive income, changes in member’s equity, and cash flows for each of the three years in the period ended December 31, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Duke Energy Carolinas, LLC and subsidiaries at December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting principles generally accepted in the United States of America.

/s/ Deloitte & Touche LLP

Charlotte, North Carolina

February 27, 2015

83

PART II

DUKE ENERGY CAROLINAS, LLC

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

	Years Ended December 31,
(in millions)	2014		2013		2012
Operating Revenues	$	7,351	$	6,954	$	6,665
Operating Expenses
Fuel used in electric generation and purchased power	2,133		1,982		1,864
Operation, maintenance and other	1,995		1,868		1,979
Depreciation and amortization	1,009		921		921
Property and other taxes	316		374		365
Impairment charges	3		—		31
Total operating expenses	5,456		5,145		5,160
Gains on Sales of Other Assets and Other, net	—		—		12
Operating Income	1,895		1,809		1,517
Other Income and Expenses, net	172		120		185
Interest Expense	407		359		384
Income Before Income Taxes	1,660		1,570		1,318
Income Tax Expense	588		594		453
Net Income	$	1,072	$	976	$	865
Other Comprehensive Income, net of tax
Reclassification into earnings from cash flow hedges	2		1		2
Unrealized gain on investments in available-for-sale securities	—		—		1
Comprehensive Income	$	1,074	$	977	$	868

See Notes to Consolidated Financial Statements

84

PART II

DUKE ENERGY CAROLINAS, LLC

CONSOLIDATED BALANCE SHEETS

	December 31,
(in millions)	2014			2013
ASSETS
Current Assets
Cash and cash equivalents	$	13		$	23
Receivables (net of allowance for doubtful accounts of $3 at December 31, 2014 and December 31, 2013)	129			186
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $6 at December 31, 2014 and December 31, 2013)	647			673
Receivables from affiliated companies	75			75
Notes receivable from affiliated companies	150			222
Inventory	1,124			1,065
Regulatory assets	399			295
Other	77			309
Total current assets	2,614			2,848
Investments and Other Assets
Nuclear decommissioning trust funds	3,042			2,840
Other	959			1,000
Total investments and other assets	4,001			3,840
Property, Plant and Equipment
Cost	37,372			34,906
Accumulated depreciation and amortization	(12,700		)	(11,894		)
Net property, plant and equipment	24,672			23,012
Regulatory Assets and Deferred Debits
Regulatory assets	2,465			1,527
Other	42			46
Total regulatory assets and deferred debits	2,507			1,573
Total Assets	$	33,794		$	31,273
LIABILITIES AND MEMBER'S EQUITY
Current Liabilities
Accounts payable	$	709		$	701
Accounts payable to affiliated companies	154			161
Taxes accrued	146			147
Interest accrued	95			97
Current maturities of long-term debt	507			47
Regulatory liabilities	34			65
Other	434			393
Total current liabilities	2,079			1,611
Long-Term Debt	7,584			8,089
Long-Term Debt Payable to Affiliated Companies	300			300
Deferred Credits and Other Liabilities
Deferred income taxes	5,812			5,706
Investment tax credits	204			210
Accrued pension and other post-retirement benefit costs	111			161
Asset retirement obligations	3,428			1,594
Regulatory liabilities	2,710			2,576
Other	642			676
Total deferred credits and other liabilities	12,907			10,923
Commitments and Contingencies
Member's Equity
Member's Equity	10,937			10,365
Accumulated other comprehensive loss	(13		)	(15		)
Total member's equity	10,924			10,350
Total Liabilities and Member's Equity	$	33,794		$	31,273

See Notes to Consolidated Financial Statements

85

PART II

DUKE ENERGY CAROLINAS, LLC

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Years Ended December 31,
(in millions)	2014			2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	1,072		$	976		$	865
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	1,273			1,167			1,143
Equity component of AFUDC	(91		)	(91		)	(154		)
FERC mitigation costs	3			—			46
Community support and charitable contributions expense	—			14			56
Gains on sales of other assets and other, net	—			—			(12		)
Deferred income taxes	376			534			479
Voluntary opportunity cost deferral	—			—			(101		)
Accrued pension and other post-retirement benefit costs	22			38			41
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	—			(9		)	—
Receivables	48			(12		)	22
Receivables from affiliated companies	—			(72		)	(1		)
Inventory	(60		)	(9		)	(128		)
Other current assets	(236		)	(1		)	46
Increase (decrease) in
Accounts payable	10			58			(51		)
Accounts payable to affiliated companies	(7		)	33			(28		)
Taxes accrued	(15		)	4			(12		)
Other current liabilities	(10		)	(40		)	165
Other assets	17			(102		)	(117		)
Other liabilities	(22		)	(77		)	(126		)
Net cash provided by operating activities	2,380			2,411			2,133
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,879		)	(1,695		)	(1,908		)
Purchases of available-for-sale securities	(2,064		)	(2,405		)	(2,481		)
Proceeds from sales and maturities of available-for-sale securities	2,044			2,363			2,445
Notes receivable from affiliated companies	72			160			541
Other	(18		)	(24		)	(12		)
Net cash used in investing activities	(1,845		)	(1,601		)	(1,415		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			100			645
Payments for the redemption of long-term debt	(45		)	(405		)	(1,177		)
Distributions to parent	(500		)	(499		)	(450		)
Other	—			(2		)	(6		)
Net cash used in financing activities	(545		)	(806		)	(988		)
Net (decrease) increase in cash and cash equivalents	(10		)	4			(270		)
Cash and cash equivalents at beginning of period	23			19			289
Cash and cash equivalents at end of period	$	13		$	23		$	19
Supplemental Disclosures:
Cash paid for interest, net of amount capitalized	$	388		$	336		$	385
Cash paid for (received from) income taxes	305			(7		)	(38		)
Significant non-cash transactions:
Accrued capital expenditures	194			199			194

See Notes to Consolidated Financial Statements

86

PART II

DUKE ENERGY CAROLINAS, LLC

CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER’S EQUITY

				Accumulated Other Comprehensive Loss
(in millions)	Member's Equity			Net Losses on Cash Flow Hedges			Unrealized Losses on Available-for-Sale Securities			Total Equity
Balance at December 31, 2011	$	9,473		$	(17	)	$	(2	)	$	9,454
Net income	865			—			—			865
Other comprehensive income				2			1			3
Distributions to parent	(450		)	—			—			(450		)
Balance at December 31, 2012	$	9,888		$	(15	)	$	(1	)	$	9,872
Net income	976			—			—			976
Other comprehensive income				1			—			1
Distributions to parent	(499		)	—			—			(499		)
Balance at December 31, 2013	$	10,365		$	(14	)	$	(1	)	$	10,350
Net income	1,072			—			—			1,072
Other comprehensive income				2			—			2
Distributions to parent	(500		)	—			—			(500		)
Balance at December 31, 2014	$	10,937		$	(12	)	$	(1	)	$	10,924

See Notes to Consolidated Financial Statements

87

PART II

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Progress Energy, Inc.

Charlotte, North Carolina

We have audited the accompanying consolidated balance sheets of Progress Energy, Inc. and subsidiaries (the "Company") as of December 31, 2014 and 2013, and the related consolidated statements of operations and comprehensive income, changes in common stockholder’s equity, and cash flows for each of the three years in the period ended December 31, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Progress Energy, Inc. and subsidiaries at December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting principles generally accepted in the United States of America.

/s/ Deloitte & Touche LLP

Charlotte, North Carolina

February 27, 2015

88

PART II

PROGRESS ENERGY, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

	Years Ended December 31,
(in millions)	2014			2013			2012
Operating Revenues	$	10,166		$	9,533		$	9,405
Operating Expenses
Fuel used in electric generation and purchased power	4,195			3,851			4,304
Operation, maintenance and other	2,335			2,247			2,445
Depreciation and amortization	1,128			883			747
Property and other taxes	517			557			570
Impairment charges	(16		)	380			200
Total operating expenses	8,159			7,918			8,266
Gains (Losses) on Sales of Other Assets and Other, net	11			3			(2		)
Operating Income	2,018			1,618			1,137
Other Income and Expenses, net	77			94			130
Interest Expense	675			680			740
Income From Continuing Operations Before Income Taxes	1,420			1,032			527
Income Tax Expense From Continuing Operations	540			373			172
Income From Continuing Operations	880			659			355
(Loss) Income From Discontinued Operations, net of tax	(6		)	16			52
Net Income	874			675			407
Less: Net Income Attributable to Noncontrolling Interests	5			3			7
Net Income Attributable to Parent	$	869		$	672		$	400
Net Income	$	874		$	675		$	407
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	9			9			(2		)
Net unrealized loss on cash flow hedges	—			—			(5		)
Reclassification into earnings from cash flow hedges	8			(1		)	8
Reclassification of cash flow hedges to regulatory assets(a)	—			—			97
Unrealized gains on investments in available-for-sale securities	1			—			—
Other Comprehensive Income, net of tax	18			8			98
Comprehensive Income	892			683			505
Less: Comprehensive Income Attributable to Noncontrolling Interests	5			3			7
Comprehensive Income Attributable to Parent	$	887		$	680		$	498

(a) Net of $62 million tax expense in 2012.  

See Notes to Consolidated Financial Statements

89

PART II

PROGRESS ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

	December 31,
(in millions)	2014			2013
ASSETS
Current Assets
Cash and cash equivalents	$	42		$	58
Receivables (net of allowance for doubtful accounts of $8 at December 31, 2014 and $14 at December 31, 2013)	129			528
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $8 at December 31, 2014)	741			417
Receivables from affiliated companies	59			4
Notes receivable from affiliated companies	220			75
Inventory	1,590			1,424
Regulatory assets	491			353
Other	1,285			726
Total current assets	4,557			3,585
Investments and Other Assets
Nuclear decommissioning trust funds	2,503			2,292
Goodwill	3,655			3,655
Other	670			804
Total investments and other assets	6,828			6,751
Property, Plant and Equipment
Cost	38,650			36,480
Accumulated depreciation and amortization	(13,506		)	(13,098		)
Net property, plant and equipment	25,144			23,382
Regulatory Assets and Deferred Debits
Regulatory assets	5,408			4,155
Other	91			96
Total regulatory assets and deferred debits	5,499			4,251
Total Assets	$	42,028		$	37,969
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	847		$	836
Accounts payable to affiliated companies	203			123
Notes payable to affiliated companies	835			1,213
Taxes accrued	114			105
Interest accrued	184			181
Current maturities of long-term debt	1,507			485
Regulatory liabilities	106			207
Other	1,021			896
Total current liabilities	4,817			4,046
Long-Term Debt	13,247			13,630
Deferred Credits and Other Liabilities
Deferred income taxes	4,759			3,283
Accrued pension and other post-retirement benefit costs	533			765
Asset retirement obligations	4,711			2,562
Regulatory liabilities	2,379			2,292
Other	406			527
Total deferred credits and other liabilities	12,788			9,429
Commitments and Contingencies
Common Stockholder's Equity
Common stock, $0.01 par value, 100 shares authorized and outstanding at December 31, 2014 and 2013	—			—
Additional paid-in capital	7,467			7,467
Retained earnings	3,782			3,452
Accumulated other comprehensive loss	(41		)	(59		)
Total common stockholder's equity	11,208			10,860
Noncontrolling interests	(32		)	4
Total equity	11,176			10,864
Total Liabilities and Equity	$	42,028		$	37,969

See Notes to Consolidated Financial Statements

90

PART II

PROGRESS ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Years Ended December 31,
(in millions)	2014			2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	874		$	675		$	407
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,313			1,041			897
Equity component of AFUDC	(26		)	(50		)	(106		)
Severance expense	—			—			38
FERC mitigation costs	(18		)	—			71
Community support and charitable contributions expense	—			20			36
(Gains) losses on sales of other assets	(6		)	2			(16		)
Impairment charges	2			380			146
Deferred income taxes	1,014			616			263
Amount to be refunded to customers	—			—			100
Accrued pension and other post-retirement benefit costs	27			172			179
Contributions to qualified pension plans	—			(250		)	(346		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	12			55			7
Receivables	(31		)	(148		)	49
Receivables from affiliated companies	(56		)	11			(15		)
Inventory	(101		)	17			(71		)
Other current assets	(934		)	(156		)	2
Increase (decrease) in
Accounts payable	6			(81		)	175
Accounts payable to affiliated companies	80			93			30
Taxes accrued	(20		)	22			25
Other current liabilities	(144		)	61			81
Other assets	(14		)	(243		)	(25		)
Other liabilities	(12		)	(115		)	(87		)
Net cash provided by operating activities	1,966			2,122			1,840
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,940		)	(2,490		)	(2,366		)
Purchases of available-for-sale securities	(1,689		)	(2,558		)	(1,374		)
Proceeds from sales and maturities of available-for-sale securities	1,652			2,513			1,325
Change in restricted cash	—			—			24
Notes receivable from affiliated companies	(145		)	(75		)	—
Other	(44		)	13			109
Net cash used in investing activities	(2,166		)	(2,597		)	(2,282		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	1,572			845			2,074
Issuance of common stock related to employee benefit plans	—			—			6
Payments for the:
Redemption of long-term debt	(931		)	(1,196		)	(962		)
Redemption of preferred stock of subsidiaries	—			(96		)	—
Proceeds from the issuance of short-term debt with original maturities greater than 90 days	—			—			65
Payments for the redemption of short-term debt with original maturities greater than 90 days	—			—			(65		)
Notes payable and commercial paper	—			—			(671		)
Notes payable to affiliated companies	(378		)	758			455
Distributions to noncontrolling interests	(37		)	(3		)	(7		)
Dividends paid	—			—			(445		)
Other	(42		)	(6		)	(7		)
Net cash provided by financing activities	184			302			443
Net (decrease) increase in cash and cash equivalents	(16		)	(173		)	1
Cash and Cash Equivalents at Beginning of Period	58			231			230
Cash and Cash Equivalents at End of Period	42			58			231
Supplemental Disclosures:
Cash paid for interest, net of amount capitalized	664			678			784
Cash paid for (received from) income taxes	141			(167		)	(4		)
Significant non-cash transactions:
Accrued capital expenditures	294			255			375
Asset retirement obligation additions for spent nuclear fuel disposal related to the Progress Energy merger	—			—			837
Capital expenditures financed through capital leases	—			—			140

See Notes to Consolidated Financial Statements

91

PART II

PROGRESS ENERGY, INC.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDER’S EQUITY

									Accumulated Other Comprehensive Income Loss
(in millions)	Common Stock			Additional Paid-in Capital		Retained Earnings			Net Losses on Cash Flow Hedges			Net Gains on Available for Sale Securities		Pension and OPEB Related Adjustments			Common Stockholders' Equity			Noncontrolling Interests			Total Equity
Balance at December 31, 2011	$	7,418		$	16	$	2,752		$	(142	)	$	—	$	(23	)	$	10,021		$	4		$	10,025
Net income(a)	—			—		400			—			—		—			400			3			403
Other comprehensive income (loss)	—			—		—			100			—		(2		)	98			—			98
Common stock issuances, including dividend   reinvestment and employee benefits	18			13		—			—			—		—			31			—			31
Common stock dividends	—			—		(369		)	—			—		—			(369		)	—			(369		)
Distributions to noncontrolling interests	—			—		—			—			—		—			—			(2		)	(2		)
Recapitalization for merger with Duke Energy	(7,436		)	7,436		—			—			—		—			—			—			—
Other	—			—		—			—			—		—			—			(1		)	(1		)
Balance at December 31, 2012	$	—		$	7,465	$	2,783		$	(42	)	$	—	$	(25	)	$	10,181		$	4		$	10,185
Net income	—			—		672			—			—		—			672			3			675
Other comprehensive (loss) income	—			—		—			(1		)	—		9			8			—			8
Premium on the redemption of preferred stock of subsidiaries	—			—		(3		)	—			—		—			(3		)	—			(3		)
Distributions to noncontrolling interests	—			—		—			—			—		—			—			(3		)	(3		)
Other	—			2		—			—			—		—			2			—			2
Balance at December 31, 2013	$	—		$	7,467	$	3,452		$	(43	)	$	—	$	(16	)	$	10,860		$	4		$	10,864
Net income	—			—		869			—			—		—			869			5			874
Other comprehensive income	—			—		—			8			1		9			18			—			18
Distributions to noncontrolling interests	—			—		—			—			—		—			—			(37		)	(37		)
Transfer of service company net assets to Duke Energy	—			—		(539		)	—			—		—			(539		)	—			(539		)
Other	—			—		—			—			—		—			—			(4		)	(4		)
Balance at December 31, 2014	$	—		$	7,467	$	3,782		$	(35	)	$	1	$	(7	)	$	11,208		$	(32	)	$	11,176

(a) For the year ended December 31, 2012, consolidated net income of $407 million included $4 million attributable to preferred shareholders of subsidiaries. Income attributable to preferred shareholders of subsidiaries is not a component of total equity and is excluded from the table above.

See Notes to Consolidated Financial Statements

92

PART II

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Duke Energy Progress, Inc.

Charlotte, North Carolina

We have audited the accompanying consolidated balance sheets of Duke Energy Progress, Inc. and subsidiaries (the "Company") as of December 31, 2014 and 2013, and the related consolidated statements of operations and comprehensive income, changes in common stockholder’s equity, and cash flows for each of the three years in the period ended December 31, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Duke Energy Progress, Inc. and subsidiaries at December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting principles generally accepted in the United States of America.

/s/ Deloitte & Touche LLP

Charlotte, North Carolina

February 27, 2015

93

PART II

DUKE ENERGY PROGRESS, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

	Years Ended December 31,
(in millions)	2014			2013		2012
Operating Revenues	$	5,176		$	4,992	$	4,706
Operating Expenses
Fuel used in electric generation and purchased power	2,036			1,925		1,895
Operation, maintenance and other	1,470			1,357		1,494
Depreciation and amortization	582			534		535
Property and other taxes	174			223		219
Impairment charges	(18		)	22		54
Total operating expenses	4,244			4,061		4,197
Gains on Sales of Other Assets and Other, net	3			1		1
Operating Income	935			932		510
Other Income and Expenses, net	51			57		79
Interest Expense	234			201		207
Income Before Income Taxes	752			788		382
Income Tax Expense	285			288		110
Net Income	467			500		272
Less: Preferred Stock Dividend Requirement	—			—		3
Net Income Available to Parent	$	467		$	500	$	269
Net Income	$	467		$	500	$	272
Other Comprehensive (Loss) Income, net of tax
Net unrealized loss on cash flow hedges	—			—		(4		)
Reclassification into earnings from cash flow hedges	—			—		4
Reclassification of cash flow hedges to regulatory assets(a)	—			—		71
Other Comprehensive Income, net of tax	—			—		71
Comprehensive Income	$	467		$	500	$	343

(a) Net of $46 million tax expense in 2012.  

See Notes to Consolidated Financial Statements

94

PART II

DUKE ENERGY PROGRESS, INC.

CONSOLIDATED BALANCE SHEETS

	December 31,
(in millions)	2014			2013
ASSETS
Current Assets
Cash and cash equivalents	$	9		$	21
Receivables (net of allowance for doubtful accounts of $7 at December 31, 2014 and $10 at December 31, 2013)	43			145
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $5 at December 31, 2014)	436			417
Receivables from affiliated companies	10			2
Notes receivable from affiliated companies	237			—
Inventory	966			853
Regulatory assets	287			127
Other	384			296
Total current assets	2,372			1,861
Investments and Other Assets
Nuclear decommissioning trust funds	1,701			1,539
Other	412			443
Total investments and other assets	2,113			1,982
Property, Plant and Equipment
Cost	24,207			22,273
Accumulated depreciation and amortization	(9,021		)	(8,623		)
Net property, plant and equipment	15,186			13,650
Regulatory Assets and Deferred Debits
Regulatory assets	2,675			1,384
Other	34			32
Total regulatory assets and deferred debits	2,709			1,416
Total Assets	$	22,380		$	18,909
LIABILITIES AND COMMON STOCKHOLDER'S EQUITY
Current Liabilities
Accounts payable	$	481		$	420
Accounts payable to affiliated companies	120			103
Notes payable to affiliated companies	—			462
Taxes accrued	47			37
Interest accrued	81			70
Current maturities of long-term debt	945			174
Regulatory liabilities	71			63
Other	409			392
Total current liabilities	2,154			1,721
Long-Term Debt	5,256			5,061
Deferred Credits and Other Liabilities
Deferred income taxes	2,908			2,557
Accrued pension and other post-retirement benefit costs	290			321
Asset retirement obligations	3,905			1,729
Regulatory liabilities	1,832			1,673
Other	168			222
Total deferred credits and other liabilities	9,103			6,502
Commitments and Contingencies
Common Stockholder's Equity
Common stock, no par value, 200 million shares authorized; 160 million shares outstanding at December 31, 2014 and 2013	2,159			2,159
Retained earnings	3,708			3,466
Total common stockholder's equity	5,867			5,625
Total Liabilities and Common Stockholder's Equity	$	22,380		$	18,909

See Notes to Consolidated Financial Statements

95

PART II

DUKE ENERGY PROGRESS, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Years Ended December 31,
(in millions)	2014			2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	467			500			272
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	761			685			676
Equity component of AFUDC	(25		)	(42		)	(69		)
Severance expense	—			—			18
FERC mitigation costs	(18		)	—			71
Community support and charitable contributions expense	—			20			36
Gains on sales of other assets and other, net	(3		)	(1		)	(1		)
Impairment charges	—			22			—
Deferred income taxes	455			368			164
Accrued pension and other post-retirement benefit costs	(7		)	72			70
Contributions to qualified pension plans	—			(63		)	(141		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	13			(9		)	(25		)
Receivables	78			(88		)	2
Receivables from affiliated companies	(8		)	3			(4		)
Inventory	(65		)	(26		)	(58		)
Other current assets	(416		)	(39		)	(24		)
Increase (decrease) in
Accounts payable	27			(18		)	149
Accounts payable to affiliated companies	17			27			47
Taxes accrued	10			15			(5		)
Other current liabilities	(68		)	(86		)	23
Other assets	48			(74		)	(28		)
Other liabilities	(21		)	(78		)	(6		)
Net cash provided by operating activities	1,245			1,188			1,167
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(1,241		)	(1,567		)	(1,525		)
Purchases of available-for-sale securities	(499		)	(901		)	(582		)
Proceeds from sales and maturities of available-for-sale securities	458			856			532
Notes receivable from affiliated companies	(237		)	—			—
Other	(12		)	4			91
Net cash used in investing activities	(1,531		)	(1,608		)	(1,484		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	1,347			845			988
Payments for the:
Redemption of long-term debt	(379		)	(451		)	(502		)
Redemption of preferred stock	—			(62		)	—
Notes payable and commercial paper	—			—			(188		)
Notes payable to affiliated companies	(462		)	98			333
Dividends to parent	(225		)	—			(310		)
Dividends paid on preferred stock	—			—			(3		)
Other	(7		)	(7		)	(3		)
Net cash provided by financing activities	274			423			315
Net (decrease) increase in cash and cash equivalents	(12		)	3			(2		)
Cash and Cash Equivalents at Beginning of Period	21			18			20
Cash and Cash Equivalents at End of Period	$	9		$	21		$	18
Supplemental Disclosures:
Cash paid for interest, net of amount capitalized	$	220		$	217		$	249
Cash paid for (received from) income taxes	81			(94		)	19
Significant non-cash transactions:
Accrued capital expenditures	194			166			232
Asset retirement obligation additions for spent nuclear fuel disposal related to the Progress Energy merger	—			—			698
Capital expenditures financed through capital leases	—			—			140

See Notes to Consolidated Financial Statements

96

PART II

DUKE ENERGY PROGRESS, INC.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDERS' EQUITY

						Accumulated Other Comprehensive Loss
(in millions)	Common Stock		Retained Earnings			Net Loss on Cash Flow Hedges			Total Equity
Balance at December 31, 2011	$	2,148	$	3,011		$	(71	)	$	5,088
Net income	—		272			—			272
Other comprehensive income	—		—			71			71
Stock-based compensation expense	11		—			—			11
Dividends to parent	—		(310		)	—			(310		)
Preferred stock dividends at stated rate	—		(3		)	—			(3		)
Tax dividend	—		(2		)	—			(2		)
Balance at December 31, 2012	$	2,159	$	2,968		$	—		$	5,127
Net income	—		500			—			500
Premium on the redemption of preferred stock	—		(2		)	—			(2		)
Balance at December 31, 2013	$	2,159	$	3,466		$	—		$	5,625
Net income	—		467			—			467
Dividends to parent	—		(225		)	—			(225		)
Balance at December 31, 2014	$	2,159	$	3,708		$	—		$	5,867

See Notes to Consolidated Financial Statements

97

PART II

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Duke Energy Florida, Inc.

Charlotte, North Carolina

We have audited the accompanying consolidated balance sheets of Duke Energy Florida, Inc. and subsidiaries (the "Company") as of December 31, 2014 and 2013, and the related consolidated statements of operations and comprehensive income, changes in common stockholder’s equity, and cash flows for each of the three years in the period ended December 31, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Duke Energy Florida, Inc. and subsidiaries at December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting principles generally accepted in the United States of America.

/s/ Deloitte & Touche LLP

Charlotte, North Carolina

February 27, 2015

98

PART II

DUKE ENERGY FLORIDA, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

	Years Ended December 31,
(in millions)	2014		2013			2012
Operating Revenues	$	4,975	$	4,527		$	4,689
Operating Expenses
Fuel used in electric generation and purchased power	2,158		1,927			2,409
Operation, maintenance and other	850		898			969
Depreciation and amortization	545		330			192
Property and other taxes	343		327			346
Impairment charges	2		358			146
Total operating expenses	3,898		3,840			4,062
Gains on Sales of Other Assets and Other, net	1		1			2
Operating Income	1,078		688			629
Other Income and Expenses, net	20		30			39
Interest Expense	201		180			255
Income Before Income Taxes	897		538			413
Income Tax Expense	349		213			147
Net Income	548		325			266
Less: Preferred Stock Dividend Requirement	—		—			2
Net Income Available to Parent	$	548	$	325		$	264
Net Income	$	548	$	325		$	266
Other Comprehensive Income (Loss), net of tax
Net unrealized loss on cash flow hedges	—		(1		)	—
Reclassification into earnings from cash flow hedges	1		—			1
Reclassification of cash flow hedges to regulatory assets(a)	—		—			26
Other Comprehensive Income (Loss), net of tax	1		(1		)	27
Comprehensive Income	$	549	$	324		$	293

(a) Net of $16 million tax expense in 2012.

See Notes to Consolidated Financial Statements

99

PART II

DUKE ENERGY FLORIDA, INC.

CONSOLIDATED BALANCE SHEETS

	December 31,
(in millions)	2014			2013
ASSETS
Current Assets
Cash and cash equivalents	$	8		$	16
Receivables (net of allowance for doubtful accounts of $2 at December 31, 2014 and $4 at December 31, 2013)	84			375
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $3 at December 31, 2014)	305			—
Receivables from affiliated companies	40			3
Inventory	623			571
Regulatory assets	203			221
Other	521			182
Total current assets	1,784			1,368
Investments and Other Assets
Nuclear decommissioning trust funds	803			753
Other	204			252
Total investments and other assets	1,007			1,005
Property, Plant and Equipment
Cost	14,433			13,863
Accumulated depreciation and amortization	(4,478		)	(4,252		)
Net property, plant and equipment	9,955			9,611
Regulatory Assets and Deferred Debits
Regulatory assets	2,733			2,729
Other	39			44
Total regulatory assets and deferred debits	2,772			2,773
Total Assets	$	15,518		$	14,757
LIABILITIES AND COMMON STOCKHOLDER'S EQUITY
Current Liabilities
Accounts payable	$	365		$	333
Accounts payable to affiliated companies	70			38
Notes payable to affiliated companies	84			181
Taxes accrued	65			66
Interest accrued	47			46
Current maturities of long-term debt	562			11
Regulatory liabilities	35			144
Other	586			445
Total current liabilities	1,814			1,264
Long-Term Debt	4,298			4,875
Deferred Credits and Other Liabilities
Deferred income taxes	2,452			1,829
Accrued pension and other post-retirement benefit costs	221			286
Asset retirement obligations	806			833
Regulatory liabilities	547			618
Other	158			255
Total deferred credits and other liabilities	4,184			3,821
Commitments and Contingencies
Common Stockholder's Equity
Common Stock, no par; 60 million shares authorized; 100 shares outstanding at December 31, 2014 and 2013	1,762			1,762
Retained earnings	3,460			3,036
Accumulated other comprehensive loss	—			(1		)
Total common stockholder's equity	5,222			4,797
Total Liabilities and Common Stockholder's Equity	$	15,518		$	14,757

See Notes to Consolidated Financial Statements

100

PART II

DUKE ENERGY FLORIDA, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Years Ended December 31,
(in millions)	2014			2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	548		$	325		$	266
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	550			335			197
Equity component of AFUDC	—			(8		)	(37		)
Severance expense	—			—			6
Gains on sales of other assets and other, net	(1		)	(1		)	(2		)
Impairment charges	2			358			146
Deferred income taxes	400			368			142
Amount to be refunded to customers	—			—			100
Accrued pension and other post-retirement benefit costs	29			79			71
Contributions to qualified pension plans	—			(133		)	(128		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	(9		)	55			73
Receivables	(33		)	(44		)	37
Receivables from affiliated companies	(37		)	17			(13		)
Inventory	(36		)	42			(13		)
Other current assets	(269		)	(109		)	22
Increase (decrease) in
Accounts payable	18			(22		)	21
Accounts payable to affiliated companies	32			(6		)	30
Taxes accrued	(31		)	18			15
Other current liabilities	(80		)	159			51
Other assets	(59		)	(154		)	8
Other liabilities	(58		)	(74		)	(94		)
Net cash provided by operating activities	966			1,205			898
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(699		)	(915		)	(809		)
Purchases of available-for-sale securities	(1,189		)	(1,656		)	(791		)
Proceeds from sales and maturities of available-for-sale securities	1,195			1,658			791
Notes receivable from affiliated companies	—			207			(207		)
Other	(31		)	—			16
Net cash used in investing activities	(724		)	(706		)	(1,000		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	225			—			642
Payments for the:
Redemption of long-term debt	(252		)	(435		)	(10		)
Redemption of preferred stock	—			(34		)	—
Proceeds from issuance of short-term debt with original maturities greater than 90 days	—			—			65
Payments for the redemption of short-term debt with original maturities greater than 90 days	—			—			(65		)
Notes payable and commercial paper	—			—			(233		)
Notes payable to affiliated companies	(97		)	181			(8		)
Dividends to parent	(124		)	(325		)	(170		)
Dividends paid on preferred stock	—			—			(2		)
Other	(2		)	(1		)	(2		)
Net cash (used in) provided by financing activities	(250		)	(614		)	217
Net (decrease) increase in cash and cash equivalents	(8		)	(115		)	115
Cash and Cash Equivalents at Beginning of Period	16			131			16
Cash and Cash Equivalents at End of Period	$	8		$	16		$	131
Supplemental Disclosures:
Cash paid for interest, net of amount capitalized	$	203		$	201		$	266
Cash paid for (received from) income taxes	59			(84		)	24
Significant non-cash transactions:
Accrued capital expenditures	100			88			139
Asset retirement obligation additions for spent nuclear fuel disposal related to the Progress Energy merger	—			—			139

See Notes to Consolidated Financial Statements

101

PART II

DUKE ENERGY FLORIDA, INC.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDER’S EQUITY

						Accumulated Other Comprehensive Loss
(in millions)	Common Stock		Retained Earnings			Net Losses on Cash Flow Hedges			Total Equity
Balance at December 31, 2011	$	1,757	$	2,945		$	(27	)	$	4,675
Net income	—		266			—			266
Other comprehensive income	—		—			27			27
Stock-based compensation expense	5		—			—			5
Dividend to parent	—		(170		)	—			(170		)
Preferred stock dividends at stated rate	—		(2		)	—			(2		)
Tax dividend	—		(2		)	—			(2		)
Balance at December 31, 2012	$	1,762	$	3,037		$	—		$	4,799
Net income	—		325			—			325
Other comprehensive loss	—		—			(1		)	(1		)
Dividend to parent	—		(325		)	—			(325		)
Premium on the redemption of preferred stock	—		(1		)	—			(1		)
Balance at December 31, 2013	$	1,762	$	3,036		$	(1	)	$	4,797
Net income	—		548			—			548
Other comprehensive income	—		—			1			1
Dividend to parent	—		(124		)	—			(124		)
Balance at December 31, 2014	$	1,762	$	3,460		$	—		$	5,222

See Notes to Consolidated Financial Statements

102

PART II

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Duke Energy Ohio, Inc.

Charlotte, North Carolina

We have audited the accompanying consolidated balance sheets of Duke Energy Ohio, Inc. and subsidiaries (the "Company") as of December 31, 2014 and 2013, and the related consolidated statements of operations and comprehensive income, changes in common stockholder’s equity, and cash flows for each of the three years in the period ended December 31, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Duke Energy Ohio, Inc. and subsidiaries at December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting principles generally accepted in the United States of America.

/s/ Deloitte & Touche LLP

Charlotte, North Carolina

February 27, 2015

103

PART II

DUKE ENERGY OHIO, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

	Years Ended December 31,
(in millions)	2014			2013		2012
Operating Revenues
Regulated electric	$	1,316		$	1,258	$	1,281
Nonregulated electric and other	19			34		68
Regulated natural gas	578			513		471
Total operating revenues	1,913			1,805		1,820
Operating Expenses
Fuel used in electric generation and purchased power - regulated	459			428		475
Fuel used in electric generation and purchased power - nonregulated	25			41		57
Cost of natural gas	185			152		142
Operation, maintenance and other	516			546		586
Depreciation and amortization	214			213		195
Property and other taxes	234			242		205
Impairment charges	94			5		2
Total operating expenses	1,727			1,627		1,662
Gains on Sales of Other Assets and Other, net	1			4		1
Operating Income	187			182		159
Other Income and Expenses, net	10			2		8
Interest Expense	86			74		89
Income From Continuing Operations Before Income Taxes	111			110		78
Income Tax Expense From Continuing Operations	43			43		33
Income From Continuing Operations	68			67		45
(Loss) Income From Discontinued Operations, net of tax	(563		)	35		130
Net (Loss) Income	$	(495	)	$	102	$	175
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	—			1		27
Comprehensive (Loss) Income	$	(495	)	$	103	$	202

See Notes to Consolidated Financial Statements

104

PART II

DUKE ENERGY OHIO, INC.

CONSOLIDATED BALANCE SHEETS

	December 31,
(in millions)	2014			2013
ASSETS
Current Assets
Cash and cash equivalents	$	20		$	36
Receivables (net of allowance for doubtful accounts of $2 at December 31, 2014 and December 31, 2013)	93			121
Receivables from affiliated companies	107			121
Notes receivable from affiliated companies	145			57
Inventory	97			229
Assets held for sale	316			—
Regulatory assets	49			57
Other	167			270
Total current assets	994			891
Investments and Other Assets
Goodwill	920			920
Assets held for sale	2,605			—
Other	23			232
Total investments and other assets	3,548			1,152
Property, Plant and Equipment
Cost	7,141			11,143
Accumulated depreciation and amortization	(2,213		)	(2,908		)
Generation facilities to be retired, net	9			—
Net property, plant and equipment	4,937			8,235
Regulatory Assets and Deferred Debits
Regulatory assets	512			471
Other	8			14
Total regulatory assets and deferred debits	520			485
Total Assets	$	9,999		$	10,763
LIABILITIES AND COMMON STOCKHOLDER'S EQUITY
Current Liabilities
Accounts payable	$	209		$	319
Accounts payable to affiliated companies	74			77
Notes payable to affiliated companies	491			43
Taxes accrued	163			167
Interest accrued	19			17
Current maturities of long-term debt	157			47
Liabilities associated with assets held for sale	246			—
Regulatory liabilities	10			27
Other	66			110
Total current liabilities	1,435			807
Long-Term Debt	1,584			2,141
Long-Term Debt Payable to Affiliated Companies	25			—
Deferred Credits and Other Liabilities
Deferred income taxes	1,765			2,012
Accrued pension and other post-retirement benefit costs	48			58
Liabilities associated with assets held for sale	34			—
Asset retirement obligations	27			28
Regulatory liabilities	241			262
Other	166			186
Total deferred credits and other liabilities	2,281			2,546
Commitments and Contingencies
Common Stockholder's Equity
Common stock, $8.50 par value, 120,000,000 shares authorized; 89,663,086 shares outstanding at December 31, 2014 and 2013	762			762
Additional paid-in capital	4,782			4,882
Accumulated deficit	(870		)	(375		)
Total common stockholder's equity	4,674			5,269
Total Liabilities and Common Stockholder's Equity	$	9,999		$	10,763

See Notes to Consolidated Financial Statements

105

PART II

DUKE ENERGY OHIO, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Years Ended December 31,
(in millions)	2014			2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$	(495	)	$	102		$	175
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation and amortization	258			357			342
Equity component of AFUDC	(4		)	(1		)	(6		)
Gains on sales of other assets and other, net	(1		)	(5		)	(7		)
Impairment charges	941			5			2
Deferred income taxes	(219		)	98			61
Accrued pension and other post-retirement benefit costs	8			17			11
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	27			17			(5		)
Receivables	(56		)	(15		)	29
Receivables from affiliated companies	14			(39		)	61
Inventory	8			(3		)	15
Other current assets	(5		)	(1		)	(62		)
Increase (decrease) in
Accounts payable	27			13			5
Accounts payable to affiliated companies	(3		)	15			(22		)
Taxes accrued	(9		)	1			(24		)
Other current liabilities	27			14			(21		)
Other assets	(4		)	(6		)	6
Other liabilities	(33		)	(73		)	(116		)
Net cash provided by operating activities	481			496			444
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(322		)	(434		)	(514		)
Net proceeds from the sales of other assets	—			11			82
Notes receivable from affiliated companies	(88		)	(56		)	400
Other	(12		)	1			6
Net cash used in investing activities	(422		)	(478		)	(26		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			450			—
Payments for the redemption of long-term debt	(449		)	(258		)	(556		)
Notes payable to affiliated companies	473			(202		)	245
Dividends to parent	(100		)	—			(175		)
Other	1			(3		)	—
Net cash used in financing activities	(75		)	(13		)	(486		)
Net (decrease) increase in cash and cash equivalents	(16		)	5			(68		)
Cash and cash equivalents at beginning of period	36			31			99
Cash and cash equivalents at end of period	20			36			31
Supplemental Disclosures:
Cash paid for interest, net of amount capitalized	$	76		$	71		$	93
Cash (received from) paid for income taxes	(5		)	9			18
Significant non-cash transactions:
Accrued capital expenditures	24			27			31
Transfer of Vermillion Generating Station to Duke Energy Indiana	—			—			28

See Notes to Consolidated Financial Statements

106

PART II

DUKE ENERGY OHIO, INC.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDER’S EQUITY

									Accumulated Other Comprehensive Loss
(in millions)	Common Stock		Additional Paid-in Capital			Accumulated Deficit			Pension and OPEB Related Adjustments			Total Equity
Balance at December 31, 2011	$	762	$	5,085		$	(652	)	$	(28	)	$	5,167
Net income	―		―			175			—			175
Other comprehensive income	—		—			—			27			27
Transfer of Vermillion Generating Station to Duke Energy Indiana	―		(28		)	―			―			(28		)
Dividends to parent	—		(175		)	—			—			(175		)
Balance at December 31, 2012	$	762	$	4,882		$	(477	)	$	(1	)	$	5,166
Net income	―		―			102			―			102
Other comprehensive income	—		—			―			1			1
Balance at December 31, 2013	$	762	$	4,882		$	(375	)	$	—		$	5,269
Net loss	―		―			(495		)	―			(495		)
Dividends to parent	—		(100		)	—			—			(100		)
Balance at December 31, 2014	$	762	$	4,782		$	(870	)	—			$	4,674

See Notes to Consolidated Financial Statements

107

PART II

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors of

Duke Energy Indiana, Inc.

Charlotte, North Carolina

We have audited the accompanying consolidated balance sheets of Duke Energy Indiana, Inc. and subsidiary (the "Company") as of December 31, 2014 and 2013, and the related consolidated statements of operations and comprehensive income, changes in common stockholder’s equity, and cash flows for each of the three years in the period ended December 31, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Duke Energy Indiana, Inc. and subsidiary at December 31, 2014 and 2013, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting principles generally accepted in the United States of America.

/s/ Deloitte & Touche LLP

Charlotte, North Carolina

February 27, 2015

108

PART II

DUKE ENERGY INDIANA, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

	Years Ended December 31,
(in millions)	2014		2013			2012
Operating Revenues	$	3,175	$	2,926		$	2,717
Operating Expenses
Fuel used in electric generation and purchased power	1,259		1,131			1,088
Operation, maintenance and other	670		649			655
Depreciation and amortization	413		342			389
Property and other taxes	128		71			81
Impairment charges	—		—			579
Total operating expenses	2,470		2,193			2,792
Operating Income (Loss)	705		733			(75		)
Other Income and Expenses, net	22		18			90
Interest Expense	171		170			138
Income (Loss) Before Income Taxes	556		581			(123		)
Income Tax Expense (Benefit)	197		223			(73		)
Net Income (Loss)	359		358			(50		)
Other Comprehensive Loss, net of tax
Reclassification into earnings from cash flow hedges	—		(2		)	(2		)
Comprehensive Income (Loss)	$	359	$	356		$	(52	)

See Notes to Consolidated Financial Statements

109

PART II

DUKE ENERGY INDIANA, INC.

CONSOLIDATED BALANCE SHEETS

	December 31,
(in millions)	2014			2013
ASSETS
Current Assets
Cash and cash equivalents	$	6		$	15
Receivables (net of allowance for doubtful accounts of $1 at December 31, 2014 and December 31, 2013)	87			22
Receivables from affiliated companies	115			151
Notes receivable from affiliated companies	—			96
Inventory	537			434
Regulatory assets	93			118
Other	326			125
Total current assets	1,164			961
Investments and Other Assets
Other	251			269
Total investments and other assets	251			269
Property, Plant and Equipment
Cost	13,034			12,489
Accumulated depreciation and amortization	(4,219		)	(3,913		)
Net property, plant and equipment	8,815			8,576
Regulatory Assets and Deferred Debits
Regulatory assets	685			717
Other	24			25
Total regulatory assets and deferred debits	709			742
Total Assets	$	10,939		$	10,548
LIABILITIES AND COMMON STOCKHOLDER'S EQUITY
Current Liabilities
Accounts payable	$	179		$	206
Accounts payable to affiliated companies	58			56
Notes payable to affiliated companies	71			—
Taxes accrued	54			57
Interest accrued	56			56
Current maturities of long-term debt	5			5
Regulatory liabilities	54			16
Other	98			88
Total current liabilities	575			484
Long-Term Debt	3,636			3,641
Long-Term Debt Payable to Affiliated Companies	150			150
Deferred Credits and Other Liabilities
Deferred income taxes	1,591			1,171
Investment tax credits	139			140
Accrued pension and other post-retirement benefit costs	82			163
Asset retirement obligations	32			30
Regulatory liabilities	796			782
Other	90			48
Total deferred credits and other liabilities	2,730			2,334
Commitments and Contingencies
Common Stockholder's Equity
Common Stock, no par; $0.01 stated value, 60,000,000 shares authorized; 53,913,701 shares outstanding at December 31, 2014 and 2013	1			1
Additional paid-in capital	1,384			1,384
Retained earnings	2,460			2,551
Accumulated other comprehensive income	3			3
Total common stockholder's equity	3,848			3,939
Total Liabilities and Common Stockholder's Equity	$	10,939		$	10,548

See Notes to Consolidated Financial Statements

110

PART II

DUKE ENERGY INDIANA, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Years Ended December 31,
(in millions)	2014			2013			2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$	359		$	358		$	(50	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	416			346			393
Equity component of AFUDC	(14		)	(15		)	(84		)
Impairment charges	—			—			579
Deferred income taxes	308			304			(74		)
Accrued pension and other post-retirement benefit costs	16			25			15
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	—			(30		)	—
Receivables	(35		)	3			6
Receivables from affiliated companies	36			(47		)	52
Inventory	(103		)	(53		)	(50		)
Other current assets	(8		)	(40		)	(25		)
Increase (decrease) in
Accounts payable	(41		)	32			18
Accounts payable to affiliated companies	2			(4		)	(12		)
Taxes accrued	(32		)	(30		)	(27		)
Other current liabilities	5			(5		)	6
Other assets	(21		)	(16		)	6
Other liabilities	17			(84		)	(37		)
Net cash provided by operating activities	905			744			716
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(625		)	(545		)	(718		)
Purchases of available-for-sale securities	(20		)	(11		)	(17		)
Proceeds from sales and maturities of available-for-sale securities	16			7			18
Notes receivable from affiliated companies	96			(96		)	—
Other	4			(3		)	(1		)
Net cash used in investing activities	(529		)	(648		)	(718		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	—			498			250
Payments for the redemption of long-term debt	(5		)	(405		)	(7		)
Notes payable to affiliated companies	71			(81		)	(219		)
Dividend to parent	(450		)	(125		)	—
Other	(1		)	(4		)	(2		)
Net cash (used in) provided by financing activities	(385		)	(117		)	22
Net (decrease) increase in cash and cash equivalents	(9		)	(21		)	20
Cash and cash equivalents at beginning of period	15			36			16
Cash and cash equivalents at end of period	$	6		$	15		$	36
Supplemental Disclosures:
Cash paid for interest, net of amount capitalized	$	169		$	194		$	130
Cash (received from) paid for income taxes	(61		)	46			57
Significant non-cash transactions:
Accrued capital expenditures	87			73			67
Transfer of Vermillion Generating Station from Duke Energy Ohio	—			—			26

See Notes to Consolidated Financial Statements

111

PART II

DUKE ENERGY INDIANA, INC.

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON STOCKHOLDER’S EQUITY

								Accumulated Other Comprehensive Income
(in millions)	Common Stock		Additional Paid-in Capital		Retained Earnings			Net Gains on Cash Flow Hedges			Total Equity
Balance at December 31, 2011	$	1	$	1,358	$	2,368		$	7		$	3,734
Net loss	—		—		(50		)	—			(50		)
Other comprehensive loss	—		—		—			(2		)	(2		)
Transfer of Vermillion Generating Station from Duke Energy Ohio	—		26		—			—			26
Balance at December 31, 2012	$	1	$	1,384	$	2,318		$	5		$	3,708
Net income	—		—		358			—			358
Other comprehensive loss	—		—		—			(2		)	(2		)
Dividend to parent	—		—		(125		)	—			(125		)
Balance at December 31, 2013	$	1	$	1,384	$	2,551		$	3		$	3,939
Net income	—		—		359			—			359
Dividend to parent	—		—		(450		)	—			(450		)
Balance at December 31, 2014	$	1	$	1,384	$	2,460		$	3		$	3,848

See Notes to Consolidated Financial Statements

112

PART II

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements

For the Years Ended December 31, 2014, 2013 and 2012

Index to Combined Notes To Consolidated Financial Statements

The notes to the consolidated financial statements are a combined presentation. The following list indicates the registrants to which the notes apply.

Applicable Notes

Registrant

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

17

18

19

20

21

22

23

24

25

Duke Energy Corporation

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Carolinas, LLC

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Progress Energy, Inc.

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Progress, Inc.

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

•

Duke Energy Florida, Inc.

•

•

•

•

•

•

•

•

•

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1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Nature of Operations and Basis of Consolidation

Duke Energy Corporation (collectively with its subsidiaries, Duke Energy) is an energy company headquartered in Charlotte, North Carolina, subject to regulation by the Federal Energy Regulatory Commission (FERC). Duke Energy operates in the United States (U.S.) and Latin America primarily through its direct and indirect subsidiaries. Duke Energy’s subsidiaries include its subsidiary registrants, Duke Energy Carolinas, LLC (Duke Energy Carolinas); Progress Energy, Inc. (Progress Energy); Duke Energy Progress, Inc. (Duke Energy Progress); Duke Energy Florida, Inc. (Duke Energy Florida); Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, Inc. (Duke Energy Indiana). When discussing Duke Energy’s consolidated financial information, it necessarily includes the results of its six separate subsidiary registrants (collectively referred to as the Subsidiary Registrants), which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants (Duke Energy Registrants).

On July 2, 2012, Duke Energy merged with Progress Energy, with Duke Energy continuing as the surviving corporation. Progress Energy became a subsidiary of Duke Energy and Progress Energy’s regulated utility subsidiaries, Duke Energy Progress (formerly Carolina Power & Light Company d/b/a Progress Energy Carolinas, Inc.) and Duke Energy Florida (formerly Florida Power Corporation d/b/a Progress Energy Florida, Inc.), became indirect subsidiaries of Duke Energy. Duke Energy’s consolidated financial statements include Progress Energy, Duke Energy Progress and Duke Energy Florida activity beginning July 2, 2012. The impacts of acquisition accounting from Progress Energy’s merger with Duke Energy were recorded by Duke Energy and were not reflected on the financial statements of Progress Energy, Duke Energy Progress and Duke Energy Florida. See Note 2 for additional information regarding the merger. On July 2, 2012, just prior to the close of the merger, Duke Energy executed a one-for-three reverse stock split with respect to the issued and outstanding shares of Duke Energy common stock. All per-share amounts included in this Form 10-K are presented as if the stock split had been effective from the beginning of the earliest period presented.

On August 21, 2014, Duke Energy Commercial Enterprises, Inc., an indirect wholly owned subsidiary of Duke Energy Corporation, and Duke Energy SAM, LLC, a wholly owned subsidiary of Duke Energy Ohio, entered into a purchase and sale agreement (PSA) with a subsidiary of Dynegy Inc. (Dynegy) whereby Dynegy will acquire Duke Energy Ohio’s nonregulated Midwest generation business and Duke Energy Retail Sales LLC (Disposal Group). The results of operations of the nonregulated Midwest generation business have been classified as Discontinued Operations on the Consolidated Statements of Operations for the current and prior periods presented. Duke Energy has elected to present cash flows of discontinued operations combined with cash flows of continuing operations. Unless otherwise noted, the notes to these consolidated financial statements exclude amounts related to discontinued operations for all periods presented, assets held for sale and liabilities associated with assets held for sale as of December 31, 2014. See Note 2 for additional information.

The information in these combined notes relate to each of the Duke Energy Registrants as noted in the Index to the Combined Notes to Consolidated Financial Statements. However, none of the registrants makes any representations as to information related solely to Duke Energy or the subsidiaries of Duke Energy other than itself.

These Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and subsidiaries where the respective Duke Energy Registrants have control. These Consolidated Financial Statements also reflect the Duke Energy Registrants’ proportionate share of certain jointly owned generation and transmission facilities.

Duke Energy Carolinas is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of North Carolina and South Carolina. Duke Energy Carolinas is subject to the regulatory provisions of the North Carolina Utilities Commission (NCUC), Public Service Commission of South Carolina (PSCSC), U.S. Nuclear Regulatory Commission (NRC) and FERC. Substantially all of Duke Energy Carolinas’ operations qualify for regulatory accounting.

Progress Energy is a public utility holding company headquartered in Raleigh, North Carolina, subject to regulation by the FERC. Progress Energy conducts operations through its wholly owned subsidiaries, Duke Energy Progress and Duke Energy Florida. Substantially all of Progress Energy’s operations qualify for regulatory accounting.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy Progress is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of North Carolina and South Carolina. Duke Energy Progress is subject to the regulatory provisions of the NCUC, PSCSC, NRC and FERC. Substantially all of Duke Energy Progress’ operations qualify for regulatory accounting.

Duke Energy Florida is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Florida. Duke Energy Florida is subject to the regulatory provisions of the Florida Public Service Commission (FPSC), NRC and FERC. Substantially all of Duke Energy Florida’s operations qualify for regulatory accounting.

Duke Energy Ohio is a regulated public utility primarily engaged in the transmission and distribution of electricity in Ohio and Kentucky, in the generation business in Kentucky, and the transportation and sale of natural gas in portions of Ohio and Kentucky. Operations in Kentucky are conducted through its wholly owned subsidiary, Duke Energy Kentucky, Inc. (Duke Energy Kentucky). Duke Energy Ohio conducts competitive auctions for retail electricity supply in Ohio whereby the energy price is recovered from retail customers. References herein to Duke Energy Ohio include Duke Energy Ohio and its subsidiaries, unless otherwise noted. Duke Energy Ohio is subject to the regulatory provisions of the Public Utilities Commission of Ohio (PUCO), Kentucky Public Service Commission (KPSC) and FERC. Duke Energy Ohio applies regulatory accounting to a portion of its operations. Duke Energy has agreed to sell Duke Energy Ohio's nonregulated Midwest generation business, which sells power into wholesale energy markets, to Dynegy. See Note 2 for additional information.

Duke Energy Indiana is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Indiana. Duke Energy Indiana is subject to the regulatory provisions of the Indiana Utility Regulatory Commission (IURC) and FERC. Substantially all of Duke Energy Indiana’s operations qualify for regulatory accounting.

Certain prior year amounts have been reclassified to conform to the current year presentation.

Other Current and Non-Current Assets and Liabilities

Other within Current Assets includes the current portion of deferred tax assets, which are disclosed in Note 22. Additionally, the following are included in Other within Current Assets or Current Liabilities in the Consolidated Balance Sheets of the Duke Energy Registrants at December 31, 2014 and 2013. The amounts presented exceeded 5 percent of current assets or 5 percent of current liabilities unless otherwise noted.

		December 31,
(in millions)	Location	2014		2013
Duke Energy
Accrued compensation	Current Liabilities	$	638	$	621
Duke Energy Carolinas
Accrued compensation	Current Liabilities	$	216	$	198
Collateral liabilities	Current Liabilities	128		120
Progress Energy
Income taxes receivable(b)	Current Assets	$	718	$	119
Customer deposits	Current Liabilities	360		349
Accrued compensation(a)	Current Liabilities	174		214
Derivative liabilities(b)	Current Liabilities	271		—
Duke Energy Progress
Income taxes receivable(b)	Current Assets	$	272	$	15
Customer deposits	Current Liabilities	135		129
Accrued compensation	Current Liabilities	116		121
Derivative liabilities(b)	Current Liabilities	108		38
Duke Energy Florida
Income taxes receivable(b)	Current Assets	$	177	$	65
Customer deposits	Current Liabilities	225		220
Accrued compensation(a)	Current Liabilities	57		65
Derivative liabilities(b)	Current Liabilities	163		—
Duke Energy Ohio
Collateral assets(a)	Current Assets	$	13	$	122
Duke Energy Indiana
Income taxes receivable	Current Assets	$	98	$	56
Accrued compensation(a)	Current Liabilities	25		25
Collateral liabilities	Current Liabilities	43		40

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

(a) Does not exceed 5 percent of total current assets or liabilities, as appropriate, on the Consolidated Balance Sheets at December 31, 2014.

(b) Does not exceed 5 percent of total current assets or liabilities, as appropriate, on the Consolidated Balance Sheets at December 31, 2013.

Preferred Stock

In March 2013, Duke Energy Progress and Duke Energy Florida redeemed all series of their outstanding preferred stock at prices ranging from $101.00 to $110.00 per share for Duke Energy Progress and $101.00 to $104.25 per share for Duke Energy Florida plus accrued dividends for all series. Duke Energy Progress and Duke Energy Florida redeemed the shares for $62 million and $34 million, respectively.

Discontinued Operations

For the year ended December 31, 2014, Duke Energy’s Loss from Discontinued Operations, net of tax was primarily related to a write-down of the carrying amount of the assets to the estimated fair value of the Disposal Group, based on the transaction price included in the PSA, and the operations of the Disposal Group. For the years ended December 31, 2013 and 2012, Duke Energy’s Income From Discontinued Operations, net of tax was primarily related to the operations of the Disposal Group. See Note 2 for additional information.

For the years ended December 31, 2014, 2013 and 2012. Progress Energy’s (Loss) Income From Discontinued Operations, net of tax was primarily due to tax impacts related to prior sales of diversified businesses.

Amounts Attributable to Controlling Interests

The following table presents Net Income Attributable to Duke Energy Corporation for continuing operations and discontinued operations.

	Years ended December 31,
	2014						2013					2012
(in millions)	Duke Energy			Progress Energy			Duke Energy			Progress Energy		Duke Energy			Progress Energy
Income from Continuing Operations	$	2,465		$	880		$	2,590		$	659	1,611			355
Income of Continuing Operations Attributable to Noncontrolling Interests	14			5			16			3		18			7
Income from Continuing Operations Attributable to Duke Energy Corporation	$	2,451		$	875		$	2,574		$	656	$	1,593		$	348
(Loss) Income From Discontinued Operations, net of tax	$	(576	)	$	(6	)	$	86		$	16	171			52
Loss of Discontinued Operations attributable to Noncontrolling Interests, net of tax	(8		)	—			(5		)	—		(4		)	—
(Loss) Income From Discontinued Operations Attributable to Duke Energy Corporation, net of tax	$	(568	)	$	(6	)	$	91		$	16	$	175		$	52
Net Income	$	1,889		$	874		$	2,676		$	675	$	1,782		$	407
Net Income Attributable to Noncontrolling Interest	6			5			11			3		14			7
Net Income Attributable to Duke Energy Corporation	$	1,883		$	869		$	2,665		$	672	$	1,768		$	400

Significant Accounting Policies

Use of Estimates

In preparing financial statements that conform to generally accepted accounting principles (GAAP) in the U.S., the Duke Energy Registrants 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.

Regulatory Accounting

The majority of the Duke Energy Registrants’ operations are subject to price regulation for the sale of electricity and gas by state utility commissions or FERC. When prices are set on the basis of specific costs of the regulated operations and an effective franchise is in place such that sufficient gas or electric services can be sold to recover those costs, the Duke Energy Registrants apply regulatory accounting. Regulatory accounting changes the timing of the recognition of costs or revenues relative to a company that does not apply regulatory accounting. As a result, Regulatory assets and Regulatory liabilities are recognized on the Consolidated Balance Sheets. Regulatory assets and liabilities are amortized consistent with the treatment of the related cost in the ratemaking process. See Note 4 for further information.

Regulated Fuel Costs and Purchased Power

The Duke Energy Registrants utilize cost-tracking mechanisms, commonly referred to as fuel adjustment clauses. These clauses allow for the recovery of fuel and fuel-related costs and portions of purchased power costs through surcharges on customer rates. The difference between the costs incurred and the surcharge revenues is recorded as an adjustment to Fuel Operating Revenues – Regulated electric on the Consolidated Statements of Operations with an off-setting impact on regulatory assets or liabilities.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Cash and Cash Equivalents

All highly liquid investments with maturities of three months or less at the date of acquisition are considered cash equivalents. At December 31, 2014, $1,680 million of Duke Energy’s total cash and cash equivalents is held by entities domiciled in foreign jurisdictions. During the fourth quarter of 2014, Duke Energy declared a taxable dividend of historical foreign earnings in the form of notes payable that will result in the repatriation of approximately $2.7 billion in cash held and expected to be generated by International Energy over a period of up to 8 years. See Note 22 to the Consolidated Financial Statements, “Income Taxes,” for additional information.

Restricted Cash

The Duke Energy Registrants have restricted cash related primarily to collateral assets, escrow deposits and variable interest entities (VIEs). Restricted cash balances are reflected in Other within Current Assets and in Other within Investments and Other Assets on the Consolidated Balance Sheets. At December 31, 2014 and 2013, Duke Energy had restricted cash totaling $298 million and $307 million, respectively.

Inventory

Inventory is used for operations and is recorded primarily using the average cost method. Inventory related to regulated operations is valued at historical cost. Inventory related to nonregulated operations is valued at the lower of cost or market. Materials and supplies are recorded as inventory when purchased and subsequently charged to expense or capitalized to property, plant and equipment when installed. Reserves are established for excess and obsolete inventory. The components of inventory are presented in the tables below.

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke  Energy   Ohio		Duke  Energy   Indiana
Materials and supplies	$	2,102	$	719	$	981	$	676	$	305	$	67	$	258
Coal held for electric generation	997		362		329		150		178		21		275
Oil, gas and other fuel held for electric generation	360		43		280		140		140		9		4
Total inventory	$	3,459	$	1,124	$	1,590	$	966	$	623	$	97	$	537

	December 31, 2013
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke  Energy   Ohio		Duke  Energy   Indiana
Materials and supplies	$	1,901	$	654	$	854	$	567	$	287	$	117	$	193
Coal held for electric generation	1,018		374		334		187		147		65		238
Oil, gas and other fuel held for electric generation	331		37		236		99		137		47		3
Total inventory	$	3,250	$	1,065	$	1,424	$	853	$	571	$	229	$	434

Investments in Debt and Equity Securities

The Duke Energy Registrants classify investments into two categories — trading and available-for-sale. Both categories are recorded at fair value on the Consolidated Balance Sheets. Realized and unrealized gains and losses on trading securities are included in earnings. For certain investments of regulated operations such as the Nuclear Decommissioning Trust Fund (NDTF), realized and unrealized gains and losses (including any other-than-temporary impairments) on available-for-sale securities are recorded as a regulatory asset or liability. Otherwise, unrealized gains and losses are included in Accumulated Other Comprehensive Income (AOCI), unless other-than-temporarily impaired. Other-than-temporary impairments for equity securities and the credit loss portion of debt securities of nonregulated operations are included in earnings. Investments in debt and equity securities are classified as either current or noncurrent based on management’s intent and ability to sell these securities, taking into consideration current market liquidity. See Note 15 for further information.

Goodwill and Intangible Assets

Goodwill

Duke Energy, Progress Energy and Duke Energy Ohio perform annual goodwill impairment tests as of August 31 each year at the reporting unit level, which is determined to be an operating segment or one level below. Duke Energy, Progress Energy and Duke Energy Ohio update these tests between annual tests if events or circumstances occur that would more likely than not reduce the fair value of a reporting unit below its carrying value.

In 2012, Progress Energy changed its goodwill impairment testing date from October 31 to August 31 to better align its annual goodwill impairment testing procedure with those of Duke Energy. The change had no impact on goodwill. Neither the change in the goodwill impairment testing date nor the merger resulted in any changes to the Progress Energy reporting units.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Intangible Assets

Intangible assets are included in Other in Investments and Other Assets on the Consolidated Balance Sheets. Generally, intangible assets are amortized using an amortization method that reflects the pattern in which the economic benefits of the intangible asset are consumed, or on a straight-line basis if that pattern is not readily determinable. Amortization of intangibles is reflected in Depreciation and amortization in the Consolidated Statements of Operations. Intangible assets are subject to impairment testing and if impaired, the carrying value is accordingly reduced.

Emission allowances permit the holder of the allowance to emit certain gaseous byproducts of fossil fuel combustion, including sulfur dioxide (SO₂) and nitrogen oxide (NO_X). Allowances are issued by the U.S. Environmental Protection Agency (EPA) at zero cost and may also be bought and sold via third-party transactions. Allowances allocated to or acquired by the Duke Energy Registrants are held primarily for consumption. Carrying amounts for emission allowances are based on the cost to acquire the allowances or, in the case of a business combination, on the fair value assigned in the allocation of the purchase price of the acquired business.

Renewable energy certificates are used to measure compliance with renewable energy standards and are held primarily for consumption. See Note 11 for further information.

Long-Lived Asset Impairments

The Duke Energy Registrants evaluate long-lived assets, excluding goodwill, for impairment when circumstances indicate the carrying value of those assets may not be recoverable. An impairment exists when a long-lived asset’s carrying value exceeds the estimated undiscounted cash flows expected to result from the use and eventual disposition of the asset. The estimated cash flows may be based on alternative expected outcomes that are probability weighted. If the carrying value of the long-lived asset is not recoverable based on these estimated future undiscounted cash flows, the carrying value of the asset is written-down to its then-current estimated fair value and an impairment charge is recognized.

The Duke Energy Registrants assess fair value of long-lived assets using various methods, including recent comparable third-party sales, internally developed discounted cash flow analysis and analysis from outside advisors. Significant changes in commodity prices, the condition of an asset or management’s interest in selling the asset are generally viewed as triggering events to re-assess cash flows. See Note 11 for further information.

Property, Plant and Equipment

Property, plant and equipment are stated at the lower of depreciated historical cost net of any disallowances or fair value, if impaired. The Duke Energy Registrants capitalize all construction-related direct labor and material costs, as well as indirect construction costs such as general engineering, taxes and financing costs. See “Allowance for Funds Used During Construction (AFUDC) and Interest Capitalized” for information on capitalized financing costs. Costs of renewals and betterments that extend the useful life of property, plant and equipment are also capitalized. The cost of repairs, replacements and major maintenance projects, which do not extend the useful life or increase the expected output of the asset, are expensed as incurred. Depreciation is generally computed over the estimated useful life of the asset using the composite straight-line method. Depreciation studies are conducted periodically to update composite rates and are approved by state utility commissions and/or the FERC when required. The composite weighted-average depreciation rates, excluding nuclear fuel, are included in the table that follows.

	Years Ended December 31,
	2014		2013		2012
Duke Energy	2.8	%	2.8	%	2.9	%
Duke Energy Carolinas	2.7	%	2.8	%	2.8	%
Progress Energy	2.5	%	2.5	%	2.6	%
Duke Energy Progress	2.5	%	2.5	%	2.7	%
Duke Energy Florida	2.7	%	2.4	%	2.5	%
Duke Energy Ohio	2.3	%	3.3	%	3.2	%
Duke Energy Indiana	3.0	%	2.8	%	3.3	%

In general, when the Duke Energy Registrants retire regulated property, plant and equipment, original cost plus the cost of retirement, less salvage value, is charged to accumulated depreciation. However, when it becomes probable a regulated asset will be retired substantially in advance of its original expected useful life or is abandoned, the cost of the asset and the corresponding accumulated depreciation is recognized as a separate asset. If the asset is still in operation, the net amount is classified as Generation facilities to be retired, net on the Consolidated Balance Sheets. If the asset is no longer operating, the net amount is classified in Regulatory Assets on the Consolidated Balance Sheets. The carrying value of the asset is based on historical cost if the Duke Energy Registrants are allowed to recover the remaining net book value and a return equal to at least the incremental borrowing rate. If not, an impairment is recognized to the extent the net book value of the asset exceeds the present value of future revenues discounted at the incremental borrowing rate.

When the Duke Energy Registrants sell entire regulated operating units, or retire or sell nonregulated properties, the original cost and accumulated depreciation and amortization balances are removed from Property, Plant and Equipment on the Consolidated Balance Sheets. Any gain or loss is recorded in earnings, unless otherwise required by the applicable regulatory body.

See Note 10 for further information.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Nuclear Fuel

Nuclear fuel is classified as Property, Plant and Equipment on the Consolidated Balance Sheets, except for Duke Energy Florida. Duke Energy Florida has reclassified all Crystal River Unit 3 Nuclear Station (Crystal River Unit 3) investments, including nuclear fuel, to a regulatory asset. Refer to Note 4, “Regulatory Matters,” for additional information on Crystal River Unit 3.

Nuclear fuel in the front-end fuel processing phase is considered work in progress and not amortized until placed in service. Amortization of nuclear fuel is included within Fuel used in electric generation and purchased power - regulated in the Consolidated Statements of Operations. Amortization is recorded using the units-of-production method.

Allowance for Funds Used During Construction and Interest Capitalized

For regulated operations, the debt and equity costs of financing the construction of property, plant and equipment are reflected as AFUDC and capitalized as a component of the cost of property, plant and equipment. AFUDC equity is reported on the Consolidated Statements of Operations as non-cash income in Other income and expenses, net. AFUDC debt is reported as a non-cash offset to Interest Expense. After construction is completed, the Duke Energy Registrants are permitted to recover these costs through their inclusion in rate base and the corresponding subsequent depreciation or amortization of those regulated assets.

AFUDC equity, a permanent difference for income taxes, reduces the effective tax rate when capitalized and increases the effective tax rate when depreciated or amortized. See Note 22 for additional information.

For nonregulated operations, interest is capitalized during the construction phase with an offsetting non-cash credit to Interest Expense on the Consolidated Statements of Operations.

Asset Retirement Obligations

Asset retirement obligations are recognized for legal obligations associated with the retirement of property, plant and equipment. Substantially all asset retirement obligations are related to regulated operations. When recording an asset retirement obligation, the present value of the projected liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The liability is accreted over time. For operating plants, the present value of the liability is added to the cost of the associated asset and depreciated over the remaining life of the asset. For retired plants, the present value of the liability is recorded as a regulatory asset and expensed over the recovery period in rates.

The present value of the initial obligation and subsequent updates are based on discounted cash flows, which include estimates regarding timing of future cash flows, selection of discount rates and cost escalation rates, among other factors. These estimates are subject to change. Depreciation expense is adjusted prospectively for any changes to the carrying amount of the associated asset. The Duke Energy Registrants receive amounts to fund the cost of the asset retirement obligation for regulated operations through a combination of regulated revenues and NDTF. As a result, the net of amounts recovered in regulated revenues, earnings on the NDTF, accretion expense and depreciation of the associated asset is deferred as a regulatory asset or liability.

Obligations for nuclear decommissioning are based on site-specific cost studies. Duke Energy Carolinas and Duke Energy Progress assume prompt dismantlement of the nuclear facilities after operations are ceased. Duke Energy Florida assumes Crystal River Unit 3 will be placed into a safe storage configuration until eventual dismantlement begins in approximately 60 years. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida also assume that spent fuel will be stored on site until such time that it can be transferred to a U.S. Department of Energy (DOE) facility.

Obligations for closure of ash basins are based upon discounted cash flows of estimated costs based upon probability weightings of the potential closure methods as evaluated on a site by site basis. Duke Energy Registrants with ash basins in North Carolina and certain basins in South Carolina and Indiana have a legal obligation that results in recognition of an asset retirement obligation at December 31, 2014. See Notes 5 and 9 for further information.

Revenue Recognition and Unbilled Revenue

Revenues on sales of electricity and gas are recognized when service is provided or the product is delivered. Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy delivered but not yet billed. Unbilled revenues can vary significantly from period to period as a result of seasonality, weather, customer usage patterns, customer mix, average price in effect for customer classes and meter reading schedules.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Unbilled revenues are included within Receivables and Restricted receivables of variable interest entities on the Consolidated Balance Sheets as shown in the following table. This table excludes amounts included in assets held for sale (AHFS).

	December 31,
(in millions)	2014		2013
Duke Energy	$	827	$	937
Duke Energy Carolinas	295		323
Progress Energy	217		189
Duke Energy Progress	135		120
Duke Energy Florida	82		69
Duke Energy Ohio	—		55
Duke Energy Indiana	27		5

Additionally, Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail accounts receivable, including receivables for unbilled revenues, to an affiliate, Cinergy Receivables Company, LLC (CRC) and account for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 17 for further information. These receivables for unbilled revenues are shown in the table below.

	December 31,
(in millions)	2014	2013
Duke Energy Ohio	79	89
Duke Energy Indiana	112	144

Allowance for Doubtful Accounts

Allowances for doubtful accounts are presented in the following table.

	December 31,
(in millions)	2014		2013	2012
Allowance for Doubtful Accounts
Duke Energy	$	17	30	34
Duke Energy Carolinas	3		3	3
Progress Energy	8		14	16
Duke Energy Progress	7		10	9
Duke Energy Florida	2		4	7
Duke Energy Ohio	2		2	2
Duke Energy Indiana	1		1	1
Allowance for Doubtful Accounts - VIEs
Duke Energy	$	51	43	44
Duke Energy Carolinas	6		6	6
Progress Energy	8		—	—
Duke Energy Progress	5		—	—
Duke Energy Florida	3		—	—

Derivatives and Hedging

Derivative and non-derivative instruments may be used in connection with commodity price, interest rate and foreign currency risk management activities, including swaps, futures, forwards and options. All derivative instruments except those that qualify for the normal purchase/normal sale (NPNS) exception are recorded on the Consolidated Balance Sheets at their fair value. Qualifying derivative instruments may be designated as either cash flow hedges or fair value hedges. Other derivative instruments (undesignated contracts) either have not been designated or do not qualify as hedges. The effective portion of the change in the fair value of cash flow hedges is recorded in AOCI. The effective portion of the change in the fair value of a fair value hedge is offset in net income by changes in the hedged item. For activity subject to regulatory accounting, gains and losses on derivative contracts are reflected as regulatory assets or liabilities and not as other comprehensive income or current period income. As a result, changes in fair value of these derivatives have no immediate earnings impact.

Formal documentation, including transaction type and risk management strategy, is maintained for all contracts accounted for as a hedge. At inception and at least every three months thereafter, the hedge contract is assessed to see if it is highly effective in offsetting changes in cash flows or fair values of hedged items.

See Note 14 for further information.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Captive Insurance Reserves

Duke Energy has captive insurance subsidiaries that provide coverage, on an indemnity basis, to the Subsidiary Registrants as well as certain third parties, on a limited basis, for various business risks and losses, such as property, workers’ compensation and general liability. Liabilities include provisions for estimated losses incurred but not yet reported (IBNR), as well as estimated provisions for known claims. IBNR reserve estimates are primarily based upon historical loss experience, industry data and other actuarial assumptions. Reserve estimates are adjusted in future periods as actual losses differ from experience.

Duke Energy, through its captive insurance entities, also has reinsurance coverage with third parties for certain losses above a per occurrence and/or aggregate retention. Receivables for reinsurance coverage are recognized when realization is deemed probable.

Unamortized Debt Premium, Discount and Expense

Premiums, discounts and expenses incurred with the issuance of outstanding long-term debt are amortized over the term of the debt issue. Call premiums and unamortized expenses associated with refinancing higher-cost debt obligations in the regulated operations are amortized. Amortization expense is recorded as Interest Expense in the Consolidated Statements of Operations and is reflected as Depreciation, amortization and accretion within Net cash provided by operating activities on the Consolidated Statements of Cash Flows.

Loss Contingencies and Environmental Liabilities

Contingent losses are recorded when it is probable a loss has occurred and can be reasonably estimated. When a range of the probable loss exists and no amount within the range is a better estimate than any other amount, the minimum amount in the range is recorded. Unless otherwise required by GAAP, legal fees are expensed as incurred.

Environmental liabilities are recorded on an undiscounted basis when environmental remediation or other liabilities becomes probable and can be reasonably estimated. Environmental expenditures related to past operations that do not generate current or future revenues are expensed. Environmental expenditures related to operations that generate current or future revenues are expensed or capitalized, as appropriate. Certain environmental expenditures receive regulatory accounting treatment and are recorded as regulatory assets.

See Notes 4 and 5 for further information.

Pension and Other Post-Retirement Benefit Plans

Duke Energy maintains qualified, non-qualified and other post-retirement benefit plans. Eligible employees of the Subsidiary Registrants participate in the respective qualified, non-qualified and other post-retirement benefit plans and the Subsidiary Registrants are allocated their proportionate share of benefit costs. See Note 21 for further information, including significant accounting policies associated with these plans.

Severance and Special Termination Benefits

Duke Energy has an ongoing severance plan under which, in general, the longer a terminated employee worked prior to termination the greater the amount of severance benefits. A liability for involuntary severance is recorded once an involuntary severance plan is committed to by management, or sooner, if involuntary severances are probable and can be reasonably estimated. For involuntary severance benefits incremental to its ongoing severance plan benefits, the fair value of the obligation is expensed at the communication date if there are no future service requirements, or over the required future service period. From time to time, Duke Energy offers special termination benefits under voluntary severance programs. Special termination benefits are recorded immediately upon employee acceptance absent a significant retention period. Otherwise, the cost is recorded over the remaining service period. Employee acceptance of voluntary severance benefits is determined by management based on the facts and circumstances of the benefits being offered. See Note 19 for further information.

Guarantees

Liabilities are recognized at the time of issuance or material modification of a guarantee for the estimated fair value of the obligation it assumes. Fair value is estimated using a probability-weighted approach. The obligation is reduced over the term of the guarantee or related contract in a systematic and rational method as risk is reduced. Any additional contingent loss for guarantee contracts subsequent to the initial recognition of a liability is accounted for and recognized at the time a loss is probable and can be reasonably estimated. See Note 7 for further information.

Stock-Based Compensation

Stock-based compensation represents costs related to stock-based awards granted to employees and Duke Energy Board of Directors (Board of Directors) members. Duke Energy recognizes stock-based compensation based upon the estimated fair value of awards, net of estimated forfeitures at the date of issuance. The recognition period for these costs begin at either the applicable service inception date or grant date and continues throughout the requisite service period, or for certain share-based awards until the employee becomes retirement eligible, if earlier. Compensation cost is recognized as expense or capitalized as a component of property, plant and equipment. See Note 20 for further information.

Income Taxes

Duke Energy and its subsidiaries file a consolidated federal income tax return and other state and foreign jurisdictional returns. The Subsidiary Registrants entered into a tax-sharing agreement with Duke Energy. Income taxes recorded represent amounts the Subsidiary Registrants would incur as separate C-Corporations. Deferred income taxes have been provided for temporary differences between GAAP and tax bases of assets and liabilities because the differences create taxable or tax-deductible amounts for future periods. Deferred taxes are not provided on translation gains and losses when earnings of a foreign operation are expected to be indefinitely reinvested. Investment tax credits (ITC) associated with regulated operations are deferred and amortized as a reduction of income tax expense over the estimated useful lives of the related properties.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Positions taken or expected to be taken on tax returns, including the decision to exclude certain income or transactions from a return, are recognized in the financial statements when it is more likely than not the tax position can be sustained based solely on the technical merits of the position. The largest amount of tax benefit that is greater than 50 percent likely of being effectively settled is recorded. Management considers a tax position effectively settled when: (i) the taxing authority has completed its examination procedures, including all appeals and administrative reviews; (ii) the Duke Energy Registrants do not intend to appeal or litigate the tax position included in the completed examination; and (iii) it is remote the taxing authority would examine or re-examine the tax position. The amount of a tax return position that is not recognized in the financial statements is disclosed as an unrecognized tax benefit. If these unrecognized tax benefits are later recognized, then there will be a decrease in income taxes payable, an income tax refund or a swap between deferred and current taxes payable. If the portion of tax benefits that has been recognized changes and those tax benefits are subsequently unrecognized, then the previously recognized tax benefits may impact the financial statements through increasing income taxes payable, reducing income tax refunds receivable changing deferred taxes. Changes in assumptions on tax benefits may also impact interest expense or interest income and may result in the recognition of tax penalties.

Tax-related interest and penalties are recorded in Interest Expense and Other Income and Expenses, net, in the Consolidated Statements of Operations.

See Note 22 for further information.

Accounting for Renewable Energy Tax Credits and Cash Grants

When Duke Energy receives ITC or cash grants on wind or solar facilities, it reduces the basis of the property recorded on the Consolidated Balance Sheets by the amount of the ITC or cash grant and, therefore, the ITC or grant benefit is recognized through reduced depreciation expense. Additionally, certain tax credits and government grants received provide for initial tax depreciable base in excess of the book carrying value equal to one half of the ITC or government grant. Deferred tax benefits are recorded as a reduction to income tax expense in the period that the basis difference is created.

Excise Taxes

Certain excise taxes levied by state or local governments are required to be paid even if not collected from the customer. These taxes are recognized on a gross basis. Otherwise, the taxes are accounted for net. Excise taxes accounted for on a gross basis as both operating revenues and property and other taxes in the Consolidated Statements of Operations were as follows.

	Years Ended December 31,
(in millions)	2014		2013		2012
Duke Energy	$	498	$	602	$	466
Duke Energy Carolinas	94		164		161
Progress Energy	263		304		317
Duke Energy Progress	56		115		113
Duke Energy Florida	207		189		205
Duke Energy Ohio	103		105		102
Duke Energy Indiana	38		29		33

During the third quarter of 2014, the North Carolina gross receipts tax was terminated due to the North Carolina Tax Simplification and Rate Reduction Act. The North Carolina gross receipts tax is no longer imposed effective July 1, 2014.

On July 23, 2013, North Carolina House Bill 998 (HB 998) was signed into law. HB 998 repealed the utility franchise tax effective July 1, 2014. The utility franchise tax was 3.22 percent gross receipts tax on sales of electricity. The result of this change in law will be an annual reduction in excise taxes of approximately $160 million for Duke Energy Carolinas and approximately $110 million for Duke Energy Progress. HB 998 also increases sales tax on electricity from 3 percent to 7 percent effective July 1, 2014. HB 998 requires the NCUC to adjust retail electric rates for the elimination of the utility franchise tax, changes due to the increase in sales tax on electricity, and the resulting change in liability of utility companies under the general franchise tax.

Foreign Currency Translation

The local currencies of most of Duke Energy’s foreign operations have been determined to be their functional currencies. However, certain foreign operations’ functional currency has been determined to be the U.S. dollar, based on an assessment of the economic circumstances of the foreign operation. Assets and liabilities of foreign operations whose functional currency is not the U.S. dollar are translated into U.S. dollars at the exchange rates in effect at period end. Translation adjustments resulting from changes in exchange rates are included in AOCI. Revenue and expense accounts are translated at average exchange rates during the year. Remeasurement gains and losses arising from balances and transactions denominated in currencies other than the local currency are included in the results of operations when they occur.

Dividend Restrictions and Unappropriated Retained Earnings

Duke Energy does not have any legal, regulatory or other restrictions on paying common stock dividends to shareholders. However, as further described in Note 4, due to conditions established by regulators in conjunction with merger transaction approvals, Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana have restrictions on paying dividends or otherwise advancing funds to Duke Energy. At December 31, 2014 and 2013, an insignificant amount of Duke Energy’s consolidated Retained earnings balance represents undistributed earnings of equity method investments.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

New Accounting Standards

The new accounting standards that were adopted for 2014, 2013 and 2012 had no significant impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. Disclosures have been enhanced to provide a discussion and tables on derivative contracts subject to enforceable master netting agreements and a table of quantitative disclosures about unobservable inputs. See Notes 14 and 16 for further information.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by the Duke Energy Registrants, as of December 31, 2014.

ASC 205 — Reporting Discontinued Operations. In April 2014, the Financial Accounting Standards Board (FASB) issued revised accounting guidance for reporting discontinued operations. A discontinued operation would be either (i) a component of an entity or a group of components of an entity that represents a separate major line of business or major geographical area of operations that either has been disposed of or is part of a single coordinated plan to be classified as held for sale or (ii) a business that, on acquisition, meets the criteria to be classified as held for sale.

For the Duke Energy Registrants, this guidance is effective on a prospective basis for interim and annual periods beginning January 1, 2015. This guidance will also result in increased disclosures for discontinued operations or disposals of individually significant components that are not classified as discontinued operations. In general, this guidance is likely to result in fewer disposals of assets qualifying as discontinued operations.

ASC 606 — Revenue from Contracts with Customers. In May 2014, the FASB issued revised accounting guidance for revenue recognition from contracts with customers. The core principle of this guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The amendments in this update also require disclosure of sufficient information to allow users to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.

For the Duke Energy Registrants, this guidance is effective for interim and annual periods beginning January 1, 2017. Duke Energy is currently evaluating the requirements. The ultimate impact of the new standard has not yet been determined.

2. ACQUISITIONS, DISPOSITIONS AND SALES OF OTHER ASSETS

ACQUISITIONS

The Duke Energy Registrants consolidate assets and liabilities from acquisitions as of the purchase date, and include earnings from acquisitions in consolidated earnings after the purchase date.

Purchase of NCEMPA's Generation

On September 5, 2014, Duke Energy Progress executed an agreement to purchase North Carolina Eastern Municipal Power Agency’s (NCEMPA) ownership interests in certain generating assets jointly owned with and operated by Duke Energy Progress. The agreement provides for the acquisition of a total of approximately 700 megawatts (MW) at Brunswick Nuclear Station (Brunswick), Shearon Harris Nuclear Station (Harris), Mayo Steam Station and Roxboro Steam Station. The purchase price for the ownership interest and fuel and spare parts inventory is approximately $1.2 billion. Under the agreement, Duke Energy Progress and NCEMPA will enter into a 30-year wholesale power supply agreement to continue meeting the needs of NCEMPA’s customers. Closing of the transaction is subject to certain conditions, including state and federal regulatory approvals and legislative action required prior to completing the transaction. On December 9, 2014, the FERC approved Duke Energy Progress' request to purchase NCEMPA's interests in the generation assets, approved Duke Energy Progress' 30-year wholesale power supply agreement with NCEMPA, and approved Duke Energy Progress' inclusion of the acquisition adjustment resulting from the asset purchase in wholesale power formula rates. The transaction is expected to close by the end of 2015 or early 2016.

Merger with Progress Energy

On July 2, 2012, Duke Energy completed its merger with Progress Energy, a North Carolina corporation engaged in the regulated utility business of generation, transmission and distribution and sale of electricity in portions of North Carolina, South Carolina and Florida. As a result of the merger, Progress Energy became a wholly owned subsidiary of Duke Energy. 

The merger between Duke Energy and Progress Energy provides increased scale and diversity with potentially enhanced access to capital over the long term and a greater ability to undertake the significant construction programs necessary to respond to increasing environmental regulation, plant retirements and customer demand growth. Duke Energy’s business risk profile is expected to improve over time due to the increased proportion of the business that is regulated. Additionally, cost savings, efficiencies and other benefits are expected from the combined operations.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Purchase Price

Total consideration transferred was based on the closing price of Duke Energy common shares on July 2, 2012, and was calculated as shown in the following table.

(dollars in millions, except per share amounts; shares in thousands)
Progress Energy common shares outstanding at July 2, 2012	296,116
Exchange ratio	0.87083
Duke Energy common shares issued for Progress Energy common shares outstanding	257,867
Closing price of Duke Energy common shares on July 2, 2012	$	69.84
Purchase price for common stock	$	18,009
Fair value of outstanding earned stock compensation awards	62
Total purchase price	$	18,071

Progress Energy’s stock-based compensation awards, including performance shares and restricted stock, were replaced with Duke Energy awards upon consummation of the merger. In accordance with accounting guidance for business combinations, a portion of the fair value of these awards is included in the purchase price as it represents consideration transferred in the merger.

Purchase Price Allocation

Fair value of assets acquired and liabilities assumed was determined based on significant estimates and assumptions, including Level 3 inputs, which are judgmental in nature. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows, and future market prices.

Additionally, the February 5, 2013 announcement of the decision to retire Crystal River Unit 3 reflected additional information related to facts and circumstances existing as of the acquisition date. See Note 4 for additional information related to Crystal River Unit 3. As such, Duke Energy presents assets acquired and liabilities assumed as if the retirement of Crystal River Unit 3 occurred on the acquisition date.

The majority of Progress Energy’s operations are subject to the rate-setting authority of the FERC, NCUC, PSCSC, and FPSC and are accounted for pursuant to U.S. GAAP, including the accounting guidance for regulated operations. Rate-setting and cost recovery provisions currently in place for Progress Energy’s regulated operations provide revenues derived from costs, including a return on investment of assets and liabilities included in rate base. Except for long-term debt, asset retirement obligations, capital leases, pension and other post-retirement benefit obligations (OPEB), and the wholesale portion of Crystal River Unit 3, fair values of tangible and intangible assets and liabilities subject to these rate-setting provisions approximate their carrying values. Accordingly, assets acquired and liabilities assumed and pro forma financial information do not reflect any net adjustments related to these amounts. The difference between fair value and pre-merger carrying amounts for long-term debt, asset retirement obligations, capital leases and pension and OPEB plans for regulated operations were recorded as Regulatory assets.

The excess of purchase price over estimated fair values of assets acquired and liabilities assumed was recognized as goodwill at the acquisition date. The goodwill reflects the value paid primarily for long-term potential for enhanced access to capital as a result of increased scale and diversity, opportunities for synergies, and an improved risk profile. Goodwill resulting from the merger was allocated entirely to the Regulated Utilities segment. None of the goodwill recognized is deductible for income tax purposes, and as such, no deferred taxes have been recorded related to goodwill.

The completed purchase price allocation is presented in the following table.

(in millions)
Current assets	$	3,204
Property, plant and equipment	23,141
Goodwill	12,469
Other long-term assets	9,990
Total assets	48,804
Current liabilities, including current maturities of long-term debt	3,593
Long-term liabilities, preferred stock and noncontrolling interests	10,394
Long-term debt	16,746
Total liabilities and preferred stock	30,733
Total purchase price	$	18,071

The purchase price allocation in the table above reflects refinements made to preliminary fair values of assets acquired and liabilities assumed as of December 31, 2012. These refinements include adjustments associated with the retirement of Crystal River Unit 3. The changes resulted in an increase to Goodwill of $2 million, an increase to the fair value of Current liabilities, including current maturities of long-term debt of $12 million, a decrease to Property, plant and equipment of $138 million, a decrease to Other long-term assets of $4 million and a decrease to Long-term liabilities, preferred stock and noncontrolling interests of $152 million. These refinements had no impact on the amortization of purchase accounting adjustments recorded to earnings during the year ended December 31, 2013, or for the six months ended December 31, 2012.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Pro Forma Financial Information

The following unaudited pro forma financial information reflects the consolidated results of operations of Duke Energy and the amortization of purchase price adjustments assuming the merger had taken place on January 1, 2012. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or future consolidated results of operations of Duke Energy.

Non-recurring merger consummation, integration and other costs incurred by Duke Energy and Progress Energy during the period have been excluded from pro forma earnings presented below. After-tax non-recurring merger consummation, integration and other costs incurred by both Duke Energy and Progress Energy were $413 million for the year ended 2012. The pro forma financial information also excludes potential future cost savings or non-recurring charges related to the merger.

	Year Ended December 31,
(in millions, except per share amounts)	2012
Revenues	$	23,976
Net Income Attributable to Duke Energy Corporation	2,417
Basic and Diluted Earnings Per Share	3.43

Accounting Charges Related to the Merger Consummation

The following pretax consummation charges were recognized upon closing of the merger and are included in the Duke Energy Registrants’ Consolidated Statements of Operations and Comprehensive Income for the year ended December 31, 2012.

(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
FERC Mitigation	$	117	$	46	$	71	$	71	$	—	$	—	$	—
Severance costs	196		63		82		55		27		21		18
Community support, charitable contributions and other	169		79		74		63		11		7		6
Total	$	482	$	188	$	227	$	189	$	38	$	28	$	24

FERC Mitigation charges reflect the portion of transmission project costs probable of disallowance, impairment of the carrying value of the generation assets serving Interim FERC Mitigation, and mark-to-market losses recognized on power sale agreements upon closing of the merger. Charges related to transmission projects and impairment of the carrying value of generation assets were recorded within Impairment charges in the Consolidated Statements of Operations. Mark-to-market losses on interim power sale agreements was recorded in Regulated electric operating revenues in the Consolidated Statements of Operations. Subsequent changes in fair value of interim power sale agreements over the life of the contracts and realized gains or losses on interim contract sales are also recorded within Regulated electric operating revenues. The ability to successfully defend future recovery of a portion of transmission projects in rates and any future changes to estimated transmission project costs could impact the amount not expected to be recovered.

In conjunction with the merger, in November 2011, Duke Energy and Progress Energy each offered a voluntary severance plan (VSP) to certain eligible employees. VSP and other severance costs incurred were recorded primarily within Operation, maintenance and other in the Consolidated Statements of Operations. See Note 19 for further information related to employee severance expenses.

Community support, charitable contributions and other reflect (i) the unconditional obligation to provide funding at a level comparable to historic practices over the next four years, and (ii) financial and legal advisory costs incurred upon the closing of the merger, retention and relocation costs paid to certain employees. These charges were recorded within Operation, maintenance and other in the Consolidated Statements of Operations.

Impact of Merger

The impact of Progress Energy on Duke Energy’s revenues and net income attributable to Duke Energy in the Consolidated Statements of Operations for the year ended December 31, 2012 was an increase of $4,943 million and $368 million, respectively.

Chilean Operations

In December 2012, Duke Energy acquired Iberoamericana de Energía Ibener, S.A. (Ibener) of Santiago, Chile, for cash consideration of $415 million. This acquisition included the 140 MW Duqueco hydroelectric generation complex consisting of two run-of-the-river plants located in southern Chile. Purchase price allocation consisted primarily of $383 million of property, plant and equipment, $30 million of intangible assets, $57 million of deferred income tax liabilities, $54 million of goodwill and $8 million of working capital.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DISPOSITIONS

Midwest Generation Exit

On August 21, 2014, Duke Energy Commercial Enterprises, Inc., an indirect wholly owned subsidiary of Duke Energy Corporation, and Duke Energy SAM, LLC, a wholly owned subsidiary of Duke Energy Ohio, entered into a PSA with a subsidiary of Dynegy whereby Dynegy will acquire Duke Energy’s Disposal Group for approximately $2.8 billion in cash subject to adjustments at closing for changes in working capital and capital expenditures. The completion of the transaction is conditioned on approval by FERC. On January 16, 2015, FERC issued a letter requesting additional information in connection with the transaction application. The request was for further economic analysis relating to the combined market power impacts of the proposed transaction and Dynegy's simultaneous acquisition of other assets in the PJM Interconnection, LLC (PJM) market, and information relating to rate protections for Dynegy's customers. On February 6, 2015, Duke Energy and Dynegy made two filings with FERC. The first filing provided additional information requested by FERC. The second filing provided information related to Dynegy's settlement agreement with the Independent Market Monitor for PJM, which no longer opposes the proposed transaction. The transaction is expected to close by the end of the second quarter of 2015.

The Disposal Group is included in the Commercial Power segment. The following table presents information related to the Duke Energy Ohio generation plants included in the Disposal Group.

Facility	Plant Type	Primary Fuel	Location	Total MW Capacity(c)	Owned MW Capacity(c)	Ownership Interest
Stuart(a)(b)	Fossil Steam	Coal	OH	2,308	900	39	%
Zimmer(a)	Fossil Steam	Coal	OH	1,300	605	46.5	%
Hanging Rock	Combined Cycle	Gas	OH	1,226	1,226	100	%
Miami Fort (Units 7 and 8)(a)	Fossil Steam	Coal	OH	1,020	652	64	%
Conesville(a)(b)	Fossil Steam	Coal	OH	780	312	40	%
Washington	Combined Cycle	Gas	OH	617	617	100	%
Fayette	Combined Cycle	Gas	PA	614	614	100	%
Killen(a)(b)	Fossil Steam	Coal	OH	600	198	33	%
Lee	Combustion Turbine	Gas	IL	568	568	100	%
Dick's Creek	Combustion Turbine	Gas	OH	136	136	100	%
Miami Fort	Combustion Turbine	Oil	OH	56	56	100	%
Total Midwest Generation				9,225	5,884

(a) Jointly owned with American Electric Power Generation Resources and/or The Dayton Power & Light Company.

(b) Station is not operated by Duke Energy Ohio.

(c) Total MW capacity is based on summer capacity.

The Disposal Group also includes a retail sales business owned by Duke Energy. In the second quarter of 2014, Duke Energy Ohio removed Ohio Valley Electric Corporation's (OVEC) purchase power agreement from the Disposal Group as it no longer intended to sell it with the Disposal Group. Duke Energy Ohio has requested cost-based recovery of its contractual entitlement in OVEC in its 2014 Electric Security Plan (ESP) application filed on May 29, 2014. See Note 4 for information related to the 2014 ESP.

The assets and associated liabilities of the Disposal Group are classified as held for sale in Duke Energy's and Duke Energy Ohio's Consolidated Balance Sheets at December 31, 2014.

The results of operations of the Disposal Group are classified as discontinued operations for current and prior periods in the accompanying Consolidated Statements of Operations and Comprehensive Income. Certain immaterial costs that that may be eliminated as a result of the sale have remained in continuing operations. The following table presents the results of discontinued operations.

Duke Energy

	Years Ended December 31,
(in millions)	2014			2013		2012
Operating Revenues	$	1,748		$	1,885	$	1,771
Estimated loss on disposition	(929		)	—		—
(Loss) Income before income taxes	$	(818	)	$	141	$	227
Income tax (benefit) expense	(294		)	56		82
(Loss) Income from discontinued operations of the Disposal Group	(524		)	85		145
Other, net of tax(a)	(52		)	1		26
(Loss) Income from Discontinued Operations, net of tax	$	(576	)	$	86	$	171

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

(a) Other discontinued operations relate to prior sales of businesses and includes indemnifications provided for certain legal, tax and environmental matters, and foreign currency translation adjustments.

Duke Energy Ohio

	Years Ended December 31,
(in millions)	2014			2013		2012
Operating Revenues	$	1,299		$	1,503	$	1,435
Estimated loss on disposition	(959		)	—		—
(Loss) Income before income taxes	$	(863	)	$	67	$	195
Income tax (benefit) expense	(300		)	32		65
(Loss) Income from Discontinued Operations, net of tax	$	(563	)	$	35	$	130

The Duke Energy and Duke Energy Ohio held for sale assets include net pretax impairments of approximately $929 million and $959 million, respectively, for the year ended December 31, 2014. The impairment was recorded to write-down the carrying amount of the assets to the estimated fair value of the business, based on the expected selling price to Dynegy less cost to sell. These losses were included in (Loss) Income from Discontinued Operations, net of tax in the Consolidated Statements of Operations and Comprehensive Income. The impairment will be updated, if necessary, based on the final sales price, after any adjustments at closing for working capital and capital expenditures.

Commercial Power has a revolving credit agreement (RCA) to support the operations of the nonregulated Midwest generation business. Interest expense associated with the RCA has been allocated to discontinued operations. No other interest expense related to corporate level debt has been allocated to discontinued operations.

The following table presents the Disposal Group's carrying values in the Consolidated Balance Sheets' major classes of Assets held for sale.

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Ohio
Current assets	$	364	$	316
Investments and other assets	52		46
Property, plant and equipment	2,590		2,559
Total assets held for sale	$	3,006	$	2,921
Current liabilities	$	262	$	246
Deferred credits and other liabilities	35		34
Total liabilities associated with assets held for sale	$	297	$	280

Duke Energy Ohio may continue to have transactions with the Disposal Group after the divestiture is complete depending on when the transaction closes. Duke Energy Ohio has a power purchase agreement with the Disposal Group, which extends through May 2015, for a portion of its standard service offer (SSO) supply requirement. In addition, for a period of up to 12 months, Duke Energy may provide transition services to Dynegy. Duke Energy will be reimbursed for transition services provided. The continuing cash flows are not expected to be material and are not considered direct cash flows. These arrangements do not allow Duke Energy or Duke Energy Ohio to significantly influence the operations of the Disposal Group once the sale is complete.

See Notes 4 and 5 for a discussion of contingencies related to the Disposal Group that will be retained by Duke Energy Ohio subsequent to the sale.

Vermillion Generating Station

On January 12, 2012, after receiving approvals from the FERC and IURC on August 12, 2011 and December 28, 2011, respectively, Duke Energy Vermillion II, LLC (Duke Energy Vermillion), an indirect wholly owned subsidiary of Duke Energy Ohio, completed the sale of its ownership interest in Vermillion Generating Station (Vermillion) to Duke Energy Indiana and Wabash Valley Power Association, Inc. (WVPA). Upon closing of the sale, Duke Energy Indiana held a 62.5 percent interest in Vermillion. Duke Energy Ohio received net proceeds of $82 million, of which $68 million was paid by Duke Energy Indiana. Following the transaction, Duke Energy Indiana retired Gallagher Units 1 and 3 effective February 1, 2012.

As Duke Energy Indiana is an affiliate of Duke Energy Vermillion, the transaction was accounted for as a transfer between entities under common control with no gain or loss recorded and did not have a significant impact to Duke Energy Ohio’s or Duke Energy Indiana’s results of operations. Proceeds received from Duke Energy Indiana are included in Net proceeds from the sales of other assets on Duke Energy Ohio’s Consolidated Statements of Cash Flows. Cash paid to Duke Energy Ohio is included in Capital expenditures on Duke Energy Indiana’s Consolidated Statements of Cash Flows. Duke Energy Ohio and Duke Energy Indiana recognized non-cash equity transfers of $28 million and $26 million, respectively, in their Consolidated Statements of Common Stockholder’s Equity on the transaction representing the difference between cash exchanged and the net book value of Vermillion. These amounts are not reflected in Duke Energy’s Consolidated Statements of Cash Flows or Consolidated Statements of Equity as the transaction is eliminated in consolidation.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Proceeds from WVPA are included in Net proceeds from the sales of other assets on Duke Energy Ohio’s Consolidated Statements of Cash Flows and Net proceeds from the sales of equity investments and other assets, and sales of and collections on notes receivable on Duke Energy’s Consolidated Statements of Cash Flows. The sale of the proportionate share of Vermillion to WVPA did not result in a significant gain or loss upon close of the transaction.

Sales Of Other Assets

During 2012, Duke Energy received proceeds of $187 million from the sale of non-core business assets within the Commercial Power segment for which no material gain or loss was recognized.

3. BUSINESS SEGMENTS

Duke Energy evaluates segment performance based on segment income. Segment income is defined as income from continuing operations net of income attributable to noncontrolling interests. Segment income, as discussed below, includes intercompany revenues and expenses that are eliminated in the Consolidated Financial Statements. Certain governance costs are allocated to each segment. In addition, direct interest expense and income taxes are included in segment income.

Operating segments are determined based on information used by the chief operating decision maker in deciding how to allocate resources and evaluate the performance.

Products and services are sold between affiliate companies and reportable segments of Duke Energy at cost. Segment assets as presented in the tables that follow exclude all intercompany assets.

Duke Energy

Duke Energy has the following reportable operating segments: Regulated Utilities, International Energy and Commercial Power.

Regulated Utilities conducts operations primarily through Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida, Duke Energy Indiana, and the regulated transmission and distribution operations of Duke Energy Ohio. These electric and natural gas operations are subject to the rules and regulations of the FERC, NCUC, PSCSC, FPSC, PUCO, IURC and KPSC. Substantially all of Regulated Utilities’ operations are regulated and, accordingly, these operations qualify for regulatory accounting treatment.

International Energy principally operates and manages power generation facilities and engages in sales and marketing of electric power, natural gas and natural gas liquids outside the U.S. Its activities principally target power generation in Latin America. Additionally, International Energy owns a 25 percent interest in National Methanol Company (NMC), a large regional producer of methyl tertiary butyl ether (MTBE) located in Saudi Arabia. The investment in NMC is accounted for under the equity method of accounting.

Commercial Power builds, develops and operates renewable generation and energy transmission projects throughout the continental U.S. As discussed in Note 2, Duke Energy entered into an agreement to sell Commercial Power's nonregulated Midwest generation business to Dynegy in a transaction that is expected to close during the second quarter of 2015. As a result of this divestiture, the results of operations of the nonregulated Midwest generation business have been reclassified to Discontinued Operations on the Consolidated Statements of Operations. Certain costs such as interest and general and administrative expenses previously allocated to the Disposal Group were not reclassified to discontinued operations. 

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The remainder of Duke Energy’s operations is presented as Other. While it is not an operating segment, Other primarily includes unallocated corporate interest expense, certain unallocated corporate costs, Bison Insurance Company Limited (Bison), Duke Energy’s wholly owned, captive insurance subsidiary, and contributions to the Duke Energy Foundation. On December 31, 2013, Duke Energy sold its interest in DukeNet Communications Holdings, LLC (DukeNet) to Time Warner Cable, Inc.

	Year Ended December 31, 2014
(in millions)	Regulated Utilities			International Energy		Commercial Power			Total Reportable Segments		Other			Eliminations			Total
Unaffiliated Revenues	$	22,228		$	1,417	$	255		$	23,900	$	25		$	—		$	23,925
Intersegment Revenues	43			—		—			43		80			(123		)	—
Total Revenues	$	22,271		$	1,417	$	255		$	23,943	$	105		$	(123	)	$	23,925
Interest Expense	$	1,093		$	93	$	58		$	1,244	$	400		$	(22	)	$	1,622
Depreciation and amortization	2,759			97		92			2,948		118			—			3,066
Equity in earnings of unconsolidated affiliates	(3		)	120		10			127		3			—			130
Income tax expense (benefit)(a)	1,628			449		(171		)	1,906		(237		)	—			1,669
Segment income(b)(c)(d)	2,795			55		(55		)	2,795		(334		)	(10		)	2,451
Add back noncontrolling interest component																	14
Loss from discontinued operations, net of tax																	(576		)
Net income																	$	1,889
Capital investments expenditures and acquisitions	$	4,744		$	67	$	555		$	5,366	$	162		$	—		$	5,528
Segment Assets	106,657			5,132		6,278			118,067		2,453			189			120,709

(a) International Energy includes a tax adjustment of $373 million related to deferred tax impact resulting from the decision to repatriate all cumulative historical undistributed foreign earnings. See Note 22 for additional information.

(b) Commercial Power recorded a pretax impairment charge of $94 million related to OVEC. See Note 11 for additional information.

(c) Other includes costs to achieve the Progress Energy merger. See Notes 2 and 25 for additional information about the merger and related costs.

(d) Regulated Utilities includes an increase in the litigation reserve related to the criminal investigation of the Dan River coal ash spill. See Note 5 for additional information.

	Year Ended December 31, 2013
(in millions)	Regulated Utilities			International Energy		Commercial Power			Total Reportable Segments		Other			Eliminations			Total
Unaffiliated Revenues(a)(b)(c)	$	20,871		$	1,546	$	254		$	22,671	$	85		$	—		$	22,756
Intersegment Revenues	39			—		6			45		90			(135		)	—
Total Revenues	$	20,910		$	1,546	$	260		$	22,716	$	175		$	(135	)	$	22,756
Interest Expense	$	986		$	86	$	61		$	1,133	$	416		$	(6	)	$	1,543
Depreciation and amortization	2,323			100		110			2,533		135			—			2,668
Equity in earnings of unconsolidated affiliates	(1		)	110		7			116		6			—			122
Income tax expense (benefit)	1,522			166		(148		)	1,540		(335		)	—			1,205
Segment income (a)(b)(c)(d)(e)(f)(g)	2,504			408		(88		)	2,824		(238		)	(12		)	2,574
Add back noncontrolling interest component																	16
Income from discontinued operations, net of tax																	86
Net income																	$	2,676
Capital investments expenditures and acquisitions	$	5,049		$	67	$	268		$	5,384	$	223		$	—		$	5,607
Segment Assets	99,884			4,998		6,955			111,837		2,754			188			114,779

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

(a) In May 2013, the PUCO approved a Duke Energy Ohio settlement agreement that provides for a net annual increase in electric distribution revenues beginning in May 2013. This rate increase impacts Regulated Utilities. See Note 4 for additional information.

(b) In June 2013, NCUC approved a Duke Energy Progress settlement agreement that included an increase in rates in the first year beginning in June 2013. This rate increase impacts Regulated Utilities. See Note 4 for additional information.

(c) In September 2013, Duke Energy Carolinas implemented revised customer rates approved by the NCUC and the PSCSC. These rate increases impact Regulated Utilities. See Note 4 for additional information.

(d) Regulated Utilities recorded an impairment charge related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information.

(e) Regulated Utilities recorded an impairment charge related to the letter Duke Energy Progress filed with the NRC requesting the NRC to suspend its review activities associated with the combined construction and operating license (COL) at the Harris site. Regulated Utilities also recorded an impairment charge related to the write-off of the wholesale portion of the Levy investments at Duke Energy Florida in accordance with the 2013 Settlement. See Note 4 for additional information.

(f) Other includes costs to achieve the Progress Energy merger. See Notes 2 and 25 for additional information about the merger and related costs.

(g) Other includes gain from the sale of Duke Energy's ownership interest in DukeNet. See Note 12 for additional information on the sale of DukeNet.

	Year Ended December 31, 2012
(in millions)	Regulated Utilities			International Energy		Commercial Power			Reportable Segments		Other			Eliminations			Total
Unaffiliated Revenues	$	16,042		$	1,549	$	299		$	17,890	$	22		$	—		$	17,912
Intersegment Revenues	38			—		8			46		62			(108		)	—
Total Revenues	$	16,080		$	1,549	$	307		$	17,936	$	84		$	(108	)	$	17,912
Interest Expense	$	806		$	77	$	63		$	946	$	298		$	—		$	1,244
Depreciation and amortization	1,827			99		85			2,011		134			—			2,145
Equity in earnings of unconsolidated affiliates	(5		)	134		14			143		5			—			148
Income tax expense (benefit)	942			149		(82		)	1,009		(386		)	—			623
Segment income (a)(b)	1,744			439		(59		)	2,124		(523		)	(8		)	1,593
Add back noncontrolling interest component																	18
Income from discontinued operations, net of tax																	171
Net income																	$	1,782
Capital investments expenditures and acquisitions	$	4,220		$	551	$	1,038		$	5,809	$	149		$	—		$	5,958
Segment Assets	98,162			5,406		6,992			110,560		3,126			170			113,856

(a) Regulated Utilities recorded charges related to Duke Energy Indiana's Integrated Gasification Combined Cycle

(IGCC) project. See Note 4 for additional information about these charges. Regulated Utilities also recorded the reversal of expenses of $60 million, net of tax, related to a prior year Voluntary Opportunity Plan in accordance with Duke Energy Carolinas' 2011 rate case. See Note 19 for additional information about these expenses.

(b) Other includes costs to achieve the Progress Energy merger. See Notes 2 and 25 for additional information about the merger and related costs.

Geographical Information

(in millions)	U.S.		Latin America(a)		Consolidated
2014
Consolidated revenues	$	22,508	$	1,417	$	23,925
Consolidated long-lived assets	80,709		2,458		83,167
2013
Consolidated revenues	$	21,211	$	1,545	$	22,756
Consolidated long-lived assets	78,581		2,781		81,362
2012
Consolidated revenues	$	16,366	$	1,546	$	17,912
Consolidated long-lived assets	79,144		2,467		81,611

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

(a) Change in amounts of long-lived assets in Latin America includes foreign currency translation adjustments on property, plant and equipment and other long-lived asset balances.

Products and Services

(in millions)	Retail Electric		Wholesale Electric		Retail Natural Gas		Wholesale Natural Gas		Other		Total Revenues
2014
Regulated Utilities	$	19,007	$	1,879	$	571	$	—	$	814	$	22,271
International Energy	—		1,326		—		91		—		1,417
Commercial Power	—		255		—		—		—		255
Total Reportable Segments	$	19,007	$	3,460	$	571	$	91	$	814	$	23,943
2013
Regulated Utilities	$	17,837	$	1,720	$	506	$	—	$	847	$	20,910
International Energy	—		1,447		—		99		—		1,546
Commercial Power	—		260		—		—		—		260
Total Reportable Segments	$	17,837	$	3,427	$	506	$	99	$	847	$	22,716
2012
Regulated Utilities	$	13,773	$	1,120	$	470	$	—	$	717	$	16,080
International Energy	—		1,444		—		105		—		1,549
Commercial Power	—		307		—		—		—		307
Total Reportable Segments	$	13,773	$	2,871	$	470	$	105	$	717	$	17,936

Duke Energy Ohio

Duke Energy Ohio has two reportable operating segments, Regulated Utilities and Commercial Power.

Regulated Utilities transmits and distributes electricity in portions of Ohio and generates, distributes and sells electricity in portions of Kentucky. Regulated Utilities also transports and sells natural gas in portions of Ohio and northern Kentucky. It conducts operations primarily through Duke Energy Ohio and its wholly owned subsidiary, Duke Energy Kentucky.

As discussed in Note 2, Duke Energy entered into an agreement to sell Commercial Power's nonregulated Midwest generation business to Dynegy in a transaction that is expected to close in the second quarter of 2015. As a result of this divestiture, the results of operations of the nonregulated Midwest generation business have been reclassified to Discontinued Operations on the Consolidated Statements of Operations and Comprehensive Income. Amounts remaining in Commercial Power relate to assets not included in the Disposal Group. Certain costs such as interest and general and administrative expenses previously allocated to the Disposal Group were not reclassified to discontinued operations.

The remainder of Duke Energy Ohio’s operations is presented as Other. While it is not considered an operating segment, Other primarily includes certain governance costs allocated by its parent, Duke Energy. See Note 13 for additional information. All of Duke Energy Ohio’s revenues are generated domestically and its long-lived assets are all in the U.S.

	Year Ended December 31, 2014
(in millions)	Regulated Utilities		Commercial Power			Total Reportable Segments		Other			Eliminations			Total
Unaffiliated revenues	$	1,894	$	19		$	1,913	$	—		$	—		$	1,913
Intersegment revenues	1		—			1		—			(1		)	—
Total revenues	$	1,895	$	19		$	1,914	$	—		$	(1	)	$	1,913
Interest expense	$	81	$	5		$	86	$	—		$	—		$	86
Depreciation and amortization	211		2			213		1			—			214
Income tax expense (benefit)	117		(67		)	50		(7		)	—			43
Segment income (loss)(a)	202		(121		)	81		(13		)	—			68
Income from discontinued operations, net of tax														(563		)
Net loss														$	(495	)
Capital expenditures	$	300	$	22		$	322	$	—		$	—		$	322
Segment assets	6,908		3,187			10,095		134			(230		)	9,999

(a) Commercial Power recorded a pretax impairment charge of $94 million related to OVEC. See Note 11 for additional information.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	Year Ended December 31, 2013
(in millions)	Regulated Utilities		Commercial Power			Total Reportable Segments		Other			Eliminations			Total
Unaffiliated revenues	$	1,765	$	40		$	1,805	$	—		$	—		$	1,805
Total revenues	$	1,765	$	40		$	1,805	$	—		$	—		$	1,805
Interest expense	$	74	$	—		$	74	$	—		$	—		$	74
Depreciation and amortization	200		13			213		—			—			213
Income tax expense (benefit)	91		(36		)	55		(12		)	—			43
Segment income (loss)	151		(65		)	86		(19		)	—			67
Income from discontinued operations, net of tax														35
Net income														$	102
Capital expenditures	$	375	$	58		$	433	$	—		$	—		$	433
Segment assets	6,649		4,170			10,819		99			(155		)	10,763

	Year Ended December 31, 2012
(in millions)	Regulated Utilities		Commercial Power			Total Reportable Segments		Other			Eliminations			Total
Unaffiliated revenues	$	1,745	$	75		$	1,820	$	—		$	—		$	1,820
Intersegment revenues	1		1			2		—			(2		)	—
Total revenues	$	1,746	$	76		$	1,822	$	—		$	(2	)	$	1,820
Interest expense	$	61	$	28		$	89	$	—		$	—		$	89
Depreciation and amortization	179		16			195		—			—			195
Income tax expense (benefit)	91		(40		)	51		(18		)	—			33
Segment income (loss)	159		(80		)	79		(34		)	—			45
Income from discontinued operations, net of tax														130
Net income														$	175
Capital expenditures	$	427	$	87		$	514	$	—		$	—		$	514
Segment assets	6,434		4,175			10,609		117			(166		)	10,560

DUKE ENERGY CAROLINAS, PROGRESS ENERGY, DUKE ENERGY PROGRESS, DUKE ENERGY FLORIDA AND DUKE ENERGY INDIANA

Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana each have one reportable operating segment, Regulated Utility, which generates, transmits, distributes and sells electricity. The remainder of each company’s operations is classified as Other. While not considered a reportable segment for any of these companies, Other consists of certain unallocated corporate costs. Other for Progress Energy also includes interest expense on corporate debt instruments of $241 million, $300 million and $304 million for the years ended December 31, 2014, 2013 and 2012. The following table summarizes the net loss for Other for each of these entities.

	Years Ended December 31,
(in millions)	2014			2013			2012
Duke Energy Carolinas	$	(79	)	$	(97	)	$	(169	)
Progress Energy	(190		)	(241		)	(379		)
Duke Energy Progress	(31		)	(46		)	(139		)
Duke Energy Florida	(19		)	(24		)	(58		)
Duke Energy Indiana	(11		)	(16		)	(27		)

Duke Energy Progress earned approximately 11 percent of its consolidated operating revenues from North Carolina Electric Membership Corporation (NCEMC) in 2014. These revenues relate to wholesale contracts and transmission revenues. The respective Regulated Utility and Regulated Utilities operating segments own substantially all of Duke Energy Carolinas’, Progress Energy’s, Duke Energy Progress’, Duke Energy Florida’s and Duke Energy Indiana’s assets at December 31, 2014, 2013 and 2012.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

4. REGULATORY MATTERS

Regulatory Assets and Liabilities

The Duke Energy Registrants record regulatory assets and liabilities that result from the ratemaking process. See Note 1 for further information.

The following tables present the regulatory assets and liabilities recorded on the Consolidated Balance Sheets.

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Regulatory Assets
Asset retirement obligations	$	3,017	$	907	$	1,882	$	1,584	$	298	$	—	$	—
Accrued pension and OPEB	2,015		412		812		354		458		132		217
Retired generation facilities	1,659		58		1,545		152		1,393		—		56
Debt fair value adjustment	1,305		—		—		—		—		—		—
Net regulatory asset related to income taxes	1,144		614		354		141		213		64		111
Hedge costs and other deferrals	628		103		490		217		273		7		28
Demand side management (DSM)/Energy efficiency (EE)	330		106		203		193		10		21		—
Grid Modernization	76		—		—		—		—		76		—
Vacation accrual	213		86		46		46		—		6		12
Deferred fuel	246		50		182		138		44		9		5
Nuclear deferral	296		141		155		43		112		—		—
Post-in-service carrying costs and deferred operating expenses	494		124		121		28		93		21		228
Gasification services agreement buyout	55		—		—		—		—		—		55
Transmission expansion obligation	70		—		—		—		—		74		—
Manufactured gas plant (MGP)	115		—		—		—		—		115		—
Other	494		263		109		66		42		36		66
Total regulatory assets	12,157		2,864		5,899		2,962		2,936		561		778
Less: current portion	1,115		399		491		287		203		49		93
Total non-current regulatory assets	$	11,042	$	2,465	$	5,408	$	2,675	$	2,733	$	512	$	685

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Regulatory Liabilities
Costs of removal	$	5,221	$	2,420	$	1,975	$	1,692	$	283	$	222	$	613
Amounts to be refunded to customers	166		—		70		—		70		—		96
Storm reserve	150		25		125		—		125		—		—
Accrued pension and OPEB	379		76		121		61		60		19		91
Deferred fuel	37		6		23		23		—		—		8
Other	444		217		171		127		44		10		42
Total regulatory liabilities	6,397		2,744		2,485		1,903		582		251		850
Less: current portion	204		34		106		71		35		10		54
Total non-current regulatory liabilities	$	6,193	$	2,710	$	2,379	$	1,832	$	547	$	241	$	796

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Regulatory Assets
Asset retirement obligations	$	1,608	$	123	786		$	389	$	397	$	—	$	—
Accrued pension and OPEB	1,723		347		750		269		438		120		219
Retired generation facilities	1,748		68		1,619		241		1,378		—		61
Debt fair value adjustment	1,338		—		—		—		—		—		—
Net regulatory asset related to income taxes	1,115		555		331		113		218		72		157
Hedge costs and other deferrals	450		98		318		165		153		5		29
DSM/EE	306		140		152		140		12		14		—
Grid Modernization	65		—		—		—		—		65		—
Vacation accrual	210		82		55		50		—		7		13
Deferred fuel	94		—		37		6		31		14		43
Nuclear deferral	262		40		222		77		145		—		—
Post-in-service carrying costs and deferred operating expenses	459		150		137		19		118		21		151
Gasification services agreement buyout	75		—		—		—		—		—		75
Transmission expansion obligation	70		—		—		—		—		74		—
MGP	90		—		—		—		—		90		—
Other	473		219		101		42		60		46		87
Total regulatory assets	10,086		1,822		4,508		1,511		2,950		528		835
Less: current portion	895		295		353		127		221		57		118
Total non-current regulatory assets	$	9,191	$	1,527	$	4,155	$	1,384	$	2,729	$	471	$	717

	December 31, 2013
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Regulatory Liabilities
Costs of removal	$	5,308	$	2,423	$	2,008	$	1,637	$	371	$	241	$	645
Amounts to be refunded to customers	151		—		120		—		120		—		31
Storm reserve	145		20		125		—		125		—		—
Accrued pension and OPEB	138		—		—		—		—		21		77
Deferred fuel	177		45		132		—		132		—		—
Other	346		153		114		99		14		27		45
Total regulatory liabilities	6,265		2,641		2,499		1,736		762		289		798
Less: current portion	316		65		207		63		144		27		16
Total non-current regulatory liabilities	$	5,949	$	2,576	$	2,292	$	1,673	$	618	$	262	$	782

Descriptions of regulatory assets and liabilities, summarized in the tables above, as well as their recovery and amortization periods follow. Items are excluded from rate base unless otherwise noted.

Asset retirement obligations. Represents legal obligations associated with the future retirement of property, plant and equipment. Asset retirement obligations relate primarily to decommissioning nuclear power facilities and closure of ash basins in North Carolina and South Carolina. No return is currently earned on these balances. The recovery period for costs related to nuclear facilities runs through the decommissioning period of each nuclear unit, the latest of which is currently estimated to be 2097. The recovery period for costs related to ash basin closures has not yet been determined. See Notes 1 and 9 for additional information.

Accrued pension and OPEB. Accrued pension and OPEB represent regulatory assets and liabilities related to each of the Duke Energy Registrants’ respective shares of unrecognized actuarial gains and losses, unrecognized prior service cost, and unrecognized transition obligation attributable to Duke Energy’s pension plans and OPEB plans. The regulatory asset or liability is amortized with the recognition of actuarial gains and losses, prior service cost, and transition obligations to net periodic benefit costs for pension and OPEB plans. See Note 21 for additional detail.

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Combined Notes To Consolidated Financial Statements – (Continued)

Retired generation facilities. Duke Energy Florida earns a reduced return on a substantial portion of the amount of regulatory asset associated with the retirement of Crystal River Unit 3 not included in rate base and a full return on a portion of the retired plant currently recovered in the nuclear cost recovery clause (NCRC). Once included in base rates the amount will be amortized over 20 years. Duke Energy Carolinas earns a return on the outstanding retail balance with recovery periods ranging from 5 to 10 years. Duke Energy Progress earns a return on the outstanding balance with recovery over a period of 10 years for retail purposes and over the longer of 10 years or the previously estimated planned retirement date for wholesale purposes. Duke Energy Indiana earns a return on the outstanding balances and the costs are included in rate base.

Debt fair value adjustment. Purchase accounting adjustment to restate the carrying value of Progress Energy debt to fair value. Amount is amortized over the life of the related debt.

Net regulatory asset related to income taxes. Regulatory assets principally associated with the depreciation and recovery of AFUDC equity. Amounts have no impact on rate base as regulatory assets are offset by deferred tax liabilities. The recovery period is over the life of the associated assets.

Hedge costs and other deferrals. Amounts relate to unrealized gains and losses on derivatives recorded as a regulatory asset or liability, respectively, until the contracts are settled. The recovery period varies for these costs, and currently extends to 2027.

DSM/EE. The recovery period varies for these costs, with some currently unknown. Duke Energy Carolinas, Duke Energy Progress, and Duke Energy Florida are required to pay interest on the outstanding liability balance. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida collect a return on DSM/EE investments.

Grid Modernization. Represents deferred depreciation and operating expenses as well as carrying costs on the portion of capital expenditures placed in service but not yet reflected in retail rates as plant in service. Recovery period is generally one year for depreciation and operating expenses. Recovery for post-in-service carrying costs are over the life of the assets.

Vacation accrual. Generally recovered within one year.

Deferred fuel. Deferred fuel costs represent certain energy costs that are recoverable or refundable as approved by the applicable regulatory body. Duke Energy Florida amount includes capacity costs. Duke Energy Florida and Duke Energy Ohio earn a return on under-recovered costs. Duke Energy Florida and Duke Energy Ohio pay interest on over-recovered costs. Duke Energy Carolinas and Duke Energy Progress pay interest on over-recovered costs in North Carolina. Recovery period is generally over one year. Duke Energy Indiana recovery period is quarterly.

Nuclear deferral. Includes (i) amounts related to levelizing nuclear plant outage costs at Duke Energy Carolinas in North Carolina and South Carolina, and Duke Energy Progress in North Carolina, which allows for the recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, resulting in the deferral of operations and maintenance costs associated with refueling and (ii) certain deferred preconstruction and carrying costs at Duke Energy Florida as approved by the FPSC primarily associated with Levy, currently expected to be recovered in revenues by the end of 2017.

Post-in-service carrying costs and deferred operating expenses. Represents deferred depreciation and operating expenses as well as carrying costs on the portion of capital expenditures placed in service but not yet reflected in retail rates as plant in service. Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana earn a return on the outstanding balance. Duke Energy Florida earns a return at a reduced rate. For Duke Energy Ohio and Duke Energy Indiana, some amounts are included in rate base. Recovery is over various lives, and the latest recovery period is 2081.

Gasification services agreement buyout. The IURC authorized Duke Energy Indiana to recover costs incurred to buyout a gasification services agreement, including carrying costs through 2018.

Transmission expansion obligation. Represents transmission expansion obligations related to Duke Energy Ohio’s withdrawal from Midcontinent Independent System Operator, Inc. (MISO).

MGP. Represents remediation costs for former MGP sites. In November 2013, the PUCO approved recovery of these costs through 2018. Duke Energy Ohio does not earn a return on these costs. See Note 5 for additional information.

Costs of removal. Represents funds received from customers to cover the future removal of property, plant and equipment from retired or abandoned sites as property is retired. Also includes certain deferred gains on NDTF investments.

Amounts to be refunded to customers. Represents required rate reductions to retail customers by the applicable regulatory body. The refund period is through 2016 for Duke Energy Florida and through 2017 for Duke Energy Indiana.

Storm reserve. Duke Energy Carolinas and Duke Energy Florida are allowed to petition the PSCSC and FPSC, respectively, to seek recovery of named storms. Funds are used to offset future incurred costs.

Restrictions on the Ability of Certain Subsidiaries to Make Dividends, Advances and Loans to Duke Energy

As a condition to the approval of merger transactions, the NCUC, PSCSC, PUCO, KPSC and IURC imposed conditions on the ability of Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio, Duke Energy Kentucky and Duke Energy Indiana to transfer funds to Duke Energy through loans or advances, as well as restricted amounts available to pay dividends to Duke Energy. Certain subsidiaries may transfer funds to Duke Energy Corporation Holding Company (the parent) by obtaining approval of the respective state regulatory commissions. These conditions imposed restrictions on the ability of the public utility subsidiaries to pay cash dividends as discussed below.

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Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy Progress and Duke Energy Florida also have restrictions imposed by their first mortgage bond indentures and Articles of Incorporation which, in certain circumstances, limit their ability to make cash dividends or distributions on common stock. Amounts restricted as a result of these provisions were not material at December 31, 2014.

Additionally, certain other subsidiaries of Duke Energy have restrictions on their ability to dividend, loan or advance funds to Duke Energy due to specific legal or regulatory restrictions, including, but not limited to, minimum working capital and tangible net worth requirements.

Duke Energy Carolinas

Duke Energy Carolinas must limit cumulative distributions subsequent to mergers to (i) the amount of retained earnings on the day prior to the closing of the mergers, plus (ii) any future earnings recorded.

Duke Energy Progress

Duke Energy Progress must limit cumulative distributions subsequent to the merger between Duke Energy and Progress Energy to (i) the amount of retained earnings on the day prior to the closing of the merger, plus (ii) any future earnings recorded.

Duke Energy Ohio

Duke Energy Ohio will not declare and pay dividends out of capital or unearned surplus without the prior authorization of the PUCO. Duke Energy Ohio received FERC and PUCO approval to pay dividends from its equity accounts that are reflective of the amount that it would have in its retained earnings account had push-down accounting for the Cinergy Corp. (Cinergy) merger not been applied to Duke Energy Ohio’s balance sheet. The conditions include a commitment from Duke Energy Ohio that equity, adjusted to remove the impacts of push-down accounting, will not fall below 30 percent of total capital.

Duke Energy Kentucky is required to pay dividends solely out of retained earnings and to maintain a minimum of 35 percent equity in its capital structure. 

Duke Energy Indiana

Duke Energy Indiana must limit cumulative distributions subsequent to the merger between Duke Energy and Cinergy to (i) the amount of retained earnings on the day prior to the closing of the merger, plus (ii) any future earnings recorded. In addition, Duke Energy Indiana will not declare and pay dividends out of capital or unearned surplus without prior authorization of the IURC.

The restrictions discussed above were less than 25 percent of Duke Energy's net assets at December 31, 2014.

Rate Related Information

The NCUC, PSCSC, FPSC, IURC, PUCO 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.

Duke Energy Carolinas

2013 North Carolina Rate Case

On September 24, 2013, the NCUC approved a settlement agreement related to Duke Energy Carolinas’ request for a rate increase with minor modifications. The NCUC Public Staff (Public Staff) was a party to the settlement. The settling parties agreed to a three-year step-in rate increase, with the first two years providing for $204 million, or a 4.5 percent average increase in rates, and the third year providing for rates to be increased by an additional $30 million, or 0.6 percent. The agreement is based upon a return on equity of 10.2 percent and an equity component of the capital structure of 53 percent. The settlement agreement (i) allows for the recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) a $10 million shareholder contribution to agencies that provide energy assistance to low-income customers, and (iii) an annual reduction in the regulatory liability for costs of removal of $30 million for each of the first two years. Duke Energy Carolinas has agreed not to request additional base rate increases to be effective before September 2015. New rates went into effect on September 25, 2013.

On October 23, 2013, the North Carolina Attorney General (NCAG) appealed the rate of return and capital structure approved in the agreement. The NC Waste Awareness and Reduction Network (NC WARN) appealed various matters in the settlement on October 24, 2013. The North Carolina Supreme Court (NCSC) denied a motion to consolidate these appeals with other North Carolina rate case appeals involving Duke Energy Carolinas and Duke Energy Progress on March 13, 2014. Briefing concluded in this matter and oral argument occurred on September 8, 2014. On January 23, 2015, the NCSC affirmed the NCUC's September 24, 2013 order.

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Combined Notes To Consolidated Financial Statements – (Continued)

2013 South Carolina Rate Case

On September 11, 2013, the PSCSC approved a settlement agreement related to Duke Energy Carolinas’ request for a rate increase. Parties to the settlement agreement were the Office of Regulatory Staff, Wal-Mart Stores East, LP and Sam’s East, Incorporated, the South Carolina Energy Users Committee, Public Works of the City of Spartanburg, South Carolina and the South Carolina Small Business Chamber of Commerce. The parties agreed to a two-year step-in rate increase, with the first year providing for approximately $80 million, or a 5.5 percent average increase in rates, and the second year providing for rates to be increased by an additional $38 million, or 2.6 percent. The settlement agreement is based upon a return on equity of 10.2 percent and a 53 percent equity component of the capital structure. The settlement agreement (i) allows for the recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) approximately $4 million of contributions to agencies that provide energy assistance to low-income customers and for economic development, and (iii) a reduction in the regulatory liability for costs of removal of $45 million for the first year. Duke Energy Carolinas has agreed not to request additional base rate increases to be effective before September 2015. New rates went into effect on September 18, 2013.

2011 North Carolina Rate Case

On January 27, 2012, the NCUC approved a settlement agreement related to Duke Energy Carolinas’ request for a rate increase. On October 23, 2013, the NCUC issued a second order in the case reaffirming the rate of return approved in the settlement agreement, in response to an appeal by the NCAG. On November 21, 2013, the NCAG appealed the NCUC's October 2013 order. On December 19, 2014, the NCSC affirmed the NCUC's October 2013 order concluding the appeal.

William States Lee Combined Cycle Facility

On April 9, 2014, the PSCSC granted Duke Energy Carolinas and NCEMC a Certificate of Environmental Compatibility and Public Convenience and Necessity (CECPCN) for the construction and operation of a 750 MW combined cycle natural gas-fired generating plant at its existing William States Lee Generating Station in Anderson, South Carolina. On May 16, 2014, Duke Energy Carolinas announced its intention to begin construction in summer 2015 and estimated a cost to build of $600 million for its share of the facility, including AFUDC. The project is expected to be commercially available in late 2017. NCEMC will own approximately 13 percent of the project. On July 3, 2014, the South Carolina Coastal Conservation League and Southern Alliance for Clean Energy jointly filed a Notice of Appeal with the Court of Appeals of South Carolina seeking the court's review of the PSCSC's decision. Duke Energy Carolinas' initial brief in support of the PSCSC's order granting the CECPCN was filed on January 12, 2015. Duke Energy Carolinas cannot predict the outcome of this matter.

William States Lee III Nuclear Station

In December 2007, Duke Energy Carolinas applied to the NRC for a COL for two Westinghouse AP1000 (advanced passive) reactors for the proposed William States Lee III Nuclear Station (Lee Nuclear Station) at a site in Cherokee County, South Carolina. Submitting the COL application did not commit Duke Energy Carolinas to build nuclear units. Through several separate orders, the NCUC and PSCSC concurred with the prudency of Duke Energy Carolinas incurring certain project development and pre-construction costs, although recovery of costs is not guaranteed. Duke Energy Carolinas has incurred approximately $427 million, including AFUDC through December 31, 2014. This amount is included in Net property, plant and equipment on Duke Energy Carolinas’ Consolidated Balance Sheets.

Design changes have been identified in the Westinghouse AP1000 certified design that must be addressed before NRC can complete its review of the Lee Nuclear Station COL application. These design changes set the schedule for completion of the NRC COL application review and issuance of the Lee COL. Receipt of the Lee Nuclear Station COL is currently expected by mid-2016.

Duke Energy Progress

2012 North Carolina Rate Case

On May 30, 2013, the NCUC approved a settlement agreement related to Duke Energy Progress’ request for a rate increase. The Public Staff was a party to the settlement agreement. The settling parties agreed to a two-year step-in rate increase, with the first year providing for a $147 million, or a 4.5 percent average increase in rates, and the second year providing for rates to be increased by an additional $31 million, or a 1.0 percent average increase in rates. The agreement is based upon a return on equity of 10.2 percent and an equity component of the capital structure of 53 percent. The settlement agreement (i) allows for the recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) a $20 million shareholder contribution to agencies that provide energy assistance to low-income customers, and (iii) a reduction in the regulatory liability for costs of removal of $20 million for the first year. The initial rate increase went into effect on June 1, 2013 and the step-in rate increase went into effect in June 2013.

On July 1, 2013, the NCAG appealed the NCUC’s approval of the rate of return and capital structure included in the agreement. NC WARN also appealed various matters in the settlement. On August 20, 2014, the NCSC affirmed the NCUC's order approving Duke Energy Progress' rate of return and capital structure concluding the appeal.

L.V. Sutton Combined Cycle Facility

Duke Energy Progress completed construction of a 625 MW combined cycle natural gas-fired generating facility at its existing L.V. Sutton Steam Station (Sutton) in New Hanover County, North Carolina. Sutton began commercial operations in the fourth quarter of 2013.

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Combined Notes To Consolidated Financial Statements – (Continued)

Shearon Harris Nuclear Station Expansion

In 2006, Duke Energy Progress selected a site at Harris to evaluate for possible future nuclear expansion. On February 19, 2008, Duke Energy Progress filed its COL application with the NRC for two Westinghouse AP1000 reactors at Harris, which the NRC docketed for review. On May 2, 2013, Duke Energy Progress filed a letter with the NRC requesting the NRC to suspend its review activities associated with the COL at the Harris site. As a result of the decision to suspend the COL applications, during the second quarter of 2013, Duke Energy Progress recorded a pretax impairment charge of $22 million which represented costs associated with the COL, which were not probable of recovery. As of December 31, 2014, approximately $48 million is recorded in Regulatory assets on Duke Energy Progress’ Consolidated Balance Sheets.

Wholesale Depreciation Rates

On April 19, 2013, Duke Energy Progress filed an application with FERC for acceptance of changes to generation depreciation rates and in August 2013 filed for acceptance of additional changes. These changes affect the rates of Duke Energy Progress' wholesale power customers that purchase or will purchase power under formula rates. Certain Duke Energy Progress wholesale customers filed interventions and protests. FERC accepted the depreciation rate changes, subject to refund, and set the matter for settlement and hearing in a consolidated proceeding. FERC further initiated an action with respect to the justness and reasonableness of the proposed rate changes. Settlement was reached in October 2014 for changes to the depreciation rates and conforming changes to the wholesale formula rates. FERC approved the settlement in December 2014. The agreement will have no material or adverse impact to the rates originally proposed by Duke Energy Progress, and Duke Energy Progress will receive cost recovery for early retired plants previously included in the depreciation rates.

Duke Energy Florida

FERC Transmission Return on Equity Complaint

On February 12, 2012, Seminole Electric Cooperative, Inc. and Florida Municipal Power Agency filed with FERC a complaint against Duke Energy Florida alleging that the current rate of return on equity in Duke Energy Florida's transmission formula rates of 10.8 percent is unjust and unreasonable and should be reduced to 9.02 percent. The complainants further alleged that return on equity adjustments should take effect retroactive to January 1, 2010 under the governing transmission formula rate protocols. On May 13, 2013, the complainants filed a second complaint alleging that the return on equity should be reduced to 8.63 percent or 8.84 percent. On June 19, 2014, FERC issued orders consolidating the two complaints, setting them for settlement and hearing procedures, setting refund effective dates of February 29, 2012 for the first complaint and May 13, 2013 for the second complaint, and setting for settlement and hearing the issue of whether return on equity adjustments should take effect prior to the refund effective date of the first complaint. On August 12, 2014, the complainants filed a third complaint alleging that the return on equity should be 8.69 percent. On December 5, 2014, FERC issued an order consolidating the third complaint with the first two complaints for the purposes of settlement, hearing, and decision, and establishing a refund effective date of August 12, 2014 for the third complaint. The parties are engaged in settlement discussions. Duke Energy Florida cannot predict the outcome of this matter.

FPSC Settlement Agreements

On February 22, 2012, the FPSC approved a settlement agreement (the 2012 Settlement) among Duke Energy Florida, the Florida Office of Public Counsel (OPC) and other customer advocates. The 2012 Settlement was to continue through the last billing cycle of December 2016. On October 17, 2013, the FPSC approved a settlement agreement (the 2013 Settlement) between Duke Energy Florida, OPC, and other customer advocates. The 2013 Settlement replaces and supplants the 2012 Settlement and substantially resolves issues related to (i) Crystal River Unit 3, (ii) Levy, (iii) Crystal River 1 and 2 coal units, and (iv) future generation needs in Florida. Refer to the remaining sections below for further discussion of these settlement agreements.

Crystal River Unit 3

On February 5, 2013, Duke Energy Florida announced the retirement of Crystal River Unit 3. On February 20, 2013, Duke Energy Florida filed with the NRC a certification of permanent cessation of power operations and permanent removal of fuel from the reactor vessel. In December 2013, and March 2014, Duke Energy Florida filed an updated site-specific decommissioning plan with the NRC and FPSC, respectively. The plan, which was approved by the FPSC in November 2014, included a decommissioning cost estimate of $1,180 million, including amounts applicable to joint owners, under the SAFSTOR option. Duke Energy Florida’s decommissioning study assumes Crystal River Unit 3 will be in SAFSTOR configuration, requiring limited staffing to monitor plant conditions, until the eventual dismantling and decontamination activities to be completed by 2073. This decommissioning approach is currently utilized at a number of retired domestic nuclear power plants and is one of three accepted approaches to decommissioning approved by the NRC.

Duke Energy Florida has reclassified all Crystal River Unit 3 investments, including property, plant and equipment, nuclear fuel, inventory, and other assets, to a regulatory asset. Duke Energy agreed to forgo recovery of $295 million of regulatory assets and an impairment charge was recorded in the second quarter of 2013 for this matter. Duke Energy Florida is allowed to accelerate cash recovery of approximately $130 million of the Crystal River Unit 3 regulatory asset from retail customers from 2014 through 2016 through its fuel clause. Duke Energy Florida will begin recovery of the remaining Crystal River Unit 3 regulatory asset, up to a cap of $1,466 million from retail customers upon the earlier of (i) full recovery of the uncollected Levy investment or (ii) the first billing period of January 2017. Recovery will continue 240 months from inception of collection of the regulatory asset in base rates. The Crystal River Unit 3 base rate component will be adjusted at least every four years.

Included in this recovery, but not subject to the cap, are costs of building an independent spent fuel storage installation (ISFSI). The return rate will be based on the currently approved AFUDC rate with a return on equity of 7.35 percent, or 70 percent of the currently approved 10.5 percent. The return rate is subject to change if the return on equity changes in the future. In December 2014, the FPSC approved Duke Energy Florida's decision to construct the ISFSI and approved Duke Energy Florida's request to defer amortization of the ISFSI pending resolution of its litigation against the federal government as a result of the Department of Energy's breach of its obligation to accept spent nuclear fuel. The regulatory asset associated with the original power uprate project to increase generating capacity will continue to be recovered through the Nuclear Cost Recovery Clause over an estimated seven-year period that began in 2013.

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Combined Notes To Consolidated Financial Statements – (Continued)

Through December 31, 2014, Duke Energy Florida deferred $1,377 million for rate recovery related to Crystal River Unit 3, which is subject to the rate recovery cap in the 2013 Settlement. In addition, Duke Energy Florida deferred $260 million for recovery associated with building an ISFSI and the original uprate project, which is not subject to the rate recovery cap discussed above. Duke Energy Florida does not expect the Crystal River Unit 3 costs to exceed the cap.

Customer Rate Matters

Pursuant to the 2013 Settlement, Duke Energy Florida will maintain base rates at the current level through the last billing period of 2018, subject to the return on equity range of 9.5 percent to 11.5 percent, with exceptions for base rate increases for the recovery of the Crystal River Unit 3 regulatory asset beginning no later than 2017 and base rate increases for new generation through 2018, per the provisions of the 2013 Settlement. Duke Energy Florida is not required to file a depreciation study, fossil dismantlement study or nuclear decommissioning study until the earlier of the next rate case filing or March 31, 2019. The 2012 Settlement provided for a $150 million increase in base revenue effective with the first billing cycle of January 2013. Costs associated with Crystal River Unit 3 investments were removed from retail rate base effective with the first billing cycle of January 2013. Duke Energy Florida is accruing, for future rate-setting purposes, a carrying charge on the Crystal River Unit 3 investment until the Crystal River Unit 3 regulatory asset is recovered in base rates. If Duke Energy Florida’s retail base rate earnings fall below the return on equity range, as reported on a FPSC-adjusted or pro forma basis on a monthly earnings surveillance report, it may petition the FPSC to amend its base rates during the term of the 2013 Settlement.

Duke Energy Florida agreed to refund $388 million to retail customers through its fuel clause, as required by the 2012 Settlement. At December 31, 2014, $120 million remains to be refunded, of which $50 million credit is recorded in Regulatory assets within Current Assets as an offset to deferred fuel and $70 million is recorded in Regulatory liabilities in Deferred Credits and Other Liabilities on the Consolidated Balance Sheets.

Levy

On July 28, 2008, Duke Energy Florida applied to the NRC for a COL for two Westinghouse AP1000 reactors at Levy. In 2008, the FPSC granted Duke Energy Florida’s petition for an affirmative Determination of Need and related orders requesting cost recovery under Florida’s nuclear cost-recovery rule, together with the associated facilities, including transmission lines and substation facilities. Design changes have been identified in the Westinghouse AP1000 certified design that must be addressed before the NRC can complete its review of the Levy COL application. These design changes set the schedule for completion of the NRC COL application review and issuance of the Levy COL. Based on the current review schedule, the Levy COL is currently expected by mid-2016.

On January 28, 2014, Duke Energy Florida terminated the Levy engineering, procurement and construction agreement (EPC). Duke Energy Florida may be required to pay for work performed under the EPC and to bring existing work to an orderly conclusion, including but not limited to costs to demobilize and cancel certain equipment and material orders placed. As of December 31, 2014, Duke Energy Florida has recorded an exit obligation of $25 million for the termination of the EPC. This liability was recorded within Other in Deferred Credits and Other Liabilities with an offset primarily to Regulatory assets on the Consolidated Balance Sheets. Duke Energy Florida is allowed to recover reasonable and prudent EPC cancellation costs from its retail customers.

The 2012 Settlement provided that Duke Energy Florida include the allocated wholesale cost of Levy as a retail regulatory asset and include this asset as a component of rate base and amortization expense for regulatory reporting. In accordance with the 2013 Settlement, Duke Energy Florida ceased amortization of the wholesale allocation of Levy investments against retail rates. In the second quarter of 2013, Duke Energy Florida recorded a pretax charge of $65 million to write off the wholesale portion of Levy investments. This amount is included in Impairment charges on Duke Energy Florida's Statements of Operations and Comprehensive Income.

On October 27, 2014, the FPSC approved Duke Energy Florida rates for 2015 for Levy as filed and consistent with those established in the 2013 Revised and Restated Settlement Agreement. Recovery of the remaining retail portion of the project costs may occur over five years from 2013 through 2017. Duke Energy Florida has an ongoing responsibility to demonstrate prudency related to the wind down of the Levy investment and the potential for salvage of Levy assets. As of December 31, 2014, Duke Energy Florida has a net uncollected investment in Levy of approximately $180 million, including AFUDC. Of this amount, $91 million related to land and the COL is included in Net, property, plant and equipment and will be recovered through base rates and $89 million is included in Regulatory assets within Current Assets on the Consolidated Balance Sheets and will be recovered through the NCRC.

Crystal River 1 and 2 Coal Units

Duke Energy Florida has evaluated Crystal River 1 and 2 coal units for retirement in order to comply with certain environmental regulations. Based on this evaluation, those units will likely be retired by 2018. Once those units are retired Duke Energy Florida will continue recovery of existing annual depreciation expense through the end of 2020. Beginning in 2021, Duke Energy Florida will be allowed to recover any remaining net book value of the assets from retail customers through the Capacity Cost Recovery Clause. In April 2014, the FPSC approved Duke Energy Florida's petition to allow for the recovery of prudently incurred costs to comply with the Mercury and Air Toxics Standard through the Environmental Cost Recovery Clause.

New Generation

The 2013 Settlement establishes a recovery mechanism for additional generation needs. This recovery mechanism, the Generation Base Rate Adjustment, allows recovery of prudent costs of these items through an increase in base rates, upon the in-service date of such assets, without a general rate case at a 10.5 percent return on equity.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

On May 27, 2014, Duke Energy Florida petitioned the FPSC for a Determination of Need to (i) construct a 1,640 MW combined cycle natural gas plant in Citrus County, Florida to be in service in 2018 with an estimated cost of $1.5 billion, (ii) construct a 320 MW combustion turbine plant at its existing Suwannee generating facility (Suwannee project) with an estimated cost of $197 million, and (iii) add inlet chilling to its existing Hines Energy Complex (Hines) combined cycle units which will increase the output of those units by 220 MW at an estimated cost of $160 million. These cost estimates include AFUDC. On August 26, 2014, Duke Energy Florida requested the FPSC withdraw consideration for the Suwannee project so that Duke Energy Florida could pursue further negotiations on an alternative power plant acquisition. On October 2, 2014, the FPSC approved the requests for the Citrus County plant and the uprate project at the Hines facility. Additional environmental and governmental approvals will be sought for the Citrus County project. The Hines uprate project is expected to be completed no later than 2017.

In December 2014, Duke Energy Florida and Osprey Energy Center, LLC, a wholly owned subsidiary of Calpine Corporation (Calpine) entered into an Asset Purchase and Sale Agreement for the purchase of a 599 MW combined cycle natural gas plant in Auburndale, Florida (Osprey Plant acquisition) for approximately $166 million. Closing is subject to the approval of FERC, FPSC and the expiration of the Hart Scott Rodino waiting period and is expected to occur by the first quarter of 2017 upon the expiration of an existing Power Purchase Agreement between Calpine and Duke Energy Florida. On January 30, 2015, Duke Energy Florida filed a petition with the FPSC requesting a determination that the Osprey Plant acquisition or, alternatively, the Suwannee project is the most cost effective generation alternative to meet Duke Energy Florida's remaining need prior to 2018.

Cost of Removal Reserve

The 2012 Settlement and the 2013 Settlement provide Duke Energy Florida the discretion to reduce cost of removal amortization expense for a certain portion of the cost of removal reserve until the earlier of its applicable cost of removal reserve reaches zero or the expiration of the 2013 Settlement. Duke Energy Florida may not reduce amortization expense if the reduction would cause it to exceed the appropriate high point of the return on equity range. Duke Energy Florida recognized a reduction in amortization expense of $114 million, and $178 million for the years ended December 31, 2013, and 2012 respectively. Duke Energy Florida had no cost of removal reserves eligible for amortization to income remaining at December 31, 2013.

Duke Energy Ohio

W.C. Beckjord Fuel Release

On August 18, 2014, approximately 9,000 gallons of fuel oil were inadvertently discharged into the Ohio River during a fuel oil transfer at the W.C. Beckjord generating plant. The Ohio Environmental Protection Agency (Ohio EPA) issued a Notice of Violation related to the discharge. Duke Energy Ohio is cooperating with the Ohio EPA, the EPA and the U.S. Attorney for the Southern District of Ohio, responding to a Request for Information from the EPA. No Notice of Violation has been issued by the EPA and no civil or criminal penalty amount has been established. Total repair and remediation costs related to the release are not expected to be material. Other costs related to the release, including state or federal civil enforcement proceedings, cannot be reasonably estimated at this time.

2014 Electric Security Plan (ESP)

On May 29, 2014, Duke Energy Ohio filed an application for approval of an SSO in the form of an ESP, effective June 1, 2015. The proposed ESP includes a competitive procurement process for SSO load, a distribution capital investment rider, a tracking mechanism for incremental distribution costs caused by major storms, and a cost-based recovery of Duke Energy Ohio’s contractual entitlement in OVEC. The proposed plan also seeks rate design modifications and continuance, revision, or termination of existing riders. An evidentiary hearing in this case concluded in November 2014 and final briefs were submitted in December 2014. Duke Energy Ohio cannot predict the outcome of this matter.

Capacity Rider Filing

On August 29, 2012, Duke Energy Ohio applied to the PUCO for the establishment of a charge for capacity provided pursuant to its obligations as a Fixed Resource Requirement entity. The charge, which was consistent with Ohio’s state compensation mechanism, was estimated to be approximately $729 million, and reflected Duke Energy Ohio’s embedded cost of capacity. On February 13, 2014, the PUCO denied Duke Energy Ohio’s request.

2012 Electric Rate Case

On May 1, 2013, the PUCO approved a settlement agreement between Duke Energy Ohio and all intervening parties (the Electric Settlement) related to Duke Energy Ohio’s electric distribution rate case. The Electric Settlement provides for a net increase in electric distribution revenues of $49 million, or an average increase of 2.9 percent, based upon a return on equity of 9.84 percent. Revised rates were effective in May 2013.

2012 Natural Gas Rate Case

On November 13, 2013, the PUCO issued an order approving a settlement among Duke Energy Ohio, the PUCO Staff and intervening parties (the Gas Settlement). The Gas Settlement provided for (i) no increase in base rates for natural gas distribution service and (ii) a return on equity of 9.84 percent. The Gas Settlement provided for a subsequent hearing on Duke Energy Ohio’s request for rider recovery of environmental remediation costs associated with its former MGP sites. After the conclusion of the evidentiary hearing and briefs, the PUCO authorized Duke Energy Ohio to recover $56 million, excluding carrying costs, of environmental remediation costs. The MGP rider became effective in April 2014 for a five-year period. On March 31, 2014, Duke Energy Ohio filed an application with the PUCO to adjust the MGP rider for investigation and remediation costs incurred in 2013. As of December 31, 2014, Duke Energy Ohio has a balance of $115 million in Regulatory assets in the Consolidated Balance Sheets related to MGP sites which includes the $56 million authorized for recovery in the rate case.

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Combined Notes To Consolidated Financial Statements – (Continued)

On May 14, 2014, the Ohio Supreme Court granted certain consumer groups' motion to stay the MGP rider pending their appeals of the PUCO approval of the Gas Settlement and Duke Energy Ohio suspended billing of the MGP rider in June 2014. Amounts collected under the rider prior to suspension were immaterial. The appellants, the PUCO and Duke Energy Ohio all filed briefs addressing the merits of this matter with the Ohio Supreme Court. On July 29, 2014, the Ohio Supreme Court denied Duke Energy Ohio's motion to lift the stay, but required appellants to post a bond. The Ohio Supreme Court also requested briefs on the appropriate amount of the bond. On November 5, 2014, the Ohio Supreme Court ordered the Appellants to post a bond of approximately $2.5 million to continue the stay of the rider. The bond was to be posted within ten days or the stay would be lifted. The Appellants failed to post the required bond and on November 18, 2014, Duke Energy Ohio requested the PUCO to reinstate the MGP rider. The PUCO approved reinstatement of the rider on January 15, 2015 and Duke Energy Ohio began billings of the MGP rider. Duke Energy Ohio cannot predict the outcome of the appeals in this matter.

Regional Transmission Organization (RTO) Realignment

Duke Energy Ohio, including Duke Energy Kentucky, transferred control of its transmission assets from MISO to PJM, effective December 31, 2011.

On December 22, 2010, the KPSC approved Duke Energy Kentucky’s request to effect the RTO realignment, subject to a commitment not to seek double-recovery in a future rate case of the transmission expansion fees that may be charged by MISO and PJM in the same period or overlapping periods.

On May 25, 2011, the PUCO approved a settlement between Duke Energy Ohio, Ohio Energy Group, the Office of the Ohio Consumers’ Counsel and the PUCO Staff related to Duke Energy Ohio’s recovery of certain costs of the RTO realignment via a non-bypassable rider. Duke Energy Ohio is allowed to recover all MISO Transmission Expansion Planning (MTEP) costs, including but not limited to Multi Value Project (MVP) costs, directly or indirectly charged to Ohio customers. Duke Energy Ohio also agreed to vigorously defend against any charges for MVP projects from MISO.

Upon its exit from MISO on December 31, 2011, Duke Energy Ohio recorded a liability for its exit obligation and share of MTEP costs, excluding MVP. This liability was recorded within Other in Current liabilities and Other in Deferred credits and other liabilities on Duke Energy Ohio’s Consolidated Balance Sheets.

The following table provides a reconciliation of the beginning and ending balance of Duke Energy Ohio’s recorded obligations related to its withdrawal from MISO. As of December 31, 2014, $74 million is recorded as a Regulatory asset on Duke Energy Ohio's Consolidated Balance Sheets.

(in millions)	December 31, 2013		Provision / Adjustments		Cash Reductions			December 31, 2014
Duke Energy Ohio	$	95	$	3	$	(4	)	$	94

MVP. MISO approved 17 MVP proposals prior to Duke Energy Ohio’s exit from MISO on December 31, 2011. Construction of these projects is expected to continue through 2020. Costs of these projects, including operating and maintenance costs, property and income taxes, depreciation and an allowed return, are allocated and billed to MISO transmission owners.

On December 29, 2011, MISO filed a tariff with the FERC providing for the allocation of MVP costs to a withdrawing owner based on monthly energy usage. The FERC set for hearing (i) whether MISO’s proposed cost allocation methodology to transmission owners who withdrew from MISO prior to January 1, 2012, is consistent with the tariff at the time of their withdrawal from MISO, and, (ii) if not, what the amount of and methodology for calculating any MVP cost responsibility should be. On July 16, 2013, a FERC Administrative Law Judge (ALJ) issued an initial decision. Under this initial decision, Duke Energy Ohio would be liable for MVP costs. Duke Energy Ohio filed exceptions to the initial decision, requesting the FERC overturn the ALJ’s decision. After reviewing the initial decision, along with all exceptions and responses filed by the parties, the FERC will issue a final decision. Duke Energy Ohio fully intends to appeal to the federal court of appeals if the FERC affirms the ALJ’s decision. Duke Energy Ohio cannot predict the outcome of these proceedings.

In 2012, MISO estimated Duke Energy Ohio’s MVP obligation over the period from 2012 to 2071 at $2.7 billion, on an undiscounted basis. The estimated obligation is subject to great uncertainty including the ultimate cost of the projects, the annual costs of operations and maintenance, taxes and return over the project lives, the number of years in service for the projects and the allocation to Duke Energy Ohio.

Any liability related to the MISO MVP matter attributable to the Disposal Group will not be transferred to Dynegy upon closing of the disposal of the Midwest generation business.

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Combined Notes To Consolidated Financial Statements – (Continued)

FERC Transmission Return on Equity and MTEP Cost Settlement

On October 14, 2011, Duke Energy Ohio and Duke Energy Kentucky submitted with FERC proposed modifications to the PJM Interconnection Open Access Transmission Tariff pertaining to recovery of the transmission revenue requirement as PJM transmission owners. The filing was made in connection with the Duke Energy Ohio's and Duke Energy Kentucky's move from MISO to PJM effective January 1, 2012. On April 24, 2012, FERC issued an order accepting the proposed filing effective January 1, 2012, except that the order denied a request to recover certain costs associated with the move from MISO to PJM without prejudice to the right to submit another filing seeking such recovery and including certain additional evidence, and set the rate of return on equity of 12.38 percent for settlement and hearing. A February 2013 settlement agreement filed with the FERC was rejected in September 2013. On October 30, 2014, the companies and six PJM transmission customers with load in the Duke Energy Ohio and Duke Energy Kentucky zone filed with FERC for approval of another settlement agreement. The principal terms of the settlement agreement are that, effective upon the date of FERC approval, (i) the return on equity will be reduced from 12.38 percent to 11.38 percent and (ii) Duke Energy Ohio and Duke Energy Kentucky will recover 30 percent of costs arising from their obligation to pay any portion of the costs of projects included in any MTEP that was approved prior to the date of the Duke Energy Ohio's and Duke Energy Kentucky's integration into PJM. The settlement is pending FERC approval. Duke Energy Ohio and Duke Energy Kentucky cannot predict the outcome of this matter

Duke Energy Indiana

Edwardsport IGCC Plant

On November 20, 2007, the IURC granted Duke Energy Indiana a Certificate of Public Convenience and Necessity for the construction of a 618 MW IGCC power plant at Duke Energy Indiana’s existing Edwardsport Generating Station in Knox County, Indiana with a cost estimate of $1.985 billion assuming timely recovery of financing costs related to the project. The Citizens Action Coalition of Indiana, Inc., Sierra Club, Inc., Save the Valley, Inc., and Valley Watch, Inc. (collectively, the Joint Intervenors) were intervenors in several matters related to the Edwardsport IGCC Plant.

On December 27, 2012, the IURC approved a settlement agreement (the 2012 Edwardsport settlement) related to the cost increase for the construction of the project, including subdockets before the IURC related to the project. The Office of Utility Consumer Counselor (OUCC), the Duke Energy Indiana Industrial Group and Nucor Steel-Indiana were parties to the settlement. The settlement agreement, as approved, capped costs to be reflected in customer rates at $2.595 billion, including estimated AFUDC through June 30, 2012. Duke Energy Indiana is allowed to recover AFUDC after June 30, 2012, until customer rates are revised, with such recovery decreasing to 85 percent on AFUDC accrued after November 30, 2012.

Over the course of construction of the project to date, Duke Energy Indiana has recorded pretax charges of approximately $897 million related to the project and the settlement agreement discussed above. Of this amount, pretax impairment and other charges of $631 million were recorded during the year ended December 31, 2012. These charges were recorded in Impairment charges and Operations, maintenance and other on Duke Energy Indiana's Consolidated Statements of Operations and Comprehensive Income.

The project was placed in commercial operation in June 2013. Costs for the Edwardsport IGCC plant are recovered from retail electric customers through a tracking mechanism, the IGCC rider. Updates to the IGCC rider are filed semi-annually. An order on the eleventh semi-annual IGCC rider is currently pending. The twelfth and thirteenth semi-annual IGGC riders were combined into one proceeding. In this proceeding, the OUCC, Duke Energy Indiana Industrial Group and Joint Intervenors alleged the Edwardsport IGCC plant was not properly placed in commercial operation in June 2013 and therefore operating and maintenance costs for the time period June 2013 through March 2014 should not be recoverable. The Duke Energy Indiana Industrial Group and Joint Intervenors also argued that the plant's performance was unsatisfactory during the first ten months of operations and recommended cost recovery disallowances. Evidentiary hearings concluded in February 2015 and an order is expected in the second half of 2015.

On March 18, 2014, the Indiana Court of Appeals denied an appeal filed by the Joint Intervenors and affirmed the IURC order approving the 2012 Edwardsport settlement and other related regulatory orders. On June 5, 2014, the Indiana Court of Appeals affirmed the decision on rehearing. The Joint Intervenors requested to seek transfer to the Indiana Supreme Court. On November 7, 2014, the Indiana Supreme Court denied the Joint Intervenors' request to transfer the appeal of these proceedings. The ninth and tenth semi-annual IGCC rider orders have also been appealed. On August 21, 2014, the Indiana Court of Appeals affirmed the IURC order in the tenth IGCC rider proceeding, and on October 29, 2014, denied Joint Intervenors' request for rehearing. The Joint Intervenors have requested a transfer of the matter to the Indiana Supreme Court. On September 8, 2014, the Indiana Court of Appeals remanded the IURC order in the ninth IGCC rider proceeding back to the IURC for further findings concerning approximately $61 million of financing charges Joint Intervenors claimed were caused by construction delay and a ratemaking issue concerning the in-service date determination for tax purposes. On February 25, 2015, the IURC issued an order on remand that upheld its prior order and added additional findings on the two issues as requested by the Indiana Court of Appeals. First, the IURC concluded the schedule delays in the construction of the IGCC plant were not the result of imprudence or unreasonable actions by Duke Energy Indiana and therefore recovery of the financing costs were appropriate. On the second issue, the IURC determined the federal tax in-service determination was to be made by the Internal Revenue Service, not the IURC, and the IURC appropriately reviewed and accepted the impact of such decision on customer rates in this and prior proceedings.

On April 2, 2014, the IURC established a subdocket to Duke Energy Indiana’s current fuel adjustment clause proceeding. In this fuel adjustment subdocket, the IURC intends to review underlying causes for net negative generation amounts at the Edwardsport IGCC plant during the period September through November 2013. Duke Energy Indiana contends the net negative generation is related to the consumption of fuel and auxiliary power when the plant was in start-up or off line. In addition to the OUCC, the Duke Energy Indiana Industrial Group, Nucor Steel-Indiana, Steel Dynamics, Inc., and the Joint Intervenors are parties to the subdocket. The IURC has deferred the fuel adjustment subdocket until resolution of the twelfth and thirteenth semi-annual IGCC rider proceedings. In addition, although the IURC approved fuel adjustment clause recovery for the period December 2013 through March 2014, it determined such fuel costs reasonably related to the operational performance of the Edwardsport IGCC plant shall be subject to refund pending the outcome of the twelfth and thirteenth semi-annual IGCC riders.

Duke Energy Indiana cannot predict the outcome of the fuel adjustment clause proceedings or pending and future IGCC Rider proceedings.

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Combined Notes To Consolidated Financial Statements – (Continued)

FERC Transmission Return on Equity Complaint

On November 12, 2013, customer groups filed with FERC a complaint against MISO and its transmission-owning members, including Duke Energy Indiana, alleging, among other things, that the current base rate of return on equity earned by MISO transmission owners of 12.38 percent is unjust and unreasonable and should be reduced to 9.15 percent. On October 16, 2014, FERC issued an order setting the return on equity issue for settlement and hearing and establishing a refund effective date of November 12, 2013. On November 6, 2014, the MISO transmission owners submitted revisions to the MISO tariff to implement a 0.50 percent adder to the base return on equity based on participation in a RTO. On January 5, 2015, FERC issued an order accepting the adder subject to it being applied to a base return on equity that is shown to be just and reasonable in the pending base return on equity complaint. On January 5, 2015, settlement procedures in the base return on equity proceeding were terminated and a hearing was scheduled for August 17, 2015. On February 12, 2015, certain MISO transmission customers filed with FERC a complaint alleging that the base return on equity should be 8.67 percent and requesting consolidation with the pending base return on equity complaint. Duke Energy Indiana cannot predict the outcome of this matter.

Grid Infrastructure Improvement Plan

On August 29, 2014, Duke Energy Indiana filed a seven-year grid infrastructure improvement plan with the IURC with an estimated cost of $1.9 billion, focusing on the reliability, integrity and modernization of the transmission and distribution system. If approved, 80 percent of the costs will be recovered through a rate rider. The remaining 20 percent are subject to recovery through future rate case proceedings. Hearings were held in January 2015 and Duke Energy Indiana expects a decision in the second quarter of 2015.

Other Regulatory Matters

Atlantic Coast Pipeline

On September 2, 2014, Duke Energy, Dominion Resources (Dominion), Piedmont Natural Gas and AGL Resources announced the formation of a joint venture, Atlantic Coast Pipeline, LLC, to build and own the proposed Atlantic Coast Pipeline (ACP), a 550-mile interstate natural gas pipeline. The ACP is designed to meet the needs identified in requests for proposals by Duke Energy Carolinas, Duke Energy Progress and Piedmont Natural Gas. Dominion will build and operate the ACP and will own 45 percent. Duke Energy will own 40 percent of the pipeline through its Commercial Power segment. The remaining share will be owned by Piedmont Natural Gas and AGL Resources. Duke Energy Carolinas and Duke Energy Progress will be customers of the pipeline and enter into 20-year transportation capacity contracts with ACP, subject to state regulatory approval. In October 2014, the NCUC and PSCSC approved the Duke Energy Carolinas and Duke Energy Progress requests to enter into certain affiliate agreements, pay compensation to ACP and to grant a waiver of certain Code of Conduct provisions relating to contractual and jurisdictional matters. The project will require FERC approval, which the joint venture will seek to secure by summer 2016. The estimated in-service date of the pipeline is late 2018.

East Bend Station

On December 30, 2014, Duke Energy Ohio acquired The Dayton Power and Light Company’s 31 percent interest in East Bend Station for approximately $12.4 million. The purchase price has been reflected in the accompanying financial statements with the net purchase amount as an increase to property, plant and equipment in accordance with FERC guidelines. Duke Energy Ohio expects FERC approval to present the property, plant and equipment and accumulated depreciation at The Dayton Power and Light Company's historical cost.

NC WARN FERC Complaint

On December 16, 2014, NC WARN filed a complaint with the FERC against Duke Energy Carolinas and Duke Energy Progress that alleged Duke Energy Carolinas and Duke Energy Progress manipulated the electricity market by constructing costly and unneeded generation facilities leading to unjust and unreasonable rates; Duke Energy Carolinas and Duke Energy Progress failed to comply with Order 1000 by not effectively connecting their transmission systems with neighboring utilities which also have excess capacity; the plans of Duke Energy Carolinas and Duke Energy Progress for unrealistic future growth leads to unnecessary and expensive generating plants; FERC should investigate the practices of Duke Energy Carolinas and Duke Energy Progress and the potential benefits of having them enter into a regional transmission organization; and FERC should force Duke Energy Carolinas and Duke Energy Progress to purchase power from other utilities rather than construct wasteful and redundant power plants. A copy of the complaint was filed with the PSCSC on January 6, 2015. Duke Energy Carolinas and Duke Energy Progress have filed a responses requesting dismissal of the complaint with the FERC and the PSCSC. Duke Energy Carolinas and Duke Energy Progress cannot predict the outcome of these proceedings.

Merger Appeals

On January 9, 2013, the City of Orangeburg and NC WARN appealed the NCUC’s approval of the merger between Duke Energy and Progress Energy. On April 29, 2013, the NCUC granted Duke Energy’s motion to dismiss certain exceptions contained in NC WARN’s appeal.

On March 4, 2014, the Court of Appeals issued an opinion affirming the NCUC’s approval of the merger. On April 8, 2014, NC WARN filed a petition for discretionary review by the North Carolina Supreme Court. On April 21, 2014, Duke Energy and the Public Staff jointly filed their response opposing NC WARN’s petition. The City of Orangeburg did not file a petition for discretionary review. On December 19, 2014, the North Carolina Supreme Court denied NC WARN's petition, concluding the appeal.

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Combined Notes To Consolidated Financial Statements – (Continued)

Progress Energy Merger FERC Mitigation

In June 2012, the FERC approved the merger with Progress Energy, including Duke Energy and Progress Energy’s revised market power mitigation plan, the Joint Dispatch Agreement (JDA) and the joint Open Access Transmission Tariff. Several intervenors filed requests for rehearing challenging various aspects of the FERC approval. On October 29, 2014, FERC denied all of the requests for rehearing.

The revised market power mitigation plan provided for the acceleration of one transmission project and the completion of seven other transmission projects (Long-Term FERC Mitigation) and interim firm power sale agreements during the completion of the transmission projects (Interim FERC Mitigation). The Long-Term FERC Mitigation was expected to increase power imported into the Duke Energy Carolinas and Duke Energy Progress service areas and enhance competitive power supply options in the service areas. All of these projects were completed in or before 2014. On May 30, 2014, the Independent Monitor filed with FERC a final report stating that the Long-Term FERC Mitigation is complete. Therefore, Duke Energy Carolinas' and Duke Energy Progress' obligations associated with the Interim FERC Mitigation have terminated. In the second quarter of 2014, Duke Energy Progress recorded an $18 million partial reversal of an impairment recorded in the third quarter of 2012. This reversal adjusts the initial disallowance from the Long-Term FERC mitigation and reflects updated information on the construction costs and in-service dates of the transmission projects.

Following the closing of the merger, outside counsel reviewed Duke Energy’s mitigation plan and discovered a technical error in the calculations. On December 6, 2013, Duke Energy submitted a filing to the FERC disclosing the error and arguing that no additional mitigation is necessary. The City of New Bern filed a protest and requested that FERC order additional mitigation. On October 29, 2014, FERC ordered that the amount of the stub mitigation be increased from 25 MW to 129 MW. The stub mitigation is Duke Energy’s commitment to set aside for third parties a certain quantity of firm transmission capacity from Duke Energy Carolinas to Duke Energy Progress during summer off-peak hours. FERC also ordered that Duke Energy operate certain phase shifters to create additional import capability and that such operation be monitored by an independent monitor. Duke Energy does not expect the costs to comply with this order to be material. FERC also referred Duke Energy’s failure to expressly designate the phase shifter reactivation as a mitigation project in Duke Energy’s original mitigation plan filing in March 2012 to the FERC Office of Enforcement for further inquiry. Duke Energy cannot predict the outcome of this additional inquiry.

Planned and Potential Coal Plant Retirements

The Subsidiary Registrants periodically file Integrated Resource Plans (IRP) with 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. Recent IRPs filed by the Subsidiary Registrants included planning assumptions to potentially retire certain coal-fired generating facilities in Florida, Ohio and Indiana earlier than their current estimated useful lives. These facilities do not have the requisite emission control equipment, primarily to meet EPA regulations recently approved or proposed.

The table below contains the net carrying value of generating facilities planned for early retirement or being evaluated for potential retirement included in Net property, plant and equipment on the Consolidated Balance Sheets, excluding the Duke Energy Carolinas 170 MW Lee Unit 3 which is being converted to gas in 2015.

	December 31, 2014
	Duke Energy		Progress Energy(b)		Duke Energy Florida(b)		Duke Energy Ohio(c)		Duke EnergyIndiana(d)
Capacity (in MW)	1,704		873		873		163		668
Remaining net book value (in millions)(a)	$	239	$	114	$	114	$	9	$	116

(a) Included in Net property, plant and equipment as of December 31, 2014, on the Consolidated Balance Sheets.

(b) Includes Crystal River Units 1 and 2. 

(c) Includes Miami Fort Unit 6 which is expected to be retired by June 1, 2015. 

(d) Includes Wabash River Units 2 through 6. Wabash River Unit 6 is being evaluated for potential conversion to gas. Duke Energy Indiana committed to retire or convert these units by June 2018 in conjunction with a settlement agreement associated with the Edwardsport air permit.

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. However, such recovery, including recovery of carrying costs on remaining book values, could be subject to future regulatory approvals and therefore cannot be assured.

5. COMMITMENTS AND CONTINGENCIES

General Insurance

The Duke Energy Registrants have insurance and reinsurance coverage either directly or through indemnification from Duke Energy’s captive insurance company, Bison, and its affiliates, consistent with companies engaged in similar commercial operations with similar type properties. The Duke Energy Registrants’ coverage includes (i) commercial general liability coverage for liabilities arising to third parties for bodily injury and property damage; (ii) workers’ compensation; (iii) automobile liability coverage; and (iv) property coverage for all real and personal property damage. Real and personal property damage coverage excludes electric transmission and distribution lines, but includes damages arising from boiler and machinery breakdowns, earthquakes, flood damage and extra expense, but not outage or replacement power coverage. All coverage is subject to certain deductibles or retentions, sublimits, exclusions, terms and conditions common for companies with similar types of operations.

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Combined Notes To Consolidated Financial Statements – (Continued)

The Duke Energy Registrants self-insure their electric transmission and distribution lines against loss due to storm damage and other natural disasters. As discussed further in Note 4, Duke Energy Florida maintains a storm damage reserve and has a regulatory mechanism to recover the cost of named storms on an expedited basis.

The cost of the Duke Energy Registrants’ coverage can fluctuate year to year reflecting claims history and conditions of the insurance and reinsurance markets.

In the event of a loss, terms and amounts of insurance and reinsurance available might not be adequate to cover claims and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered by other sources, could have a material effect on the Duke Energy Registrants’ results of operations, cash flows or financial position. Each company is responsible to the extent losses may be excluded or exceed limits of the coverage available.

Nuclear Insurance

Duke Energy Carolinas owns and operates the McGuire Nuclear Station (McGuire) and the Oconee Nuclear Station (Oconee) and operates and has a partial ownership interest in the Catawba Nuclear Station (Catawba). McGuire and Catawba each have two reactors. Oconee has three reactors. The other joint owners of Catawba reimburse Duke Energy Carolinas for certain expenses associated with nuclear insurance per the Catawba joint owner agreements.

Duke Energy Progress owns and operates the Robinson Nuclear Station (Robinson) and operates and has a partial ownership interest in the Brunswick and Harris stations. Robinson and Harris each have one reactor. Brunswick has two reactors. The other joint owners of Brunswick and Harris reimburse Duke Energy Progress for certain expenses associated with nuclear insurance per the Brunswick and Harris joint owner agreements.

Duke Energy Florida manages and has a partial ownership interest in Crystal River Unit 3, which has been retired. The other joint owners of Crystal River Unit 3 reimburse Duke Energy Florida for certain expenses associated with nuclear insurance per the Crystal River Unit 3 joint owner agreement.

In the event of a loss, terms and amounts of insurance available might not be adequate to cover property damage and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered by other sources, could have a material effect on Duke Energy Carolinas’, Duke Energy Progress’ and Duke Energy Florida’s results of operations, cash flows or financial position. Each company is responsible to the extent losses may be excluded or exceed limits of the coverage available.

Nuclear Liability Coverage

The Price-Anderson Act requires owners of nuclear reactors to provide for public nuclear liability protection per nuclear incident up to a maximum total financial protection liability. The maximum total financial protection liability, which is currently $13.6 billion, is subject to change every five years for inflation and the number of licensed reactors. Total nuclear liability coverage consists of a combination of private primary nuclear liability insurance coverage and a mandatory industry risk-sharing program to provide for excess nuclear liability coverage above the maximum reasonably available private primary coverage. The United States Congress could impose revenue-raising measures on the nuclear industry to pay claims.

Primary Liability Insurance

Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida have purchased the maximum reasonably available private primary nuclear liability insurance as required by law, which currently is $375 million per station.

Excess Liability Program

This program provides $13.2 billion of coverage per incident through the Price-Anderson Act’s mandatory industry-wide excess secondary financial protection program of risk pooling. This amount is the product of potential cumulative retrospective premium assessments of $127 million times the current 104 licensed commercial nuclear reactors in U.S. Under this program, licensees could be assessed retrospective premiums to compensate for public nuclear liability damages in the event of a nuclear incident at any licensed facility in the U.S. Retrospective premiums may be assessed at a rate not to exceed $19 million per year per licensed reactor for each incident. The assessment may be subject to state premium taxes.

Nuclear Property and Accidental Outage Coverage

Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida are members of Nuclear Electric Insurance Limited (NEIL), an industry mutual insurance company, which provides "all risk" property damage, decontamination, and premature decommissioning insurance for each station for losses resulting from damage to its nuclear plants, either due to accidents or acts of terrorism. Additionally, NEIL provides some replacement power cost insurance for each station for losses in the event of a major accidental outage at an insured nuclear station. NEIL requires its members to maintain an investment grade credit rating or to ensure collectability of their annual retrospective premium obligation by providing a financial guarantee, letter of credit, deposit premium or other means of assurance. The companies are required each year to report to the NRC the current levels and sources of insurance that demonstrate it possesses sufficient financial resources to stabilize and decontaminate its reactors and reactor station sites in the event of an accident.

Pursuant to regulations of the NRC, each company’s property damage insurance policies provide that all proceeds from such insurance be applied, first, to place the plant in a safe and stable condition after a qualifying accident, and second, to decontaminate the plant before any proceeds can be used for decommissioning, plant repair or restoration.

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Combined Notes To Consolidated Financial Statements – (Continued)

Losses resulting from acts of terrorism are covered as common occurrences, such that if terrorist acts occur against one or more commercial nuclear power plants insured by NEIL within a 12-month period, they would be treated as one event and the owners of the plants where the act occurred would share one full limit of liability. The full limit of liability is currently $3.2 billion. NEIL sublimits the total aggregate for all of their policies for non-nuclear terrorist events to approximately $1.83 billion.

Each nuclear facility has accident property damage, decontamination and premature decommissioning liability insurance from NEIL with limits of $1.5 billion, except for Crystal River Unit 3. Crystal River Unit 3’s limit is $1.1 billion and is on an actual cash value basis. NEIL coverage for Crystal River 3 does not include property damage to or resulting from the containment structure except coverage does apply to decontamination and debris removal, if required following an accident, to ensure public health and safety or if property damage results from a terrorism event. All nuclear facilities except for Catawba and Crystal River Unit 3 also share an additional $1.25 billion nuclear accident insurance limit above their dedicated underlying limit. This shared additional excess limit is not subject to reinstatement in the event of a loss. Catawba has a dedicated $1.25 billion of additional nuclear accident insurance limit above its dedicated underlying limit. Catawba and Oconee also have an additional $750 million of non-nuclear accident property damage limit.

NEIL’s Accidental Outage policy provides some replacement power cost insurance for losses in the event of a major accident property damage outage of a nuclear unit. Coverage is provided on a weekly limit basis after a significant waiting period deductible and at 100 percent of the available weekly limits for 52 weeks and 80 percent of the available weekly limits for the next 110 weeks. Coverage is provided until policy aggregate limits are met where the accidental outage policy limit is $490 million for McGuire and Catawba, $381 million for Oconee, $419 million for Brunswick, $384 million for Harris and $329 million for Robinson. NEIL sublimits the accidental outage recovery to the first 104 weeks of coverage not to exceed $328 million from non-nuclear accidental property damage. Coverage amounts decrease in the event more than one unit at a station is out of service due to a common accident.

Potential Retroactive Premium Assessments

In the event of NEIL losses, NEIL’s board of directors may assess member companies retroactive premiums of amounts up to 10 times their annual premiums for up to 6 years after a loss. NEIL has never exercised this assessment. The maximum aggregate annual retrospective premium obligations for Duke Energy Carolinas are $73 million for primary property insurance and $32 million for accidental outage insurance. The maximum aggregate annual retrospective premium obligations Duke Energy Progress are $60 million for primary property insurance and $16 million for accidental outage insurance. Duke Energy Carolinas maintains excess property insurance for Catawba with a maximum assessment of $7 million, and shares with Duke Energy Progress blanket excess property limits across other sites with a combined potential maximum assessment of $17 million. The current potential maximum assessments for Duke Energy Florida are $8 million for primary property insurance. The maximum assessment amounts include 100 percent of Duke Energy Carolinas’, Duke Energy Progress’, and Duke Energy Florida’s potential obligations to NEIL for their share of jointly owned reactors.

ENVIRONMENTAL

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

The following environmental matters impact all of the Duke Energy Registrants.

Remediation Activities

The Duke Energy Registrants are responsible for environmental remediation at various contaminated sites. These include some 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, activities vary with site conditions and locations, 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 contamination 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. 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 in the Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.

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Combined Notes To Consolidated Financial Statements – (Continued)

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 Deferred Credits and Other Liabilities on the Consolidated Balance Sheets.

(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Balance at December 31, 2011	61		12		23		11		12		28		9
Provisions / adjustments	39		1		19		5		14		5		3
Cash reductions	(25	)	(1	)	(9	)	(2	)	(7	)	(18	)	(4	)
Balance at December 31, 2012	75		12		33		14		19		15		8
Provisions / adjustments	26		—		4		(1	)	5		20		1
Cash reductions	(22	)	(1	)	(10	)	(5	)	(5	)	(8	)	(2	)
Balance at December 31, 2013	79		11		27		8		19		27		7
Provisions / adjustments	32		(1	)	1		4		(3	)	28		4
Cash reductions	(14	)	—		(11	)	(7	)	(4	)	(1	)	(1	)
Balance at December 31, 2014	97		10		17		5		12		54		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 presented in the table below.

(in millions)
Duke Energy	$	89
Duke Energy Carolinas	25
Progress Energy	15
Duke Energy Progress	1
Duke Energy Florida	14
Duke Energy Ohio	42
Duke Energy Indiana	7

North Carolina and South Carolina Ash Basins

On February 2, 2014, a break in a 48-inch stormwater pipe beneath an ash basin at Duke Energy Carolinas’ retired Dan River steam station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the 48-inch stormwater pipe, stopping the release of materials into the river. Duke Energy Carolinas estimates 30,000 to 39,000 tons of ash and 24 million to 27 million gallons of basin water were released into the river during the incident. Duke Energy Carolinas incurred approximately $24 million of repairs and remediation expense related to this incident during the year ended December 31, 2014. These amounts are recorded in Operations, maintenance and other on the Consolidated Statements of Operations and Comprehensive Income. Duke Energy Carolinas will not seek recovery of these costs from customers. In July, Duke Energy completed remediation work identified by the EPA and continues to cooperate with the EPA's civil enforcement process. See the "Litigation" section below for additional information on litigation, investigations, and enforcement actions related to ash basins. Other costs related to the Dan River release, including pending or future state or federal civil enforcement proceedings, future regulatory directives, natural resources damages, additional pending litigation, future claims or litigation, and long-term environmental impact costs cannot be reasonably estimated at this time.

On September 20, 2014, the North Carolina Coal Ash Management Act of 2014 (Coal Ash Act) became law. The Coal Ash Act (i) establishes a Coal Ash Management Commission to oversee handling of coal ash within the state; (ii) prohibits construction of new and expansion of existing ash impoundments and use of existing impoundments at retired facilities, effective October 1, 2014; (iii) requires closure of ash impoundments at Duke Energy Progress' Asheville and Sutton stations and Duke Energy Carolinas' Riverbend and Dan River stations no later than August 1, 2019; (iv) requires dry disposal of fly ash at active plants not retired by December 31, 2018; (v) requires dry disposal of bottom ash at active plants by December 31, 2019, or retirement of active plants; (vi) requires all remaining ash impoundments in North Carolina to be categorized as high-risk, intermediate-risk, or low-risk no later than December 31, 2015 by the North Carolina Department of Environment and Natural Resources (DENR) with the method of closure and timing to be based upon the assigned risk, with closure no later than December 31, 2029; (vii) establishes requirements to deal with groundwater and surface water impacts from impoundments and (viii) enhances the level of regulation for structural fills utilizing coal ash. The Coal Ash Act includes a variance procedure for compliance deadlines and modification of requirements regarding structural fills and compliance boundaries. Provisions of the Coal Ash Act prohibit cost recovery for unlawful discharge of ash basin waters occurring after January 1, 2014. The Coal Ash Act included a moratorium for any NCUC ordered rate changes to effectuate the legislation, which ended January 15, 2015. The Coal Ash Act leaves the decision on cost recovery determinations related to closure of coal combustion residuals surface impoundments (ash basins or impoundments) to the normal ratemaking processes before utility regulatory commissions. In November 2014, Duke Energy submitted to DENR site specific coal ash excavation plans for the four high priority stations required to be closed no later than August 1, 2019. These plans and all associated permits must be approved by DENR before any excavation work can begin.

In September 2014, Duke Energy Carolinas executed a consent agreement with the South Carolina Department of Health and Environmental Control (SCDHEC) requiring the excavation of an inactive ash basin and ash fill area at the W.S. Lee Steam Station. As part of this agreement, in December 2014, Duke Energy Carolinas filed an ash removal plan and schedule with SCDHEC.

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Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy Carolinas and Duke Energy Progress recorded asset retirement obligations at December 31, 2014 based upon the legal obligation for closure of coal ash basins and the disposal of related ash as a result of the Coal Ash Act and the agreement with SCDHEC. Refer to Note 9 for further discussion of the asset retirement obligations recorded at December 31, 2014.

Coal Combustion Residuals

On December 19, 2014, the EPA signed the first federal regulation for the disposal of coal combustion residuals (CCR) from power plants. The federal regulation classifies CCR as nonhazardous waste under the Resource Conservation and Recovery Act and applies to all new and existing landfills, new and existing surface impoundments, structural fills and CCR piles. The rule establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. In addition to the requirements of the federal CCR regulation, CCR landfills and surface impoundments will continue to be independently regulated by most states. Duke Energy records an asset retirement obligation when it has a legal obligation to incur retirement costs associated with the retirement of a long-lived asset and the obligation can be reasonably estimated. Once the rule is effective in 2015, additional asset retirement obligation amounts will be recorded at the Duke registrants. Cost recovery for future expenditures will be pursued through the normal ratemaking process with state utility commissions, which permit recovery of necessary and prudently incurred costs associated with Duke Energy’s regulated operations. At this time, Duke Energy is evaluating the CCR regulation and developing cost estimates that will largely be dependent upon compliance alternatives selected to meet requirements of the regulations. For further discussion of asset retirement obligations see Note 9.

Litigation

Duke Energy

Ash Basin Shareholder Derivative Litigation

Five shareholder derivative lawsuits have been filed in Delaware Chancery Court relating to the release at Dan River and to the management of Duke Energy’s ash basins. On October 31, 2014, the five lawsuits were consolidated in a single proceeding titled "In Re Duke Energy Corporation Coal Ash Derivative Litigation." On December 2, 2014, plaintiffs filed a Corrected Verified Consolidated Shareholder Derivative Complaint (Consolidated Complaint).

The Consolidated Complaint names as defendants several current and former Duke Energy officers and directors (collectively, the “Duke Energy Defendants”). Duke Energy is named as a nominal defendant.

The Consolidated Complaint alleges the Duke Energy Defendants breached their fiduciary duties to the company by failing to adequately oversee Duke Energy’s ash basins and that these breaches of fiduciary duty may have contributed to the incident at Dan River and continued thereafter. The lawsuit also asserts claims against the Duke Energy Defendants for corporate waste (relating to the money Duke Energy has spent and will spend as a result of the fines, penalties, and coal ash removal) and unjust enrichment (relating to the compensation and director remuneration that was received despite these alleged breaches of fiduciary duty). The lawsuit seeks both injunctive relief against Duke Energy and restitution from the Duke Energy Defendants. On January 21, 2015, the Duke Energy Defendants filed a Motion to Stay and an alternative Motion to Dismiss.

On May 28, 2014, Duke Energy received a shareholder litigation demand letter sent on behalf of shareholder Mitchell Pinsly. The letter alleges that the members of the Board of Directors and certain officers breached their fiduciary duties by allowing the company to illegally dispose of and store coal ash pollutants. The letter demands that the Board of Directors take action to recover damages associated with those breaches of fiduciary duty; otherwise, the attorney will file a shareholder derivative action. By letter dated July 3, 2014, counsel for the shareholder was informed that the Board of Directors appointed a Demand Review Committee to evaluate the allegations in the Demand Letter.

It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with these matters.

Progress Energy Merger Shareholder Litigation

Duke Energy, the eleven members of the Board of Directors who were also members of the pre-merger Board of Directors (Legacy Duke Energy Directors) and certain Duke Energy officers are defendants in a purported securities class action lawsuit (Nieman v. Duke Energy Corporation, et al). This lawsuit consolidates three lawsuits originally filed in July 2012, and is pending in the United States District Court for the Western District of North Carolina. The plaintiffs allege federal Securities Act and Exchange Act claims based on allegations of materially false and misleading representations and omissions in the Registration Statement filed on July 7, 2011, and purportedly incorporated into other documents, all in connection with the post-merger change in Chief Executive Officer (CEO). On August 15, 2014, the parties reached an agreement in principle to settle the litigation for an amount which, net of the expected proceeds of insurance policies, is not anticipated to have a material effect on the results of operations, cash flows or financial position of Duke Energy. On December 2, 2014, the parties executed a Memorandum of Understanding relating to the settlement which will be submitted to the court for approval.

On May 31, 2013, the Delaware Chancery Court consolidated four shareholder derivative lawsuits filed in 2012. The Court also appointed a lead plaintiff and counsel for plaintiffs and designated the case as In Re Duke Energy Corporation Derivative Litigation. The lawsuit names as defendants the Legacy Duke Energy Directors. Duke Energy is named as a nominal defendant. The case alleges claims for breach of fiduciary duties of loyalty and care in connection with the post-merger change in CEO. The case is stayed pending resolution of the Nieman v. Duke Energy Corporation, et al. case in North Carolina.

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Combined Notes To Consolidated Financial Statements – (Continued)

Two shareholder Derivative Complaints, filed in 2012 in federal district court in Delaware, were consolidated as Tansey v. Rogers, et al. The case alleges claims for breach of fiduciary duty and waste of corporate assets, as well as claims under Section 14(a) and 20(a) of the Exchange Act. Duke Energy is named as a nominal defendant. Pursuant to an Order entered on September 2, 2014, the court administratively closed this consolidated derivative action. The parties filed a status report with the court on December 1, 2014, and will continue to do so every six months thereafter until the Nieman v. Duke Energy Corporation, et al. case in North Carolina has been resolved.

On August 3, 2012, Duke Energy was served with a shareholder Derivative Complaint, which was transferred to the North Carolina Business Court (Krieger v. Johnson, et al.). The lawsuit names as defendants William D. Johnson and the Legacy Duke Energy Directors. Duke Energy is named as a nominal defendant. The lawsuit alleges claims for breach of fiduciary duty in granting excessive compensation to Mr. Johnson. On April 30, 2014, the North Carolina Business Court granted the Legacy Duke Energy Directors’ motion to dismiss the lawsuit.

It is not possible to estimate the maximum exposure of loss that may occur in connection with these lawsuits.

Price Reporting Cases

A total of five lawsuits were filed against Duke Energy affiliates and other energy companies and remain pending in a consolidated, single federal court proceeding in Nevada. Each of these lawsuits contain similar claims that defendants allegedly manipulated natural gas markets by various means, including providing false information to natural gas trade publications and entering into unlawful arrangements and agreements in violation of the antitrust laws of the respective states. Plaintiffs seek damages in unspecified amounts.

On July 18, 2011, the judge granted a defendant’s motion for summary judgment in two of the remaining five cases to which Duke Energy affiliates are a party. The U.S. Court of Appeals for the Ninth Circuit subsequently reversed the lower court’s decision. On July 1, 2014, the U.S. Supreme Court granted the defendants', including Duke Energy, petition for certiorari. Oral argument was held on January 12, 2015.

It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with the remaining matters. However, based on Duke Energy’s past experiences with similar cases of this nature, it does not believe its exposure under these remaining matters is material.

Brazil Expansion Lawsuit

On August 9, 2011, the State of São Paulo sued Duke Energy International Geracao Paranapenema S.A. (DEIGP) in Brazilian state court. The lawsuit claims DEIGP is under a continuing obligation to expand installed generation capacity in the State of São Paulo by 15 percent pursuant to a stock purchase agreement under which DEIGP purchased generation assets from the state. On August 10, 2011, a judge granted an ex parte injunction ordering DEIGP to present a detailed expansion plan in satisfaction of the 15 percent obligation. DEIGP has previously taken a position the expansion obligation is no longer viable given changes that have occurred in the electric energy sector since privatization. DEIGP submitted its proposed expansion plan on November 11, 2011, but reserved objections regarding enforceability. It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with this matter.

Duke Energy Carolinas and Duke Energy Progress

DENR State Enforcement Actions

In the first quarter of 2013, environmental organizations sent notices of intent to sue Duke Energy Carolinas and Duke Energy Progress related to alleged groundwater violations and Clean Water Act (CWA) violations from coal ash basins at two of their coal-fired power plants in North Carolina. DENR filed enforcement actions against Duke Energy Carolinas and Duke Energy Progress alleging violations of water discharge permits and North Carolina groundwater standards. The case against Duke Energy Carolinas was filed in Mecklenburg County Superior Court. The case against Duke Energy Progress was filed in Wake County Superior Court. The cases are being heard before a single judge.

On October 4, 2013, Duke Energy Carolinas, Duke Energy Progress and DENR negotiated a proposed consent order covering these two plants. The consent order would have assessed civil penalties and imposed a compliance schedule requiring Duke Energy Carolinas and Duke Energy Progress to undertake monitoring and data collection activities toward making appropriate corrective action to address any substantiated violations. In light of the coal ash release that occurred at Dan River on February 2, 2014, on March 21, 2014, DENR withdrew its support of the consent orders and requested that the court proceed with the litigation.

On August 16, 2013, DENR filed an enforcement action against Duke Energy Carolinas and Duke Energy Progress related to their remaining plants in North Carolina, alleging violations of the CWA and violations of the North Carolina groundwater standards. The case against Duke Energy Carolinas was filed in Mecklenburg County Superior Court. The case against Duke Energy Progress was filed in Wake County Superior Court. Both of these cases have been assigned to the judge handling the enforcement actions discussed above. Southern Environmental Law Center (SELC), on behalf of several environmental groups, has been permitted to intervene in these cases.

It is not possible to predict any liability or estimate any damages Duke Energy Carolinas or Duke Energy Progress might incur in connection with these matters.

North Carolina Declaratory Judgment Action

On October 10, 2012, the SELC, on behalf of the same environmental groups that were permitted to challenge the consent decrees discussed above, filed a petition with the North Carolina Environmental Management Commission (EMC) asking for a declaratory ruling seeking to clarify the application of the state’s groundwater protection rules to coal ash basins. The petition sought to change the interpretation of regulations that permitted DENR to assess the extent, cause and significance of any groundwater contamination before ordering action to eliminate the source of contamination, among other issues. Duke Energy Carolinas and Duke Energy Progress were both permitted to intervene in the matter. On December 3, 2012, the EMC affirmed this interpretation of the regulations.

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Combined Notes To Consolidated Financial Statements – (Continued)

On March 6, 2014, the North Carolina State Court judge overturned the ruling of the EMC holding that in the case of groundwater contamination, DENR was required to issue an order to immediately eliminate the source of the contamination before an assessment of the nature, significance and extent of the contamination or the continuing damage to the groundwater was conducted. Duke Energy Carolinas, Duke Energy Progress, and the EMC appealed the ruling in April 2014. On May 16, 2014, the North Carolina Court of Appeals denied a petition to stay the case during the appeal. On October 10, 2014, the parties were notified the case has been transferred to the NCSC. Oral argument has been scheduled for March 16, 2015.

Federal Citizens Suits

There are currently five cases filed in various North Carolina federal courts contending that the DENR state enforcement actions discussed above do not adequately address the issues raised in the notices of intent to sue related to the Riverbend, Sutton, Cape Fear, H.F. Lee and Buck plants.

On June 11, 2013, Catawba Riverkeeper Foundation, Inc. (Catawba Riverkeeper) filed a separate action in the United States Court for the Western District of North Carolina. The lawsuit contends the state enforcement action discussed above does not adequately address issues raised in Catawba Riverkeeper’s notice of intent to sue relating to the Riverbend plant. On April 11, 2014, the Court denied Catawba Riverkeeper’s objections to the Magistrate Judge’s recommendation that plaintiff’s case be dismissed as well as Duke Energy Carolinas’ motion to dismiss. The Court allowed limited discovery, after which Duke Energy Carolinas may file any renewed motions to dismiss.

On September 12, 2013, Cape Fear River Watch, Inc., Sierra Club, and Waterkeeper Alliance filed a citizen suit in the Federal District Court for the Eastern District of North Carolina. The lawsuit alleges unpermitted discharges to surface water and groundwater violations at the Sutton plant. On June 9, 2014, the court granted Duke Energy Progress' request to dismiss the groundwater claims but rejected its request to dismiss the surface water claims. In response to a motion filed by the SELC, on August 1, 2014, the court modified the original June 9^th order to dismiss only the plaintiff's federal law claim based on hydrologic connections at Sutton Lake. The claims related to the alleged state court violations of the permits are back in the case.

On September 3, 2014, three cases were filed by various environmental groups: (i) a citizen suit in the United States Court for the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Cape Fear plant; (ii) a citizen suit in the United States Court for the Eastern District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the H.F. Lee plant; and (iii) a citizen suit in the United States Court for the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Buck plant. On January 5, 2015, Duke Energy Carolinas filed a Motion to Dismiss and a Motion to Stay the proceeding relating to the Buck plant.

It is not possible to predict whether Duke Energy Carolinas or Duke Energy Progress will incur any liability or to estimate the damages, if any, they might incur in connection with these matters.

North Carolina Ash Basin Grand Jury Investigation

As a result of the Dan River ash basin water release discussed above, DENR issued a Notice of Violation and Recommendation of Assessment of Civil Penalties with respect to this matter on February 28, 2014, which the company responded to on March 13, 2014. Duke Energy and certain Duke Energy employees received subpoenas issued by the United States Attorney for the Eastern District of North Carolina in connection with a criminal investigation related to the release and all 14 of the North Carolina facilities with ash basins and the nature of Duke Energy's contacts with DENR with respect to those facilities. This is a multidistrict investigation that also involves state law enforcement authorities.

On February 20, 2015, Duke Energy Carolinas, Duke Energy Progress and Duke Energy Business Services LLC (DEBS), a wholly owned subsidiary of Duke Energy, each entered into a Memorandum of Plea Agreement (Plea Agreements) in connection with the investigation initiated by the United States Department of Justice Environmental Crimes Section and the United States Attorneys for the Eastern District of North Carolina, the Middle District of North Carolina and the Western District of North Carolina (collectively, USDOJ). The Plea Agreements are subject to the approval of the United States District Court for the Eastern District of North Carolina and, if approved, will end the grand jury investigation related to the Dan River ash basin release and the management of coal ash basins at 14 plants in North Carolina with coal ash basins, as discussed above.

Under the Plea Agreements, the USDOJ charged DEBS and Duke Energy Progress with four misdemeanor CWA violations related to violations at Duke Energy Progress’ H.F. Lee Steam Electric Plant, Cape Fear Steam Electric Plant and Asheville Steam Electric Generating Plant. The USDOJ charged Duke Energy Carolinas and DEBS with five misdemeanor CWA violations related to violations at Duke Energy Carolinas’ Dan River Steam Station and Riverbend Steam Station. DEBS, Duke Energy Carolinas and Duke Energy Progress also agreed (i) to a five-year probation period, (ii) to pay a total of approximately $68 million in fines and restitution and $34 million for community service and mitigation (the Payments), and (iii) to establish environmental compliance plans subject to the oversight of a court-appointed monitor paid for by the companies for the duration of the probation period (iii) for Duke Energy Carolinas and Duke Energy Progress each to maintain $250 million under their Master Credit Facility as security to meet their obligations under the Pleas Agreements, in addition to certain other conditions set out in the Plea Agreements. Payments under the Plea Agreements will be borne by shareholders and are not tax deductible. Duke Energy Corporation has agreed to issue a guarantee of all payments and performance due from the Companies, including but not limited to payments for fines, restitution, community service, mitigation and the funding of, and obligations under, the environmental compliance plans. As a result of the Plea Agreements, Duke Energy Carolinas and Duke Energy Progress recognized charges of $72 million and $30 million, respectively, in the fourth quarter of 2014. The amounts are recorded in Operation, maintenance and other on the Consolidated Statements of Operations and Comprehensive Income.

The Plea Agreements do not cover pending civil claims related to the Dan River coal ash release and operations at other North Carolina coal plants. Duke Energy Corporation will continue to cooperate with government agencies and defend against remaining civil litigation associated with these matters.

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Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy Carolinas

New Source Review

In 1999-2000, the U.S. Department of Justice on behalf of the EPA filed a number of complaints and notices of violation against multiple utilities, including Duke Energy Carolinas, for alleged violations of the New Source Review (NSR) provisions of the Clean Air Act (CAA). The government alleges the utilities violated the CAA when undertaking certain maintenance and repair projects at certain coal plants without (i) obtaining NSR permits and (ii) installing the best available emission controls for sulfur dioxide, nitrogen oxide and particulate matter. The complaints seek the installation of pollution control technology on generating units that allegedly violated the CAA, and unspecified civil penalties in amounts of up to $37,500 per day for each violation. Duke Energy Carolinas asserts there were no CAA violations because the applicable regulations do not require NSR permitting in cases where the projects undertaken are “routine” or otherwise do not result in a net increase in emissions.

In 2000, the government sued Duke Energy Carolinas in the U.S. District Court in Greensboro, North Carolina, claiming NSR violations for 29 projects performed at 25 of Duke Energy Carolinas’ coal-fired units. Duke Energy Carolinas asserts the projects were routine and not projected to increase emissions. The parties subsequently filed a stipulation agreeing to dismiss with prejudice all but 13 claims at 13 generating units, 11 of which have since been retired. The parties filed opposing motions for summary judgment on the remaining claims. The Court substantially denied both motions for summary judgment. A Duke Energy request for leave to file another motion for summary judgment on alternative grounds, including expiration of the applicable statute of limitations, was denied. On October 24, 2014, Duke Energy Carolinas filed a motion to certify an appeal of the statute of limitations issue to the U.S. Court of Appeals for the Fourth Circuit. That motion is pending. Trial date has been set for October 2015. It is not possible to predict whether Duke Energy Carolinas will incur any liability or to estimate the damages, if any, it might incur in connection with this matter. Ultimate resolution of these matters could have a material effect on the results of operations, cash flows or financial position of Duke Energy Carolinas. However, the appropriate regulatory recovery will be pursued for costs incurred in connection with such resolution.

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 December 31, 2014, there were 54 asserted claims for non-malignant cases with the cumulative relief sought of up to $11 million, and 28 asserted claims for malignant cases with the cumulative relief sought of up to $7 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 $575 million at December 31, 2014 and $616 million at December 31, 2013. These reserves are classified in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities on the Consolidated Balance Sheets. These reserves are based upon the minimum amount of the range of loss for current and future asbestos claims through 2033, are recorded on an undiscounted basis and incorporate anticipated inflation. In light of the uncertainties inherent in a longer-term forecast, management does not believe they can reasonably estimate the indemnity and medical costs that might be incurred after 2033 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 of $476 million. Duke Energy Carolinas’ cumulative payments began to exceed the self-insurance retention in 2008. Future payments up to the policy limit will be reimbursed by the third-party insurance carrier. The insurance policy limit for potential future insurance recoveries for indemnification and medical cost claim payments is $864 million in excess of the self-insured retention. Receivables for insurance recoveries were $616 million at December 31, 2014 and $649 million at December 31, 2013. These amounts are classified in Other within Investments and Other Assets and Receivables on the 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.

Progress Energy

Synthetic Fuels Matters

Progress Energy and a number of its subsidiaries and affiliates are defendants in lawsuits arising out of a 1999 Asset Purchase Agreement. Parties to the Asset Purchase Agreement include U.S. Global, LLC (Global) and affiliates of Progress Energy.

In a case filed in the Circuit Court for Broward County, Florida, in March 2003 (the Florida Global Case), Global requested an unspecified amount of compensatory damages, as well as declaratory relief. In November 2009, the court ruled in favor of Global. In December 2009, Progress Energy made a $154 million payment which represented payment of the total judgment, including prejudgment interest, and a required premium equivalent to two years of interest, to the Broward County Clerk of Court bond account. Progress Energy continued to accrue interest related to this judgment.

On October 3, 2012, the Florida Fourth District Court of Appeals reversed the lower court ruling. The court held that Global was entitled to approximately $90 million of the amount paid into the registry of the court. Progress Energy was entitled to a refund of the remainder of the funds. Progress Energy received cash and recorded a $63 million pretax gain for the refund in December 2012. The gain was recorded in Income from Discontinued Operations, net of tax in the Consolidated Statements of Operations and Comprehensive Income.

On May 9, 2013, Global filed a Seventh Amended Complaint asserting a single count for breach of the Asset Purchase Agreement and seeking specific performance. The parties reached a settlement in this matter in May 2014, and the case has been dismissed. The amount of the settlement did not have a material effect on the results of operations, cash flows or financial position of Progress Energy. As a result of the settlement of the Florida Global Case, a second suit filed in the Superior Court for Wake County, North Carolina, Progress Synfuel Holdings, Inc. et al. v. U.S. Global, LLC, has been dismissed.

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Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy Progress and Duke Energy Florida

Spent Nuclear Fuel Matters

On December 12, 2011, Duke Energy Progress and Duke Energy Florida sued the United States in the U.S. Court of Federal Claims. The lawsuit claimed the Department of Energy breached a contract in failing to accept spent nuclear fuel under the Nuclear Waste Policy Act of 1982 and asserted damages for the cost of on-site storage. Duke Energy Progress and Duke Energy Florida asserted damages for the period January 1, 2006 through December 31, 2010. Claims for all periods prior to 2006 have been resolved. On March 24, 2014, the U.S. Court of Federal Claims issued a judgment in favor of Duke Energy Progress and Duke Energy Florida on this matter, awarding amounts of $83 million and $21 million, respectively. The majority of the awards were recorded as a reduction to capital costs associated with construction of on-site storage facilities. Duke Energy Progress and Duke Energy Florida received payment of the award in September 2014. On October 16, 2014, Duke Energy Progress and Duke Energy Florida filed a new action for costs incurred from 2011 through 2013.

Duke Energy Florida

Westinghouse Contract Litigation

On March 28, 2014 Duke Energy Florida filed a lawsuit against Westinghouse in the U.S. District Court for the Western District of North Carolina. The lawsuit seeks recovery of $54 million in milestone payments in excess of work performed under the terminated EPC for Levy as well as a determination by the court of the amounts due to Westinghouse as a result of the termination of the EPC.

On March 31, 2014, Westinghouse filed a lawsuit against Duke Energy Florida in U.S. District Court for the Western District of Pennsylvania. The Pennsylvania lawsuit alleged damages under the EPC in excess of $510 million for engineering and design work, costs to end supplier contracts and an alleged termination fee.

On June 9, 2014, the judge in the North Carolina case ruled that the litigation will proceed in the Western District of North Carolina. In November 2014, Westinghouse filed a Motion for Partial Judgment on the pleadings which was denied by the Magistrate Judge on February 20, 2015, subject to court approval. Trial is set for February 2016. It is not possible to predict the outcome of the litigation and whether Duke Energy Florida will incur any liability for terminating the EPC or to estimate the damages, if any, it might incur in connection with these matters. Ultimate resolution of these matters could have a material effect on the results of operations, financial position or cash flows of Duke Energy Florida. However, appropriate regulatory recovery will be pursued for the retail portion of any costs incurred in connection with such resolution.

Duke Energy Ohio

Antitrust Lawsuit

In January 2008, four plaintiffs, including individual, industrial and nonprofit customers, filed a lawsuit against Duke Energy Ohio in federal court in the Southern District of Ohio. Plaintiffs alleged Duke Energy Ohio conspired to provide inequitable and unfair price advantages for certain large business consumers by entering into non-public option agreements in exchange for their withdrawal of challenges to Duke Energy Ohio’s Rate Stabilization Plan implemented in early 2005. In March 2014, a federal judge certified this matter as a class action. The parties have agreed to mediation on March 31, 2015. Trial has been set to begin on July 27, 2015. It is not possible to predict whether Duke Energy Ohio will incur any liability or to estimate the damages, if any, that may be incurred in connection with this matter. Ultimate resolution of this matter could have a material effect on the results of operations, cash flows or financial position of Duke Energy Ohio.

Any liability related to the lawsuit attributable to the Disposal Group will not be transferred to Dynegy upon closing of the disposal of the Midwest generation business.

Asbestos-related Injuries and Damages Claims

Duke Energy Ohio has been named as a defendant or co-defendant in lawsuits related to asbestos exposure at its electric generating stations. The impact on Duke Energy Ohio’s results of operations, cash flows or financial position of these cases to date has not been material. Based on estimates under varying assumptions concerning uncertainties, such as, among others: (i) the number of contractors potentially exposed to asbestos during construction or maintenance of Duke Energy Ohio generating plants, (ii) the possible incidence of various illnesses among exposed workers, and (iii) the potential settlement costs without federal or other legislation that addresses asbestos tort actions, Duke Energy Ohio estimates that the range of reasonably possible exposure in existing and future suits over the foreseeable future is not material. This assessment may change as additional settlements occur, claims are made, and more case law is established.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy Indiana

Edwardsport IGCC

On December 11, 2012, Duke Energy Indiana filed an arbitration action against General Electric Company and Bechtel Corporation in connection with their work at the Edwardsport IGCC facility. Duke Energy Indiana is seeking damages equaling some or all of the additional costs incurred in the construction of the project not recovered at the IURC. The arbitration hearing concluded December 15, 2014. The parties will submit post hearing briefs. Duke Energy Indiana cannot predict the outcome of this matter.

Other Litigation and Legal Proceedings

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

The table below presents recorded reserves based on management’s best estimate of probable loss for legal matters discussed above, excluding asbestos related reserves. Reserves are classified on the Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Accounts payable and Other within Current Liabilities. The reasonably possible range of loss for all non-asbestos related matters in excess of recorded reserves is not material.

	December 31,
(in millions)	2014		2013
Reserves for Legal Matters
Duke Energy	$	323	$	204
Duke Energy Carolinas	72		—
Progress Energy	93		78
Duke Energy Progress	37		10
Duke Energy Florida	36		43

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 Consolidated Balance Sheets and have unlimited maximum potential payments. However, the Duke Energy Registrants do not believe these guarantees will have a material effect on their results of operations, cash flows or financial position.

Purchase Obligations

Purchased Power

Duke Energy Progress and Duke Energy Florida have ongoing purchased power contracts, including renewable energy contracts, with other utilities, wholesale marketers, co-generators, and qualified facilities. These purchased power contracts generally provide for capacity and energy payments. In addition, Duke Energy Progress and Duke Energy Florida have various contracts to secure transmission rights.

The following table presents executory purchased power contracts, excluding contracts classified as leases. All contracts represent 100 percent of net plant output.

		Minimum Purchase Amount at December 31, 2014
(in millions)	Contract Expiration	2015		2016	2017		2018		2019		Thereafter		Total
Duke Energy Progress	2019-2022	$	59	60	$	61	$	62	$	63	$	93	$	398
Duke Energy Florida	2023-2043	244		273	291		306		322		1,907		3,343

Operating and Capital Lease Commitments

The Duke Energy Registrants lease office buildings, railcars, vehicles, computer equipment and other property and equipment with various terms and expiration dates. Additionally, Duke Energy Progress has a capital lease related to firm gas pipeline transportation capacity. Duke Energy Progress and Duke Energy Florida have entered into certain purchased power agreements, which are classified as leases. Consolidated capitalized lease obligations are classified as Long-Term Debt or Other within Current Liabilities on the Consolidated Balance Sheets. Amortization of assets recorded under capital leases is included in Depreciation and amortization and Fuel used in electric generation – regulated on the Consolidated Statements of Operations.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following table presents rental expense for operating leases. These amounts are included in Operation, maintenance and other on the Consolidated Statements of Operations.

	Years Ended December 31,
(in millions)	2014		2013		2012
Duke Energy	$	355	$	321	$	232
Duke Energy Carolinas	41		39		38
Progress Energy	257		225		232
Duke Energy Progress	161		153		164
Duke Energy Florida	96		72		68
Duke Energy Ohio	17		14		14
Duke Energy Indiana	21		22		20

The following table presents future minimum lease payments under operating leases, which at inception had a non-cancelable term of more than one year.

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
2015	$	205	$	33	$	129	$	65	$	64	$	12	$	17
2016	198		29		130		66		64		11		15
2017	172		26		111		65		46		9		13
2018	157		20		109		64		45		7		10
2019	148		17		103		58		45		6		9
Thereafter	938		64		709		421		288		18		9
Total	$	1,818	$	189	$	1,291	$	739	$	552	$	63	$	73

The following table presents future minimum lease payments under capital leases.

	December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
2015	$	178		$	6		$	46		$	21		$	26		$	7		$	4
2016	188			6			47			21			26			7			4
2017	190			7			47			21			26			3			2
2018	198			7			48			22			26			4			2
2019	208			8			51			25			26			2			2
Thereafter	1,771			60			678			398			280			—			42
Minimum annual payments	2,733			94			917			508			410			23			56
Less: amount representing interest	(1,305		)	(67		)	(603		)	(361		)	(242		)	(3		)	(39		)
Total	$	1,428		$	27		$	314		$	147		$	168		$	20		$	17

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

6. DEBT AND CREDIT FACILITIES

Summary of Debt and Related Terms

The following tables summarize outstanding debt.

	December 31, 2014
(in millions)	Weighted Average Interest Rate		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Unsecured debt, maturing 2015 - 2073	4.92	%	$	12,937		$	1,155		$	3,850		$	—		$	150		$	773		$	742
Secured debt, maturing 2016 - 2037	2.50	%	2,806			400			525			300			225			—			—
First mortgage bonds, maturing 2015 - 2044(a)	4.76	%	19,180			6,161			9,800			5,475			4,325			900			2,319
Capital leases, maturing 2015 - 2051(b)	5.30	%	1,428			27			314			146			168			20			16
Tax-exempt bonds, maturing 2015 - 2041(c)	2.13	%	1,296			355			291			291			—			77			573
Notes payable and commercial paper(d)	0.70	%	2,989			—			—			—			—			—			—
Money pool/intercompany borrowings			—			300			835			—			84			516			221
Fair value hedge carrying value adjustment			8			8			—			—			—			—			—
Unamortized debt discount and premium, net(e)			1,890			(15		)	(26		)	(11		)	(8		)	(29		)	(9		)
Total debt	4.29	%	$	42,534		$	8,391		$	15,589		$	6,201		$	4,944		$	2,257		$	3,862
Short-term notes payable and commercial paper			(2,514		)	—			—			—			—			—			—
Short-term money pool borrowings			—			—			(835		)	—			(84		)	(491		)	(71		)
Current maturities of long-term debt(f)			(2,807		)	(507		)	(1,507		)	(945		)	(562		)	(157		)	(5		)
Total long-term debt(f)	4.58	%	$	37,213		$	7,884		$	13,247		$	5,256		$	4,298		$	1,609		$	3,786

(a)    Substantially all electric utility property is mortgaged under mortgage bond indentures.

(b) Duke Energy includes $129 million and $787 million of capital lease purchase accounting adjustments related to Duke Energy Progress and Duke Energy Florida, respectively, related to power purchase agreements that are not accounted for as capital leases in their respective financial statements because of grandfathering provisions in GAAP.

(c) Substantially all tax-exempt bonds are secured by first mortgage bonds or letters of credit.

(d) Includes $475 million that was classified as Long-Term Debt on the Consolidated Balance Sheets due to the existence of long-term credit facilities that back-stop these commercial paper balances, along with Duke Energy’s ability and intent to refinance these balances on a long-term basis. The weighted-average days to maturity was 27 days.

(e) Duke Energy includes $1,975 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.

(f) Refer to Note 17 for additional information on amounts from consolidated VIE’s.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
(in millions)	Weighted Average Interest Rate		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Unsecured debt, maturing 2014 - 2073	5.18	%	$	13,550		$	1,157		$	4,150		$	—		$	150		$	805		$	744
Secured debt, maturing 2014 - 2037	2.69	%	2,559			400			305			305			—			—			—
First mortgage bonds, maturing 2015 - 2043(a)	4.90	%	17,831			6,161			8,450			4,125			4,325			900			2,319
Capital leases, maturing 2014 - 2051(b)	5.23	%	1,516			30			327			148			179			27			20
Other debt, maturing 2027	4.77	%	8			—			—			—			—			8			—
Tax-exempt bonds, maturing 2014 - 2041(c)	1.28	%	2,356			395			910			669			241			479			573
Notes payable and commercial paper(d)	1.02	%	1,289			—			—			—			—			—			—
Money pool/intercompany borrowings			—			300			1,213			462			181			43			150
Fair value hedge carrying value adjustment			9			9			—			—			—			—			—
Unamortized debt discount and premium, net(e)			1,977			(16		)	(27		)	(12		)	(9		)	(31		)	(10		)
Total debt	4.52	%	$	41,095		$	8,436		$	15,328		$	5,697		$	5,067		$	2,231		$	3,796
Short-term notes payable and commercial paper			(839		)	—			—			—			—			—			—
Short-term money pool borrowings			—			—			(1,213		)	(462		)	(181		)	(43		)	—
Current maturities of long-term debt(f)			(2,104		)	(47		)	(485		)	(174		)	(11		)	(47		)	(5		)
Total long-term debt(f)	4.59	%	$	38,152		$	8,389		$	13,630		$	5,061		$	4,875		$	2,141		$	3,791

(a)    Substantially all electric utility property is mortgaged under mortgage bond indentures.

(b) Duke Energy includes $144 million and $838 million of capital lease purchase accounting adjustments related to Duke Energy Progress and Duke Energy Florida, respectively, related to power purchase agreements that are not accounted for as capital leases in their respective financial statements because of grandfathering provisions in GAAP.

(c) Substantially all tax-exempt bonds are secured by first mortgage bonds or letters of credit.

(d) Includes $450 million that was classified as Long-Term Debt on the Consolidated Balance Sheets due to the existence of long-term credit facilities that back-stop these commercial paper balances, along with Duke Energy’s ability and intent to refinance these balances on a long-term basis. The weighted-average days to maturity was 49 days.

(e) Duke Energy includes $2,067 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.

(f) Refer to Note 17 for additional information on amounts from consolidated VIE’s.

Current Maturities of Long-Term Debt

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

(in millions)	Maturity Date	Interest Rate		December 31, 2014
Unsecured Debt
Duke Energy (Parent)	April 2015	3.350	%	$	450
First Mortgage Bonds
Duke Energy Ohio	March 2015	0.375	%	150
Duke Energy Progress	April 2015	5.150	%	300
Duke Energy Carolinas	October 2015	5.300	%	500
Duke Energy Florida	November 2015	0.650	%	250
Duke Energy Florida	December 2015	5.100	%	300
Duke Energy Progress	December 2015	5.250	%	400
Tax-exempt Bonds
Duke Energy Progress	January 2015	0.108	%	243
Other				214
Current maturities of long-term debt				$	2,807

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Maturities and Call Options

The following table shows the annual maturities of long-term debt for the next five years and thereafter. Amounts presented exclude short-term notes payable and commercial paper and money pool borrowings for the Subsidiary Registrants.

	December 31, 2014
(in millions)	Duke Energy(a)		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
2015	$	2,793	$	507	$	1,507	$	945	$	562	$	157	$	5
2016	2,980		756		614		302		12		57		480
2017	2,452		116		940		453		487		3		3
2018	3,207		1,505		515		3		512		28		153
2019	2,810		5		1,418		606		12		552		62
Thereafter	23,803		5,502		9,760		3,892		3,275		969		3,088
Total long-term debt, including current maturities	$	38,045	$	8,391	$	14,754	$	6,201	$	4,860	$	1,766	$	3,791

(a) Excludes $1,975 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.

The Duke Energy Registrants have the ability under certain debt facilities to call and repay the obligation prior to its scheduled maturity. Therefore, the actual timing of future cash repayments could be materially different than as presented above.

Short-Term Obligations Classified as Long-Term Debt

Tax-exempt bonds that may be put to the Duke Energy Registrants at the option of the holder and certain commercial paper issuances and money pool borrowings are classified as Long-Term Debt on the Consolidated Balance Sheets. These tax-exempt bonds, commercial paper issuances and money pool borrowings, which are short-term obligations by nature, are classified as long term due to Duke Energy’s intent and ability to utilize such borrowings as long-term financing. As Duke Energy’s Master Credit Facility and other bilateral letter of credit agreements have non-cancelable terms in excess of one year as of the balance sheet date, Duke Energy has the ability to refinance these short-term obligations on a long-term basis. The following tables show short-term obligations classified as long-term debt.

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Duke Energy Ohio		Duke Energy Indiana
Tax-exempt bonds	$	347	$	35	$	27	$	285
Commercial paper	475		300		25		150
Secured debt(a)	200		—		—		—
Total	$	1,022	$	335	$	52	$	435

	December 31, 2013
(in millions)	Duke Energy		Duke Energy Carolinas		Duke Energy Ohio		Duke Energy Indiana
Tax exempt bonds	$	471	$	75	$	111	$	285
Commercial paper	450		300		—		150
Secured debt(a)	200		—		—		—
Total	$	1,121	$	375	$	111	$	435

(a) Instrument has a term of less than one year with the right to extend the maturity date for additional one-year periods with a final maturity date no later than December 2026.

Summary of Significant Debt Issuances

The following tables summarize significant debt issuances (in millions).

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

				Year Ended December 31, 2014
Issuance Date	Maturity Date	Interest Rate		Duke Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy
Unsecured Debt
April 2014(a)	April 2024	3.750	%	600		—		—		600
April 2014(a)(b)	April 2017	0.613	%	400		—		—		400
June 2014(c)	May 2019	11.970	%	—		—		—		108
June 2014(c)	May 2021	13.680	%	—		—		—		110
Secured Debt
March 2014(d)	March 2017	0.863	%	—		—		225		225
July 2014(e)	July 2036	5.340	%	—		—		—		129
First Mortgage Bonds
March 2014(f)	March 2044	4.375	%	—		400		—		400
March 2014(f)(g)	March 2017	0.435	%	—		250		—		250
November 2014(h)	December 2044	4.150	%	—		500		—		500
November 2014(g)(h)	November 2017	0.432	%	—		200		—		200
Total issuances				$	1,000	$	1,350	$	225	$	2,922

(a) Proceeds were used to redeem $402 million of tax-exempt bonds at Duke Energy Ohio, the repayment of outstanding commercial paper and for general corporate purposes. See Note 13 for additional information related to the redemption of Duke Energy Ohio's tax-exempt bonds.

(b) The debt is floating rate based on three-month London Interbank Offered Rate (LIBOR) plus a fixed credit spread of 38 basis points.

(c) Proceeds were used to repay $196 million of debt for International Energy and for general corporate purposes.

(d) Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Florida. Proceeds were used to repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes. See Note 17 for further details.

(e) Proceeds were used to fund a portion of Duke Energy's prior investment in the existing Wind Star renewables portfolio.

(f) Proceeds were used to repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes.

(g) The debt is floating rate based on three-month LIBOR plus a fixed credit spread of 20 basis points.

(h) Proceeds will be used to redeem $450 million of tax-exempt bonds, repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes.

				Year Ended December 31, 2013
Issuance Date	Maturity Date	Interest Rate		Duke Energy (Parent)		Duke Energy Progress		Duke Energy Ohio		Duke Energy Indiana		Duke Energy
Unsecured Debt
January 2013(a)	January 2073	5.125	%	$	500	$	—	$	—	$	—	$	500
June 2013(b)	June 2018	2.100	%	500		—		—		—		500
August 2013(c)(d)	August 2023	11.000	%	―		—		—		—		220
October 2013(e)	October 2023	3.950	%	400		—		—		—		400
Secured Debt
February 2013(f)(g)	December 2030	2.043	%	—		—		—		—		203
February 2013(f)	June 2037	4.740	%	—		—		—		—		220
April 2013(h)	April 2026	5.456	%	—		—		—		—		230
December 2013(i)	December 2016	0.852	%	—		300		—		—		300
First Mortgage Bonds
March 2013(j)	March 2043	4.100	%	—		500		—		—		500
July 2013(k)	July 2043	4.900	%	—		—		—		350		350
July 2013(k)(l)	July 2016	0.619	%	—		—		—		150		150
September 2013(m)	September 2023	3.800	%	—		—		300		—		300
September 2013(m)(n)	March 2015	0.400	%	—		—		150		—		150
Total issuances				$	1,400	$	800	$	450	$	500	$	4,023

(a) Callable after January 2018 at par. Proceeds were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS) and to repay a portion of outstanding commercial paper and for general corporate purposes.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

(b) Proceeds were used to repay $250 million of current maturities and for general corporate purposes, including the repayment of outstanding commercial paper.

(c) Proceeds were used to repay $200 million of current maturities. The maturity date included above applies to half of the instrument. The remaining half matures in August 2018.

(d) The debt is floating rate based on a consumer price index and an overnight funds rate in Brazil. The debt is denominated in Brazilian Real.

(e) Proceeds were used to repay commercial paper as well as for general corporate purposes.

(f) Represents the conversion of construction loans related to two renewable energy projects issued in December 2012 to term loans. No cash proceeds were received in conjunction with the conversion. The term loans have varying maturity dates. The maturity date presented represents the latest date for all components of the respective loans.

(g) The debt is floating rate. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 95 percent of the loans.

(h) Represents the conversion of a $190 million bridge loan issued in conjunction with the acquisition of Ibener in December 2012. Duke Energy received incremental proceeds of $40 million upon conversion of the bridge loan. The debt is floating rate and is denominated in U.S. dollars. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 75 percent of the loan.

(i) Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Progress; the proceeds were used to repay short-term debt. See Note 17 for further details.

(j) Proceeds were used to repay notes payable to affiliated companies as well as for general corporate purposes.

(k) Proceeds were used to repay $400 million of current maturities.

(l) The debt is floating rate based on three-month LIBOR and a fixed credit spread of 35 basis points.

(m) Proceeds were used for general corporate purposes including the repayment of short-term notes payable, a portion of which was incurred to fund the retirement of $250 million of first mortgage bonds that matured in the first half of 2013.

(n) The debt is floating rate based on three-month LIBOR plus a fixed credit spread of 14 basis points.

Available Credit Facilities

At December 31, 2014, Duke Energy had a Master Credit Facility with a capacity of $6 billion through December 2018. In January 2015, Duke Energy amended the Master Credit Facility to increase its capacity to $7.5 billion through January 2020. The Duke Energy Registrants, excluding Progress Energy, each have borrowing capacity under the Master Credit Facility up to specified sublimits 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 the 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 the Master Credit Facility.

	December 31, 2014
(in millions)	Duke Energy			Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Facility size(a)	$	6,000		$	2,250		$	1,000		$	750		$	650		$	650		$	700
Reduction to backstop issuances
Commercial paper(b)	(2,021		)	(1,479		)	(300		)	—			(29		)	(38		)	(175		)
Outstanding letters of credit	(70		)	(62		)	(4		)	(2		)	(1		)	—			(1		)
Tax-exempt bonds	(116		)	—			(35		)	—			—			—			(81		)
Available capacity	$	3,793		$	709		$	661		$	748		$	620		$	612		$	443

(a) Represents the sublimit of each borrower.

(b) Duke Energy issued $475 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana. The balances are classified as Long-Term Debt Payable to Affiliated Companies in the Consolidated Balance Sheets.

On February 20, 2015, Duke Energy Carolinas, Duke Energy Progress and DEBS, a wholly owned subsidiary of Duke Energy, each entered into the Plea Agreements in connection with the investigation initiated by the USDOJ. Under the terms of the Plea Agreements, Duke Energy Carolinas and Duke Energy Progress are required to each maintain $250 million of available capacity under the Master Credit Facility as security to meet their obligations under the Plea Agreements, in addition to certain other conditions set out in the Plea Agreements. The Plea Agreements are subject to court approval. See Note 5 for further details.

Other Debt Matters

In September 2013, Duke Energy filed a registration statement (Form S-3) with the Securities and Exchange Commission (SEC). Under this Form S-3, which is uncapped, the Duke Energy Registrants, excluding Progress Energy, may issue debt and other securities in the future at amounts, prices and with terms to be determined at the time of future offerings. The registration statement also allows for the issuance of common stock by Duke Energy.

Duke Energy has an effective Form S-3 with the SEC to sell up to $3 billion of variable denomination floating-rate demand notes, called PremierNotes. The Form S-3 states that no more than $1.5 billion of the notes will be outstanding at any particular time. The notes are offered on a continuous basis and bear interest at a floating rate per annum determined by the Duke Energy PremierNotes Committee, or its designee, on a weekly basis. The interest rate payable on notes held by an investor may vary based on the principal amount of the investment. The notes have no stated maturity date, are non-transferable and may be redeemed in whole or in part by Duke Energy or at the investor’s option at any time. The balance as of December 31, 2014 and 2013 was $968 million and $836 million, respectively. The notes are short-term debt obligations of Duke Energy and are reflected as Notes payable and commercial paper on Duke Energy’s Consolidated Balance Sheets.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

At December 31, 2014 and 2013, $767 million and $811 million, respectively, of debt issued by Duke Energy Carolinas was guaranteed by Duke Energy.

Money Pool

The Subsidiary Registrants, excluding Progress Energy receive support for their short-term borrowing needs through participation with Duke Energy and certain of its subsidiaries in a money pool arrangement. Under this arrangement, those companies with short-term funds may provide short-term loans to affiliates participating in this arrangement. The money pool is structured such that the Subsidiary Registrants, excluding Progress Energy, separately manage their cash needs and working capital requirements. Accordingly, there is no net settlement of receivables and payables between money pool participants. Duke Energy (Parent), may loan funds to its participating subsidiaries, but may not borrow funds through the money pool. Accordingly, as the money pool activity is between Duke Energy and its wholly owned subsidiaries, all money pool balances are eliminated within Duke Energy’s Consolidated Balance Sheets.

Money pool receivable balances are reflected within Notes receivable from affiliated companies on the Subsidiary Registrants’ Consolidated Balance Sheets. Money pool payable balances are reflected within either Notes payable to affiliated companies or Long-Term Debt Payable to Affiliated Companies on the Subsidiary Registrants’ Consolidated Balance Sheets.

Restrictive Debt Covenants

The Duke Energy Registrants’ debt and credit agreements contain various financial and other covenants. The Master Credit Facility contains a covenant requiring the debt-to-total capitalization ratio not exceed 65 percent for each borrower. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of December 31, 2014, each of the Duke Energy Registrants were in compliance with all covenants related to their significant debt agreements. In addition, some credit agreements may allow for acceleration of payments or termination of the agreements due to nonpayment, or acceleration of other significant indebtedness of the borrower or some of its subsidiaries. None of the significant debt or credit agreements contain material adverse change clauses.

Other Loans

During 2014 and 2013, Duke Energy and Duke Energy Progress had loans outstanding against the cash surrender value of life insurance policies it owns on the lives of its executives. The amounts outstanding were $603 million, including $44 million at Duke Energy Progress and $571 million, including $48 million at Duke Energy Progress as of December 31, 2014 and 2013, respectively. The amounts outstanding were carried as a reduction of the related cash surrender value that is included in Other within Investments and Other Assets on the Consolidated Balance Sheets.

7. GUARANTEES AND INDEMNIFICATIONS

Duke Energy and Progress Energy have various financial and performance guarantees and indemnifications, which are issued in the normal course of business. As discussed below, these contracts include performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and indemnifications. Duke Energy and Progress Energy enter into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party. At December 31, 2014, Duke Energy and Progress Energy do not believe conditions are likely for significant performance under these guarantees. To the extent liabilities are incurred as a result of the activities covered by the guarantees, such liabilities are included on the accompanying Consolidated Balance Sheets.

On January 2, 2007, Duke Energy completed the spin-off of its natural gas businesses to shareholders. Guarantees issued by Duke Energy or its affiliates, or assigned to Duke Energy prior to the spin-off, remained with Duke Energy subsequent to the spin-off. Guarantees issued by Spectra Energy Capital, LLC, formerly known as Duke Capital LLC, (Spectra Capital) or its affiliates prior to the spin-off remained with Spectra Capital subsequent to the spin-off, except for guarantees that were later assigned to Duke Energy. Duke Energy has indemnified Spectra Capital against any losses incurred under certain of the guarantee obligations that remain with Spectra Capital. At December 31, 2014, the maximum potential amount of future payments associated with these guarantees was $205 million, the majority of which expires by 2028.

Duke Energy has issued performance guarantees to customers and other third parties that guarantee the payment and performance of other parties, including certain non-wholly owned entities, as well as guarantees of debt of certain non-consolidated entities and less than wholly owned consolidated entities. If such entities were to default on payments or performance, Duke Energy would be required under the guarantees to make payments on the obligations of the less than wholly owned entity. The maximum potential amount of future payments required under these guarantees as of December 31, 2014, was $267 million. Of this amount, $15 million relates to guarantees issued on behalf of less than wholly owned consolidated entities, with the remainder related to guarantees issued on behalf of third parties and unconsolidated affiliates of Duke Energy. Of the guarantees noted above, $120 million of the guarantees expire between 2015 and 2033, with the remaining performance guarantees having no contractual expiration.

Duke Energy has guaranteed certain issuers of surety bonds, obligating itself to make payment upon the failure of a wholly owned and former non-wholly owned entity to honor its obligations to a third party. Under these arrangements, Duke Energy has payment obligations that are triggered by a draw by the third party or customer due to the failure of the wholly owned or former non-wholly owned entity to perform according to the terms of its underlying contract. At December 31, 2014, Duke Energy had guaranteed $44 million of outstanding surety bonds, most of which have no set expiration.

Duke Energy uses bank-issued stand-by letters of credit to secure the performance of wholly owned and non-wholly owned entities to a third party or customer. Under these arrangements, Duke Energy has payment obligations to the issuing bank which are triggered by a draw by the third party or customer due to the failure of the wholly owned or non-wholly owned entity to perform according to the terms of its underlying contract. At December 31, 2014, Duke Energy had issued a total of $452 million in letters of credit, which expire between 2015 and 2020. The unused amount under these letters of credit was $46 million.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy and Progress Energy have issued indemnifications for certain asset performance, legal, tax and environmental matters to third parties, including indemnifications made in connection with sales of businesses. At December 31, 2014, the estimated maximum exposure for these indemnifications was $107 million, the majority of which expires in 2017. Of this amount, $7 million has no contractual expiration. For certain matters for which Progress Energy receives timely notice, indemnity obligations may extend beyond the notice period. Certain indemnifications related to discontinued operations have no limitations as to time or maximum potential future payments.

The following table includes the liabilities recognized for the guarantees discussed above. These amounts are primarily recorded in Other within Deferred Credits and other Liabilities on the Consolidated Balance Sheets. As current estimates change, additional losses related to guarantees and indemnifications to third parties, which could be material, may be recorded by the Duke Energy Registrants in the future.

	December 31,
	2014		2013
Duke Energy	$	28	$	24
Progress Energy	13		9
Duke Energy Florida	7		3

8. JOINT OWNERSHIP OF GENERATING AND TRANSMISSION FACILITIES

The Duke Energy Registrants hold ownership interests in certain jointly owned generating and transmission facilities. The Duke Energy Registrants are entitled to shares of the generating capacity and output of each unit equal to their respective ownership interests, except as outlined below. The Duke Energy Registrants pay their ownership share of additional construction costs, fuel inventory purchases and operating expenses, except in certain instances where agreements have been executed to limit certain joint owners’ maximum exposure to the additional costs. The Duke Energy Registrants share of revenues and operating costs of the jointly owned generating facilities is included within the corresponding line in the Consolidated Statements of Operations. Each participant in the jointly owned facilities must provide its own financing, except in certain instances where agreements have been executed to limit certain joint owners’ maximum exposure to the additional costs. 

The following table presents the share of jointly owned plant or facilities included on the Consolidated Balance Sheets. All facilities are operated by the Duke Energy Registrants unless otherwise noted.

	December 31, 2014
	Ownership Share		Property, Plant and Equipment		Accumulated Depreciation		Construction Work in Progress
Duke Energy Carolinas
Catawba Nuclear Station (Units 1 and 2)(a)(b)	19.25	%	$	886	$	534	$	29
Duke Energy Progress
Mayo Station(a)(c)	83.83	%	1,111		360		10
Shearon Harris Nuclear Station(a)(c)	83.83	%	3,872		2,242		208
Brunswick Nuclear Station(a)(c)	81.67	%	2,673		1,372		290
Roxboro Station (Unit 4)(a)(c)	87.06	%	954		514		24
Duke Energy Florida
Crystal River Nuclear Station (Unit 3)(a)(d)	91.78	%	—		—		—
Intercession City Station (Unit P11)(a)	(e)		24		14		—
Duke Energy Ohio
Miami Fort Station (Units 7 and 8)(f)(g)	64.0	%	—		—		—
J.M. Stuart Station(f)(h)(i)	39.0	%	—		—		—
Conesville Station (Unit 4)(f)(h)(i)	40.0	%	—		—		—
W.M. Zimmer Station(f)(h)	46.5	%	—		—		—
Killen Station(f)(g)(i)	33.0	%	—		—		—
Transmission facilities(a)(h)	Various		96		51		1
Duke Energy Indiana
Gibson Station (Unit 5)(a)(j)	50.05	%	315		170		6
Vermillion(a)(k)	62.5	%	154		105		—
Transmission and local facilities(a)(j)	Various		3,918		1,633		—
International Energy
Brazil - Canoas I and II(l)	47.2	%	235		78		—

(a) Included in Regulated Utilities segment.

(b) Jointly owned with North Carolina Municipal Power Agency Number 1, NCEMC and Piedmont Municipal Power Agency.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

(c) Jointly owned with NCEMPA. Duke Energy Progress executed an agreement in September 2014 to purchase NCEMPA's ownership interest in these facilities. See Note 2 for further discussion.

(d) All costs associated with Crystal River Unit 3 are included within Regulatory assets on the Consolidated Balance Sheets of Duke Energy, Progress Energy and Duke Energy Florida. See Note 4 for additional information. Co-owned with Seminole Electric Cooperative, Inc., City of Ocala, Orlando Utilities Commission, City of Gainesville, City of Leesburg, Kissimmee Utility Authority, Utilities Commission of the City of New Smyrna Beach, City of Alachua and City of Bushnell (Florida Municipal Joint Owners). Duke Energy Florida is in the process of obtaining the remaining ownership interest from the Florida Municipal Joint Owners.

(e) Jointly owned with Georgia Power Company (GPC). GPC has exclusive rights to the output of the unit during the months of June through September and pays all fuel and water costs during this period. Duke Energy Florida pays all fuel and water costs during the remaining months. Other costs are allocated 66.67 percent to Duke Energy Florida and the remainder to GPC.

(f) All costs associated with these plants are included in Assets held for sale on the Consolidated Balance Sheets of Duke Energy and Duke Energy Ohio as part of the Disposal Group. See Note 2 for further discussion.

(g) Jointly owned with The Dayton Power and Light Company.

(h) Jointly owned with America Electric Power Generation Resources and The Dayton Power and Light Company. 

(i) Station is not operated by Duke Energy Ohio.

(j) Jointly owned with WVPA and Indiana Municipal Power Agency.

(k) Jointly owned with WVPA.

(l) Included in International Energy segment. Jointly owned with Companhia Brasileira de Aluminio.

9. ASSET RETIREMENT OBLIGATIONS

Asset retirement obligations recognized by Duke Energy Carolinas, Progress Energy and Duke Energy Progress relate primarily to decommissioning nuclear power facilities, closure of ash basins in North Carolina and South Carolina, asbestos removal and closure of landfills at fossil generation facilities. Asset retirement obligations recognized at Duke Energy Florida relate primarily to decommissioning nuclear power facilities, asbestos removal and closure of landfills at fossil generation facilities. Asset retirement obligations at Duke Energy Ohio relate primarily to the retirement of natural gas mains, asbestos removal and closure of landfills at fossil generation facilities. Asset retirement obligations at Duke Energy Indiana relate primarily to obligations associated with asbestos removal and closure of landfills at fossil generation facilities. Duke Energy also has asset retirement obligations related to the removal of renewable energy generation assets in addition to the above items. Certain of the Duke Energy Registrants’ assets have an indeterminate life, such as transmission and distribution facilities, and thus the fair value of the retirement obligation is not reasonably estimable. A liability for these asset retirement obligations will be recorded when a fair value is determinable.

The following table presents changes in the liability associated with asset retirement obligations.

(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Balance at December 31, 2012(a)	$	5,176		$	1,959		$	2,420		$	1,656	$	764		$	28		$	37
Acquisitions	4			—			—			—		—			—			—
Accretion expense(b)	239			122			113			80		33			2			—
Liabilities settled	(12		)	—			(12		)	—		(12		)	—			—
Revisions in estimates of cash flows(c)	(449		)	(487		)	49			1		48			(2		)	(7		)
Balance at December 31, 2013(a)	4,958			1,594			2,570			1,737		833			28			30
Acquisitions	4			—			—			—		—			—			—
Accretion expense(b)	246			113			135			97		38			2			2
Liabilities settled(d)	(68		)	—			(68		)	—		(68		)	—			—
Liabilities incurred in the current year(e)	3,500			1,717			1,783			1,783		—			—			—
Revisions in estimates of cash flows(c)	(174		)	4			291			288		3			(3		)	—
Balance at December 31, 2014	$	8,466		$	3,428		$	4,711		$	3,905	$	806		$	27		$	32

(a) Balances at December 31, 2013 and 2012, include $8 million and $7 million, respectively, reported in Other current liabilities on the Consolidated Balance Sheets at Duke Energy, Progress Energy and Duke Energy Progress.

(b) Substantially all accretion expense for the years ended December 31, 2014 and 2013 relates to Duke Energy’s regulated electric operations and has been deferred in accordance with regulatory accounting treatment.

(c) For 2014, amounts for Duke Energy, Progress Energy and Duke Energy Progress primarily relate to Duke Energy Progress' site-specific nuclear decommissioning cost studies. Amounts at Duke Energy also include impacts from Duke Energy Progress' site-specific nuclear decommissioning cost studies on purchase accounting amounts. For 2013, amounts for Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Florida primarily relate to the site-specific nuclear decommissioning cost studies.

(d) Amounts relate to liability settlements for Crystal River Unit 3.

(e) Amounts primarily relate to asset retirement obligations recorded as a result of the Coal Ash Act and an agreement with the SCDHEC related to the W.S. Lee Steam Station.

The Duke Energy Registrants’ regulated operations accrue costs of removal for property that does not have an associated legal retirement obligation based on regulatory orders from state commissions. These costs of removal are recorded as a regulatory liability in accordance with regulatory accounting treatment. The Duke Energy Registrants do not accrue the estimated cost of removal for any nonregulated assets. See Note 4 for the estimated cost of removal for assets without an associated legal retirement obligation, which are included in Regulatory liabilities on the Consolidated Balance Sheets.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Ash Basins

As of December 31, 2014, as a result of the Coal Ash Act and the agreement with SCDHEC discussed in Note 5, Duke Energy Carolinas and Duke Energy Progress have asset retirement obligations in the amount of $1,735 million and $1,792 million, respectively, related to closure of ash basins in North Carolina and South Carolina.

The asset retirement obligation amount is based upon estimated ash basin closure costs for each of Duke Energy's 32 ash basins located at 14 plants in North Carolina and an ash basin and ash fill area at a plant in South Carolina. The amount recorded represents the discounted cash flows for estimated ash basin closure costs based upon probability weightings of the potential closure methods as evaluated on a site by site basis. Actual costs to be incurred will be dependent upon factors that vary from site to site. The most significant factors are the method and timeframe of closure at the individual sites. Closure methods considered include removing the water from the basins and capping the ash with a synthetic barrier, excavating and relocating the ash to a lined structural fill or lined landfill, or recycling the ash for concrete or some other beneficial use. The ultimate method and timetable for closure will be in compliance with future standards set by the Coal Ash Management Commission established by the Coal Ash Act. The asset retirement obligation amounts will be adjusted as additional information is gained from the Coal Ash Management Commission on acceptable compliance approaches which may change management assumptions.

Asset retirement costs associated with the asset retirement obligations for operating plants and retired plants are included in Net property, plant and equipment, and Regulatory assets, respectively, on the Consolidated Balance Sheets. Of the asset retirement obligations recorded, $896 million and $603 million were recorded in Net property, plant and equipment for Duke Energy Carolinas and Duke Energy Progress, respectively, and $839 million and $1,152 million were recorded in Regulatory assets for Duke Energy Carolinas and Duke Energy Progress, respectively. The asset retirement costs recorded for Duke Energy Progress are net of $37 million of Regulatory liabilities related to cost of removal. Cost recovery for these expenditures is believed to be probable and will be pursued through the normal ratemaking process with the NCUC, PSCSC and FERC.

In December 2014, the EPA signed the first regulation for the disposal of CCR. The federal regulation classifies CCR as nonhazardous waste. The regulation applies to all new and existing landfills, new and existing surface impoundments, structural fills and CCR piles. The law establishes requirements regarding landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to ensure the safe disposal and management of CCR. Once the rule is effective in 2015, additional ARO amounts will be recorded at the Duke Energy Registrants. For more information, see Note 5.

Nuclear Decommissioning Costs

Use of the NDTF investments are restricted to nuclear decommissioning activities. The NDTF investments are managed and invested in accordance with applicable requirements of various regulatory bodies, including the NRC, FERC, NCUC, PSCSC, FPSC and the Internal Revenue Service (IRS). The fair value of assets legally restricted for purposes of settling asset retirement obligations associated with nuclear decommissioning are $5,182 million and $2,678 million for Duke Energy and Duke Energy Carolinas at December 31, 2014, respectively, and $4,769 million and $2,477 million for Duke Energy and Duke Energy Carolinas at December 31, 2013, respectively. The NDTF balances for Progress Energy, Duke Energy Progress and Duke Energy Florida represent the fair value of assets legally restricted for purposes of settling asset retirement obligations associated with nuclear decommissioning. The NCUC, PSCSC and FPSC require updated cost estimates for decommissioning nuclear plants every five years.

The following table summarizes information about nuclear decommissioning cost studies.

(in millions)	Annual Funding Requirement		Decommissioning Costs(a)(b)(c)		Year of Cost Study
Duke Energy Carolinas(d)	$	21	$	3,420	2013
Duke Energy Progress(e)	14		3,062		2014
Duke Energy Florida	—		1,083		2013

(a) Represents cost per the most recent site-specific nuclear decommissioning cost studies, including costs to decommission plant components not subject to radioactive contamination.

(b) Includes the Subsidiary Registrants' ownership interest in jointly owned reactors. Other joint owners are responsible for decommissioning costs related to their interest in the reactors.

(c) Amounts are in dollars of year of cost study.

(d) In the fourth quarter of 2014, Duke Energy Carolinas requested from the NCUC a reduction in the annual funding requirement to zero. Duke Energy Carolinas received approval from the NCUC in January 2015.

(e) Duke Energy Progress' site-specific cost nuclear decommissioning cost studies are expected to be filed with the NCUC and PSCSC by the second quarter of 2015. Duke Energy Progress will also complete a new funding study, which will be completed and filed with the NCUC and PSCSC in 2015.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Nuclear Operating Licenses

Operating licenses for nuclear units are potentially subject to extension. The following table includes the current expiration of nuclear operating licenses.

Unit	Year of Expiration
Duke Energy Carolinas
Catawba Unit 1	2043
Catawba Unit 2	2043
McGuire Unit 1	2041
McGuire Unit 2	2043
Oconee Unit 1	2033
Oconee Unit 2	2033
Oconee Unit 3	2034
Duke Energy Progress
Brunswick Unit 1	2036
Brunswick Unit 2	2034
Harris	2046
Robinson	2030
Duke Energy Florida
Crystal River Unit 3	(a)

(a) Duke Energy Florida has requested the NRC terminate the operating license as Crystal River Unit 3 permanently ceased operation in February 2013. Refer to Note 4 for further information on decommissioning activity and transition to SAFSTOR.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

10. PROPERTY, PLANT AND EQUIPMENT

The following tables summarize the property, plant and equipment.

	December 31, 2014
(in millions)	Estimated Useful Life (Years)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Land		$	1,459		$	403		$	704		$	380		$	324		$	114		$	108
Plant - Regulated
Electric generation, distribution and transmission	2 - 138	82,206			31,751			33,672			20,616			13,056			3,956			11,911
Natural gas transmission and distribution	12 - 67	2,230			—			—			—			—			2,230			—
Other buildings and improvements	9 - 100	1,445			465			607			286			318			200			173
Plant - Nonregulated
Electric generation, distribution and transmission	1- 30	2,380			—			—			—			—			—			—
Other buildings and improvements	5 - 50	2,498			—			—			—			—			—			—
Nuclear fuel		2,865			1,676			1,190			1,190			—			—			—
Equipment	3 - 34	1,762			341			506			388			118			330			166
Construction in process		4,519			2,081			1,215			908			307			97			481
Other	5 - 80	3,497			655			756			439			310			214			195
Total property, plant and equipment(a)(d)		104,861			37,372			38,650			24,207			14,433			7,141			13,034
Total accumulated depreciation - regulated(b)(c)(d)		(32,628		)	(12,700		)	(13,506		)	(9,021		)	(4,478		)	(2,213		)	(4,219		)
Total accumulated depreciation - nonregulated(c)(d)		(2,196		)	—			—			—			—			—			—
Generation facilities to be retired, net		9			—			—			—			—			9			—
Total net property, plant and equipment		$	70,046		$	24,672		$	25,144		$	15,186		$	9,955		$	4,937		$	8,815

(a) Includes capitalized leases of $1,548 million, $40 million, $315 million, $146 million, $169 million, $98 million, and $30 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $72 million, $5 million and $67 million, respectively, of accumulated amortization of capitalized leases.

(b) Includes $1,408 million, $847 million, $561 million and $561 million of accumulated amortization of nuclear fuel at Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Progress, respectively.

(c) Includes accumulated amortization of capitalized leases of $52 million, $8 million, $25 million and $6 million at Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, respectively.

(d) Includes gross property, plant and equipment cost of consolidated VIEs of $1,873 million and accumulated depreciation of consolidated VIEs of $257 million at Duke Energy.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
(in millions)	Estimated Useful Life (Years)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Land		$	1,481		$	397		$	705		$	383		$	321		$	137		$	105
Plant - Regulated
Electric generation, distribution and transmission	2 - 125	78,272			30,018			31,792			19,190			12,601			3,925			11,594
Natural gas transmission and distribution	12 - 67	2,138			—			—			—			—			2,138			—
Other buildings and improvements	2 - 100	1,397			447			610			282			315			190			159
Plant - Nonregulated
Electric generation, distribution and transmission	2 - 100	6,267			—			—			—			—			4,017			—
Other buildings and improvements	9 -100	2,512			—			—			—			—			5			—
Nuclear fuel		2,458			1,446			1,012			1,012			—			—			—
Equipment	1 - 33	1,557			287			621			357			94			317			146
Construction in process		3,595			1,741			873			631			238			166			307
Other	5 - 33	3,438			570			867			418			294			248			178
Total property, plant and equipment(a)(d)		103,115			34,906			36,480			22,273			13,863			11,143			12,489
Total accumulated depreciation - regulated(b)(c)(d)		(31,659		)	(11,894		)	(13,098		)	(8,623		)	(4,252		)	(2,160		)	(3,913		)
Total accumulated depreciation - nonregulated(c)(d)		(1,966		)	—			—			—			—			(748		)	—
Total net property, plant and equipment		$	69,490		$	23,012		$	23,382		$	13,650		$	9,611		$	8,235		$	8,576

(a) Includes capitalized leases of $1,606 million, $53 million, $328 million, $148 million, $180 million, $96 million, and $30 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $60 million, an insignificant amount and $57 million, respectively, of accumulated amortization of capitalized leases.

(b) Includes $1,118 million, $681 million, $438 million and $438 million of accumulated amortization of nuclear fuel at Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Progress, respectively.

(c) Includes accumulated amortization of capitalized leases of $40 million, $4 million, $21 million and $5 million at Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, respectively.

(d) Includes gross property, plant and equipment cost of consolidated VIEs of $1,678 million and accumulated depreciation of consolidated VIEs of $175 million at Duke Energy.

The following table presents capitalized interest, which includes the debt component of AFUDC.

	Years Ended December 31,
(in millions)	2014		2013		2012
Duke Energy	$	75	$	89	$	176
Duke Energy Carolinas	38		41		72
Progress Energy	11		19		41
Duke Energy Progress	10		16		23
Duke Energy Florida	1		3		18
Duke Energy Ohio	10		11		13
Duke Energy Indiana	6		9		39

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

11. GOODWILL AND INTANGIBLE ASSETS

Goodwill

The following tables present goodwill by reportable operating segment for Duke Energy and Duke Energy Ohio. 

Duke Energy

(in millions)	Regulated Utilities		International Energy			Commercial Power			Total
Balance at December 31, 2013
Goodwill	$	15,950	$	326		$	935		$	17,211
Accumulated impairment charges	—		—			(871		)	(871		)
Balance at December 31, 2013, net of accumulated impairment charges	15,950		326			64			16,340
Foreign exchange and other changes	—		(19		)	—			(19		)
Balance at December 31, 2014
Goodwill	15,950		307			935			17,192
Accumulated impairment charges	—		—			(871		)	(871		)
Balance at December 31, 2014, net of accumulated impairment charges	$	15,950	$	307		$	64		$	16,321

Duke Energy Ohio

(in millions)	Regulated Utilities			Commercial Power			Total
Balance at December 31, 2013
Goodwill	$	1,136		$	1,188		$	2,324
Accumulated impairment charges	(216		)	(1,188		)	(1,404		)
Balance at December 31, 2013, net of accumulated impairment charges	920			—			920
Balance at December 31, 2014
Goodwill	1,136			1,188			2,324
Accumulated impairment charges	(216		)	(1,188		)	(1,404		)
Balance at December 31, 2014, net of accumulated impairment charges	$	920		$	—		$	920

Progress Energy

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

Impairment Testing

Duke Energy, Duke Energy Ohio and Progress Energy are required to perform an annual goodwill impairment test as of the same date each year and, accordingly, performs its annual impairment testing of goodwill as of August 31. Duke Energy, Duke Energy Ohio and Progress Energy 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 of Duke Energy, Duke Energy Ohio and Progress Energy’s reporting units exceeded their respective carrying values at the date of the annual impairment analysis, no impairment charges were recorded in 2014.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Intangible Assets

The following tables show the carrying amount and accumulated amortization of intangible assets within Other on the Consolidated Balance Sheets of the Duke Energy Registrants at December 31, 2014 and 2013.

	December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio (a)		Duke Energy Indiana
Emission allowances	$	23		$	1	$	7	$	3	$	4	$	—	$	16
Renewable energy certificates	97			25		69		69		—		3		—
Gas, coal and power contracts	24			—		—		—		—		—		24
Wind development rights	97			—		—		—		—		—		—
Other	76			—		—		—		—		—		—
Total gross carrying amounts	317			26		76		72		4		3		40
Accumulated amortization - gas, coal and power contracts	(15		)	—		—		—		—		—		(15		)
Accumulated amortization - wind development rights	(14		)	—		—		—		—		—		—
Accumulated amortization - other	(25		)	—		—		—		—		—		—
Total accumulated amortization	(54		)	—		—		—		—		—		(15		)
Total intangible assets, net	$	263		$	26	$	76	$	72	$	4	$	3	$	25

(a) During 2014, Duke Energy Ohio reduced the carrying amount of OVEC to zero. A charge of $94 million is recorded in Impairment Charges on Duke Energy Ohio's Consolidated Statement of Operations. In addition, Duke Energy Ohio has emission allowances and renewable energy certificates that have been reclassified to Assets Held For Sale pending the sale of the Disposal Group. See Note 17 for further information.

	December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio			Duke Energy Indiana
Emission allowances	$	63		$	1	$	21	$	3	$	18	$	20		$	21
Renewable energy certificates	82			16		64		64		—		2			—
Gas, coal and power contracts	180			—		—		—		—		156			24
Wind development rights	86			—		—		—		—		—			—
Other	76			—		—		—		—		—			—
Total gross carrying amounts	487			17		85		67		18		178			45
Accumulated amortization - gas, coal and power contracts	(73		)	—		—		—		—		(60		)	(13		)
Accumulated amortization - wind development rights	(12		)	—		—		—		—		—			—
Accumulated amortization - other	(24		)	—		—		—		—		—			—
Total accumulated amortization	(109		)	—		—		—		—		(60		)	(13		)
Total intangible assets, net	$	378		$	17	$	85	$	67	$	18	$	118		$	32

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Amortization Expense

The following table presents amortization expense for gas, coal and power contracts, wind development rights and other intangible assets.

	December 31,
(in millions)	2014		2013		2012
Duke Energy	$	6	$	13	$	14
Duke Energy Ohio	2		8		12
Duke Energy Indiana	1		1		1

The table below shows the expected amortization expense for the next five years for intangible assets as of December 31, 2014. The expected amortization expense includes estimates of emission allowances consumption and estimates of consumption of commodities such as gas and coal under existing contracts, as well as estimated amortization related to the wind development projects. The amortization amounts discussed below are estimates and actual amounts may differ from these estimates due to such factors as changes in consumption patterns, sales or impairments of emission allowances or other intangible assets, delays in the in-service dates of wind assets, additional intangible acquisitions and other events.

(in millions)	2015		2016		2017		2018		2019
Duke Energy	$	11	$	8	$	7	$	7	$	7
Duke Energy Ohio	2		1		1		1		1
Duke Energy Indiana	5		3		2		2		2

12. INVESTMENTS IN UNCONSOLIDATED AFFILIATES

EQUITY METHOD INVESTMENTS

Investments in domestic and international affiliates that are not controlled by Duke Energy, but over which it has significant influence, are accounted for using the equity method. As of December 31, 2014 and 2013, the carrying amount of investments in affiliates with carrying amounts greater than zero approximated the amount of underlying equity in net assets.

The following table presents Duke Energy’s investments in unconsolidated affiliates accounted for under the equity method, as well as the respective equity in earnings, by segment.

	Years Ended December 31,
	2014					2013					2012
(in millions)	Investments		Equity in earnings			Investments		Equity in earnings			Equity in earnings
Regulated Utilities	$	3	$	(3	)	$	4	$	(1	)	$	(5	)
International Energy	69		120			82		110			134
Commercial Power	258		10			252		7			14
Other	28		3			52		6			5
Total	$	358	$	130		$	390	$	122		$	148

During the years ended December 31, 2014, 2013 and 2012, Duke Energy received distributions from equity investments of $154 million, $144 million and $183 million, respectively, which are included in Other assets within Cash Flows from Operating Activities on the Consolidated Statements of Cash Flows.

Significant investments in affiliates accounted for under the equity method are discussed below.

International Energy

Duke Energy owns a 25 percent indirect interest in NMC, which owns and operates a methanol and MTBE business in Jubail, Saudi Arabia.

Commercial Power

Investments accounted for under the equity method primarily consist of Duke Energy’s approximate 50 percent ownership interest in the five Catamount Sweetwater, LLC wind farm projects (Phase I-V), INDU Solar Holdings, LLC and DS Cornerstone, LLC. All of these entities own solar or wind power projects in the United States. Duke Energy also owns a 50 percent interest in Duke American Transmission Co., LLC, which builds, owns and operates electric transmission facilities in North America.

Other

On December 31, 2013, Duke Energy completed the sale of its 50 percent ownership interest in DukeNet, which owned and operated telecommunications businesses, to Time Warner Cable, Inc. After retiring existing DukeNet debt and payment of transaction expenses, Duke Energy received $215 million in cash proceeds and recorded a $105 million pretax gain in the fourth quarter of 2013.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

13. RELATED PARTY TRANSACTIONS

The Subsidiary Registrants engage in related party transactions, which are generally performed at cost and in accordance with the applicable state and federal commission regulations. Refer to the 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 in the Consolidated Statements of Operations and Comprehensive Income are presented in the following table.

	Years Ended December 31,
(in millions)	2014		2013		2012
Duke Energy Carolinas
Corporate governance and shared service expenses(a)	$	851	$	927	$	1,112
Indemnification coverages(b)	21		22		21
JDA revenue(c)	133		121		18
JDA expense(c)	198		116		91
Progress Energy
Corporate governance and shared services provided by Duke Energy(a)	$	732	$	290	$	63
Corporate governance and shared services provided to Duke Energy(d)	—		96		47
Indemnification coverages(b)	33		34		17
JDA revenue(c)	198		116		91
JDA expense(c)	133		121		18
Duke Energy Progress
Corporate governance and shared service expenses(a)	$	386	$	266	$	254
Indemnification coverages(b)	17		20		8
JDA revenue(c)	198		116		91
JDA expense(c)	133		121		18
Duke Energy Florida
Corporate governance and shared service expenses(a)	$	346	$	182	$	186
Indemnification coverages(b)	16		14		8
Duke Energy Ohio
Corporate governance and shared service expenses(a)	$	316	$	347	$	358
Indemnification coverages(b)	13		15		15
Duke Energy Indiana
Corporate governance and shared service expenses(a)	$	384	$	422	$	419
Indemnification coverages(b)	11		14		8

(a) The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These amounts are recorded in Operation, maintenance and other on the 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 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 under the JDA are recorded in Operating Revenues on the Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Consolidated Statements of Operations and Comprehensive Income.

(d) In 2013 and 2012, Progress Energy Service Company (PESC), a consolidated subsidiary of Progress Energy, charged a proportionate share of corporate governance and other costs to consolidated affiliates of Duke Energy. Corporate governance and other shared costs were primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges were recorded as an offset to Operation, maintenance and other in the Consolidated Statements of Operations and Comprehensive Income. Effective January 1, 2014, PESC was contributed to Duke Energy Corporate Services (DECS), a consolidated subsidiary of Duke Energy, and these costs were no longer charged out of Progress Energy. Progress Energy recorded a non-cash after-tax equity transfer related to the contribution of PESC to DECS in its Consolidated Statements of Changes in Common Stockholder's Equity.

In addition to the amounts presented above, the Subsidiary Registrants record the impact on net income of other affiliate transactions, including rental of office space, participation in a money pool arrangement, other operational transactions and their proportionate share of certain charged expenses. See Note 6 for more information regarding money pool. The net impact of these transactions was not material for the years ended December 31, 2014, 2013 and 2012 for the Subsidiary Registrants.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

As discussed in Note 17, 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.

In January 2012, Duke Energy Ohio recorded a non-cash equity transfer of $28 million related to the sale of Vermillion to Duke Energy Indiana. Duke Energy Indiana recorded a non-cash after-tax equity transfer of $26 million for the purchase of Vermillion from Duke Energy Ohio. See Note 2 for further discussion.

Duke Energy Commercial Asset Management (DECAM) is a nonregulated, indirect subsidiary of Duke Energy Ohio that owns generating plants included in the Disposal Group discussed in Note 2. DECAM's business activities include the execution of commodity transactions, third-party vendor and supply contracts, and service contracts for certain of Duke Energy’s nonregulated entities. The commodity contracts DECAM enters are accounted for as undesignated contracts or NPNS. Consequently, mark-to-market impacts of intercompany contracts with, and sales of power to, nonregulated entities are included in (Loss) Income from discontinued operations in Duke Energy Ohio’s Consolidated Statements of Operations and Comprehensive Income. These amounts totaled net expense of $24 million and $6 million and net revenue of $24 million, for the years ended December 31, 2014, 2013 and 2012, respectively.

Because it is not a rated entity, DECAM receives credit support from Duke Energy or its nonregulated subsidiaries, not from the regulated utility operations of Duke Energy Ohio. DECAM meets its funding needs through an intercompany loan agreement from a subsidiary of Duke Energy. DECAM also has the ability to loan money to the subsidiary of Duke Energy. DECAM had an outstanding intercompany loan payable of $459 million and $43 million for the years ended December 31, 2014 and 2013, respectively, These amounts are recorded in Notes payable to affiliated companies on Duke Energy Ohio’s Consolidated Balance Sheets.

As discussed in Note 6, in April 2014, Duke Energy issued $1 billion of senior unsecured notes. Proceeds from the issuances of approximately $400 million were loaned to DECAM, and such funds were ultimately used to redeem $402 million of tax-exempt bonds at Duke Energy Ohio. This transaction substantially completed the restructuring of Duke Energy Ohio’s capital structure to reflect appropriate debt and equity ratios for its regulated operations. The restructuring was completed in the second quarter of 2014, and resulted in the transfer of all of Duke Energy Ohio’s nonregulated generation assets, excluding Beckjord, out of its regulated public utility subsidiary and into DECAM.

14. DERIVATIVES AND HEDGING

The Duke Energy Registrants use commodity and interest rate contracts to manage commodity price and interest rate risks. The primary use of energy commodity derivatives is to hedge the generation portfolio against changes in the prices of electricity and natural gas. Interest rate swaps are used to manage interest rate risk associated with borrowings.

All derivative instruments not identified as NPNS are recorded at fair value as assets or liabilities on the Consolidated Balance Sheets. Cash collateral related to derivative instruments executed under master netting agreement is offset against the collateralized derivatives on the balance sheet.

Changes in the fair value of derivative agreements that either do not qualify for or have not been designated as hedges are reflected in current earnings or as regulatory assets or liabilities.

COMMODITY PRICE RISK

The Duke Energy Registrants are exposed to the impact of changes in the future prices of electricity, coal and natural gas. Exposure to commodity price risk is influenced by a number of factors including the term of contracts, the liquidity of markets, and delivery locations.

Fair Value and Cash Flow Hedges

At December 31, 2014, there were no open commodity derivative instruments designated as hedges.

Undesignated Contracts

Undesignated contracts may include contracts not designated as a hedge, contracts that do not qualify for hedge accounting, derivatives that do not or no longer qualify for the NPNS scope exception, and de-designated hedge contracts. These contracts expire as late as 2018.

Duke Energy Carolinas’ undesignated contracts are primarily associated with forward sales and purchases of electricity. Duke Energy Progress’ and Duke Energy Florida’s undesignated contracts are primarily associated with forward purchases of natural gas. Duke Energy Ohio’s undesignated contracts are primarily associated with forward sales and purchases of electricity, coal, and natural gas. Duke Energy Indiana’s undesignated contracts are primarily associated with forward purchases and sales of electricity and financial transmission rights.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Volumes

The tables below show information relating to volumes of outstanding commodity derivatives. Amounts disclosed represent the notional volumes of commodity contracts excluding NPNS. Amounts disclosed represent the absolute value of notional amounts. 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.

	December 31, 2014
	Duke Energy	Duke Energy Carolinas	Progress Energy	Duke Energy Progress	Duke Energy Florida	Duke Energy Ohio	Duke Energy Indiana
Electricity (gigawatt-hours)(a)	25,370	—	—	—	—	19,141	—
Natural gas (millions of decatherms)	676	35	328	116	212	313	—

	December 31, 2013
	Duke Energy	Duke Energy Carolinas	Progress Energy	Duke Energy Progress	Duke Energy Florida	Duke Energy Ohio	Duke Energy Indiana
Electricity (gigawatt-hours)(a)	71,466	1,205	925	925	—	69,362	203
Natural gas (millions of decatherms)	636	—	363	141	222	274	—

(a) Amounts at Duke Energy Ohio include intercompany positions that eliminate at Duke Energy.

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 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. Pretax gains or losses recognized from inception to termination of the hedges are amortized as a component of interest expense over the life of the debt.

Duke Energy has a combination foreign exchange, pay fixed-receive floating interest rate swap to fix the U.S. dollar equivalent payments on a floating-rate Chilean debt issue.

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

	December 31, 2014						December 31, 2013
(in millions)	Duke Energy		Duke Energy Florida		Duke Energy Ohio		Duke Energy		Duke Energy Ohio
Cash flow hedges(a)	$	750	$	—	$	—	$	798	$	—
Undesignated contracts	277		250		27		34		27
Total notional amount	$	1,027	250		$	27	$	832	$	27

(a) Duke Energy includes amounts related to consolidated VIEs of $541 million at December 31, 2014 and $584 million at December 31, 2013.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY

The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the 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.

	December 31,
	2014				2013
(in millions)	Asset		Liability		Asset		Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current liabilities: other	$	—	$	—	$	—	$	1
Interest rate contracts
Investments and other assets: other	10		—		27		—
Current liabilities: other	—		13		—		18
Deferred credits and other liabilities: other	—		29		—		4
Total Derivatives Designated as Hedging Instruments	$	10	$	42	$	27	$	23
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current assets: other	$	18	$	—	$	201	$	158
Current assets: assets held for sale	15		—		—		—
Investments and other assets: other	3		—		215		131
Investments and other assets: assets held for sale	15		—		—		—
Current liabilities: other	1		307		13		153
Current liabilities: assets held for sale	174		253		—		—
Deferred credits and other liabilities: other	2		91		5		166
Deferred credits and other liabilities: assets held for sale	111		208		—		—
Interest rate contracts
Current assets: other	2		—		—		—
Current liabilities: other	—		1		—		1
Deferred credits and other liabilities: other	—		7		—		4
Total Derivatives Not Designated as Hedging Instruments	341		867		434		613
Total Derivatives	$	351	$	909	$	461	$	636

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

	Derivative Assets
	December 31, 2014						December 31, 2013
(in millions)	Current(a)			Non-Current(b)			Current(e)			Non-Current(f)
Gross amounts recognized	$	210		$	136		$	214		$	233
Gross amounts offset	(153		)	(88		)	(179		)	(138		)
Net amount subject to master netting	57			48			35			95
Amounts not subject to master netting	—			5			—			14
Net amounts recognized on the Consolidated Balance Sheet	$	57		$	53		$	35		$	109

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	Derivative Liabilities
	December 31, 2014						December 31, 2013
(in millions)	Current(c)			Non-Current(d)			Current(g)			Non-Current(h)
Gross amounts recognized	$	573		$	319		$	322		$	299
Gross amounts offset	(213		)	(173		)	(192		)	(155		)
Net amounts subject to master netting	360			146			130			144
Amounts not subject to master netting	1			16			4			11
Net amounts recognized on the Consolidated Balance Sheet	$	361		$	162		$	134		$	155

(a)    Included in Other and Assets Held for Sale within Current Assets on the Consolidated Balance Sheet.

(b) Included in Other and Assets held for Sale within Investments and Other Assets on the Consolidated Balance Sheet.

(c) Included in Other and Liabilities Associated with Assets Held for Sale within Current Liabilities on the Consolidated Balance Sheet.

(d) Included in Other and Liabilities Associated with Assets Held for Sale within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

(e) Included in Other within Current Assets on the Consolidated Balance Sheet.

(f) Included in Other within Investments and Other Assets on the Consolidated Balance Sheet.

(g) Included in Other within Current Liabilities on the Consolidated Balance Sheet.

(h) Included in Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

The following table shows the gains and losses recognized on cash flow hedges and the line items on the Consolidated Statements of Operations where such gains and losses are included when reclassified from AOCI. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013			2012
Pretax Gains (Losses) Recorded in AOCI
Interest rate contracts	$	(39	)	$	79		$	(23	)
Commodity contracts	—			1			1
Total Pretax Gains (Losses) Recorded in AOCI	$	(39	)	$	80		$	(22	)
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense	(7		)	(2		)	2

There was no hedge ineffectiveness during the years ended December 31, 2014, 2013 and 2012, and no gains or losses were excluded from the assessment of hedge effectiveness during the same periods.

A $10 million pretax gain is expected to be recognized in earnings during the next 12 months as interest expense.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations or the Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013			2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Regulated electric	$	—		$	11		$	(23	)
Other income and expenses	—			—			(2		)
Fuel used in electric generation and purchased power-regulated	(44		)	(200		)	(194		)
Income (Loss) From Discontinued Operations	(729		)	(57		)	40
Interest rate contracts
Interest expense	(6		)	(18		)	(8		)
Total Pretax (Losses) Gains Recognized in Earnings	$	(779	)	$	(264	)	$	(187	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	(268	)	$	10		$	(2	)
Regulatory liabilities	14			15			36
Interest rate contracts
Regulatory assets	—			55			10
Regulatory liabilities	2			—			—
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	(252	)	$	80		$	44

DUKE ENERGY CAROLINAS

The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the 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.

	December 31,
	2014				2013
(in millions)	Asset		Liability		Asset		Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current liabilities: other	$	—	$	14	$	—	$	1
Deferred credits and other liabilities: other	—		5		—		1
Total Derivatives Not Designated as Hedging Instruments	—		19		—		2
Total Derivatives	$	—	$	19	$	—	$	2

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

	Derivative Assets
	December 31, 2014				December 31, 2013
(in millions)	Current(a)		Non-Current(b)		Current(a)		Non-Current(b)
Gross amounts recognized	$	—	$	—	$	—	$	—
Gross amounts offset	—		—		—		—
Net amount subject to master netting	—		—		—		—
Amounts not subject to master netting	—		—		—		—
Net amounts recognized on the Consolidated Balance Sheet	$	—	$	—	$	—	$	—

174

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	Derivative Liabilities
	December 31, 2014				December 31, 2013
(in millions)	Current(c)		Non-Current(d)		Current(c)		Non-Current(d)
Gross amounts recognized	$	14	$	5	$	—	$	—
Gross amounts offset	—		—		—		—
Net amount subject to master netting	14		5		—		—
Amounts not subject to master netting	—		—		1		1
Net amounts recognized on the Consolidated Balance Sheet	$	14	$	5	$	1	$	1

(a) Included in Other within Current Assets on the Consolidated Balance Sheet.

(b) Included in Other within Investments and Other Assets on the Consolidated Balance Sheet.

(c) Included in Other within Current Liabilities on the Consolidated Balance Sheet.

(d) Included in Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income where such gains and losses are included when reclassified from AOCI. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013			2012
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense	$	(3	)	$	(3	)	$	(3	)

A $3 million pretax gain is expected to be recognized in earnings during the next 12 months as interest expense.

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts not included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013			2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Regulated electric	$	—		$	(12	)	$	(12	)
Total Pretax (Losses) Gains Recognized in Earnings	—			(12		)	(12		)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	(19	)	$	—		$	—

175

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

PROGRESS ENERGY

The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the 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.

	December 31,
	2014				2013
(in millions)	Asset		Liability		Asset		Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current liabilities: other	$	—	$	1	$	—	$	1
Deferred credits and other liabilities: other	—		—		—		4
Total Derivatives Designated as Hedging Instruments	$	—	$	1	$	—	$	5
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current assets: other	$	—	$	—	$	3	$	2
Investments and other assets: other	—		—		2		1
Current liabilities: other	—		288		11		105
Deferred credits and other liabilities: other	—		80		4		91
Interest rate contracts
Current assets: other	2		—		—		—
Deferred credits and other liabilities: other	—		2		—		—
Total Derivatives Not Designated as Hedging Instruments	2		370		20		199
Total Derivatives	$	2	$	371	$	20	$	204

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

	Derivative Assets
	December 31, 2014					December 31, 2013
(in millions)	Current(a)			Non-Current(b)		Current(a)			Non-Current(b)
Gross amounts recognized	$	2		$	—	$	15		$	5
Gross amounts offset	(2		)	—		(13		)	(4		)
Net amounts recognized on the Consolidated Balance Sheet	$	—		$	—	$	2		$	1

	Derivative Liabilities
	December 31, 2014						December 31, 2013
(in millions)	Current(c)			Non-Current(d)			Current(c)			Non-Current(d)
Gross amounts recognized	$	289		$	82		$	107		$	93
Gross amounts offset	(17		)	(8		)	(17		)	(10		)
Net amounts subject to master netting	272			74			90			83
Amounts not subject to master netting	—			—			—			4
Net amounts recognized on the Consolidated Balance Sheet	$	272		$	74		$	90		$	87

(a)    Included in Other within Current Assets on the Consolidated Balance Sheet.

(b) Included in Other within Investments and Other Assets on the Consolidated Balance Sheet.

(c) Included in Other within Current Liabilities on the Consolidated Balance Sheet.

(d) Included in Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

176

PART II

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheet where such gains and losses are included when reclassified from AOCI. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013		2012
Pretax Gains (Losses) Recorded in AOCI
Commodity contracts	$	—		$	1	$	1
Interest rate contracts	—			—		(11		)
Total Pretax Gains (Losses) Recorded in AOCI	$	—		$	1	$	(10	)
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense	(13		)	—		(14		)
Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets or Liabilities(a)
Interest rate contracts
Regulatory assets	—			$	—	(159		)

(a)    Effective with the merger, Duke Energy Progress and Duke Energy Florida no longer designates interest rate derivatives for

regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to regulatory assets.

There was no hedge ineffectiveness during the years ended December 31, 2014, 2013 and 2012, and no gains or losses have been excluded from the assessment of hedge effectiveness during the same periods.

A $13 million pretax loss is expected to be recognized in earnings during the next 12 months as interest expense.

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013			2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues	$	—		$	11		$	(11	)
Fuel used in electric generation and purchased power	(44		)	(200		)	(454		)
Other income and expenses, net	—			—			7
Interest rate contracts
Interest expense	(4		)	(17		)	(8		)
Total Pretax (Losses) Gains Recognized in Earnings	$	(48	)	$	(206	)	$	(466	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	(233	)	$	10		$	(171	)
Regulatory liabilities	2			—			—
Interest rate contracts
Regulatory assets	2			18			6
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	(229	)	$	28		$	(165	)

177

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY PROGRESS

The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the 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. Substantially all derivatives not designated as hedging instruments receive regulatory accounting treatment.

	December 31,
	2014				2013
(in millions)	Asset		Liability		Asset		Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current liabilities: other	$	—	$	1	$	—	$	1
Total Derivatives Designated as Hedging Instruments	—		1		—		1
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Investments and other assets: other	$	—	$	—	$	2	$	1
Current liabilities: other	—		108		2		40
Deferred credits and other liabilities: other	—		23		2		29
Total Derivatives Not Designated as Hedging Instruments	—		131		6		70
Total Derivatives	$	—	$	132	$	6	$	71

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

	Derivative Assets
	December 31, 2014				December 31, 2013
(in millions)	Current(a)		Non-Current(b)		Current(a)			Non-Current(b)
Gross amounts recognized	$	—	$	—	$	3		$	3
Gross amounts offset	—		—		(3		)	(3		)
Net amounts recognized on the Consolidated Balance Sheet	$	—	$	—	$	—		$	—

	Derivative Liabilities
	December 31, 2014				December 31, 2013
(in millions)	Current(c)		Non-Current(d)		Current(c)			Non-Current(d)
Gross amounts recognized	$	109	$	23	$	41		$	30
Gross amounts offset	—		—		(3		)	(3		)
Net amounts recognized on the Consolidated Balance Sheet	$	109	$	23	$	38		$	27

(a)    Included in Other within Current Assets on the Consolidated Balance Sheet.

(b) Included in Other within Investments and Other Assets on the Consolidated Balance Sheet.

(c) Included in Other within Current Liabilities on the Consolidated Balance Sheet.

(d) Included in Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheets in which such gains and losses are included when reclassified from AOCI. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

178

PART II

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	Years Ended December 31,
(in millions)	2014		2013		2012
Pretax Gains (Losses) Recorded in AOCI
Interest rate contracts	$	—	$	—	$	(7	)
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense	—		—		(5		)
Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets or Liabilities(a)
Interest rate contracts
Regulatory assets	—		$	—	(117		)

(a) Effective with the merger, Duke Energy Progress no longer designates interest rate derivatives for regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to Regulatory assets.

There was no hedge ineffectiveness during the years ended December 31, 2014, 2013 and 2012, and no gains or losses have been excluded from the assessment of hedge effectiveness during the same periods.

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013			2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues	$	—		$	11		$	(11	)
Fuel used in electric generation and purchased power	(15		)	(71		)	(115		)
Interest rate contracts
Interest expense	—			(13		)	(6		)
Total Pretax (Losses) Gains Recognized in Earnings	$	(15	)	$	(73	)	$	(132	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	(82	)	$	(6	)	$	(55	)
Interest rate contracts
Regulatory assets	—			13			6
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	(82	)	$	7		$	(49	)

179

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY FLORIDA

The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the 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.

	December 31,
	2014				2013
(in millions)	Asset		Liability		Asset		Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current assets: other	$	—	$	—	$	3	$	2
Current liabilities: other	—		180		9		64
Deferred credits and other liabilities: other	—		57		2		63
Interest rate contracts
Current assets: other	2		—		—		—
Deferred credits and other liabilities: other	—		2		—		—
Total Derivatives Not Designated as Hedging Instruments	2		239		14		129
Total Derivatives	$	2	$	239	$	14	$	129

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

	Derivative Assets
	December 31, 2014					December 31, 2013
(in millions)	Current(a)			Non-Current(b)		Current(a)			Non-Current(b)
Gross amounts recognized	$	2		$	—	$	12		$	2
Gross amounts offset	(2		)	—		(10		)	(2		)
Net amounts recognized on the Consolidated Balance Sheet	$	—		$	—	$	2		$	—

	Derivative Liabilities
	December 31, 2014						December 31, 2013
(in millions)	Current(c)			Non-Current(d)			Current(c)			Non-Current(d)
Gross amounts recognized	$	180		$	59		$	66		$	63
Gross amounts offset	(17		)	(8		)	(15		)	(7		)
Net amounts recognized on the Consolidated Balance Sheet	$	163		$	51		$	51		$	56

(a) Included in Other within Current Assets on the Consolidated Balance Sheet.

(b) Included in Other within Investments and Other Assets on the Consolidated Balance Sheet.

(c) Included in Other within Current Liabilities on the Consolidated Balance Sheet.

(d) Included in Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

180

PART II

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheets in which such gains and losses are included when reclassified from AOCI. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013		2012
Pretax Gains (Losses) Recorded in AOCI
Commodity contracts	$	—		$	1	$	1
Interest rate contracts	—			—		(2		)
Total Pretax Gains (Losses) Recorded in AOCI	$	—		$	1	$	(1	)
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense	(2		)	—		(2		)
Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets(a)
Interest rate contracts
Regulatory assets	—			$	—	(42		)

(a) Effective with the merger, Duke Energy Florida no longer designates interest rate derivatives for regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to Regulatory assets.

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013			2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Fuel used in electric generation and purchased power	$	(29	)	$	(129	)	$	(339	)
Interest rate contracts
Interest expense	(4		)	(5		)	(2		)
Total Pretax (Losses) Gains Recognized in Earnings	$	(33	)	$	(134	)	$	(341	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	(151	)	$	16		$	(116	)
Interest rate contracts
Regulatory assets	2			5			—
Regulatory liabilities	2			—			—
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	(147	)	$	21		$	(116	)

181

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY OHIO

The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the 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.

	December 31,
	2014				2013
(in millions)	Asset		Liability		Asset		Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current assets: other	$	1	$	—	$	186	$	163
Current assets: assets held for sale	28		4		—		—
Investments and other assets: other	—		—		202		130
Investments and other assets: assets held for sale	26		4		—		—
Current liabilities: other	—		—		1		36
Current liabilities: assets held for sale	175		252		—		—
Deferred credits and other liabilities: other	—		—		2		56
Deferred credits and other liabilities: assets held for sale	111		207		—		—
Interest rate contracts
Current liabilities: other	—		1		—		1
Deferred credits and other liabilities: other	—		5		—		4
Total Derivatives Not Designated as Hedging Instruments	341		473		391		390
Total Derivatives	$	341	$	473	$	391	$	390

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

	Derivative Assets
	December 31, 2014						December 31, 2013
(in millions)	Current(a)			Non-Current(b)			Current(e)			Non-Current(f)
Gross amounts recognized	$	204		$	137		$	186		$	205
Gross amounts offset	(179		)	(114		)	(165		)	(132		)
Net amounts recognized on the Consolidated Balance Sheet	$	25		$	23		$	21		$	73

	Derivative Liabilities
	December 31, 2014						December 31, 2013
(in millions)	Current(c)			Non-Current(d)			Current(g)			Non-Current(h)
Gross amounts recognized	$	257		$	216		$	199		$	186
Gross amounts offset	(222		)	(193		)	(173		)	(143		)
Net amounts subject to master netting	35			23			26			43
Amounts not subject to master netting	—			—			1			4
Net amounts recognized on the Consolidated Balance Sheet	$	35		$	23		$	27		$	47

(a)    Included in Other and Assets Held for Sale within Current Assets on the Consolidated Balance Sheet.

(b) Included in Other and Assets held for Sale within Investments and Other Assets on the Consolidated Balance Sheet.

(c) Included in Other and Liabilities Associated with Assets Held for Sale within Current Liabilities on the Consolidated Balance Sheet.

(d) Included in Other and Liabilities Associated with Assets Held for Sale within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

(e) Included in Other within Current Assets on the Consolidated Balance Sheet.

(f) Included in Other within Investments and Other Assets on the Consolidated Balance Sheet.

(g) Included in Other within Current Liabilities on the Consolidated Balance Sheet.

(h) Included in Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

182

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013			2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Income (Loss) from discontinued operations	(758		)	(56		)	78
Interest rate contracts
Interest expense	(1		)	(1		)	(1		)
Total Pretax (Losses) Gains Recognized in Earnings	$	(759	)	$	(57	)	$	77
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	1		$	—		$	2
Regulatory liabilities	5			—			(1		)
Interest rate contracts
Regulatory assets	(2		)	4			—
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	4		$	4		$	1

DUKE ENERGY INDIANA

The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the 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.

	December 31,
	2014				2013
(in millions)	Asset		Liability		Asset		Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current Assets: Other	$	14	$	—	$	12	$	—
Total Derivatives Not Designated as Hedging Instruments	14		—		12		—
Total Derivatives	$	14	$	—	$	12	$	—

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

	Derivative Assets
	December 31, 2014				December 31, 2013
(in millions)	Current(a)		Non-Current(b)		Current(a)			Non-Current(b)
Gross amounts recognized	$	14	$	—	$	12		$	—
Gross amounts offset	—		—		(1		)	—
Net amounts recognized on the Consolidated Balance Sheet	$	14	$	—	$	11		$	—

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	Derivative Liabilities
	December 31, 2014				December 31, 2013
(in millions)	Current(c)		Non-Current(d)		Current(c)		Non-Current(d)
Gross amounts recognized	$	—	$	—	$	—	$	—
Gross amounts offset	—		—		—		—
Net amount subject to master netting	—		—		—		—
Amounts not subject to master netting	—		—		—		—
Net amounts recognized on the Consolidated Balance Sheet	$	—	$	—	$	—	$	—

(a) Included in Other within Current Assets on the Consolidated Balance Sheet.

(b) Included in Other within Investments and Other Assets on the Consolidated Balance Sheet.

(c) Included in Other within Current Liabilities on the Consolidated Balance Sheet.

(d) Included in Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income where such gains and losses are included when reclassified from AOCI. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014		2013		2012
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense	$	—	$	3	$	3

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.

	Years Ended December 31,
(in millions)	2014			2013		2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Regulated electric	$	—		$	1	$	—
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	(16	)	$	—	$	2
Regulatory liabilities	9			16		35
Interest rate contracts
Regulatory assets	—			34		4
Regulatory liabilities	—			—		—
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	(7	)	$	50	$	41

CREDIT RISK

Certain derivative contracts contain contingent credit features. These features may include (i) material adverse change clauses or payment acceleration clauses that could result in immediate payments or (ii) the posting of letters of credit or termination of the derivative contract before maturity if specific events occur, such as a credit rating downgrade below investment grade.

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following tables show information with respect to derivative contracts that are in a net liability position and contain objective credit-risk related payment provisions.

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio
Aggregate fair value amounts of derivative instruments in a net liability position	$	845	$	19	$	370	$	131	$	239	$	456
Fair value of collateral already posted	209		—		23		—		23		186
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	407		19		347		131		216		41

	December 31, 2013
(in millions)	Duke Energy		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio
Aggregate fair value amounts of derivative instruments in a net liability position	$	525	$	168	$	60	$	108	$	355
Fair value of collateral already posted	135		10		—		10		125
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	205		158		60		98		47

The Duke Energy Registrants have elected to offset cash collateral and fair values of derivatives. For amounts to be netted, the derivative must be executed with the same counterparty under the same master netting agreement. Amounts disclosed below represent the receivables related to the right to reclaim cash collateral and payables related to the obligation to return cash collateral under master netting arrangements.

	December 31,
	2014				2013
(in millions)	Receivables		Payables		Receivables		Payables
Duke Energy
Amounts offset against net derivative positions	$	145	$	—	$	30	$	—
Amounts not offset against net derivative positions	64		—		122		—
Progress Energy
Amounts offset against net derivative positions	23		—		10		—
Duke Energy Florida
Amounts offset against net derivative positions	23		—		10		—
Duke Energy Ohio
Amounts offset against net derivative positions	122		—		19		—
Amounts not offset against net derivative positions	64		—		115		—
Duke Energy Indiana
Amounts offset against net derivative positions	—		—		—		1
Amounts not offset against net derivative positions	—		—		1		—

15. INVESTMENTS IN DEBT AND EQUITY SECURITIES

The Duke Energy Registrants classify their investments in debt and equity securities as either trading or available-for-sale.

TRADING SECURITIES

Investments in debt and equity securities held in grantor trusts associated with certain deferred compensation plans and certain other investments are classified as trading securities. The fair value of these investments was $7 million as of December 31, 2014 and $18 million as of December 31, 2013.

AVAILABLE-FOR-SALE SECURITIES

All other investments in debt and equity securities are classified as available-for-sale securities.

Duke Energy’s available-for-sale securities are primarily comprised of investments held in (i) the NDTF at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, (ii) grantor trusts at Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana related to OPEB plans, (iii) Duke Energy’s captive insurance investment portfolio, and (iv) Duke Energy’s foreign operations investment portfolio.

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy holds corporate debt securities that were purchased using excess cash from its foreign operations. These investments are either classified as Cash and cash equivalents or Short-term investments on the Consolidated Balance Sheets based on maturity date and are available for current operations of Duke Energy’s foreign business. The fair value of these investments classified as Short-term investments was $44 million as of December 31, 2013.

Duke Energy classifies all other investments in debt and equity securities as long-term, unless otherwise noted.

Investment Trusts

The investments within the NDTF at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida and the Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana grantor trusts (Investment Trusts) are managed by independent investment managers with discretion to buy, sell, and invest pursuant to the objectives set forth by the trust agreements. The Duke Energy Registrants have limited oversight of the day-to-day management of these investments. As a result, the ability to hold investments in unrealized loss positions is outside the control of the Duke Energy Registrants. Accordingly, all unrealized losses associated with debt and equity securities within the Investment Trusts are considered other-than-temporary impairments and are recognized immediately. Pursuant to regulatory accounting, realized and unrealized gains and losses associated with investments within the Investment Trusts are deferred as a regulatory asset or liability. As a result, there is no immediate impact on earnings of the Duke Energy Registrants.

Other Available-for-Sale Securities

Unrealized gains and losses on all other available-for-sale securities are included in other comprehensive income until realized, unless it is determined the carrying value of an investment is other-than-temporarily impaired. If an other-than-temporary impairment exists, the unrealized loss is included in earnings based on the criteria discussed below.

The Duke Energy Registrants analyze all investment holdings each reporting period to determine whether a decline in fair value should be considered other-than-temporary. Criteria used to evaluate whether an impairment associated with equity securities is other-than-temporary includes, but is not limited to, (i) the length of time over which the market value has been lower than the cost basis of the investment, (ii) the percentage decline compared to the cost of the investment, and (iii) management’s intent and ability to retain its investment for a period of time sufficient to allow for any anticipated recovery in market value. If a decline in fair value is determined to be other-than-temporary, the investment is written down to its fair value through a charge to earnings.

If the entity does not have an intent to sell a debt security and it is not more likely than not management will be required to sell the debt security before the recovery of its cost basis, the impairment write-down to fair value would be recorded as a component of other comprehensive income, except for when it is determined a credit loss exists. In determining whether a credit loss exists, management considers, among other things, (i) the length of time and the extent to which the fair value has been less than the amortized cost basis, (ii) changes in the financial condition of the issuer of the security, or in the case of an asset backed security, the financial condition of the underlying loan obligors, (iii) consideration of underlying collateral and guarantees of amounts by government entities, (iv) ability of the issuer of the security to make scheduled interest or principal payments, and (v) any changes to the rating of the security by rating agencies. If a credit loss exists, the amount of impairment write-down to fair value is split between credit loss and other factors. The amount related to credit loss is recognized in earnings. The amount related to other factors is recognized in other comprehensive income. There were no credit losses as of December 31, 2014 and 2013. There were no other-than-temporary impairments for debt or equity securities as of December 31, 2014 and 2013.

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY

The following table presents the estimated fair value of investments in available-for-sale securities.

	December 31, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value
NDTF
Cash and cash equivalents	$	—	$	—	$	136	$	—	$	—	$	110
Equity securities	1,926		29		3,650		1,813		10		3,579
Corporate debt securities	14		2		454		8		6		400
Municipal bonds	5		—		184		2		6		160
U.S. government bonds	19		2		978		7		12		730
Other debt securities	1		2		147		22		2		154
Total NDTF	1,965		35		5,549		1,852		36		5,133
Other Investments
Cash and cash equivalents	—		—		15		—		—		21
Equity securities	34		—		96		29		—		91
Corporate debt securities	1		1		58		1		1		99
Municipal bonds	3		1		76		2		2		79
U.S. government bonds	—		—		27		—		—		17
Other debt securities	1		1		80		—		8		111
Total Other Investments(a)	39		3		352		32		11		418
Total Investments	$	2,004	$	38	$	5,901	$	1,884	$	47	$	5,551

(a) These amounts are recorded in Other within Investments and Other Assets on the Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	December 31, 2014
Due in one year or less	178
Due after one through five years	571
Due after five through 10 years	464
Due after 10 years	791
Total	2,004

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.

	Years Ended December 31,
(in millions)	2014		2013		2012
Realized gains	$	271	$	209	$	117
Realized losses	105		65		19

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY CAROLINAS

The following table presents the estimated fair value of investments in available-for-sale securities.

	December 31, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value
NDTF
Cash and cash equivalents	$	—	$	—	$	51	$	—	$	—	$	42
Equity securities	1,102		17		2,162		974		6		1,964
Corporate debt securities	8		2		316		5		5		274
Municipal bonds	1		—		62		—		2		54
U.S. government bonds	7		1		308		3		7		354
Other debt securities	1		2		133		22		2		146
Total NDTF	1,119		22		3,032		1,004		22		2,834
Other Investments
Other debt securities	—		1		3		—		1		3
Total Other Investments(a)	—		1		3		—		1		3
Total Investments	$	1,119	$	23	$	3,035	$	1,004	$	23	$	2,837

(a) These amounts are recorded in Other within Investments and Other Assets on the Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	December 31, 2014
Due in one year or less	$	1
Due after one through five years	155
Due after five through 10 years	257
Due after 10 years	409
Total	$	822

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.

	Years Ended December 31,
(in millions)	2014		2013		2012
Realized gains	$	109	$	115	$	89
Realized losses	93		12		6

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

PROGRESS ENERGY

The following table presents the estimated fair value of investments in available-for-sale securities.

	December 31, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value
NDTF
Cash and cash equivalents	$	—	$	—	$	85	$	—	$	—	$	68
Equity securities	824		12		1,488		839		4		1,615
Corporate debt securities	6		—		138		3		1		126
Municipal bonds	4		—		122		2		4		106
U.S. government bonds	12		1		670		4		5		376
Other debt securities	—		—		14		—		—		8
Total NDTF	846		13		2,517		848		14		2,299
Other Investments
Cash and cash equivalents	—		—		15		—		—		20
Municipal bonds	3		—		43		1		—		39
Total Other Investments(a)	3		—		58		1		—		59
Total Investments	$	849	$	13	$	2,575	$	849	$	14	$	2,358

(a) These amounts are recorded in Other within Investments and Other Assets on the Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	December 31, 2014
Due in one year or less	$	161
Due after one through five years	350
Due after five through 10 years	157
Due after 10 years	319
Total	$	987

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.

	Years Ended December 31,
(in millions)	2014		2013		2012
Realized gains	$	157	$	90	$	34
Realized losses	11		46		18

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY PROGRESS

The following table presents the estimated fair value of investments in available-for-sale securities.

	December 31, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value
NDTF
Cash and cash equivalents	$	—	$	—	$	50	$	—	$	—	$	48
Equity securities	612		10		1,171		535		3		1,069
Corporate debt securities	5		—		97		3		1		80
Municipal bonds	4		—		120		2		4		104
U.S. government bonds	9		1		265		4		3		232
Other debt securities	—		—		8		—		—		5
Total NDTF	630		11		1,711		544		11		1,538
Other Investments
Cash and cash equivalents	—		—		—		—		—		2
Total Other Investments(a)	—		—		—		—		—		2
Total Investments	$	630	$	11	$	1,711	$	544	$	11	$	1,540

(a) These amounts are recorded in Other within Investments and Other Assets on the Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	December 31, 2014
Due in one year or less	$	14
Due after one through five years	140
Due after five through 10 years	109
Due after 10 years	227
Total	$	490

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.

	Years Ended December 31,
(in millions)	2014		2013		2012
Realized gains	$	19	$	58	$	21
Realized losses	5		26		8

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY FLORIDA

The following table presents the estimated fair value of investments in available-for-sale securities.

	December 31, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value
NDTF
Cash and cash equivalents	$	—	$	—	$	35	$	—	$	—	$	20
Equity securities	212		2		317		304		1		546
Corporate debt securities	1		—		41		—		—		46
Municipal bonds	—		—		2		—		—		2
U.S. government bonds	3		—		405		—		2		144
Other debt securities	—		—		6		—		—		3
Total NDTF	216		2		806		304		3		761
Other Investments
Cash and cash equivalents	—		—		1		—		—		3
Municipal bonds	3		—		43		1		—		39
Total Other Investments(a)	3		—		44		1		—		42
Total Investments	$	219	$	2	$	850	$	305	$	3	$	803

(a) These amounts are recorded in Other within Investments and Other Assets on the Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities.

(in millions)	December 31, 2014
Due in one year or less	$	147
Due after one through five years	210
Due after five through 10 years	48
Due after 10 years	92
Total	$	497

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were as follows.

	Years Ended December 31,
(in millions)	2014		2013		2012
Realized gains	$	138	$	32	$	13
Realized losses	5		20		9

DUKE ENERGY INDIANA

The following table presents the estimated fair value of investments in available-for-sale securities.

	December 31, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value
Other Investments
Cash and cash equivalents	$	—	$	—	$	—	$	—	$	—	$	1
Equity securities	28		—		71		24		—		65
Municipal bonds	—		1		30		—		1		28
Total Other Investments(a)	28		1		101		24		1		94
Total Investments	$	28	$	1	$	101	$	24	$	1	$	94

(a) These amounts are recorded in Other within Investments and Other Assets on the Consolidated Balance Sheets.

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The table below summarizes the maturity date for debt securities.

(in millions)	December 31, 2014
Due in one year or less	$	1
Due after one through five years	17
Due after five through 10 years	8
Due after 10 years	4
Total	$	30

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were insignificant for the years ended December 31, 2014, 2013 and 2012.

16. FAIR VALUE MEASUREMENTS

Fair value is the exchange price to sell an asset or transfer a liability in an orderly transaction between market participants at the measurement date. The fair value definition focuses on an exit price versus the acquisition cost. Fair value measurements use market data or assumptions market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs may be readily observable, corroborated by market data, or generally unobservable. Valuation techniques maximize the use of observable inputs and minimize use of unobservable inputs. A midmarket pricing convention (the midpoint price between bid and ask prices) is permitted for use as a practical expedient.

Fair value measurements are classified in three levels based on the fair value hierarchy:

Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities that the reporting entity can access at the measurement date. An active market is one in which transactions for an asset or liability occur with sufficient frequency and volume to provide ongoing pricing information.

Level 2 – A fair value measurement utilizing inputs other than quoted prices included in Level 1 that are observable, either directly or indirectly, for an asset or liability. Inputs include (i) quoted prices for similar assets or liabilities in active markets, (ii) quoted prices for identical or similar assets or liabilities in markets that are not active, (iii) and inputs other than quoted market prices that are observable for the asset or liability, such as interest rate curves and yield curves observable at commonly quoted intervals, volatilities and credit spreads. A Level 2 measurement cannot have more than an insignificant portion of its valuation based on unobservable inputs. Instruments in this category include non-exchange-traded derivatives, such as over-the-counter forwards, swaps and options; certain marketable debt securities; and financial instruments traded in less than active markets.

Level 3 – Any fair value measurement which includes unobservable inputs for more than an insignificant portion of the valuation. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. Level 3 measurements may include longer-term instruments that extend into periods in which observable inputs are not available.

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

Transfers between levels represent assets or liabilities that were previously (i) categorized at a higher level for which the inputs to the estimate became less observable or (ii) classified at a lower level for which the inputs became more observable during the period. The Duke Energy Registrant’s policy is to recognize transfers between levels of the fair value hierarchy at the end of the period. There were no transfers between Levels 1 and 2 during the years ended December 31, 2014, 2013 and 2012. Transfers out of Level 3 during the year ended December 31, 2014 are the result of forward commodity prices becoming observable due to the passage of time.

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 NASDAQ and New York Stock Exchange (NYSE). 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 equity securities that are Level 2 or 3 are typically ownership interests in commingled investment funds.

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

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Commodity derivatives with clearinghouses are classified as Level 1. Other commodity derivatives are primarily fair valued using internally developed discounted cash flow models which incorporate forward price, adjustments for liquidity (bid-ask spread) and credit or non-performance risk (after reflecting credit enhancements such as collateral), and are discounted to present value. Pricing inputs are derived from published exchange transaction prices and other observable data sources. In the absence of an active market, the last available price may be used. If forward price curves are not observable for the full term of the contract and the unobservable period had more than an insignificant impact on the valuation, the commodity derivative is classified as Level 3. In isolation, increases (decreases) in natural gas forward prices result in favorable (unfavorable) fair value adjustments for 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 fair value of 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 which 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.

Goodwill and Long-Lived Assets and Assets Held for Sale

See Note 11 for a discussion of the valuation of goodwill and long-lived assets and Note 2 related to the assets and related liabilities of the Disposal Group classified as held for sale.

DUKE ENERGY

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

	December 31, 2014
(in millions)	Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	3,650		$	3,493		$	6		$	151
Nuclear decommissioning trust fund debt securities	1,899			648			1,251			—
Other trading and available-for-sale equity securities	96			96			—			—
Other trading and available-for-sale debt securities	263			41			217			5
Derivative assets	110			49			24			37
Total assets	6,018			4,327			1,498			193
Derivative liabilities	(668		)	(162		)	(468		)	(38		)
Net assets	$	5,350		$	4,165		$	1,030		$	155

	December 31, 2013
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	3,579		$	3,495	$	57		$	27
Nuclear decommissioning trust fund debt securities	1,553			402		1,100			51
Other trading and available-for-sale equity securities	102			91		11			—
Other trading and available-for-sale debt securities	333			36		277			20
Derivative assets	145			33		70			42
Total assets	5,712			4,057		1,515			140
Derivative liabilities	(321		)	11		(303		)	(29		)
Net assets	$	5,391		$	4,068	$	1,212		$	111

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements. Amounts included in earnings for derivatives are primarily included in Operating Revenues.

	December 31, 2014
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	98		$	13		$	111
Total pretax realized or unrealized gains (losses) included in earnings	—			(7		)	(7		)
Purchases, sales, issuances and settlements:
Purchases	34			50			84
Sales	(58		)	—			(58		)
Settlements	—			(54		)	(54		)
Transfers into Level 3	68			6			74
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities	14			(9		)	5
Balance at end of period	$	156		$	(1	)	$	155
Pretax amounts included in the Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding	$	—		$	(14	)	$	(14	)

	December 31, 2013
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	98		$	(85	)	$	13
Total pretax realized or unrealized gains (losses) included in earnings	—			(42		)	(42		)
Purchases, sales, issuances and settlements:
Purchases	9			21			30
Sales	(6		)	—			(6		)
Issuances	—			11			11
Settlements	(9		)	25			16
Transfers into Level 3	—			86			86
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities	6			(3		)	3
Balance at end of period	$	98		$	13		$	111

	December 31, 2012
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	124		$	(39	)	$	85
Amounts acquired in Progress Energy Merger	—			(30		)	(30		)
Total pretax realized or unrealized gains (losses) included in earnings	—			8			8
Total pretax gains included in other comprehensive income	13			—			13
Purchases, sales, issuances and settlements:
Purchases	14			22			36
Sales	(2		)	—			(2		)
Issuances	—			(15		)	(15		)
Settlements	(55		)	(32		)	(87		)
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities	4			1			5
Balance at end of period	$	98		$	(85	)	$	13

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY CAROLINAS

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

	December 31, 2014
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	2,162		$	2,005	$	6		$	151
Nuclear decommissioning trust fund debt securities	870			138		732			—
Other trading and available-for-sale debt securities	3			—		—			3
Total assets	3,035			2,143		738			154
Derivative liabilities	(19		)	—		(19		)	—
Net assets	$	3,016		$	2,143	$	719		$	154

	December 31, 2013
(in millions)	Total Fair Value			Level 1		Level 2		Level 3
Nuclear decommissioning trust fund equity securities	$	1,964		$	1,879	$	58	$	27
Nuclear decommissioning trust fund debt securities	870			168		651		51
Other trading and available-for-sale debt securities	3			—		—		3
Total assets	2,837			2,047		709		81
Derivative liabilities	(2		)	—		—		(2		)
Net assets	$	2,835		$	2,047	$	709	$	79

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

	December 31, 2014
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	81		$	(2	)	$	79
Purchases, sales, issuances and settlements:
Purchases	34			—			34
Sales	(43		)	—			(43		)
Settlements	—			2			2
Transfers into Level 3	68			—			68
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities	14			—			14
Balance at end of period	$	154		$	—		$	154

	December 31, 2013
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	72		$	(12	)	$	60
Purchases, sales, issuances and settlements:
Purchases	9			—			9
Issuances	(6		)	—			(6		)
Settlements	—			10			10
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities	6			—			6
Balance at end of period	$	81		$	(2	)	$	79

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2012
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	65		$	—		$	65
Total pretax gains included in other comprehensive income	2			—			2
Purchases, sales, issuances and settlements:
Purchases	14			—			14
Sales	—			(14		)	(14		)
Issuances	(2		)	—			(2		)
Settlements	(11		)	2			(9		)
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities	4			—			4
Balance at end of period	$	72		$	(12	)	$	60

PROGRESS ENERGY

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis end on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

	December 31, 2014
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	1,488		$	1,488	$	—		$	—
Nuclear decommissioning trust fund debt securities	1,029			510		519			—
Other trading and available-for-sale debt securities	58			15		43			—
Derivative assets	4			—		4			—
Total assets	2,579			2,013		566			—
Derivative liabilities	(373		)	—		(373		)	—
Net assets	$	2,206		$	2,013	$	193		$	—

	December 31, 2013
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	1,615		$	1,615	$	—		$	—
Nuclear decommissioning trust fund debt securities	677			233		444			—
Other trading and available-for-sale debt securities	58			19		39			—
Derivative assets	3			—		3			—
Total assets	2,353			1,867		486			—
Derivative liabilities	(187		)	—		(187		)	—
Net assets	$	2,166		$	1,867	$	299		$	—

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

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

	Derivatives (net)
	Years Ended December 31,
(in millions)	2014		2013			2012
Balance at beginning of period	$	—	$	(38	)	$	(24	)
Total pretax realized or unrealized gains included in earnings	—		—			1
Purchases, sales, issuances and settlements:
Issuances	—		10			(16		)
Settlements	—		—			4
Transfers into Level 3	—		34			—
Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities	—		(6		)	(3		)
Balance at end of period	$	—	$	—		$	(38	)

DUKE ENERGY PROGRESS

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

	December 31, 2014
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	1,171		$	1,171	$	—		$	—
Nuclear decommissioning trust fund debt securities and other	540			151		389			—
Total assets	1,711			1,322		389			—
Derivative liabilities	(132		)	—		(132		)	—
Net assets	$	1,579		$	1,322	$	257		$	—

	December 31, 2013
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	1,069		$	1,069	$	—		$	—
Nuclear decommissioning trust fund debt securities and other	470			137		333			—
Other trading and available-for-sale debt securities and other	3			3		—			—
Derivative assets	1			—		1			—
Total assets	1,543			1,209		334			—
Derivative liabilities	(66		)	—		(66		)	—
Net assets	$	1,477		$	1,209	$	268		$	—

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)
	Years Ended December 31,
(in millions)	2014		2013			2012
Balance at beginning of period	$	—	$	(38	)	$	(24	)
Total pretax realized or unrealized gains included in earnings	—		—			1
Purchases, sales, issuances and settlements:
Issuances	—		10			(16		)
Settlements	—		—			4
Transfers into Level 3	—		34			—
Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities	—		(6		)	(3		)
Balance at end of period	$	—	$	—		$	(38	)

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY FLORIDA

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

	December 31, 2014
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	317		$	317	$	—		$	—
Nuclear decommissioning trust fund debt securities and other	489			359		130			—
Other trading and available-for-sale debt securities and other	44			—		44			—
Derivative assets	4			—		4			—
Total assets	854			676		178			—
Derivative liabilities	(241		)	—		(241		)	—
Net assets (liabilities)	$	613		$	676	$	(63	)	$	—

	December 31, 2013
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	546		$	546	$	—		$	—
Nuclear decommissioning trust fund debt securities and other	214			96		118			—
Other trading and available-for-sale debt securities and other	40			2		38			—
Derivative assets	1			—		1			—
Total assets	801			644		157			—
Derivative liabilities	(116		)	—		(116		)	—
Net assets	$	685		$	644	$	41		$	—

DUKE ENERGY OHIO

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which are disclosed in Note 14.

	December 31, 2014
(in millions)	Total Fair Value			Level 1			Level 2			Level 3
Derivative assets	$	49		$	20		$	9		$	20
Derivative liabilities	(181		)	(117		)	(26		)	(38		)
Net assets (liabilities)	$	(132	)	$	(97	)	$	(17	)	$	(18	)

	December 31, 2013
(in millions)	Total Fair Value			Level 1			Level 2			Level 3
Derivative assets	$	96		$	50		$	21		$	25
Derivative liabilities	(95		)	(1		)	(65		)	(29		)
Net assets (liabilities)	$	1		$	49		$	(44	)	$	(4	)

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

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

	Derivatives (net)
	Years Ended December 31,
(in millions)	2014			2013			2012
Balance at beginning of period	$	(4	)	$	(6	)	$	(3	)
Total pretax realized or unrealized gains included in earnings	(9		)	(42		)	(3		)
Purchases, sales, issuances and settlements:
Purchases	1			1			—
Settlements	(13		)	—			1
Transfers into Level 3	6			43			—
Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities	1			—			(1		)
Balance at end of period	$	(18	)	$	(4	)	$	(6	)

DUKE ENERGY INDIANA

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

	December 31, 2014
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Available-for-sale equity securities	$	71	$	71	$	—	$	—
Available-for-sale debt securities	30		—		30		—
Derivative assets	14		—		—		14
Net assets (liabilities)	$	115	$	71	$	30	$	14

	December 31, 2013
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Available-for-sale equity securities	$	65	$	65	$	—	$	—
Available-for-sale debt securities	29		—		29		—
Derivative assets	12		—		—		12
Net assets (liabilities)	$	106	$	65	$	29	$	12

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)
	Years Ended December 31,
(in millions)	2014			2013			2012
Balance at beginning of period	$	12		$	10		$	4
Total pretax realized or unrealized gains included in earnings	3			8			36
Purchases, sales, issuances and settlements:
Purchases	49			20			—
Issuances	—			—			22
Settlements	(41		)	(30		)	(52		)
Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities	(9		)	4			—
Balance at end of period	$	14		$	12		$	10

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

	December 31, 2014
Investment Type	Fair Value (in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy
Natural gas contracts	$	(5	)	Discounted cash flow	Forward natural gas curves - price per Million British Thermal Unit (MMBtu)	$	2.12		-	4.35
Financial transmission rights (FTRs)	14			RTO auction pricing	FTR price - per Megawatt-Hour (MWh)	(1.92		)	-	9.86
Electricity contracts	(1		)	Discounted cash flow	Forward electricity curves - price per MWh	25.16			-	51.75
Commodity capacity option contracts	2			Discounted cash flow	Forward capacity option curves  - price per MW day	21.00			-	109.00
Reserves	(11		)		Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives	$	(1	)
Duke Energy Ohio
Electricity contracts	$	(6	)	Discounted cash flow	Forward electricity curves - price per MWh	$	25.25		-	51.75
Natural gas contracts	(5		)	Discounted cash flow	Forward natural gas curves - price per MMBtu	2.12			-	4.35
Reserves	(7		)		Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives	$	(18	)
Duke Energy Indiana
FTRs	$	14		RTO auction pricing	FTR price - per MWh	$	(1.92	)	-	9.86

	December 31, 2013
Investment Type	Fair Value (in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy
Natural gas contracts	$	(2	)	Discounted cash flow	Forward natural gas curves - price per MMBtu	$	3.07		-	5.37
FERC mitigation power sale agreements	(2		)	Discounted cash flow	Forward electricity curves - price per MWh	25.79			-	52.38
FTRs	12			RTO auction pricing	FTR price - per MWh	(0.30		)	-	13.80
Electricity contracts	23			Discounted cash flow	Forward electricity curves - price per MWh	20.77			-	58.90
Commodity capacity option contracts	4			Discounted cash flow	Forward capacity option curves  - price per MW day	30.40			-	165.10
Reserves	(22		)		Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives	$	13
Duke Energy Carolinas
FERC mitigation power sale agreements	$	(2	)	Discounted cash flow	Forward electricity curves - price per MWh	$	25.79		-	52.38
Duke Energy Ohio
Electricity contracts	$	18		Discounted cash flow	Forward electricity curves - price per MWh	$	20.77		-	58.90
Natural gas contracts	(2		)	Discounted cash flow	Forward natural gas curves - price per MMBtu	3.07			-	5.37
Reserves	(20		)		Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives	$	(4	)
Duke Energy Indiana
FTRs	$	12		RTO auction pricing	FTR price - per MWh	$	(0.30	)	-	13.80

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

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.

	December 31, 2014				December 31, 2013
(in millions)	Book Value		Fair Value		Book Value		Fair Value
Duke Energy	$	40,020	$	44,566	$	40,256	$	42,592
Duke Energy Carolinas	8,391		9,626		8,436		9,123
Progress Energy	14,754		16,951		14,115		15,234
Duke Energy Progress	6,201		6,696		5,235		5,323
Duke Energy Florida	4,860		5,767		4,886		5,408
Duke Energy Ohio	1,766		1,970		2,188		2,237
Duke Energy Indiana	3,791		4,456		3,796		4,171

At both December 31, 2014 and December 31, 2013, fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper, and non-recourse notes payable of variable interest entities 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.

17. VARIABLE INTEREST ENTITIES

A VIE is an entity that is evaluated for consolidation using more than a simple analysis of voting control. The analysis to determine whether an entity is a VIE considers contracts with an entity, credit support for an entity, the adequacy of the equity investment of an entity, and the relationship of voting power to the amount of equity invested in an entity. This analysis is performed either upon the creation of a legal entity or upon the occurrence of an event requiring reevaluation, such as a significant change in an entity’s assets or activities. A qualitative analysis of control determines the party that consolidates a VIE. This assessment is based on (i) what party has the power to direct the most significant activities of the VIE that impact its economic performance, and (ii) what party has rights to receive benefits or is obligated to absorb losses that are significant to the VIE. The analysis of the party that consolidates a VIE is a continual reassessment.

No financial support was provided to any of the consolidated VIEs during the years ended December 31, 2014, 2013 and 2012, or is expected to be provided in the future, that was not previously contractually required.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

CONSOLIDATED VIEs

The following tables summarize the impact of VIEs consolidated by Duke Energy and the Subsidiary Registrants on the Consolidated Balance Sheets.

	December 31, 2014
	Duke Energy
	Duke Energy Carolinas		Duke Energy Progress		Duke Energy Florida
(in millions)	DERF		DEPR(c)		DEFR(c)		CRC		Renewables			Other			Total
ASSETS
Current Assets
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	$	647	$	436	$	305	$	547	$	20		$	18		$	1,973
Other	—		—		—		—		68			6			74
Investments and Other Assets
Other	—		—		—		—		25			25			50
Property, Plant and Equipment
Property, plant and equipment, cost(a)	—		—		—		—		1,855			18			1,873
Accumulated depreciation and amortization	—		—		—		—		(250		)	(5		)	(255		)
Regulatory Assets and Deferred Debits
Other	—		—		—		—		34			2			36
Total assets	$	647	$	436	$	305	$	547	$	1,752		$	64		$	3,751
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	—		—		—		—		3			—			3
Taxes accrued	—		—		—		—		6			—			6
Current maturities of long-term debt	—		—		—		—		68			16			84
Other	—		—		—		—		16			5			21
Long-Term Debt(b)	400		300		225		325		967			17			2,234
Deferred Credits and Other Liabilities
Deferred income taxes	—		—		—		—		283			—			283
Asset retirement obligations	—		—		—		—		29			—			29
Other	—		—		—		—		34			4			38
Total liabilities	$	400	$	300	$	225	$	325	$	1,406		$	42		$	2,698
Net assets of consolidated variable interest entities	$	247	$	136	$	80	$	222	$	346		$	22		$	1,053

(a) Restricted as collateral for non-recourse debt of VIEs.

(b) Non-recourse to the general assets of the applicable registrant.

(c) The amount for Progress Energy is equal to the amount for Duke Energy Progress Receivables Company, LLC (DEPR) and Duke Energy Florida Receivables Company, LLC (DEFR).

202

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
	Duke Energy
	Duke Energy Carolinas		Duke Energy Progress
(in millions)	DERF		DEPR(c)		CRC		Renewables			Other			Total
ASSETS
Current Assets
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	$	673	$	416	$	595	$	18		$	17		$	1,719
Other	—		—		—		89			12			101
Investments and Other Assets
Other	—		—		—		29			51			80
Property, Plant and Equipment
Property, plant and equipment, cost(a)	—		—		—		1,662			18			1,680
Accumulated depreciation and amortization	—		—		—		(170		)	(5		)	(175		)
Regulatory Assets and Deferred Debits
Other	1		1		—		34			—			36
Total assets	$	674	$	417	$	595	$	1,662		$	93		$	3,441
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	—		—		—		2			—			2
Taxes accrued	—		—		—		10			—			10
Current maturities of long-term debt	—		—		—		66			14			80
Other	—		—		—		17			10			27
Long-Term Debt(b)	400		300		325		907			34			1,966
Deferred Credits and Other Liabilities										—
Deferred income taxes	—		—		—		290			—			290
Asset retirement obligations	—		—		—		26			—			26
Other	1		—		—		17			13			31
Total liabilities	$	401	$	300	$	325	$	1,335		$	71		$	2,432
Net assets of consolidated variable interest entities	$	273	$	117	$	270	$	327		$	22		$	1,009

(a) Restricted as collateral for non-recourse debt of VIEs.

(b) Non-recourse to the general assets of the applicable registrant.

(c) The amount Progress Energy is equal to the amount for DEPR.

The obligations of these VIEs are non-recourse to Duke Energy, Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida. These entities have no requirement to provide liquidity to, purchase assets of, or guarantee performance of these VIEs unless noted in the following paragraphs.

DERF / DEPR / DEFR

Duke Energy Receivables Finance Company, LLC (DERF), DEPR, and DEFR are bankruptcy remote, special purpose subsidiaries of Duke Energy Carolinas, Duke Energy Progress, and Duke Energy Florida, respectively. On a daily basis, DERF, DEPR, and DEFR buy certain accounts receivable arising from the sale of electricity and/or related services from their parent companies. DERF, DEPR, and DEFR are wholly owned limited liability companies with separate legal existence from their parents, and their assets are not generally available to creditors of their parent companies. DERF, DEPR, and DEFR borrow amounts under credit facilities to buy the receivables. Borrowing availability is limited to the amount of qualified receivables sold, which is generally expected to be in excess of the credit facilities. The credit facilities are reflected on the Consolidated Balance Sheets as Long-Term Debt. The secured credit facilities were not structured to meet the criteria for sale accounting treatment under the accounting guidance for transfers and servicing of financial assets.

The most significant activity that impacts the economic performance of DERF, DEPR, and DEFR are the decisions made to manage delinquent receivables. Duke Energy Carolinas, Duke Energy Progress, and Duke Energy Florida consolidate DERF, DEPR, and DEFR, respectively, as they make those decisions.

203

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following table outlines amounts and expiration dates of the credit facilities.

	DERF		DEPR		DEFR
Credit facility amount (in millions)	$	400	$	300	$	225
Expiration date	October 2016		December 2016		March 2017

CRC

On a revolving basis, CRC buys certain accounts receivable arising from the sale of electricity and/or related services from Duke Energy Ohio and Duke Energy Indiana. Receivables sold are securitized by CRC through a credit facility managed by two unrelated third parties. The proceeds Duke Energy Ohio and Duke Energy Indiana receive from the sale of receivables to CRC are typically 75 percent cash and 25 percent in the form of a subordinated note from CRC. The subordinated note is a retained interest in the receivables sold. Cash collections from the receivables are the sole source of funds to satisfy the related debt obligation. Depending on experience with collections, additional equity infusions to CRC may be required by Duke Energy to maintain a minimum equity balance of $3 million. There were no infusions to CRC during the years ended December 31, 2014 and 2013. Borrowing availability is limited to the amount of qualified receivables sold, which is generally expected to be in excess of the credit facility. The credit facility expires in November 2016 and is reflected on the Consolidated Balance Sheets as Long-Term Debt.

CRC is considered a VIE because (i) equity capitalization is insufficient to support its operations, (ii) power to direct the most significant activities that impact economic performance of the entity are not performed by the equity holder, Cinergy, and (iii) deficiencies in net worth of CRC are not funded by Cinergy, but by Duke Energy. The most significant activity of CRC relates to the decisions made with respect to the management of delinquent receivables. Duke Energy consolidates CRC as it makes these decisions. Neither Duke Energy Ohio nor Duke Energy Indiana consolidate CRC.

Renewables

Certain of Duke Energy’s renewable energy facilities are VIEs due to long-term fixed price power purchase agreements. These fixed price agreements effectively transfer commodity price risk to the buyer of the power. Certain other 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. For certain VIEs, assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders. The most significant activities that impact the economic performance of these renewable energy facilities were decisions associated with siting, negotiating purchase power agreements, engineering, procurement and construction, and decisions associated with ongoing operations and maintenance-related activities. Duke Energy consolidates the entities as it makes all of these decisions.

NON-CONSOLIDATED VIEs

The tables below show VIEs not consolidated and how these entities impact the Consolidated Balance Sheets.

	December 31, 2014
	Duke Energy
(in millions)	Renewables		Other		Total		Duke Energy Ohio		Duke Energy Indiana
Receivables	$	—	$	—	$	—	$	91	$	113
Investments in equity method unconsolidated affiliates	150		38		188		—		—
Investments and other assets	—		4		4		—		—
Total assets(a)	$	150	$	42	$	192	$	91	$	113
Other current liabilities	—		3		3		—		—
Deferred credits and other liabilities	—		14		14		—		—
Total liabilities	$	—	$	17	$	17	$	—	$	—
Net assets (liabilities)	$	150	$	25	$	175	$	91	$	113

(a) Duke Energy Ohio recorded a pretax impairment charge of $94 million related to OVEC.

204

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
	Duke Energy
(in millions)	Renewables		Other		Total		Duke Energy Ohio		Duke Energy Indiana
Receivables	$	—	$	—	$	—	$	114	$	143
Investments in equity method unconsolidated affiliates	153		60		213		—		—
Intangibles	—		96		96		96		—
Investments and other assets	—		4		4		—		—
Total assets	$	153	$	160	$	313	$	210	$	143
Other current liabilities	—		3		3		—		—
Deferred credits and other liabilities	—		15		15		—		—
Total liabilities	$	—	$	18	$	18	$	—	$	—
Net assets	$	153	$	142	$	295	$	210	$	143

The Duke Energy Registrants are not aware of any situations where the maximum exposure to loss significantly exceeds the carrying values shown above except for the power purchase agreement with OVEC, which is discussed below, and various guarantees, some of which are reflected in the table above as Deferred credits and other liabilities. For more information on various guarantees, refer to Note 7, "Guarantees and Indemnifications."

Renewables

Duke Energy has investments in various renewable energy project entities. Some of these entities are VIEs due to long-term fixed price power purchase agreements. These fixed price agreements effectively transfer commodity price risk to the buyer of the power. Duke Energy does not consolidate these VIEs because power to direct and control key activities is shared jointly by Duke Energy and other owners.

Other

At December 31, 2013, the most significant of the Other non-consolidated VIEs was Duke Energy Ohio’s 9 percent ownership interest in OVEC. Through its ownership interest in OVEC, Duke Energy Ohio has a contractual arrangement to buy power from OVEC’s power plants through June 2040. The initial carrying value of this contract was recorded as an intangible asset when Duke Energy acquired Cinergy in April 2006. Proceeds from the sale of power by OVEC to its power purchase agreement counterparties are designed to be sufficient to meet its operating expenses, fixed costs, debt amortization and interest expense, as well as earn a return on equity. Accordingly, the value of this contract is subject to variability due to fluctuations in power prices and changes in OVEC’s costs of business, including costs associated with its 2,256 MW of coal-fired generation capacity. Proposed environmental rulemaking could increase the costs of OVEC, which would be passed through to Duke Energy Ohio. In 2014, Duke Energy recorded a $94 million impairment related to OVEC.

CRC

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

Amounts included in Receivables in the above table for Duke Energy Ohio and Duke Energy Indiana reflect their retained interest in receivables sold to CRC. These subordinated notes held by Duke Energy Ohio and Duke Energy Indiana are stated at fair value. Carrying values of retained interests are determined by allocating carrying value of the receivables between assets sold and interests retained based on relative fair value. The allocated bases of the subordinated notes are not materially different than their face value because (i) the receivables generally turnover in less than two months, (ii) credit losses are reasonably predictable due to the broad customer base and lack of significant concentration, and (iii) the equity in CRC is subordinate to all retained interests and thus would absorb losses first. The hypothetical effect on fair value of the retained interests assuming both a 10 percent and a 20 percent unfavorable variation in credit losses or discount rates is not material due to the short turnover of receivables and historically low credit loss history. Interest accrues to Duke Energy Ohio and Duke Energy Indiana on the retained interests using the acceptable yield method. This method generally approximates the stated rate on the notes since the allocated basis and the face value are nearly equivalent. An impairment charge is recorded against the carrying value of both retained interests and purchased beneficial interest whenever it is determined that an other-than-temporary impairment has occurred.

205

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Key assumptions used in estimating fair value are detailed in the following table.

	Duke Energy Ohio				Duke Energy Indiana
	2014		2013		2014		2013
Anticipated credit loss ratio	0.6	%	0.6	%	0.3	%	0.3	%
Discount rate	1.2	%	1.2	%	1.2	%	1.2	%
Receivable turnover rate	12.8	%	12.8	%	10.5	%	10.3	%

The following table shows the gross and net receivables sold.

	Duke Energy Ohio				Duke Energy Indiana
(in millions)	2014		2013		2014		2013
Receivables sold	$	273	$	290	$	310	$	340
Less: Retained interests	91		114		113		143
Net receivables sold	$	182	$	176	$	197	$	197

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

	Duke Energy Ohio						Duke Energy Indiana
	Years Ended December 31,						Years Ended December 31,
(in millions)	2014		2013		2012		2014		2013		2012
Sales
Receivables sold	$	2,246	$	2,251	$	2,154	$	2,913	$	2,985	$	2,773
Loss recognized on sale	11		12		13		11		11		12
Cash Flows
Cash proceeds from receivables sold	2,261		2,220		2,172		2,932		2,944		2,784
Collection fees received	1		1		1		1		1		1
Return received on retained interests	4		5		5		6		6		7

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

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

18. COMMON STOCK

Basic Earnings Per Share (EPS) is computed by dividing net income attributable to Duke Energy common shareholders, adjusted for distributed and undistributed earnings allocated to participating securities, by the weighted-average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income attributable to Duke Energy common shareholders, as adjusted for distributed and undistributed earnings allocated to participating securities, by the diluted weighted-average number of common shares outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as stock options, phantom shares and stock-based performance unit awards were exercised or settled. Duke Energy’s participating securities are restricted stock units that are entitled to dividends declared on Duke Energy common shares during the restricted stock units’ vesting period.

206

PART II

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

On July 2, 2012, just prior to the close of the merger with Progress Energy, Duke Energy executed a one-for-three reverse stock split. All earnings per share amounts included in this 10-K are presented as if the one-for-three reverse stock split had been effective January 1, 2012. The following table presents Duke Energy’s basic and diluted EPS calculations and reconciles the weighted-average number of common shares outstanding to the diluted weighted-average number of common shares outstanding.

	Years Ended December 31,
(in millions, except per share amounts)	2014		2013	2012
Income from continuing operations attributable to Duke Energy common shareholders excluding impact of participating securities	2,446		2,565	1,588
Weighted-average shares outstanding - basic	707		706	574
Stock options, performance and restricted shares	—		—	1
Weighted-average shares outstanding - diluted	707		706	575
Earnings per share from continuing operations attributable to Duke Energy common shareholders
Basic	$	3.46	3.64	2.77
Diluted	$	3.46	3.63	2.77
Potentially dilutive items excluded from the calculation(a)	2		2	1
Dividends declared per common share	$	3.15	3.09	3.03

(a) Stock options and performance and unvested stock awards were not included in the dilutive securities calculation because either the option exercise prices were greater than the average market price of the common shares during those periods, or performance measures related to the awards had not yet been met.

19. SEVERANCE

In conjunction with the merger with Progress Energy, in November 2011 Duke Energy and Progress Energy offered a voluntary severance plan to certain eligible employees. Approximately 1,100 employees from Duke Energy and Progress Energy requested severance during the voluntary window, which closed on November 30, 2011. As this was a voluntary severance plan, all severance benefits offered under this plan are considered special termination benefits under U.S. GAAP. Special termination benefits are measured upon employee acceptance and recorded immediately absent any significant retention period. If a significant retention period exists, the cost of the special termination benefits are recorded ratably over the retention period. Most plan participants have separated from the company as of December 31, 2014. The amount of severance expense associated with this voluntary plan, and other severance expense for involuntary terminations related to the merger, was not material for the year ended December 31, 2014.

Amounts included in the table below represent direct and allocated severance and related expense recorded by the Duke Energy Registrants, and are in Operation, maintenance and other within Operating Expenses on the Consolidated Statements of Operations.

	Year Ended December 31,
(in millions)	2013		2012
Duke Energy(a)	$	34	$	201
Duke Energy Carolinas	8		63
Progress Energy	19		82
Duke Energy Progress	14		55
Duke Energy Florida	5		27
Duke Energy Ohio	2		21
Duke Energy Indiana	2		18

(a) Includes $5 million and $14 million of accelerated stock award expense and $2 million and $19 million of COBRA and health care reimbursement expenses for 2013 and 2012, respectively.

In conjunction with the retirement of Crystal River Unit 3, severance benefits have been made available to certain eligible impacted unionized and non-unionized employees, to the extent that those employees do not find job opportunities at other locations. Approximately 600 employees worked at Crystal River Unit 3. For the year ended December 31, 2013, Duke Energy Florida deferred $26 million of severance costs as a regulatory asset. Duke Energy Florida did not defer severance costs as a regulatory asset for the year ended December 31, 2014. Severance costs expected to be accrued over the remaining retention period for employees identified to have a significant retention period is not material. However, these employees maintain the ability to accept job opportunities at other Duke Energy locations, which would result in severance not being paid. If a significant amount of these individuals redeploy within Duke Energy, the final severance benefits paid under the plan may be less than what has been accrued to date. Refer to Note 4 for further discussion regarding Crystal River Unit 3.

During 2014, in conjunction with the disposition of the nonregulated Midwest Generation business, severance benefits have been made available to certain eligible non-unionized employees, to the extent those employees do not find other job opportunities. Approximately 50 employees are expected to receive benefits. Duke Energy Ohio recorded severance expense of $6 million and included in (Loss) Income from Discontinued Operations, net of tax in the Duke Energy Statements of Operations and Comprehensive Income for the year ended December 31, 2014. For further information related to the Midwest Generation Exit, see Note 2, "Acquisitions, Dispositions and Sales of Other Assets."

207

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Amounts included in the table below represent the severance liability for past and ongoing severance plans. Amounts for Subsidiary Registrants do not include allocated expense or associated cash payments. Amounts for Duke Energy Indiana are not material.

(in millions)	Balance at December 31, 2013		Provision / Adjustments			Cash Reductions			Balance at December 31, 2014
Duke Energy	$	64	$	5		$	(41	)	28
Duke Energy Carolinas	5		2			(5		)	2
Progress Energy	44		(10		)	(16		)	18
Duke Energy Progress	11		—			(10		)	1
Duke Energy Florida	24		(1		)	(6		)	17
Duke Energy Ohio	2		5			(1		)	6

As part of Duke Energy Carolinas’ 2011 rate case, the NCUC approved the recovery of $101 million of previously recorded expenses related to a prior year Voluntary Opportunity Plan. This amount was recorded as a reduction to Operation, maintenance, and other within Operating Expenses on the Consolidated Statements of Operations and recognized as a Regulatory asset on the Consolidated Balance Sheets in 2012.

20. STOCK-BASED COMPENSATION

Duke Energy’s 2010 Long-Term Incentive Plan (the 2010 Plan) reserved 25 million shares of common stock for awards to employees and outside directors. Duke Energy has historically issued new shares upon exercising or vesting of share-based awards. However, Duke Energy may use a combination of new share issuances and open market repurchases for share-based awards that are exercised or become vested in the future. Duke Energy has not determined with certainty the amount of such new share issuances or open market repurchases.

The 2010 Plan allows for a maximum of 6.25 million shares of common stock to be issued under various stock-based awards other than options and stock appreciation rights.

In connection with the acquisition of Progress Energy in July 2012, Duke Energy assumed Progress Energy’s 2007 Equity Incentive Plan (EIP). Stock-based awards granted under the Progress Energy EIP and held by Progress Energy employees were generally converted into outstanding Duke Energy stock-based compensation awards. The estimated fair value of these awards allocated to the purchase price was $62 million. Refer to Note 2 for further information regarding the merger transaction.

The following table summarizes the total expense recognized by each of the Duke Energy Registrants, net of tax, for stock-based compensation.

	Years Ended December 31,
(in millions)	2014		2013		2012
Duke Energy	$	38	$	52	$	48
Duke Energy Carolinas	12		13		12
Progress Energy	14		23		25
Duke Energy Progress	9		14		16
Duke Energy Florida	5		9		9
Duke Energy Ohio	5		4		4
Duke Energy Indiana	3		4		4

Pretax stock-based compensation costs, the tax benefit associated with stock-based compensation expense, and stock-based compensation costs capitalized are included in the following table.

	Years Ended December 31,
(in millions)	2014		2013		2012
Restricted stock unit awards	$	39	$	49	$	43
Performance awards	22		34		33
Stock options	—		2		2
Pretax stock-based compensation cost	$	61	$	85	$	78
Tax benefit associated with stock-based compensation expense	$	23	$	33	$	30
Stock-based compensation costs capitalized	4		3		2

208

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

STOCK OPTIONS

The following table summarizes information about stock options outstanding.

	Options (in thousands)		Weighted-Average Exercise Price (per share)		Weighted-Average Remaining Life	Aggregate Intrinsic Value (in millions)
Outstanding at December 31, 2013	793		$	61
Exercised	(420	)	59
Outstanding at December 31, 2014	373		64		6 years, 10 months	$	7
Exercisable at December 31, 2014	53		46		1 year	2
Options expected to vest	320		67		7 years, 10 months	5

The exercise price of each option granted cannot be less than the market price of Duke Energy’s common stock on the date of grant and the maximum option term is 10 years. The vesting periods range from immediate to three years. Options granted in 2013 and 2012 were expensed immediately; therefore, there is no future compensation cost associated with these options.

The following table summarizes additional information related to stock options exercised and granted.

	Years Ended December 31,
	2014		2013		2012
Intrinsic value of options exercised (in millions)	$	6	$	26	$	17
Tax benefit related to options exercised (in millions)	2		10		7
Cash received from options exercised (in millions)	25		9		21
Stock options granted (in thousands)	—		310		340

RESTRICTED STOCK UNIT AWARDS

Restricted stock unit awards issued and outstanding generally vest over periods from immediate to 3 years. Fair value amounts are based on the market price of Duke Energy's common stock at the grant date. The following table includes information related to restricted stock unit awards.

	Years Ended December 31,
	2014		2013		2012
Shares awarded (in thousands)	557		612		443
Fair value (in millions)	$	40	$	42	$	28

The following table summarizes information about restricted stock unit awards outstanding.

	Shares (in thousands)		Weighted-Average Grant Date Fair Value (Per Share)
Outstanding at December 31, 2013	1,400		$	66
Granted	557		71
Vested	(832	)	62
Forfeited	(45	)	68
Outstanding at December 31, 2014	1,080		69
Restricted stock unit awards expected to vest	1,057		69

The total grant date fair value of shares vested during the years ended December 31, 2014, 2013 and 2012 was $52 million, $50 million and $34 million, respectively. At December 31, 2014, Duke Energy had $18 million of unrecognized compensation cost, which is expected to be recognized over a weighted-average period of one year, ten months.

PERFORMANCE AWARDS

Stock-based awards issued and outstanding generally vest over three years if performance targets are met.

Certain performance awards granted in 2014, 2013 and 2012 contain market conditions based on the total shareholder return (TSR) of Duke Energy stock relative to a predefined peer group (relative TSR). These awards are valued using a path-dependent model that incorporates expected relative TSR into the fair value determination of Duke Energy’s performance-based share awards. The model uses three-year historical volatilities and correlations for all companies in the predefined peer group, including Duke Energy, to simulate Duke Energy’s relative TSR as of the end of the performance period. For each simulation, Duke Energy’s relative TSR associated with the simulated stock price at the end of the performance period plus expected dividends within the period results in a value per share for the award portfolio. The average of these simulations is the expected portfolio value per share. Actual life to date results of Duke Energy’s relative TSR for each grant is incorporated within the model.

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Other performance awards not containing market conditions were awarded in 2012. The performance goal for these awards is Duke Energy’s return on equity over a three-year period. Awards are measured at grant date price.

The following table includes information related to performance awards.

	Years Ended December 31,
	2014		2013		2012
Shares awarded (in thousands)	542		633		352
Fair value (in millions)	$	19	$	28	$	19

The following table summarizes information about stock-based performance awards outstanding at the maximum level.

	Shares (in thousands)		Weighted-Average Grant Date Fair Value (per share)
Outstanding at December 31, 2013	1,822		$	46
Granted	542		34
Vested	(524	)	52
Forfeited	(213	)	37
Outstanding at December 31, 2014	1,627		42
Stock-based performance awards expected to vest	1,418		42

The total grant date fair value of shares vested during the years ended December 31, 2014, 2013 and 2012 was $27 million, $42 million and $56 million, respectively. At December 31, 2014, Duke Energy had $21 million of unrecognized compensation cost, which is expected to be recognized over a weighted-average period of one year, nine months.

The grant date fair value of performance awards granted in 2014 was determined based on a risk-fee interest rate of 0.7 percent, which reflects the yield on three-year Treasury bonds as of the grant date, and an expected volatility of 13.5 percent based on Duke Energy's historical volatility over three years using daily stock prices.

21. EMPLOYEE BENEFIT PLANS

DEFINED BENEFIT RETIREMENT PLANS

Duke Energy maintains, and the Subsidiary Registrants participate in, qualified, non-contributory defined benefit retirement plans. The plans cover most U.S. employees using a cash balance formula. Under a cash balance formula, a plan participant accumulates a retirement benefit consisting of pay credits based upon a percentage of current eligible earnings based on age and/or years of service and interest credits. Certain employees are covered under plans that use a final average earnings formula. Under these average earnings formulas, a plan participant accumulates a retirement benefit equal to the sum of percentages of their (i) highest three-year or four-year average earnings, (ii) highest three-year or four-year average earnings in excess of covered compensation per year of participation (maximum of 35 years), and/or (iii) highest three or four-year average earnings times years of participation in excess of 35 years. Duke Energy also maintains, and the Subsidiary Registrants participate in, non-qualified, non-contributory defined benefit retirement plans which cover certain executives. As of January 1, 2014, the qualified and non-qualified non-contributory defined benefit plans are closed to new and rehired non-union and certain unionized employees.

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

Net periodic benefit costs disclosed in the tables below represent the cost of the respective benefit plan for the periods presented. However, portions of the net periodic benefit costs disclosed in the tables below have been capitalized as a component of property, plant and equipment. Amounts presented in the tables below for the Subsidiary Registrants represent the amounts of pension and other post-retirement benefit cost allocated by Duke Energy for employees of the Subsidiary Registrants. Additionally, the Subsidiary Registrants are allocated their proportionate share of pension and post-retirement benefit cost for employees of Duke Energy’s shared services affiliate that provide support to the Subsidiary Registrants. These allocated amounts are included in the governance and shared service costs discussed in Note 13.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Duke Energy’s policy is to fund amounts on an actuarial basis to provide assets sufficient to meet benefit payments to be paid to plan participants. The following table includes information related to the Duke Energy Registrants’ contributions to its U.S. qualified defined benefit pension plans.

(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Anticipated Contributions:
2015	$	302	$	91	$	83	$	42	$	40	$	8	$	19
Contributions Made:
2014	$	—	$	—	$	—	$	—	$	—	$	—	$	—
2013	250		—		250		63		133		—		—
2012	304		—		346		141		128		—		—

QUALIFIED PENSION PLANS

Components of Net Periodic Pension Costs

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost	$	135		$	41		$	40		$	21		$	20		$	4		$	9
Interest cost on projected benefit obligation	344			85			112			54			57			20			29
Expected return on plan assets	(511		)	(132		)	(173		)	(85		)	(85		)	(27		)	(41		)
Amortization of actuarial loss	150			36			68			32			32			4			13
Amortization of prior service credit	(15		)	(8		)	(3		)	(2		)	(1		)	—			—
Other	8			2			3			1			1			—			1
Net periodic pension costs	$	111		$	24		$	47		$	21		$	24		$	1		$	11

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost	$	167		$	49		$	60		$	22		$	30		$	6		$	11
Interest cost on projected benefit obligation	320			80			116			50			53			21			28
Expected return on plan assets	(549		)	(148		)	(199		)	(94		)	(87		)	(31		)	(46		)
Amortization of actuarial loss	244			60			101			46			49			13			24
Amortization of prior service (credit) cost	(11		)	(6		)	(4		)	(1		)	(2		)	—			1
Other	7			2			2			1			1			—			1
Net periodic pension costs	$	178		$	37		$	76		$	24		$	44		$	9		$	19

	Year Ended December 31, 2012
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost	$	122		$	35		$	63		$	25		$	30		$	6		$	9
Interest cost on projected benefit obligation	307			90			127			58			56			31			30
Expected return on plan assets	(472		)	(146		)	(188		)	(96		)	(81		)	(45		)	(46		)
Amortization of actuarial loss	144			45			93			37			48			10			15
Amortization of prior service cost (credit)	10			1			9			8			(1		)	1			1
Other	6			2			2			1			1			—			—
Net periodic pension costs	$	117		$	27		$	106		$	33		$	53		$	3		$	9

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Amounts Recognized in Accumulated Other Comprehensive Income and Regulatory Assets

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress			Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Regulatory assets, net increase (decrease)	$	112		$	30	$	(73	)	$	(17	)	$	11	$	17	$	4
Accumulated other comprehensive (income) loss
Deferred income tax expense	$	(10	)	—		(2		)	—			—		—		—
Actuarial losses arising during the year	29			—		—			—			—		—		—
Prior year service credit arising during the year	—			—		—			—			—		—		—
Amortization of prior year actuarial losses	(9		)	—		—			—			—		—		—
Reclassification of actuarial losses to regulatory assets	(1		)	—		—			—			—		—		—
Net amount recognized in accumulated other comprehensive income	$	9		$	—	$	(2	)	$	—		$	—	$	—	$	—

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Regulatory assets, net decrease	$	(788	)	$	(205	)	$	(253	)	$	(109	)	$	(146	)	$	(96	)	$	(99	)
Accumulated other comprehensive (income) loss
Deferred income tax benefit	$	18		$	—		$	—		$	—		$	—		$	—		$	—
Actuarial gains arising during the year	(33		)	—			(2		)	—			—			—			—
Prior year service credit arising during the year	(1		)	—			—			—			—			—			—
Amortization of prior year actuarial losses	(15		)	—			(3		)	—			—			—			—
Reclassification of actuarial losses to regulatory assets	3			—			—			—			—			—			—
Net amount recognized in accumulated other comprehensive income	$	(28	)	$	—		$	(5	)	$	—		$	—		$	—		$	—

Reconciliation of Funded Status to Net Amount Recognized

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Obligation at prior measurement date	$	7,510		$	1,875		$	2,739		$	1,172		$	1,233		$	442		$	632
Service cost	135			41			40			21			20			4			9
Interest cost	344			85			112			54			57			20			29
Actuarial loss(a)	618			132			211			98			105			41			41
Transfers	—			37			(375		)	(61		)	(9		)	(6		)	—
Plan amendments	(4		)	(1		)	—			—			—			(1		)	—
Benefits paid	(496		)	(116		)	(170		)	(97		)	(71		)	(31		)	(38		)
Obligation at measurement date	$	8,107		$	2,053		$	2,557		$	1,187		$	1,335		$	469		$	673
Accumulated Benefit Obligation at measurement date	$	7,966		$	2,052		$	2,519		$	1,187		$	1,297		$	459		$	645
Change in Fair Value of Plan Assets
Plan assets at prior measurement date	$	8,142		$	2,162		$	2,944		$	1,330		$	1,299		$	448		$	654
Actual return on plan assets	852			217			300			149			144			45			65
Benefits paid	(496		)	(116		)	(170		)	(97		)	(71		)	(31		)	(38		)
Transfers	—			37			(352		)	(61		)	(9		)	(6		)	—
Plan assets at measurement date	$	8,498		$	2,300		$	2,722		$	1,321		$	1,363		$	456		$	681
Funded status of plan	$	391		$	247		$	165		$	134		$	28		$	(13	)	$	8

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

(a) Includes an increase in benefit obligation of $180 million as a result of changes in Duke Energy's mortality assumptions.

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Obligation at prior measurement date	8,030			2,028			2,868			1,264			1,309			527			684
Service cost	167			49			60			22			30			6			11
Interest cost	320			80			116			50			53			21			28
Actuarial gains	(399		)	(73		)	(118		)	(26		)	(75		)	(71		)	(56		)
Transfers	—			(26		)	(7		)	(45		)	(17		)	(2		)	(2		)
Plan amendments	(41		)	(13		)	(19		)	(8		)	(7		)	—			—
Benefits paid	(567		)	(170		)	(161		)	(85		)	(60		)	(39		)	(33		)
Obligation at measurement date	7,510			1,875			2,739			1,172			1,233			442			632
Accumulated Benefit Obligation at measurement date	7,361			1,875			2,698			1,172			1,192			429			608
Change in Fair Value of Plan Assets
Plan assets at prior measurement date	7,754			2,151			2,647			1,289			1,150			446			627
Actual return on plan assets	705			207			215			108			93			43			62
Benefits paid	(567		)	(170		)	(161		)	(85		)	(60		)	(39		)	(33		)
Transfers	—			(26		)	(7		)	(45		)	(17		)	(2		)	(2		)
Employer contributions	250			—			250			63			133			—			—
Plan assets at measurement date	$	8,142		$	2,162		$	2,944		$	1,330		$	1,299		$	448		$	654
Funded status of plan	$	632		$	287		$	205		$	158		$	66		$	6		$	22

Amounts Recognized in the Consolidated Balance Sheets

	December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Prefunded pension(a)	$	441		$	247		$	165		$	134		$	28		$	—		$	8
Non-current pension liability(b)	$	50		$	—		$	—		$	—		$	—		$	13		$	—
Net asset recognized	$	391		$	247		$	165		$	134		$	28		$	(13	)	$	8
Regulatory assets	$	1,711		$	407		$	753		$	346		$	406		$	65		$	151
Accumulated other comprehensive (income) loss
Deferred income tax asset	$	(51	)	$	—		$	(11	)	$	—		$	—		$	—		$	—
Prior service credit	(5		)	—			—			—			—			—			—
Net actuarial loss	140			—			21			—			—			—			—
Net amounts recognized in accumulated other comprehensive loss(c)	$	84		$	—		$	10		$	—		$	—		$	—		$	—
Amounts to be recognized in net periodic pension expense in the next year
Unrecognized net actuarial loss	$	166		$	39		$	65		$	34		$	31		$	6		$	14
Unrecognized prior service credit	(15		)	(8		)	(3		)	(2		)	(1		)	—			—

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio			Duke Energy Indiana
Prefunded pension(a)	$	632		$	287	$	230		$	158	$	66	$	2		$	75
Non-current pension liability(b)	$	—		$	—	$	25		$	—	$	—	$	(4	)	$	53
Net asset recognized	$	632		$	287	$	205		$	158	$	66	$	6		$	22
Regulatory assets	$	1,599		$	377	$	826		$	363	$	395	$	48		$	147
Accumulated other comprehensive (income) loss
Deferred income tax asset	$	(41	)	$	—	$	(9	)	$	—	$	—	$	—		$	—
Prior service credit	(5		)	—		—			—		—		—			—
Net actuarial loss	121			—		21			—		—		—			—
Net amounts recognized in accumulated other comprehensive loss(c)	$	75		$	—	$	12		$	—	$	—	$	—		$	—

(a) Included in Other within Investments and Other Assets on the Consolidated Balance Sheets.

(b) Included in Accrued pension and other post-retirement benefit costs on the Consolidated Balance Sheets.

(c) Excludes accumulated other comprehensive income of $22 million and $16 million as of 2014 and 2013, respectively, net of tax, associated with a Brazilian retirement plan.

Information for Plans with Accumulated Benefit Obligation in Excess of Plan Assets

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Ohio
Projected benefit obligation	$	702	$	315
Accumulated benefit obligation	672		306
Fair value of plan assets	652		302

As of December 31, 2013, none of the qualified pension plans had an accumulated benefit obligation in excess of plan assets.

Assumptions Used for Pension Benefits Accounting

The discount rate used to determine the current year pension obligation and following year’s pension expense is based on a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flow to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of non-callable corporate bonds rated Aa quality or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plan’s projected benefit payments discounted at this rate with the market value of the bonds selected.

The average remaining service period of active covered employees is nine years for Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana.

The following tables present the assumptions or range of assumptions used for pension benefit accounting.

	December 31,
	2014				2013				2012(a)
Benefit Obligations
Discount rate				4.10%				4.70%				4.10%
Salary increase	4.00	%	-	4.40%	4.00	%	-	4.40%	4.00	%	-	4.30%
Net Periodic Benefit Cost
Discount rate				4.70%				4.10%	4.60	%	-	5.10%
Salary increase	4.00	%	-	4.40%	4.00	%	-	4.30%	4.00	%	-	4.40%
Expected long-term rate of return on plan assets				6.75%				7.75%	8.00	%	-	8.25%

(a) For Progress Energy plans, the assumptions used in 2012 to determine net periodic pension costs reflect remeasurement as of July 1, 2012, due to the merger between Duke Energy and Progress Energy.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Expected Benefit Payments

(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Years ending December 31,
2015	$	584	$	175	$	150	$	80	$	67	$	34	$	45
2016	604		184		158		85		70		35		46
2017	616		195		161		86		73		34		45
2018	625		200		165		87		76		34		46
2019	626		194		168		88		78		34		46
2020 - 2024	3,107		924		868		437		420		168		229

NON-QUALIFIED PENSION PLANS

Components of Net Periodic Pension Costs

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Service cost	$	3		$	—	$	1		$	1	$	—	$	—	$	—
Interest cost on projected benefit obligation	14			1		5			1		2		—		—
Amortization of actuarial loss	3			—		2			—		—		—		—
Amortization of prior service credit	(1		)	—		(1		)	—		—		—		—
Net periodic pension costs	$	19		$	1	$	7		$	2	$	2	$	—	$	—

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Service cost	$	3		$	—	$	1		$	1	$	—	$	—	$	—
Interest cost on projected benefit obligation	13			1		7			1		1		—		—
Amortization of actuarial loss	5			—		3			1		1		—		—
Amortization of prior service credit	(1		)	—		(1		)	—		—		—		—
Net periodic pension costs	$	20		$	1	$	10		$	3	$	2	$	—	$	—

	Year Ended December 31, 2012
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Service cost	$	2	$	—	$	2		$	1	$	—	$	—	$	—
Interest cost on projected benefit obligation	12		1		8			1		2		—		—
Amortization of actuarial loss	4		—		5			1		—		—		—
Amortization of prior service cost (credit)	1		—		(1		)	—		—		—		—
Net periodic pension costs	$	19	$	1	$	14		$	3	$	2	$	—	$	—

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Amounts Recognized in Accumulated Other Comprehensive Income and Regulatory Assets and Liabilities

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Regulatory assets, net increase	$	44		$	1	$	14		$	4	$	19	$	1	$	2
Regulatory liabilities, net decrease	$	(7	)	$	—	$	—		$	—	$	—	$	—	$	—
Accumulated other comprehensive (income) loss
Deferred income tax benefit	$	4		$	—	$	5		$	—	$	—	$	—	$	—
Actuarial gains arising during the year	(9		)	—		(11		)	—		—		—		—
Net amount recognized in accumulated other comprehensive loss (income)	$	(5	)	$	—	$	(6	)	$	—	$	—	$	—	$	—

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio		Duke Energy Indiana
Regulatory assets, net (decrease) increase	$	(14	)	$	1	$	(16	)	$	(4	)	$	(3	)	$	—	$	(2	)
Regulatory liabilities, net increase	$	5		$	—	$	—		$	—		$	—		$	—	$	—
Accumulated other comprehensive (income) loss
Deferred income tax benefit	$	—		$	—	$	1		$	—		$	—		$	—	$	—
Actuarial losses (gains) arising during the year	2			—		(5		)	—			—			—		—
Prior year service credit arising during the year	(1		)	—		—			—			—			—		—
Net amount recognized in accumulated other comprehensive loss (income)	$	1		$	—	$	(4	)	$	—		$	—		$	—	$	—

Reconciliation of Funded Status to Net Amount Recognized

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio		Duke Energy Indiana
Change in Projected Benefit Obligation
Obligation at prior measurement date	$	304		$	15		$	140		$	34		$	39		$	3	$	5
Service cost	3			—			1			1			—			—		—
Interest cost	14			1			5			1			2			—		—
Actuarial losses(a)	43			2			11			2			20			1		1
Settlements	—			—			—			—			—			—		—
Plan amendments	—			—			—			—			—			—		—
Transfers	—			—			(32		)	—			4			—		—
Benefits paid	(27		)	(2		)	(9		)	(3		)	(4		)	—		(1		)
Obligation at measurement date	$	337		$	16		$	116		$	35		$	61		$	4	$	5
Accumulated Benefit Obligation at measurement date	$	333		$	15		$	116		$	35		$	61		$	4	$	5
Change in Fair Value of Plan Assets
Plan assets at prior measurement date	—			—			—			—			—			—		—
Benefits paid	(27		)	(2		)	(9		)	(3		)	(4		)	—		(1		)
Employer contributions	27			2			9			3			4			—		1
Plan assets at measurement date	$	—		$	—		$	—		$	—		$	—		$	—	$	—

(a) Includes an increase in benefit obligation of $21 million as a result of changes in Duke Energy's mortality assumptions.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Obligation at prior measurement date	$	335		$	16		$	176		$	38		$	45		$	4		$	5
Service cost	3			—			1			1			—			—			—
Interest cost	13			1			7			1			1			—			—
Actuarial (gains) losses	(15		)	1			(11		)	(3		)	(3		)	(1		)	—
Settlements	(5		)	—			—			—			—			—			—
Plan amendments	(1		)	—			—			—			—			—			—
Transfers	—			—			(21		)	—			—			—			—
Benefits paid	(26		)	(3		)	(12		)	(3		)	(4		)	—			—
Obligation at measurement date	$	304		$	15		$	140		$	34		$	39		$	3		$	5
Accumulated Benefit Obligation at measurement date	$	302		$	15		$	140		$	34		$	39		$	3		$	5
Change in Fair Value of Plan Assets
Plan assets at prior measurement date	—			—			—			—			—			—			—
Benefits paid	(26		)	(3		)	(12		)	(3		)	(4		)	—			—
Employer contributions	26			3			12			3			4			—			—
Plan assets at measurement date	$	—		$	—		$	—		$	—		$	—		$	—		$	—

Amounts Recognized in the Consolidated Balance Sheets

	December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Current pension liability(a)	$	27		$	2	$	8		$	3	$	4	$	—	$	—
Non-current pension liability(b)	310			14		108			32		57		4		5
Total accrued pension liability	$	337		$	16	$	116		$	35	$	61	$	4	$	5
Regulatory assets	$	89		$	5	$	32		$	7	$	25	$	1	$	2
Regulatory liabilities	$	—		$	—	$	—		$	—	$	—	$	—	$	—
Accumulated other comprehensive (income) loss
Deferred income tax asset	4			—		$	2		—		—		—		—
Prior service credit	(1		)	—		—			—		—		—		—
Net actuarial gain	(8		)	—		(4		)	—		—		—		—
Net amounts recognized in accumulated other comprehensive income	$	(5	)	$	—	$	(2	)	$	—	$	—	$	—	$	—
Amounts to be recognized in net periodic pension expense in the next year
Unrecognized net actuarial loss	$	6		—		$	2		$	1	2		—		—
Unrecognized prior service credit	(1		)	—		—			—		—		—		—

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Current pension liability(a)	$	30		$	2	$	11		$	2	$	3	$	—	$	—
Non-current pension liability(b)	274			13		129			32		36		3		5
Total accrued pension liability	$	304		$	15	$	140		$	34	$	39	$	3	$	5
Regulatory assets	$	45		$	4	$	18		$	3	$	6	$	—	$	—
Regulatory liabilities	$	7		$	—	$	—		$	—	$	—	$	—	$	—
Accumulated other comprehensive (income) loss
Deferred income tax asset	$	—		$	—	$	(3	)	$	—	$	—	$	—	$	—
Prior service credit	(1		)	—		—			—		—		—		—
Net actuarial loss	1			—		7			—		—		—		—
Net amounts recognized in accumulated other comprehensive loss	$	—		$	—	$	4		$	—	$	—	$	—	$	—

(a) Included in Other within Current Liabilities on the Consolidated Balance Sheets.

(b) Included in Accrued pension and other post-retirement benefit costs on the Consolidated Balance Sheets.

Information for Plans with Accumulated Benefit Obligation in Excess of Plan Assets

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Projected benefit obligation	$	337	$	16	$	116	$	35	$	61	$	4	$	5
Accumulated benefit obligation	333		15		116		35		61		4		5

	December 31, 2013
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Projected benefit obligation	$	304	$	15	$	140	$	34	$	39	$	3	$	5
Accumulated benefit obligation	302		15		140		34		39		3		5

Assumptions Used for Pension Benefits Accounting

The discount rate used to determine the current year pension obligation and following year’s pension expense is based on a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flow to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of non-callable corporate bonds rated Aa quality or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plan’s projected benefit payments discounted at this rate with the market value of the bonds selected.

The average remaining service period of active covered employees is 13 years for Duke Energy and Progress Energy, nine years for Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, 12 years for Duke Energy Progress and 17 years for Duke Energy Florida.

The following tables present the assumptions used for pension benefit accounting.

	December 31,
	2014		2013		2012(a)
Benefit Obligations
Discount rate	4.10	%	4.70	%				4.10%
Salary increase	4.40	%	4.40	%				4.30%
Net Periodic Benefit Cost
Discount rate	4.70	%	4.10	%	4.60	%	-	5.10%
Salary increase	4.40	%	4.30	%				4.40%

(a) For Progress Energy plans, the assumptions used in 2012 to determine net periodic pension costs reflect remeasurement as of July 1, 2012, due to the merger between Duke Energy and Progress Energy.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Expected Benefit Payments

(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Years ending December 31,
2015	$	28	$	2	$	8	$	3	$	4	$	—	$	—
2016	27		2		8		3		4		—		—
2017	27		2		8		3		4		—		—
2018	24		2		8		3		4		—		—
2019	24		2		8		3		4		—		—
2020 - 2024	116		6		38		13		19		2		2

Other Post-Retirement Benefit Plans

Duke Energy provides, and the Subsidiary Registrants participate in, some health care and life insurance benefits for retired employees on a contributory and non-contributory basis. Employees are eligible for these benefits if they have met age and service requirements at retirement, as defined in the plans. The health care benefits include medical, dental, and prescription drug coverage and are subject to certain limitations, such as deductibles and co-payments.

Duke Energy did not make any pre-funding contributions to its other post-retirement benefit plans during the years ended December 31, 2014, 2013 or 2012.

Components of Net Periodic Other Post-Retirement Benefit Costs

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost	$	10		$	2		$	4		$	1		$	3		$	—		$	1
Interest cost on accumulated post-retirement benefit obligation	49			12			22			11			12			2			5
Expected return on plan assets	(13		)	(9		)	—			—			—			—			(1		)
Amortization of actuarial loss (gain)	39			3			42			31			10			(2		)	—
Amortization of prior service credit	(125		)	(11		)	(95		)	(73		)	(21		)	—			—
Net periodic post-retirement benefit costs	$	(40	)	$	(3	)	$	(27	)	$	(30	)	$	4		$	—		$	5

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost	$	24		$	2		$	18		$	9		$	7		$	1		$	1
Interest cost on accumulated post-retirement benefit obligation	68			13			41			22			16			2			5
Expected return on plan assets	(14		)	(11		)	—			—			—			(1		)	(1		)
Amortization of actuarial loss (gain)	52			3			57			34			16			(1		)	1
Amortization of prior service credit	(41		)	(7		)	(30		)	(20		)	(6		)	(1		)	—
Net periodic post-retirement benefit costs	$	89		$	—		$	86		$	45		$	33		$	—		$	6

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	Year Ended December 31, 2012
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost	$	16		$	2		$	17		$	8	$	7		$	1		$	1
Interest cost on accumulated post-retirement benefit obligation	56			15			43			23		18			3			6
Expected return on plan assets	(17		)	(10		)	(2		)	—		(2		)	(1		)	(1		)
Amortization of actuarial loss (gain)	14			3			35			20		12			(2		)	—
Amortization of prior service credit	(8		)	(5		)	—			—		—			(1		)	—
Amortization of net transition liability	10			7			4			—		3			—			—
Special termination benefit cost	9			1			5			2		1			—			—
Net periodic post-retirement benefit costs	$	80		$	13		$	102		$	53	$	39		$	—		$	6

Amounts Recognized in Accumulated Other Comprehensive Income and Regulatory Assets and Liabilities

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Regulatory assets, net increase (decrease)	$	162		$	34	$	129		$	97	$	(4	)	$	—		$	(7	)
Regulatory liabilities, net increase (decrease)	$	249		$	76	$	122		$	61	$	61		$	(2	)	$	14
Accumulated other comprehensive (income) loss
Deferred income tax benefit	$	1		$	—	$	1		$	—	$	—		$	—		$	—
Actuarial losses (gains) arising during the year	1			—		(2		)	—		—			—			—
Prior year service credit arising during the year	(6		)	—		—			—		—			—			—
Amortization of prior year prior service credit	2			—		—			—		—			—			—
Net amount recognized in accumulated other comprehensive income	$	(2	)	$	—	$	(1	)	$	—	$	—		$	—		$	—

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio		Duke Energy Indiana
Regulatory assets, net (decrease) increase	$	(683	)	$	(51	)	$	(634	)	$	(388	)	$	(166	)	$	—	$	(6	)
Regulatory liabilities, net increase (decrease)	$	30		$	—		$	—		$	—		$	—		$	3	$	9
Accumulated other comprehensive (income) loss
Deferred income tax benefit	$	2		$	—		$	—		$	—		$	—		$	—	$	—
Actuarial gains arising during the year	(4		)	—			—			—			—			—		—
Prior year service credit arising during the year	(3		)	—			—			—			—			—		—
Amortization of prior year actuarial loss	1			—			—			—			—			—		—
Net amount recognized in accumulated other comprehensive income	$	(4	)	$	—		$	—		$	—		$	—		$	—	$	—

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Reconciliation of Funded Status to Accrued Other Post-Retirement Benefit Costs

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Accumulated post-retirement benefit obligation at prior measurement date	$	1,106		$	265		$	533		$	233		$	253		$	42		$	118
Service cost	10			2			4			1			3			—			1
Interest cost	49			12			22			11			12			2			5
Plan participants' contributions	25			10			8			4			4			—			2
Actuarial gains(a)	(87		)	(35		)	(19		)	(21		)	—			—			(20		)
Transfers	—			1			(48		)	(2		)	—			(1		)	—
Plan amendments	(85		)	(4		)	(77		)	—			(78		)	(1		)	—
Benefits paid	(103		)	(31		)	(44		)	(19		)	(24		)	(3		)	(10		)
Accrued retiree drug subsidy	1			—			—			—			—			—			—
Accumulated post-retirement benefit obligation at measurement date	$	916		$	220		$	379		$	207		$	170		$	39		$	96
Change in Fair Value of Plan Assets
Plan assets at prior measurement date	$	214		$	143		—			—			—			$	8		$	18
Actual return on plan assets	18			12			—			—			—			—			2
Benefits paid	(103		)	(31		)	(44		)	(19		)	(24		)	(3		)	(10		)
Transfers	—			(1		)	—			—			—			—			—
Employer contributions	73			12			36			14			20			3			11
Plan participants' contributions	25			10			8			4			4			—			2
Plan assets at measurement date	$	227		$	145		$	—		$	(1	)	$	—		$	8		$	23

(a) Includes an increase in benefit obligation of $7 million as a result of changes in Duke Energy's mortality assumptions.

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Accumulated post-retirement benefit obligation at prior measurement date	$	1,794		$	316		$	1,128		$	612		$	413		$	48		$	136
Service cost	24			2			18			9			7			1			1
Interest cost	68			13			41			22			16			2			5
Plan participants' contributions	47			15			14			6			7			3			3
Actuarial gains	(227		)	(32		)	(156		)	(73		)	(70		)	(6		)	(12		)
Transfers	—			—			(1		)	(8		)	—			—			—
Plan amendments	(476		)	(16		)	(455		)	(311		)	(91		)	—			(3		)
Benefits paid	(132		)	(36		)	(60		)	(26		)	(31		)	(6		)	(14		)
Accrued retiree drug subsidy	8			3			4			2			2			—			2
Accumulated post-retirement benefit obligation at measurement date	$	1,106		$	265		$	533		$	233		$	253		$	42		$	118
Change in Fair Value of Plan Assets
Plan assets at prior measurement date	$	198		$	134		$	—		$	—		$	—		$	7		$	17
Actual return on plan assets	18			13			—			—			—			2			2
Benefits paid	(132		)	(36		)	(60		)	(26		)	(31		)	(6		)	(14		)
Transfers	—			(1		)	—			—			—			—			—
Employer contributions	83			18			46			20			24			2			10
Plan participants' contributions	47			15			14			6			7			3			3
Plan assets at measurement date	$	214		$	143		$	—		$	—		$	—		$	8		$	18

221

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Amounts Recognized in the Consolidated Balance Sheets

	December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current post-retirement liability(a)	$	35		$	—		$	29		$	16		$	14		$	2		$	—
Non-current post-retirement liability(b)	654			75			350			192			156			29			73
Total accrued post-retirement liability	$	689		$	75		$	379		$	208		$	170		$	31		$	73
Regulatory assets	$	—		$	—		$	—		$	—		$	—		$	—		$	64
Regulatory liabilities	$	380		$	76		$	122		$	61		$	61		$	19		$	91
Accumulated other comprehensive (income) loss
Deferred income tax liability	$	5		$	—		$	1		$	—		$	—		$	—		$	—
Prior service credit	(9		)	—			—			—			—			—			—
Net actuarial gain	(5		)	—			(2		)	—			—			—			—
Net amounts recognized in accumulated other comprehensive income	$	(9	)	$	—		$	(1	)	$	—		$	—		$	—		$	—
Amounts to be recognized in net periodic pension expense in the next year
Unrecognized net actuarial loss (gain)	$	16		$	(1	)	$	28		$	18		$	10		$	(2	)	$	—
Unrecognized prior service credit	(140		)	(14		)	(103		)	(68		)	(35		)	—			—

	December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Current post-retirement liability(a)	$	39		$	—		$	36		$	17		$	16	$	2	$	—
Non-current post-retirement liability(b)	853			122			497			216			237		32		100
Total accrued post-retirement liability	$	892		$	122		$	533		$	233		$	253	$	34	$	100
Regulatory assets	$	(162	)	$	(34	)	$	(129	)	$	(97	)	$	4	$	—	$	71
Regulatory liabilities	$	131		$	—		$	—		$	—		$	—	$	21	$	77
Accumulated other comprehensive (income) loss
Deferred income tax liability	$	4		$	—		$	—		$	—		$	—	$	—	$	—
Prior service credit	(5		)	—			—			—			—		—		—
Net actuarial gain	(6		)	—			—			—			—		—		—
Net amounts recognized in accumulated other comprehensive income	$	(7	)	$	—		$	—		$	—		$	—	$	—	$	—

(a) Included in Other within Current Liabilities on the Consolidated Balance Sheets. 

(b) Included in Accrued pension and other post-retirement benefit costs on the Consolidated Balance Sheets.

Assumptions Used for Other Post-Retirement Benefits Accounting

The discount rate used to determine the current year other post-retirement benefits obligation and following year’s other post-retirement benefits expense is based on a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flow to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of non-callable corporate bonds rated Aa quality or higher. After the bond portfolio is selected, a single interest rate is determined that equates present value of the plan’s projected benefit payments discounted at this rate with the market value of the bonds selected.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following tables present the assumptions used for other post-retirement benefits accounting.

	December 31,
	2014		2013		2012(a)
Benefit Obligations
Discount rate	4.10	%	4.70	%				4.10	%
Net Periodic Benefit Cost
Discount rate	4.70	%	4.10	%	4.60	%	-	5.10	%
Expected long-term rate of return on plan assets	6.75	%	7.75	%	5.00	%	-	8.00	%
Assumed tax rate	35	%	35	%				35	%

(a) For Progress Energy plans, the assumptions used in 2012 to determine net periodic post-retirement benefit costs reflect remeasurement as of July 1, 2012, due to the merger between Duke Energy and Progress Energy.

Assumed Health Care Cost Trend Rate

	December 31,
	2014		2013
Health care cost trend rate assumed for next year	6.75	%	8.50	%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	4.75	%	5.00	%
Year that rate reaches ultimate trend	2023		2021

Sensitivity to Changes in Assumed Health Care Cost Trend Rates

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
1-Percentage Point Increase
Effect on total service and interest costs	$	2		$	1		$	1		$	—		$	1		$	—		$	—
Effect on post-retirement benefit obligation	36			9			15			8			7			2			4
1-Percentage Point Decrease
Effect on total service and interest costs	(2		)	(1		)	(1		)	—			(1		)	—			—
Effect on post-retirement benefit obligation	(31		)	(8		)	(13		)	(7		)	(6		)	(1		)	(3		)

Expected Benefit Payments

(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Years ending December 31,
2015	$	77	$	17	$	30	$	16	$	14	$	4	$	10
2016	77		18		30		16		14		4		10
2017	76		18		29		15		14		3		9
2018	74		19		29		15		14		3		9
2019	73		19		29		15		13		3		8
2020 - 2024	332		84		132		70		61		15		35

PLAN ASSETS

Description and Allocations

Duke Energy Master Retirement Trust

Assets for both the qualified pension and other post-retirement benefits are maintained in the Duke Energy Master Retirement Trust. Approximately 98 percent of the Duke Energy Master Retirement Trust assets were allocated to qualified pension plans and approximately 2 percent were allocated to other post-retirement plans, as of December 31, 2014 and 2013. The investment objective of the Duke Energy Master Retirement Trust is to achieve reasonable returns, subject to a prudent level of portfolio risk, for the purpose of enhancing the security of benefits for plan participants.

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Combined Notes To Consolidated Financial Statements – (Continued)

The asset allocation targets were set after considering the investment objective and the risk profile. Equity securities are held for their higher expected return. Debt securities are primarily held to hedge qualified pension plan liability. Hedge funds, real estate and other global securities are held for diversification. Investments within asset classes are to be diversified to achieve broad market participation and reduce the impact of individual managers or investments.

In 2013, Duke Energy adopted a de-risking investment strategy for the Duke Energy Master Retirement Trust. As the funded status of the qualified pension plans increases, the targeted allocation to return seeking assets will be reduced and the targeted allocation to fixed-income assets will be increased to better manage Duke Energy’s qualified pension liability and reduced funded status volatility. Duke Energy regularly reviews its actual asset allocation and periodically rebalances its investments to the targeted allocation when considered appropriate.

The Duke Energy Retirement Master Trust is authorized to engage in the lending of certain plan assets. Securities lending is an investment management enhancement that utilizes certain existing securities of the Duke Energy Retirement Master Trust to earn additional income. Securities lending involves the loaning of securities to approved parties. In return for the loaned securities, the Duke Energy Retirement Master Trust receives collateral in the form of cash as a safeguard against possible default of any borrower on the return of the loan under terms that permit the Duke Energy Retirement Master Trust to sell the securities. The Master Trust mitigates credit risk associated with securities lending arrangements by monitoring the fair value of the securities loaned, with additional collateral obtained or refunded as necessary. The fair value of securities on loan was approximately $383 million and $43 million at December 31, 2014 and 2013, respectively. Cash obtained as collateral exceeded the fair value of the securities loaned at December 31, 2014 and 2013, respectively. Securities lending income earned by the Master Trust was immaterial for the years ended December 31, 2014, 2013 and 2012, respectively.

Qualified pension and other post-retirement benefits for the Subsidiary Registrants are derived from the Duke Energy Master Retirement Trust, as such, each are allocated their proportionate share of the assets discussed below.

The following table includes the target asset allocations by asset class at December 31, 2014 and the actual asset allocations for the Duke Energy Master Retirement Trust.

			Actual Allocation at December 31,
	Target Allocation		2014		2013
U.S. equity securities	10	%	10	%	10	%
Non-U.S. equity securities	8	%	8	%	8	%
Global equity securities	10	%	10	%	10	%
Global private equity securities	3	%	3	%	3	%
Debt securities	63	%	63	%	63	%
Hedge funds	2	%	3	%	3	%
Real estate and cash	2	%	1	%	1	%
Other global securities	2	%	2	%	2	%
Total	100	%	100	%	100	%

VEBA I

Duke Energy also invests other post-retirement assets in the Duke Energy Corporation Employee Benefits Trust (VEBA I). The investment objective of VEBA I is to achieve sufficient returns, subject to a prudent level of portfolio risk, for the purpose of promoting the security of plan benefits for participants. VEBA I is passively managed. 

The following table presents target and actual asset allocations for VEBA I at December 31, 2014.

			Actual Allocation at December 31,
	Target Allocation		2014		2013
U.S. equity securities	30	%	29	%	29	%
Debt securities	45	%	28	%	29	%
Cash	25	%	43	%	42	%
Total	100	%	100	%	100	%

Fair Value Measurements

Duke Energy classifies recurring and non-recurring fair value measurements based on the fair value hierarchy as discussed in Note 16.

Valuation methods of the primary fair value measurements disclosed above are as follows:

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Combined Notes To Consolidated Financial Statements – (Continued)

Investments in equity securities

Investments in equity securities, other than those accounted for as equity and cost method investments, are typically valued at the closing price in the principal active market as of the last business day of the reporting period. Principal active markets for equity prices include published exchanges such as NASDAQ and NYSE. Foreign equity prices are translated from their trading currency using the currency exchange rate in effect at the close of the principal active market. Prices have not been adjusted to reflect after-hours market activity. The majority of investments in equity securities are valued using Level 1 measurements. When (i) the Duke Energy Registrants lack the ability to redeem investments valued on a net asset value per share basis in the near future or (ii) net asset value per share is not available at the measurement date, the fair value measurement of the investment is categorized as Level 3.

Investments in debt securities

Most debt investments are valued based on a calculation using 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. Most debt valuations are Level 2 measurements. If the market for a particular fixed income security is relatively inactive or illiquid, the measurement is Level 3. U.S. Treasury debt is typically Level 2.

Investments in short-term investment funds

Investments in short-term investment funds are valued at the net asset value of units held at year end. Investments in short-term investment funds with published prices are valued as Level 1. Investments in short-term investment funds with unpublished prices are valued as Level 2.

Investments in real estate limited partnerships

Investments in real estate limited partnerships are valued by the trustee at each valuation date (monthly). As part of the trustee’s valuation process, properties are externally appraised generally on an annual basis, conducted by reputable, independent appraisal firms, and signed by appraisers that are members of the Appraisal Institute, with the professional designation MAI. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. There are three valuation techniques that can be used to value investments in real estate assets: the market, income or cost approach. The appropriateness of each valuation technique depends on the type of asset or business being valued. In addition, the trustee may cause additional appraisals to be performed as warranted by specific asset or market conditions. Property valuations and the salient valuation-sensitive assumptions of each direct investment property are reviewed by the trustee quarterly and values are adjusted if there has been a significant change in circumstances related to the investment property since the last valuation. Value adjustments for interim capital expenditures are only recognized to the extent that the valuation process acknowledges a corresponding increase in fair value. An independent firm is hired to review and approve quarterly direct real estate valuations. Key inputs and assumptions used to determine fair value includes among others, rental revenue and expense amounts and related revenue and expense growth rates, terminal capitalization rates and discount rates. Development investments are valued using cost incurred to date as a primary input until substantive progress is achieved in terms of mitigating construction and leasing risk at which point a discounted cash flow approach is more heavily weighted. Key inputs and assumptions in addition to those noted above used to determine the fair value of development investments include construction costs, and the status of construction completion and leasing. Investments in real estate limited partnerships are valued as Level 3.

Duke Energy Master Retirement Trust

The following tables provide the fair value measurement amounts for the Duke Energy Master Retirement Trust qualified pension and other post-retirement assets.

	December 31, 2014
(in millions)	Total Fair Value		Level 1			Level 2		Level 3
Equity securities	$	2,346	$	1,625		$	721	$	—
Corporate debt securities	4,349		—			4,348		1
Short-term investment funds	333		171			162		—
Partnership interests	298		—			—		298
Hedge funds	146		—			146		—
Real estate limited partnerships	104		—			—		104
U.S. government securities	917		—			916		1
Guaranteed investment contracts	32		—			—		32
Governments bonds - foreign	44		—			44		—
Cash	30		30			—		—
Government and commercial mortgage backed securities	9		—			9		—
Net pending transactions and other investments	10		(10		)	20		—
Total assets(a)	$	8,618	$	1,816		$	6,366	$	436

(a) Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana were allocated approximately 28 percent, 31 percent, 15 percent, 16 percent, 5 percent and 8 percent, respectively, of the Duke Energy Master Retirement Trust assets at December 31, 2014. Accordingly, all Level 1, 2 and 3 amounts included in the table above are allocable to the Subsidiary Registrants using these percentages.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Equity securities	$	2,877	$	1,801	$	1,022	$	54
Corporate debt securities	2,604		—		2,601		3
Short-term investment funds	1,158		254		904		—
Partnership interests	307		—		—		307
Hedge funds	164		—		111		53
Real estate limited partnerships	95		—		—		95
U.S. government securities	927		—		927		—
Guarantees investment contracts	33		—		—		33
Governments bonds - foreign	19		—		18		1
Cash	58		58		—		—
Asset backed securities	7		—		7		—
Net pending transactions and other investments	12		7		5		—
Total assets(a)	$	8,261	$	2,120	$	5,595	$	546

(a) Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana were allocated approximately 28 percent, 35 percent, 16 percent, 16 percent, 5 percent and 8 percent, respectively, of the Duke Energy Master Retirement Trust assets at December 31, 2013. Accordingly, all Level 1, 2 and 3 amounts included in the table above are allocable to the Subsidiary Registrants using these percentages.

The following table provides a reconciliation of beginning and ending balances of assets of master trusts measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3).

(in millions)	2014			2013
Balance at January 1	$	546		$	352
Combination of trust assets(a)	—			288
Purchases, sales, issuances and settlements
Purchases	17			25
Sales	(164		)	(152		)
Total gains (losses) and other, net	37			33
Balance at December 31	$	436		$	546

(a) As of January 1, 2013, assets previously held in the Progress Energy Master Retirement Trust were transferred into the Duke Energy Master Retirement Trust.

VEBA I

The following tables provide the fair value measurement amounts for VEBA I other post-retirement assets.

	December 31, 2014
(in millions)	Total Fair Value		Level 1	Level 2		Level 3
Cash and cash equivalents	$	21	—	$	21	—
Equity securities	14		—	14		—
Debt securities	13		—	13		—
Total assets	$	48	—	$	48	—

	December 31, 2013
(in millions)	Total Fair Value		Level 1	Level 2		Level 3
Cash and cash equivalents	$	21	—	$	21	—
Equity securities	15		—	15		—
Debt securities	15		—	15		—
Total assets	$	51	—	$	51	—

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

EMPLOYEE SAVINGS PLANS

Duke Energy sponsors, and the Subsidiary Registrants participate in, employee savings plans that cover substantially all U.S. employees. Most employees participate in a matching contribution formula where Duke Energy provides a matching contribution generally equal to 100 percent of employee before-tax and Roth 401(k) contributions, and, as applicable, after-tax contributions, of up to 6 percent of eligible pay per pay period. Dividends on Duke Energy shares held by the savings plans are charged to retained earnings when declared and shares held in the plans are considered outstanding in the calculation of basic and diluted earnings per share.

As of January 1, 2014, for new and rehired non-union and certain unionized employees who are not eligible to participate in Duke Energy’s defined benefit plans, an additional employer contribution of 4 percent of eligible pay per pay period, which is subject to a three-year vesting schedule, is provided to the employee’s savings plan account.

The following table includes pretax employer matching contributions made by Duke Energy and expensed by the Subsidiary Registrants.

(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Years ended December 31,
2014(a)	$	143	$	47	$	43	$	30	$	14	$	3	$	7
2013	134		45		45		25		14		3		7
2012	107		37		45		24		15		4		6

(a) For 2014, amounts include the additional employer contribution of 4 percent of eligible pay per pay period for employees not eligible to participate in a defined benefit plan.

22. INCOME TAXES

Income Tax Expense

Components of Income Tax Expense

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current income taxes
Federal	$	—		$	161		$	(466	)	$	(184	)	$	(53	)	$	(73	)	$	(112	)
State	56			51			(8		)	14			1			3			1
Foreign	144			—			—			—			—			—			—
Total current income taxes	200			212			(474		)	(170		)	(52		)	(70		)	(111		)
Deferred income taxes
Federal	1,517			407			938			436			350			113			294
State	35			(25		)	84			25			52			1			15
Foreign	(67		)	—			—			—			—			—			—
Total deferred income taxes(a)(b)	1,485			382			1,022			461			402			114			309
Investment tax credit amortization	(16		)	(6		)	(8		)	(6		)	(1		)	(1		)	(1		)
Income tax expense from continuing operations	1,669			588			540			285			349			43			197
Tax benefit from discontinued operations	(295		)	—			(4		)	—			—			(300		)	—
Total income tax expense included in Consolidated Statements of Operations	$	1,374		$	588		$	536		$	285		$	349		$	(257	)	$	197

(a) There were no benefits of net operating loss (NOL) carryforwards.

(b) Includes utilization of NOL and tax credit carryforwards of $1,544 million at Duke Energy, $345 million at Duke Energy Carolinas, $530 million at Progress Energy, $291 million at Duke Energy Progress, $64 million at Duke Energy Florida, $56 million at Duke Energy Ohio and $141 million at Duke Energy Indiana.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current income taxes
Federal	$	(141	)	$	49		$	(221	)	$	(70	)	$	(143	)	$	(24	)	$	(88	)
State	(40		)	11			(37		)	(10		)	(13		)	(4		)	7
Foreign	151			—			—			—			—			—			—
Total current income taxes	(30		)	60			(258		)	(80		)	(156		)	(28		)	(81		)
Deferred income taxes
Federal	1,092			464			555			316			326			65			276
State	144			75			84			59			44			6			29
Foreign	14			—			—			—			—			—			—
Total deferred income taxes(a)	1,250			539			639			375			370			71			305
Investment tax credit amortization	(15		)	(5		)	(8		)	(7		)	(1		)	—			(1		)
Income tax expense from continuing operations	1,205			594			373			288			213			43			223
Tax expense from discontinued operations	29			—			(26		)	—			—			32			—
Total income tax expense included in Consolidated Statements of Operations	$	1,234		$	594		$	347		$	288		$	213		$	75		$	223

(a) Includes benefits of NOL carryforwards of $808 million at Duke Energy, $458 million at Progress Energy, $64 million at Duke Energy Progress, $301 million at Duke Energy Florida and $179 million at Duke Energy Indiana.

	Year Ended December 31, 2012
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current income taxes
Federal	$	(108	)	$	(1	)	$	(88	)	$	(48	)	$	6		$	(8	)	$	(27	)
State	29			(25		)	2			(6		)	—			5			27
Foreign	133			—			—			—			—			—			—
Total current income taxes	54			(26		)	(86		)	(54		)	6			(3		)	—
Deferred income taxes
Federal	491			408			226			162			121			40			(47		)
State	71			77			40			9			21			(2		)	(25		)
Foreign	20			—			—			—			—			—			—
Total deferred income taxes(a)	582			485			266			171			142			38			(72		)
Investment tax credit amortization	(13		)	(6		)	(8		)	(7		)	(1		)	(2		)	(1		)
Income tax expense (benefit) from continuing operations	623			453			172			110			147			33			(73		)
Tax benefit from discontinued operations	107			—			29			—			—			65			—
Total income tax expense (benefit) included in Consolidated Statements of Operations	$	730		$	453		$	201		$	110		$	147		$	98		$	(73	)

(a) Includes benefits of NOL carryforwards of $1,062 million at Duke Energy, $245 million at Duke Energy Carolinas, $357 million at Progress Energy, $257 million at Duke Energy Progress, $25 million at Duke Energy Florida, $34 million at Duke Energy Ohio and $205 million at Duke Energy Indiana.

Duke Energy Income from Continuing Operations before Income Taxes

	Years Ended December 31,
(in millions)	2014		2013		2012
Domestic	$	3,600	$	3,183	$	1,600
Foreign	534		612		634
Income from continuing operations before income taxes	$	4,134	$	3,795	$	2,234

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Statutory Rate Reconciliation

The following tables present a reconciliation of income tax expense at the U.S. federal statutory tax rate to the actual tax expense from continuing operations.

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Income tax expense, computed at the statutory rate of 35 percent	$	1,447		$	581		$	497		$	263		$	314		$	39		$	195
State income tax, net of federal income tax effect	59			17			49			25			34			3			10
Tax differential on foreign earnings(a)	(110		)	—			—			—			—			—			—
AFUDC equity income	(47		)	(32		)	(9		)	(9		)	—			(1		)	(5		)
Renewable energy production tax credits	(67		)	—			—			—			—			—			—
International tax dividend	373			—			—			—			—			—			—
Other items, net	14			22			3			6			1			2			(3		)
Income tax expense from continuing operations	$	1,669		$	588		$	540		$	285		$	349		$	43		$	197
Effective tax rate	40.4		%	35.4		%	38.0		%	37.9		%	38.9		%	38.9		%	35.5		%

(a) Includes a $57 million benefit as a result of the merger of two Chilean subsidiaries and a change in income tax rates in various countries primarily relating to Peru.

During the fourth quarter of 2014, Duke Energy declared a taxable dividend of foreign earnings in the form of notes payable that will result in the repatriation of approximately $2.7 billion of cash held and expected to be generated by International Energy over a period of up to 8 years. As a result of the decision to repatriate all cumulative historical undistributed foreign earnings, during the fourth quarter of 2014, Duke Energy recorded U.S. income tax expense of approximately $373 million. Duke Energy’s intention is to indefinitely reinvest prospective undistributed earnings generated by Duke Energy's foreign subsidiaries, and accordingly U.S. deferred taxes will not be provided for those earnings.

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Income tax expense, computed at the statutory rate of 35 percent	$	1,328		$	549		$	361		$	276		$	188		$	39		$	203
State income tax, net of federal income tax effect	66			56			31			31			20			2			23
Tax differential on foreign earnings	(49		)	—			—			—			—			—			—
AFUDC equity income	(55		)	(32		)	(18		)	(15		)	(3		)	—			(5		)
Renewable energy production tax credits	(62		)	—			—			—			—			—			—
Other items, net	(23		)	21			(1		)	(4		)	8			2			2
Income tax expense (benefit) from continuing operations	$	1,205		$	594		$	373		$	288		$	213		$	43		$	223
Effective tax rate	31.8		%	37.8		%	36.2		%	36.5		%	39.6		%	39.1		%	38.4		%

	Year Ended December 31, 2012
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Income tax expense, computed at the statutory rate of 35 percent	$	782		$	461		$	185		$	134		$	145		$	27		$	(43	)
State income tax, net of federal income tax effect	65			34			33			1			14			2			1
Tax differential on foreign earnings	(69		)	—			—			—			—			—			—
AFUDC equity income	(101		)	(54		)	(37		)	(24		)	(13		)	(2		)	(26		)
Renewable energy production tax credits	(25		)	—			—			—			—			—			—
Other items, net	(29		)	12			(9		)	(1		)	1			6			(5		)
Income tax expense from continuing operations	$	623		$	453		$	172		$	110		$	147		$	33		$	(73	)
Effective tax rate	27.9		%	34.3		%	32.7		%	28.7		%	35.7		%	42.9		%	59.5		%

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

Valuation allowances have been established for certain foreign and state NOL carryforwards and state income tax credits that reduce deferred tax assets to an amount that will be realized on a more-likely-than-not basis. The net change in the total valuation allowance is included in Tax differential on foreign earnings and State income tax, net of federal income tax effect in the above tables.

DEFERRED TAXES

Net Deferred Income Tax Liability Components

	December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Deferred credits and other liabilities	$	188		$	53		$	108		$	28		$	78		$	(8	)	$	12
Capital lease obligations	63			10			—			—			—			—			2
Pension, postretirement and other employee benefits	546			4			188			96			93			17			43
Progress Energy merger purchase accounting adjustments(a)	1,124			—			—			—			—			—			—
Tax credits and NOL carryforwards	3,540			157			980			91			252			38			260
Investments and other assets	—			—			—			—			—			14			—
Other	—			12			—			55			—			35			11
Valuation allowance	(184		)	—			(13		)	(1		)	—			—			—
Total deferred income tax assets	5,277			236			1,263			269			423			96			328
Investments and other assets	(1,625		)	(1,051		)	(427		)	(232		)	(245		)	—			(4		)
Accelerated depreciation rates	(11,715		)	(4,046		)	(3,284		)	(2,030		)	(1,252		)	(1,660		)	(1,603		)
Regulatory assets and deferred debits	(3,694		)	(953		)	(1,602		)	(809		)	(792		)	(141		)	(106		)
Other	(44		)	—			(151		)	—			(246		)	—			—
Total deferred income tax liabilities	(17,078		)	(6,050		)	(5,464		)	(3,071		)	(2,535		)	(1,801		)	(1,713		)
Net deferred income tax liabilities	$	(11,801	)	$	(5,814	)	$	(4,201	)	$	(2,802	)	$	(2,112	)	$	(1,705	)	$	(1,385	)

(a) Primarily related to capital lease obligations and debt fair value adjustments.

On July 23, 2013, HB 998 was signed into law. HB 998 reduces the North Carolina corporate income tax rate from a statutory 6.9 percent to 6.0 percent in January 2014 with a further reduction to 5.0 percent in January 2015. Duke Energy recorded a net reduction of approximately $145 million to its North Carolina deferred tax liability in the third quarter of 2013. The significant majority of this deferred tax liability reduction was offset by recording a regulatory liability pending NCUC determination of the disposition of the amounts related to Duke Energy Carolinas and Duke Energy Progress. The impact of HB 998 did not have a significant impact on the financial position, results of operation, or cash flows of Duke Energy, Duke Energy Carolinas, Progress Energy or Duke Energy Progress.

The following table presents the expiration of tax credits and NOL carryforwards.

	December 31, 2014
(in millions)	Amount		Expiration Year
Investment tax credits	$	581	2029	—	2034
Alternative minimum tax credits	1,093		Indefinite
Federal NOL carryforwards	749		2030	—	2033
State NOL carryforwards and credits(a)	162		2015	—	2034
Foreign NOL carryforwards(b)	117		2015	—	2033
Foreign Tax Credits	838		2024
Total tax credits and NOL carryforwards	$	3,540

(a) A valuation allowance of $79 million has been recorded on the state Net Operating Loss carryforwards, as presented in the Net Deferred Income Tax Liability Components table.

(b) A valuation allowance of $105 million has been recorded on the foreign Net Operating Loss carryforwards, as presented in the Net Deferred Income Tax Liability Components table.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

	December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Deferred credits and other liabilities	$	245		$	56		$	136		$	9		$	96		$	(13	)	$	9
Capital lease obligations	59			11			—			—			—			—			(2		)
Pension, postretirement and other employee benefits	649			18			341			119			145			23			54
Progress Energy merger purchase accounting adjustments(a)	1,184			—			—			—			—			—			—
Tax credits and NOL carryforwards	4,307			488			1,965			396			365			165			521
Other	265			15			116			39			43			20			14
Valuation allowance	(192		)	—			(40		)	(1		)	—			—			—
Total deferred income tax assets	6,517			588			2,518			562			649			195			596
Investments and other assets	(1,396		)	(999		)	(209		)	(160		)	(49		)	(17		)	(7		)
Accelerated depreciation rates	(12,615		)	(4,400		)	(3,663		)	(2,528		)	(1,160		)	(1,937		)	(1,591		)
Regulatory assets and deferred debits	(3,185		)	(609		)	(1,389		)	(202		)	(1,159		)	(168		)	(117		)
Total deferred income tax liabilities	(17,196		)	(6,008		)	(5,261		)	(2,890		)	(2,368		)	(2,122		)	(1,715		)
Net deferred income tax liabilities	$	(10,679	)	$	(5,420	)	$	(2,743	)	$	(2,328	)	$	(1,719	)	$	(1,927	)	$	(1,119	)

(a) Primarily related to capital lease obligations and debt fair value adjustments.

Classification of Deferred Tax Assets (Liabilities) in the Consolidated Balance Sheets

	December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current Assets: Other	$	1,593		$	3		$	558		$	106		$	340		$	60		$	206
Investments and Other Assets: Other	29			—			—			—			—			—			—
Current Liabilities: Other	—			(5		)	—			—			—			—			—
Deferred Credits and Other Liabilities: Other	(13,423		)	(5,812		)	(4,759		)	(2,908		)	(2,452		)	(1,765		)	(1,591		)
Net deferred income tax liabilities	$	(11,801	)	$	(5,814	)	$	(4,201	)	$	(2,802	)	$	(2,112	)	$	(1,705	)	$	(1,385	)

	December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current Assets: Other	$	1,373		$	286		$	540		$	229		$	110		$	85		$	52
Investments and Other Assets: Other	45			—			—			—			—			—			—
Deferred Credits and Other Liabilities: Other	(12,097		)	(5,706		)	(3,283		)	(2,557		)	(1,829		)	(2,012		)	(1,171		)
Net deferred income tax liabilities	$	(10,679	)	$	(5,420	)	$	(2,743	)	$	(2,328	)	$	(1,719	)	$	(1,927	)	$	(1,119	)

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

UNRECOGNIZED TAX BENEFITS

The following tables present changes to unrecognized tax benefits.

	Year Ended December 31, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Indiana
Unrecognized tax benefits — January 1	$	230		$	171		$	32		$	22	$	8	$	1
Unrecognized tax benefits increases (decreases)
Gross increases — tax positions in prior periods	—			—			1			1		—		—
Gross decreases — tax positions in prior periods	(2		)	—			—			—		—		—
Decreases due to settlements	(15		)	(11		)	(1		)	—		—		—
Total changes	(17		)	(11		)	—			1		—		—
Unrecognized tax benefits — December 31	$	213		$	160		$	32		$	23	$	8	$	1

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Unrecognized tax benefits — January 1	$	540		$	271		$	131		$	67		$	44		$	36		$	32
Unrecognized tax benefits (decreases) increases
Gross decreases — tax positions in prior periods	(231		)	(100		)	(86		)	(45		)	(37		)	(36		)	(31		)
Decreases due to settlements	(66		)	—			—			—			—			—			—
Reduction due to lapse of statute of limitations	(13		)	—			(13		)	—			1			—			—
Total changes	(310		)	(100		)	(99		)	(45		)	(36		)	(36		)	(31		)
Unrecognized tax benefits — December 31	$	230		$	171		$	32		$	22		$	8		$	—		$	1

	Year Ended December 31, 2012
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Unrecognized tax benefits — January 1	$	385		$	260		$	173		$	73		$	80		$	32		$	24
Acquisitions	128			—			—			—			—			—			—
Unrecognized tax benefits increases (decreases)
Gross increases — tax positions in prior periods	29			12			23			10			12			2			6
Gross decreases — tax positions in prior periods	(4		)	—			(72		)	(19		)	(52		)	—			—
Gross increases — current period tax positions	28			15			8			4			4			4			4
Gross decreases — current period tax positions	(9		)	(5		)	(1		)	(1		)	—			(2		)	(2		)
Decreases due to settlements	(13		)	(11		)	—			—			—			—			—
Reduction due to lapse of statute of limitations	(4		)	—			—			—			—			—			—
Total changes	155			11			(42		)	(6		)	(36		)	4			8
Unrecognized tax benefits — December 31	$	540		$	271		$	131		$	67		$	44		$	36		$	32

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following table includes additional information regarding the Duke Energy Registrants' unrecognized tax benefits. It is reasonably possible that Duke Energy and Progress Energy will reflect an approximate $28 million reduction, Duke Energy Progress will reflect an approximate $17 million reduction, and Duke Energy Florida will reflect an approximate $7 million reduction in unrecognized tax benefits within the next 12 months due to the expected lapse of the statute of limitations. All other Duke Energy Registrants do not anticipate a material increase or decrease in unrecognized tax benefits within the next 12 months.

	December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke  Energy Florida		Duke Energy Indiana
Amount that if recognized, would affect the   effective tax rate or regulatory liability(a)	$	121	$	112	$	3	$	2	$	2	$	2
Amount that if recognized, would be recorded as a component   of discontinued operations	8		—		—		—		—		—

(a) Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana are unable to estimate the specific amounts that would affect the effective tax rate versus the regulatory liability.

OTHER TAX MATTERS

The following tables include interest recognized in the Consolidated Statements of Operations and the Consolidated Balance Sheets.

	Year Ended December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Net interest income recognized related to income taxes	$	6	$	—	$	3	$	—	$	1	$	4	$	4
Net interest expense recognized related to income taxes	—		1		—		1		—		—		—
Interest receivable related to income taxes	—		—		—		—		—		—		2
Interest payable related to income taxes	13		13		5		3		5		—		—

	Year Ended December 31, 2013
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy	Duke Energy Progress	Duke Energy Florida	Duke Energy Ohio	Duke Energy Indiana
Net interest income recognized related to income taxes	$	2	$	2	6	7	—	4	$	1
Interest payable related to income taxes	27		8		10	2	7	—	—

	Year Ended December 31, 2012
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio	Duke Energy Indiana
Net interest income recognized related to income taxes	$	10	$	9	$	—	$	—	$	—	—	2
Net interest expense recognized related to income taxes	—		—		2		—		2		—	—
Interest receivable related to income taxes	—		7		—		—		—		—	—
Interest payable related to income taxes	7		—		17		8		9		3	1

Duke Energy and its subsidiaries are no longer subject to U.S. federal examination for years before 2008. The years 2008 through 2011 are in Appeals. The IRS is currently auditing the federal income tax returns for years 2012 and 2013. With few exceptions, Duke Energy and its subsidiaries are no longer subject to state, local or non-U.S. income tax examinations by tax authorities for years before 2004.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

23. OTHER INCOME AND EXPENSES, NET

The components of Other income and expenses, net on the Consolidated Statements of Operations are as follows.

	Year Ended December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio			Duke Energy Indiana
Interest income	$	57	$	4	$	3	$	—	$	2	$	8		$	6
Foreign exchange gains	3		—		—		—		—		—			—
AFUDC equity	135		91		26		25		—		4			14
Deferred returns	89		71		17		17		—		—			—
Other income (expense)	67		6		31		9		18		(2		)	2
Other income and expense, net	$	351	$	172	$	77	$	51	$	20	$	10		$	22

	Year Ended December 31, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio			Duke Energy Indiana
Interest income	$	26		$	1		$	7	$	1	$	3	$	5		$	6
Foreign exchange losses	(18		)	—			—		—		—		—			—
AFUDC equity	157			91			50		42		8		1			15
Deferred returns	39			32			7		7		—		—			—
Other income (expense)	58			(4		)	30		7		19		(4		)	(3		)
Other income and expense, net	$	262		$	120		$	94	$	57	$	30	$	2		$	18

	Year Ended December 31, 2012
(in millions)	Duke Energy		Duke Energy Carolinas			Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Interest income	$	50	$	11		$	2	$	1	$	1	$	—	$	7
Foreign exchange gains	4		—			—		—		—		—		—
AFUDC equity	300		154			106		69		37		6		84
Deferred returns	24		24			—		—		—		—		—
Other income (expense)	19		(4		)	22		9		1		2		(1		)
Other income and expense, net	$	397	$	185		$	130	$	79	$	39	$	8	$	90

24. SUBSEQUENT EVENTS

For information on subsequent events related to acquisitions, dispositions and sales of other assets, regulatory matters, commitments and contingencies, and debt and credit facilities, see Notes 2, 4, 5 and 6.

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

25. QUARTERLY FINANCIAL DATA (UNAUDITED)

DUKE ENERGY

Quarterly EPS amounts are meant to be stand-alone calculations and are not always additive to the full-year amount due to rounding and the weighting of share issuances.

(in millions, except per share data)	First Quarter(a)			Second Quarter(a)			Third Quarter(a)		Fourth Quarter(a)		Total
2014
Operating revenues	$	6,263		$	5,708		$	6,395	$	5,559	$	23,925
Operating income	1,362			1,289			1,619		988		5,258
Income from continuing operations	750			725			891		99		2,465
(Loss) income from discontinued operations, net of tax	(843		)	(112		)	378		1		(576		)
Net loss (income)	(93		)	613			1,269		100		1,889
Net loss (income) attributable to Duke Energy Corporation	(97		)	609			1,274		97		1,883
Earnings per share:
Income from continuing operations attributable to Duke Energy Corporation common shareholders
Basic	$	1.05		$	1.02		$	1.25	$	0.14	$	3.46
Diluted	$	1.05		$	1.02		$	1.25	$	0.14	$	3.46
(Loss) income from discontinued operations attributable to Duke Energy Corporation common shareholders
Basic	$	(1.19	)	$	(0.16	)	$	0.55	$	—	$	(0.80	)
Diluted	$	(1.19	)	$	(0.16	)	$	0.55	$	—	$	(0.80	)
Net (loss) income attributable to Duke Energy Corporation common shareholders
Basic	$	(0.14	)	$	0.86		$	1.80	$	0.14	$	2.66
Diluted	$	(0.14	)	$	0.86		$	1.80	$	0.14	$	2.66
2013
Operating revenues	$	5,536		$	5,393		$	6,217	$	5,610	$	22,756
Operating income	1,259			742			1,660		1,193		4,854
Income from continuing operations	663			292			946		689		2,590
(Loss) income from discontinued operations, net of tax	(29		)	50			62		3		86
Net income	634			342			1,008		692		2,676
Net income attributable to Duke Energy Corporation	634			339			1,004		688		2,665
Earnings per share:
Income from continuing operations attributable to Duke Energy Corporation common shareholders
Basic	$	0.93		$	0.40		$	1.33	$	0.96	$	3.64
Diluted	$	0.93		$	0.40		$	1.33	$	0.96	$	3.63
(Loss) income from discontinued operations attributable to Duke Energy Corporation common shareholders
Basic	$	(0.04	)	$	0.08		$	0.09	$	0.01	$	0.13
Diluted	$	(0.04	)	$	0.08		$	0.09	$	0.01	$	0.13
Net income attributable to Duke Energy Corporation common shareholders
Basic	$	0.89		$	0.48		$	1.42	$	0.97	$	3.77
Diluted	$	0.89		$	0.48		$	1.42	$	0.97	$	3.76

(a) Operating results reflect reclassifications due to the impact of discontinued operations (see Note 2 for further information).

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)	First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2014
Costs to achieve Progress Energy merger (see Note 2)	$	(55	)	$	(61	)	$	(56	)	$	(33	)	$	(205	)
Midwest Generation Impairment (see Note 2)	(1,287		)	—			477			(39		)	(849		)
Coal ash Plea Agreements Reserve (see Note 5)	—			—			—			(102		)	(102		)
International Tax Adjustment (see Note 22)	—			—			—			(373		)	(373		)
Asset Impairment (see Note 11)	(94		)	—			—			—			(94		)
Total	$	(1,436	)	$	(61	)	$	421		$	(547	)	$	(1,623	)
2013(a)
Costs to achieve Progress Energy merger (see Note 2)	$	(55	)	$	(82	)	$	(88	)	$	(72	)	$	(297	)
Crystal River Unit 3 charges (see Note 4)	—			(295		)	—			(57		)	(352		)
Harris and Levy nuclear development charges (see Note 4)	—			(87		)	—			—			(87		)
Gain on sale of DukeNet (see Note 12)	—			—			—			105			105
Total	$	(55	)	$	(464	)	$	(88	)	$	(24	)	$	(631	)

(a) Revised retail rates became effective in January for Duke Energy Florida, May for Duke Energy Ohio, June for Duke Energy Progress and September for Duke Energy Carolinas (see Note 4 for further information).

DUKE ENERGY CAROLINAS

(in millions)	First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total
2014
Operating revenues	$	2,000	$	1,755	$	1,938	$	1,658	$	7,351
Operating income	509		438		630		318		1,895
Net income	286		270		377		139		1,072
2013
Operating revenues	$	1,729	$	1,591	$	1,919	$	1,715	$	6,954
Operating income	434		351		604		420		1,809
Net income	244		181		342		209		976

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)	First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2014
Costs to achieve Progress Energy merger (see Note 2)	$	(29	)	$	(38	)	$	(25	)	$	(17	)	$	(109	)
Coal ash Plea Agreements Reserve (see Note 5)	—			—			—			(72		)	(72		)
Total	(29		)	(38		)	(25		)	(89		)	(181		)
2013(a)
Costs to achieve Progress Energy merger (see Note 2)	$	(22	)	$	(35	)	$	(34	)	$	(29	)	$	(120	)

(a) Revised retail rates became effective in September in both North Carolina and South Carolina (see Note 4 for further information).

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DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

PROGRESS ENERGY

(in millions)	First Quarter		Second Quarter			Third Quarter		Fourth Quarter		Total
2014
Operating revenues	$	2,541	$	2,421		$	2,863	$	2,341	$	10,166
Operating income	477		488			665		388		2,018
Income from continuing operations	204		207			330		139		880
Net income	203		202			330		139		874
Net income attributable to Parent	202		202			329		136		869
2013
Operating revenues	$	2,186	$	2,281		$	2,766	$	2,300	$	9,533
Operating income	430		114			671		403		1,618
Income (loss) from continuing operations	154		(13		)	328		190		659
Net income (loss)	154		(17		)	342		196		675
Net income (loss) attributable to Parent	153		(17		)	341		195		672

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)	First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2014
Costs to achieve the merger with Duke Energy (see Note 2)	$	(19	)	$	(12	)	$	(21	)	$	(13	)	$	(65	)
Coal ash Plea Agreements Reserve (see Note 5)	—			—			—			(30		)	(30		)
Total	(19		)	(12		)	(21		)	(43		)	(95		)
2013(a)
Costs to achieve the merger with Duke Energy (see Note 2)	$	(19	)	$	(33	)	$	(42	)	$	(28	)	$	(122	)
Crystal River Unit 3 charges (see Note 4)	—			(295		)	—			(57		)	(352		)
Harris and Levy nuclear development charges (see Note 4)	—			(87		)	—			—			(87		)
Total	$	(19	)	$	(415	)	$	(42	)	$	(85	)	$	(561	)

(a) Revised retail rates became effective in January in Florida and June in North Carolina (see Note 4 for further information).

DUKE ENERGY PROGRESS

(in millions)	First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total
2014
Operating revenues	$	1,422	$	1,191	$	1,367	$	1,196	$	5,176
Operating income	258		212		285		180		935
Net income	133		101		157		76		467
2013
Operating revenues	$	1,216	$	1,135	$	1,430	$	1,211	$	4,992
Operating income	212		166		303		251		932
Net income	110		77		175		138		500

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)	First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2014
Costs to achieve the merger with Duke Energy (see Note 2)	$	(14	)	$	(3	)	$	(15	)	$	(10	)	$	(42	)
Coal ash Plea Agreements Reserve (see Note 5)	—			—			—			(30		)	(30		)
Total	(14		)	(3		)	(15		)	(40		)	(72		)
2013(a)
Costs to achieve the merger with Duke Energy (see Note 2)	$	(11	)	$	(22	)	$	(32	)	$	(19	)	$	(84	)
Harris nuclear development charges (see Note 4)	$	—		$	(22	)	$	—		$	—		$	(22	)
Total	$	(11	)	$	(44	)	$	(32	)	$	(19	)	$	(106	)

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PART II

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

(a) Revised retail rates became effective in June in North Carolina (see Note 4 for further information).

DUKE ENERGY FLORIDA

(in millions)	First Quarter		Second Quarter			Third Quarter		Fourth Quarter		Total
2014
Operating revenues	$	1,116	$	1,225		$	1,491	$	1,143	$	4,975
Operating income	219		276			378		205		1,078
Net income	108		142			205		93		548
2013
Operating revenues	$	968	$	1,142		$	1,332	$	1,085	$	4,527
Operating income (loss)	221		(53		)	369		151		688
Net income (loss)	110		(57		)	197		75		325

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)	First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2014
Costs to achieve the merger with Duke Energy (see Note 2)	$	(5	)	$	(9	)	$	(6	)	$	(3	)	$	(23	)
2013(a)
Costs to achieve the merger with Duke Energy (see Note 2)	$	(8	)	$	(11	)	$	(10	)	$	(9	)	$	(38	)
Crystal River Unit 3 charges (see Note 4)	—			(295		)	—			(57		)	(352		)
Levy nuclear development charges (see Note 4)	—			(65		)	—			—			(65		)
Total	$	(8	)	$	(371	)	$	(10	)	$	(66	)	$	(455	)

(a) Revised retail rates became effective in January (see Note 4 for further information).

DUKE ENERGY OHIO

(in millions)	First Quarter(a)			Second Quarter(a)			Third Quarter(a)		Fourth Quarter(a)			Total
2014												��
Operating revenues	$	575		$	412		$	446	$	480		$	1,913
Operating (loss) income	(7		)	62			58		74			187
(Loss) income from discontinued operations, net of tax	(875		)	(135		)	413		34			(563		)
Net (loss) income	(890		)	(108		)	439		64			(495		)
2013
Operating revenues	$	503		$	408		$	438	$	456		$	1,805
Operating income	56			27			50		49			182
(Loss) income from discontinued operations, net of tax	(47		)	51			35		(4		)	35
Net (loss) income	(21		)	58			59		6			102

(a) Operating results reflect reclassifications due to the impact of discontinued operations (see Note 2 for further information).

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)	First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2014
Costs to achieve Progress Energy merger (see Note 2)	$	(2	)	$	(4	)	$	(3	)	$	(2	)	$	(11	)
Midwest Generation Impairment (see Note 2)	(1,318		)	—			477			(39		)	(880		)
Asset Impairment (see Note 11)	(94		)	—			—			—			(94		)
Total	$	(1,414	)	$	(4	)	$	474		$	(41	)	$	(985	)
2013(a)
Costs to achieve Progress Energy merger (see Note 2)	$	(4	)	$	(4	)	$	(4	)	$	(4	)	$	(16	)

(a) Revised retail rates became effective in May (see Note 4 for further information).

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PART II

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

DUKE ENERGY PROGRESS, INC. – DUKE ENERGY FLORIDA, INC. - DUKE ENERGY OHIO, INC. - DUKE ENERGY INDIANA, INC.

Combined Notes To Consolidated Financial Statements – (Continued)

DUKE ENERGY INDIANA

(in millions)	First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total
2014
Operating revenues	$	845	$	748	$	790	$	792	$	3,175
Operating income	215		178		182		130		705
Net income	113		87		101		58		359
2013
Operating revenues	$	724	$	700	$	755	$	747	$	2,926
Operating income	181		168		203		181		733
Net income	90		82		104		82		358

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)	First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2014
Costs to achieve Progress Energy merger (see Note 2)	$	(2	)	$	(5	)	$	(3	)	$	(2	)	$	(12	)
2013
Costs to achieve Progress Energy merger (see Note 2)	$	(4	)	$	(5	)	$	(5	)	$	(5	)	$	(19	)

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PART II

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed by the Duke Energy Registrants in the reports they file or submit under the Securities Exchange Act of 1934 (Exchange Act) 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 December 31, 2014, 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(f) and 15d-15(f) under the Exchange Act) that occurred during the fiscal quarter ended December 31, 2014 and have concluded no change has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

Management’s Annual Report On Internal Control Over Financial Reporting

The Duke Energy Registrants’ management is responsible for establishing and maintaining an adequate system of internal control over financial reporting, as such term is defined in Exchange Act Rules 13a−15(f) and 15d−15(f). The Duke Energy Registrants’ internal control system was designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes, in accordance with generally accepted accounting principles in the United States. Due to inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness of the internal control over financial reporting to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with policies and procedures may deteriorate.

The Duke Energy Registrants’ management, including their Chief Executive Officer and Chief Financial Officer, has conducted an evaluation of the effectiveness of their internal control over financial reporting as of December 31, 2014 based on the framework in the Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on that evaluation, management concluded that its internal controls over financial reporting were effective as of December 31, 2014.

Deloitte & Touche LLP, Duke Energy’s independent registered public accounting firm, has issued an attestation report on the effectiveness of Duke Energy’s internal control over financial reporting.

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PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

Duke Energy will provide information that is responsive to this Item 10 in its definitive proxy statement or in an amendment to this Annual Report not later than 120 days after the end of the fiscal year covered by this Annual Report. That information is incorporated in this Item 10 by reference.

ITEM 11. EXECUTIVE COMPENSATION

Duke Energy will provide information that is responsive to this Item 11 in its definitive proxy statement or in an amendment to this Annual Report not later than 120 days after the end of the fiscal year covered by this Annual Report. That information is incorporated in this Item 11 by reference.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

Duke Energy will provide information that is responsive to this Item 12 in its definitive proxy statement or in an amendment to this Annual Report not later than 120 days after the end of the fiscal year covered by this Annual Report. That information is incorporated in this Item 12 by reference.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

Duke Energy will provide information that is responsive to this Item 13 in its definitive proxy statement or in an amendment to this Annual Report not later than 120 days after the end of the fiscal year covered by this Annual Report. That information is incorporated in this Item 13 by reference.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES

Deloitte & Touche LLP, and the member firms of Deloitte Touche Tohmatsu and their respective affiliates (collectively, Deloitte) provided professional services to the Duke Energy Registrants. The following tables present the Deloitte fees for services rendered to the Duke Energy Registrants during 2014 and 2013.

	Year Ended December 31, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Types of Fees
Audit Fees(a)	$	12.0	$	4.2	$	4.6	$	2.6	$	2.0	$	1.2	$	1.2
Audit-Related Fees(b)	4.2		0.1		0.1		0.1		—		2.6		—
Tax Fees(c)	0.7		0.3		0.3		0.2		0.1		0.1		0.1
Total Fees	$	16.9	$	4.6	$	5.0	$	2.9	$	2.1	$	3.9	$	1.3

	Year Ended December 31, 2013
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Types of Fees
Audit Fees(a)	$	11.5	$	4.1	$	4.3	$	2.5	$	1.8	$	1.3	$	1.2
Audit-Related Fees(b)	2.3		0.4		0.2		0.1		0.1		—		—
Tax Fees(c)	0.5		0.2		0.2		0.1		0.1		0.1		0.1
Total Fees	$	14.3	$	4.7	$	4.7	$	2.7	$	2.0	$	1.4	$	1.3

(a) Audit Fees are fees billed or expected to be billed for professional services for the audit of the Duke Energy Registrants’ financial statements included in the annual report on Form 10-K and the review of financial statements included in quarterly reports on

Form 10-Q, for services that are normally provided by Deloitte in connection with statutory, regulatory or other filings or engagements or for any other service performed by Deloitte to comply with generally accepted auditing standards.

(b) Audit-Related Fees are fees for assurance and related services that are reasonably related to the performance of an audit or review of financial statements, including assistance with acquisitions and divestitures and internal control reviews.

(c) Tax Fees are fees for tax return assistance and preparation, tax examination assistance, and professional services related to tax planning and tax strategy.

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PART III

To safeguard the continued independence of the independent auditor, the Audit Committee of the Board of Directors (Duke Energy Audit Committee) adopted a policy that provides the independent public auditor is only permitted to provide services to Duke Energy and its consolidated subsidiaries, including the Subsidiary Registrants that have been pre-approved by the Duke Energy Audit Committee. Pursuant to the policy, detailed audit services, audit-related services, tax services and certain other services have been specifically pre-approved up to certain fee limits. In the event the cost of any of these services may exceed the pre-approved limits, the Duke Energy Audit Committee must pre-approve the service. All other services that are not prohibited pursuant to the Securities and Exchange Commission’s or other applicable regulatory bodies’ rules of regulations must be specifically pre-approved by the Duke Energy Audit Committee. All services performed in in 2014 and 2013 by the independent public accountant were approved by the Duke Energy Audit Committee pursuant to their pre-approval policies.

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PART IV

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

(a) Consolidated Financial Statements, Supplemental Financial Data and Supplemental Schedules included in Part II of this annual report are as follows:

Duke Energy Corporation

Consolidated Financial Statements

Consolidated Statements of Operations for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Balance Sheets as of December 31, 2014 and 2013

Consolidated Statements of Cash Flows for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Statements of Changes in Equity for the Years Ended December 31, 2014, 2013 and 2012

Notes to the Consolidated Financial Statements

Quarterly Financial Data, (unaudited, included in Note 25 to the Consolidated Financial Statements)

Report of Independent Registered Public Accounting Firm

All other schedules are omitted because they are not required, or because the required information is included in the Consolidated Financial Statements or Notes.

Duke Energy Carolinas, LLC

Consolidated Financial Statements

Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Balance Sheets as of December 31, 2014 and 2013

Consolidated Statements of Cash Flows for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Statements of Changes in Member’s Equity for the Years Ended December 31, 2014, 2013 and 2012

Notes to the Consolidated Financial Statements

Quarterly Financial Data, (unaudited, included in Note 25 to the Consolidated Financial Statements)

Report of Independent Registered Public Accounting Firm

All other schedules are omitted because they are not required, or because the required information is included in the Consolidated Financial Statements or Notes.

Progress Energy, Inc.

Consolidated Financial Statements

Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Balance Sheets as of December 31, 2014 and 2013

Consolidated Statements of Cash Flows for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Statements of Changes in Common Stockholder’s Equity for the Years Ended December 31, 2014, 2013 and 2012

Notes to the Consolidated Financial Statements

Quarterly Financial Data, (unaudited, included in Note 25 to the Consolidated Financial Statements)

Report of Independent Registered Public Accounting Firm

All other schedules are omitted because they are not required, or because the required information is included in the Consolidated Financial Statements or Notes.

Duke Energy Progress, Inc.

Consolidated Financial Statements

Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Balance Sheets as of December 31, 2014 and 2013

Consolidated Statements of Cash Flows for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Statements of Changes in Common Stockholder’s Equity for the Years Ended December 31, 2014, 2013 and 2012

Notes to the Consolidated Financial Statements

Quarterly Financial Data, (unaudited, included in Note 25 to the Consolidated Financial Statements)

Report of Independent Registered Public Accounting Firm

All other schedules are omitted because they are not required, or because the required information is included in the Consolidated Financial Statements or Notes.

Duke Energy Florida, Inc.

Consolidated Financial Statements

Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Balance Sheets as of December 31, 2014 and 2013

Consolidated Statements of Cash Flows for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Statements of Changes in Common Stockholder’s Equity for the Years Ended December 31, 2014, 2013 and 2012

Notes to the Consolidated Financial Statements

Quarterly Financial Data, (unaudited, included in Note 25 to the Consolidated Financial Statements)

Report of Independent Registered Public Accounting Firm

All other schedules are omitted because they are not required, or because the required information is included in the Consolidated Financial Statements or Notes.

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PART IV

Duke Energy Ohio, Inc.

Consolidated Financial Statements

Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Balance Sheets as of December 31, 2014 and 2013

Consolidated Statements of Cash Flows for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Statements of Changes in Common Stockholder’s Equity for the Years Ended December 31, 2014, 2013 and 2012

Notes to the Consolidated Financial Statements

Quarterly Financial Data, (unaudited, included in Note 25 to the Consolidated Financial Statements)

Report of Independent Registered Public Accounting Firm

All other schedules are omitted because they are not required, or because the required information is included in the Consolidated Financial Statements or Notes.

Duke Energy Indiana, Inc.

Consolidated Financial Statements

Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Balance Sheets as of December 31, 2014 and 2013

Consolidated Statements of Cash Flows for the Years Ended December 31, 2014, 2013 and 2012

Consolidated Statements of Changes in Common Stockholder’s Equity for the Years Ended December 31, 2014, 2013 and 2012

Notes to the Consolidated Financial Statements

Quarterly Financial Data, (unaudited, included in Note 25 to the Consolidated Financial Statements)

Report of Independent Registered Public Accounting Firm

All other schedules are omitted because they are not required, or because the required information is included in the Consolidated Financial Statements or Notes.

(b) Exhibits — See Exhibit Index immediately following the signature page.

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PART IV

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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.

Date: February 27, 2015

DUKE ENERGY CORPORATION (Registrant)
By:	/s/ LYNN J. GOOD
	Lynn J. Good Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

(i)	/s/ LYNN J. GOOD
	Lynn J. Good
	Vice Chairman, President and Chief Executive Officer (Principal Executive Officer and Director)
(ii)	/s/ STEVEN K. YOUNG
	Steven K. Young
	Executive Vice President and Chief Financial Officer (Principal Financial Officer)
(iii)	/s/ BRIAN D. SAVOY
	Brian D. Savoy
	Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)
(iv)	Directors:
	G. Alex Bernhardt, Sr.*	James B. Hyler, Jr.*
	Michael G. Browning*	William E. Kennard *
	Harris E. DeLoach, Jr.*	E. Marie McKee*
	Daniel R. DiMicco*	Richard A. Meserve*
	John H. Forsgren*	E. James Reinsch*
	Ann Maynard Gray*	James T. Rhodes*
	James H. Hance, Jr.*	Carlos A. Saladrigas*
	John T. Herron*

Steven K. Young, by signing his name hereto, does hereby sign this document on behalf of the registrant and on behalf of each of the above-named persons previously indicated by asterisk (*) pursuant to a power of attorney duly executed by the registrant and such persons, filed with the Securities and Exchange Commission as an exhibit hereto.

By:		/s/ STEVEN K. YOUNG
	Attorney-In-Fact

 Date: February 27, 2015

245

PART IV

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: February 27, 2015

DUKE ENERGY CAROLINAS, LLC (Registrant)
By:	/s/ LYNN J. GOOD
	Lynn J. Good Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

(i)	/s/ LYNN J. GOOD
	Lynn J. Good
	Chief Executive Officer (Principal Executive Officer)
(ii)	/s/ STEVEN K.YOUNG
	Steven K. Young
	Executive Vice President and Chief Financial Officer (Principal Financial Officer)
(iii)	/s/ BRIAN D. SAVOY
	Brian D. Savoy
	Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)
(iv)	Directors:
	/s/ LYNN J. GOOD
	Lynn J. Good
	/s/ B. KEITH TRENT
	B. Keith Trent
	/s/ LLOYD M. YATES
	Lloyd M. Yates

Date: February 27, 2015

246

PART IV

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: February 27, 2015

PROGRESS ENERGY, INC. (Registrant)
By:	/s/ LYNN J. GOOD
	Lynn J. Good Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

(i)	/s/ LYNN J. GOOD
	Lynn J. Good
	Chief Executive Officer (Principal Executive Officer)
(ii)	/s/ STEVEN K. YOUNG
	Steven K. Young
	Executive Vice President and Chief Financial Officer (Principal Financial Officer)
(iii)	/s/ BRIAN D. SAVOY
	Brian D. Savoy
	Chief Accounting Officer and Controller (Principal Accounting Officer)
(iv)	Directors:
	/s/ LYNN J. GOOD
	Lynn J. Good
	/s/ JULIA S. JANSON
	Julia S. Janson

Date: February 27, 2015

247

PART IV

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: February 27, 2015

DUKE ENERGY PROGRESS, INC. (Registrant)
By:	/s/ LYNN J. GOOD
	Lynn J. Good Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

(i)	/s/ LYNN J. GOOD
	Lynn J. Good
	Chief Executive Officer (Principal Executive Officer)
(ii)	/s/ STEVEN K. YOUNG
	Steven K. Young
	Executive Vice President and Chief Financial Officer (Principal Financial Officer)
(iii)	/s/ BRIAN D. SAVOY
	Brian D. Savoy
	Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)
(iv)	Directors:
	/s/ LYNN J. GOOD
	Lynn J. Good
	/s/ DHIAA M. JAMIL
	Dhiaa M. Jamil
	/s/ JULIA S. JANSON
	Julia S. Janson
	/s/ B. KEITH TRENT
	B. Keith Trent
	/s/ LLOYD M. YATES
	Lloyd M. Yates

Date: February 27, 2015

248

PART IV

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: February 27, 2015

DUKE ENERGY FLORIDA, INC. (Registrant)
By:	/s/ LYNN J. GOOD
	Lynn J. Good Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

(i)	/s/ LYNN J. GOOD
	Lynn J. Good
	Chief Executive Officer (Principal Executive Officer)
(ii)	/s/ STEVEN K. YOUNG
	Steven K. Young
	Executive Vice President and Chief Financial Officer (Principal Financial Officer)
(iii)	/s/ BRIAN D. SAVOY
	Brian D. Savoy
	Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)
(iv)	Directors:
	/s/ LYNN J. GOOD
	Lynn J. Good
	/s/ DHIAA M. JAMIL
	Dhiaa M. Jamil
	/s/ JULIA S. JANSON
	Julia S. Janson
	/s/ B. KEITH TRENT
	B. Keith Trent
	/s/ LLOYD M. YATES
	Lloyd M. Yates

Date: February 27, 2015

249

PART IV

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: February 27, 2015

DUKE ENERGY OHIO, INC. (Registrant)
By:	/s/ LYNN J. GOOD
	Lynn J. Good Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

(i)	/s/ LYNN J. GOOD
	Lynn J. Good
	Chief Executive Officer (Principal Executive Officer)
(ii)	/s/ STEVEN K. YOUNG
	Steven K. Young
	Executive Vice President and Chief Financial Officer (Principal Financial Officer)
(iii)	/s/ BRIAN D. SAVOY
	Brian D. Savoy
	Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)
(iv)	Directors:
	/s/ LYNN J. GOOD
	Lynn J. Good
	/s/ B. KEITH TRENT
	B. Keith Trent
	/s/ LLOYD M. YATES
	Lloyd M. Yates

Date: February 27, 2015

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PART IV

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: February 27, 2015

DUKE ENERGY INDIANA, INC. (Registrant)
By:	/s/ LYNN J. GOOD
	Lynn J. Good Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

(i)	/s/ LYNN J. GOOD
	Lynn J. Good
	Chief Executive Officer (Principal Executive Officer)
(ii)	/s/ STEVEN K. YOUNG
	Steven K. Young
	Executive Vice President and Chief Financial Officer (Principal Financial Officer)
(iii)	/s/ BRIAN. D. SAVOY
	Brian D. Savoy
	Senior Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)
(iv)	Directors:
	/s/ DOUGLAS F ESAMANN
	Douglas F. Esamann
	/s/ KELLEY A. KARN
	Kelley A. Karn
	/s/ LLOYD M. YATES
	Lloyd M. Yates

Date: February 27, 2015

251

PART IV

EXHIBIT INDEX

Exhibits filed herewithin 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 (***). A management contract or compensation plan or arrangement under legacy Progress Energy that is required to be filed as an exhibit to this report pursuant to Item 15 (b) of Form 10-K is designated by a plus (+).

Exhibit  Number		Duke Energy	Duke Energy Carolinas	Progress Energy	Duke Energy Progress	Duke Energy Florida	Duke Energy Ohio		Duke Energy Indiana
2.1	Agreement and Plan of Merger between Duke Energy Corporation, Diamond Acquisition Corporation and Progress Energy, Inc., dated as of January 8, 2011, (incorporated by reference to Exhibit 2.1 to Duke Energy Corporation's Current Report on Form 8-K filed on January 11, 2011, File No. 1-32853).	X
3.1	Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to Duke Energy Corporation's Current Report on Form 8-K filed on May 20, 2014, File No. 1-32853).	X
3.2	Articles of Organization including Articles of Conversion (incorporated by reference to Exhibit 3.1 to Duke Energy Carolinas, LLC's Current Report on Form 8-K filed on April 7, 2006, File No. 1-04928).		X
3.2.1	Amended Articles of Organization, effective October 1, 2006, (incorporated by reference to Exhibit 3.1 to Duke Energy Carolinas, LLC's Quarterly Report on Form 10-Q for the quarter ended September 30, 2006 filed on November 13, 2006, File No. 1-04928).		X
3.3	Amended Articles of Consolidation of Duke Energy Ohio, Inc. (formerly The Cincinnati Gas & Electric Company), effective October 23, 1996, (incorporated by reference to Exhibit 3(a) to registrant's Quarterly Report on Form 10-Q for the quarter ended September 30, 1996 filed on November 13, 1996, File No. 1-01232).						X
3.3.1	Amended Articles of Consolidation, effective October 1, 2006, (incorporated by reference to Exhibit 3.1 to Duke Energy Ohio, Inc.'s (formerly The Cincinnati Gas & Electric Company) Quarterly Report on Form 10-Q for the quarter ended September 30, 2006 filed on November 17, 2006, File No. 1-01232).						X
3.4	Amended Articles of Consolidation of Duke Energy Indiana, Inc. (formerly PSI Energy Inc.), effective April 20, 1995, (incorporated by reference to Exhibit 3(a) to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 1995 filed on August 11, 1995, File No. 1-03543).								X
3.4.1	Amendment to Article D of the Amended Articles of Consolidation of Duke Energy Indiana, Inc. (formerly PSI Energy Inc.), effective July 10, 1997, (incorporated by reference to Exhibit 3(f) to registrant's Annual Report on Form 10-K for the year ended December 31, 1997 filed on March 27, 1998, File No. 1-03543).								X
3.4.2	Amended Articles of Consolidation, effective October 1, 2006, (incorporated by reference to Exhibit 3.1 to Duke Energy Indiana, Inc.'s (formerly PSI Energy, Inc.) Quarterly Report on Form 10-Q for the quarter ended September 30, 2006 filed on November 17, 2006, File No. 1-03543).								X
3.5	Amended and Restated By-Laws of Duke Energy Corporation (incorporated by reference to Exhibit 3.1 to registrant's Current Report on Form 8-K filed on November 3, 2014, File No. 1-32853).	X
3.6	Limited Liability Company Operating Agreement of Duke Energy Carolinas, LLC (incorporated by reference to Exhibit 3.2 to registrant's Current Report on Form 8-K filed on April 7, 2006, File No. 1-04928).		X
3.7	Regulations of Duke Energy Ohio, Inc. (formerly The Cincinnati Gas & Electric Company), effective July 23, 2003, (incorporated by reference to Exhibit 3.2 to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2003 filed on August 13, 2003, File No. 1-01232).						X
3.8	By-Laws of Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.), effective July 23, 2003, (incorporated by reference to Exhibit 3.1 to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2003 filed on August 13, 2003, File No. 1-03543).								X
3.9	Restated Charter of Duke Energy Progress (formerly Carolina Power & Light Company), effective May 10, 1996, (incorporated by reference to Exhibit 3(i) to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 1997 filed on August 13, 1997, File No. 1-03382).				X
3.10	Amended and Restated Articles of Incorporation of Progress Energy, Inc. (formerly CP&L Energy, Inc.), effective June 15, 2000, (incorporated by reference to Exhibit 3(a)(1) to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2000 filed on August 14, 2000, File No. 1-03382).			X
3.10.1	Articles of Amendment to the Amended and Restated Articles of Incorporation of Progress Energy, Inc. (formerly CP&L Energy, Inc.), effective December 4, 2000, (incorporated by reference to Exhibit 3(b)(1) to registrant's Annual Report on Form 10-K for the year ended December 31, 2001 filed on March 28, 2002, File No. 1-03382).			X
3.10.2	Articles of Amendment to the Amended and Restated Articles of Incorporation of Progress Energy, Inc. (formerly CP&L Energy, Inc.), effective May 10, 2006, (incorporated by reference to Exhibit 3(a) to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2006 filed on August 9, 2006, File No. 1-15929).			X
3.11	Amended Articles of Incorporation of Duke Energy Florida, Inc. (formerly Florida Power Corporation) (incorporated by reference to Exhibit 3(a) to registrant's Annual Report on Form 10-K for the year ended December 31, 1991 filed on March 30, 1992, File No. 1-03274).					X
3.12	By-Laws of Progress Energy, Inc. (formerly CP&L Energy, Inc.), effective May 10, 2006, (incorporated by reference to Exhibit 3(b) to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2006 filed on August 9, 2006, File No. 1-15929).			X
3.13	By-Laws of Duke Energy Progress, Inc. (formerly Carolina Power & Light Company), effective May 13, 2009, (incorporated by reference to Exhibit 3(b) to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2009 filed on August 7, 2009, File No. 1-15929).				X
3.14	By-Laws of Duke Energy Florida, Inc. (formerly Florida Power Corporation), effective September 20, 2010, (incorporated by reference to Exhibit 3.1 to registrant's Current Report on Form 8-K filed on September 20, 2010, File No. 1-3274).					X
4.1	Indenture between Duke Energy Corporation and The Bank of New York Mellon Trust Company, N.A., as Trustee, dated as of June 3, 2008, (incorporated by reference to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on June 16, 2008, File No. 1-32853).	X
4.1.1	First Supplemental Indenture, dated as of June 16, 2008, (incorporated by reference to Exhibit 4.2 to Duke Energy Corporation's Current Report on Form 8-K filed on June 16, 2008, File No. 1-32853).	X
4.1.2	Second Supplemental Indenture, dated as of January 26, 2009, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on January 26, 2009, File No. 1-32853).	X
4.1.3	Third Supplemental Indenture, dated as of August 28, 2009, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on August 28, 2009, File No. 1-32853).	X
4.1.4	Fourth Supplemental Indenture, dated as of March 25, 2010, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on March 25, 2010, File No. 1-32853).	X
4.1.5	Fifth Supplemental Indenture, dated as of August 25, 2011, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on August 25, 2011, File No. 1-32853).	X
4.1.6	Sixth Supplemental Indenture, dated as of November 17, 2011, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on November 17, 2011, File No. 1-32853).	X
4.1.7	Seventh Supplemental Indenture, dated as of August 16 , 2012, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on August 16, 2012, File No. 1-32853).	X
4.1.8	Eighth Supplemental Indenture, dated as of January 14, 2013, (incorporated by reference to Exhibit 2 to Duke Energy Corporation's Form 8-A filed on January 14, 2013, File No. 1-32853).	X
4.1.9	Ninth Supplemental Indenture, dated as of June 13, 2013, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on June 13, 2013, File No. 1-32853).	X
4.1.10	Tenth Supplemental Indenture, dated as of October 11, 2013, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on October 11, 2013, File No.1-32853).	X
4.1.11	Eleventh Supplemental Indenture, dated as of April 4, 2014, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on April 4, 2014, File No. 1-32853).	X
4.2	Senior Indenture between Duke Energy Carolinas, LLC and The Bank of New York Mellon Trust Company, N.A., as successor trustee to JPMorgan Chase Bank (formerly known as The Chase Manhattan Bank), dated as of September 1, 1998, (incorporated by reference to Exhibit 4-D-1 to registrant's Post-Effective Amendment No. 2 to Registration Statement on Form S-3 filed on April 7, 1999, File No. 333-14209).		X
4.2.1	Fifteenth Supplemental Indenture, dated as of April 3, 2006, (incorporated by reference to Exhibit 4.4.1 to registrant's Registration Statement on Form S-3 filed on October 3, 2007, File No. 333-146483-03).		X
4.2.2	Sixteenth Supplemental Indenture, dated as of June 5, 2007, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on June 6, 2007, File No. 1-04928).		X
4.3	First and Refunding Mortgage from Duke Energy Carolinas, LLC to The Bank of New York Mellon Trust Company, N.A., successor trustee to Guaranty Trust Company of New York, dated as of December 1, 1927, (incorporated by reference to Exhibit 7(a) to registrant's Form S-1, effective October 15, 1947, File No. 2-7224).		X
4.3.1	Instrument of Resignation, Appointment and Acceptance among Duke Energy Carolinas, LLC, JPMorgan Chase Bank, N.A., as Trustee, and The Bank of New York Mellon Trust Company, N.A., as Successor Trustee, dated as of September 24, 2007, (incorporated by reference to Exhibit 4.6.1 to registrant's Registration Statement on Form S-3 filed on October 3, 2007, File No. 333-146483).		X
4.3.2	Ninth Supplemental Indenture, dated as of February 1, 1949, (incorporated by reference to Exhibit 7 (j) to registrant's Form S-1 filed on February 3, 1949, File No. 2-7808).		X
4.3.3	Twentieth Supplemental Indenture, dated as of June 15, 1964, (incorporated by reference to Exhibit 4-B-20 to registrant's Form S-1 filed on August 23, 1966, File No. 2-25367).		X
4.3.4	Twenty-third Supplemental Indenture, dated as of February 1, 1968, (incorporated by reference to Exhibit 2-B-26 to registrant's Form S-9 filed on January 21, 1969, File No. 2-31304).		X
4.3.5	Sixtieth Supplemental Indenture, dated as of March 1, 1990, (incorporated by reference to Exhibit 4-B-61 to registrant's Annual Report on Form 10-K for the year ended December 31, 1990, File No.1-04928).		X
4.3.6	Sixty-third Supplemental Indenture, dated as of July 1, 1991, (incorporated by reference to Exhibit 4-B-64 to registrant's Registration Statement on Form S-3 filed on February 13, 1992, File No. 33-45501).		X
4.3.7	Eighty-fourth Supplemental Indenture, dated as of March 20, 2006, (incorporated by reference to Exhibit 4.6.9 to registrant's Registration Statement on Form S-3 filed on October 3, 2007, File No. 333-146483-03).		X
4.3.8	Eighty-fifth Supplemental Indenture, dated as of January 10, 2008, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on January 11, 2008, File No.1-04928).		X
4.3.9	Eighty-seventh Supplemental Indenture, dated as of April 14, 2008, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on April 15, 2008, File No.1-04928).		X
4.3.10	Eighty-eighth Supplemental Indenture, dated as of November 17, 2008, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on November 20, 2008, File No.1-04928).		X
4.3.11	Ninetieth Supplemental Indenture, dated as of November 19, 2009, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on November 19, 2009, File No.1-04928).		X
4.3.12	Ninety-first Supplemental Indenture, dated as of June 7, 2010, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on June 7, 2010, File No.1-04928).		X
4.3.13	Ninety-third Supplemental Indenture, dated as of May 19, 2011, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on May 19, 2011, File No.1-04928).		X
4.3.14	Ninety-fourth Supplemental Indenture, dated as of December 8, 2011, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on December 8, 2011, File No.1-04928).		X
4.3.15	Ninety-fifth Supplemental Indenture, dated as of September 21, 2012, (incorporated by reference to Exhibit 4.1 to Duke Energy Carolinas, LLC’s Current Report on Form 8-K filed on September 21, 2012, File No.1-04928).		X
4.4	Mortgage and Deed of Trust between Duke Energy Progress, Inc. (formerly Carolina Power & Light Company) and The Bank of New York Mellon (formerly Irving Trust Company) and Frederick G. Herbst (Tina D. Gonzalez, successor), as Trustees, dated as of May 1, 1940.				X
4.4.1	First through Fifth Supplemental Indentures thereto (Exhibit 2(b), File No. 2-64189); the Sixth through Sixty-sixth Supplemental Indentures (Exhibit 2(b)-5, File No. 2-16210; Exhibit 2(b)-6, File No. 2-16210; Exhibit 4(b)-8, File No. 2-19118; Exhibit 4(b)-2, File No. 2-22439; Exhibit 4(b)-2, File No. 2-24624; Exhibit 2(c), File No. 2-27297; Exhibit 2(c), File No. 2-30172; Exhibit 2(c), File No. 2-35694; Exhibit 2(c), File No. 2-37505; Exhibit 2(c), File No. 2-39002; Exhibit 2(c), File No. 2-41738; Exhibit 2(c), File No. 2-43439; Exhibit 2(c), File No. 2-47751; Exhibit 2(c), File No. 2-49347; Exhibit 2(c), File No. 2-53113; Exhibit 2(d), File No. 2-53113; Exhibit 2(c), File No. 2-59511; Exhibit 2(c), File No. 2-61611; Exhibit 2(d), File No. 2-64189; Exhibit 2(c), File No. 2-65514; Exhibits 2(c) and 2(d), File No. 2-66851; Exhibits 4(b)-1, 4(b)-2, and 4(b)-3, File No. 2-81299; Exhibits 4(c)-1 through 4(c)-8, File No. 2-95505; Exhibits 4(b) through 4(h), File No. 33-25560; Exhibits 4(b) and 4(c), File No. 33-33431; Exhibits 4(b) and 4(c), File No. 33-38298; Exhibits 4(h) and 4(i), File No. 33-42869; Exhibits 4(e)-(g), File No. 33-48607; Exhibits 4(e) and 4(f), File No. 33-55060; Exhibits 4(e) and 4(f), File No. 33-60014; Exhibits 4(a) and 4(b) to Post-Effective Amendment No. 1, File No. 33-38349; Exhibit 4(e), File No. 33-50597; Exhibit 4(e) and 4(f) to Registration Statement on Form S-3, File No. 33-57835, filed on February 24, 1995; Exhibit to the Current Report on Form 8-K filed on August 28, 1997, File No. 1-03382; Exhibit 4(b) to Registration Statement on Form S-3, File No. 333-69237, filed on December 18, 1998; and Exhibit 4(c) to the Current Report on Form 8-K filed on March 19, 1999, File No. 1-03382).				X
4.4.2	Seventy-second Supplemental Indenture, dated as of September 1, 2003, (incorporated by reference to Exhibit 4 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on September 12, 2003, File No. 1-03382).				X
4.4.3	Seventy-third Supplemental Indenture, dated as of March 1, 2005, (incorporated by reference to Exhibit 4 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on March 22, 2005, File No. 1-03382).				X
4.4.4	Seventy-fourth Supplemental Indenture, dated as of November 1, 2005, (incorporated by reference to Exhibit 4 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on November 30, 2005, File No. 1-03382).				X
4.4.5	Seventy-fifth Supplemental Indenture, dated as of March 1, 2008, (incorporated by reference to Exhibit 4 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on March 13, 2008, File No. 1-03382).				X
4.4.6	Seventy-sixth Supplemental Indenture, dated as of January 1, 2009, (incorporated by reference to Exhibit 4 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on January 15, 2009, File No. 1-03382).				X
4.4.7	Seventy-seventh Supplemental Indenture, dated as of June 18, 2009, (incorporated by reference to Exhibit 4 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on June 23, 2009, File No. 1-03382).				X
4.4.8	Seventy-eighth Supplemental Indenture, dated as of September 1, 2011, (incorporated by reference to Exhibit 4 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on September 15, 2011, File No. 1-03382).				X
4.4.9	Seventy-ninth Supplemental Indenture, dated as of May 1, 2012, (incorporated by reference to Exhibit 4 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on May 18, 2012, File No. 1-03382).				X
4.4.10	Eightieth Supplemental Indenture, dated as of March 1, 2013, (incorporated by reference to Exhibit 4.1 to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Current Report on Form 8-K filed on March 12, 2013, File No. 1-03382).				X
4.4.11	Eighty Second Supplemental Indenture, dated as of March 1, 2014, between the Company and The Bank of New York Mellon (formerly Irving Trust Company) and Tina D. Gonzalez (successor to Frederick G. Herbst) and forms of global notes (incorporated by reference to Exhibit 4.1 to Duke Energy Progress, Inc.'s Current Report on Form 8-K filed on March 6, 2014, File No. 1-03382).				X
4.4.12	Eighty Third Supplemental Indenture, dated as of November 1, 2014, between the Company and The Bank of New York Mellon (formerly Irving Trust Company) and Tina D. Gonzalez (successor to Frederick G. Herbst) and forms of global notes (incorporated by reference to Exhibit 4.1 to Duke Energy Progress, Inc.'s Current Report on Form 8-K filed on November 20, 2014, File No. 1-03382).				X
4.5	Indenture (for Debt Securities) between Duke Energy Progress, Inc. (formerly Carolina Power & Light Company) and The Bank of New York Mellon (successor in interest to The Chase Manhattan Bank), as Trustee (incorporated by reference to Exhibit 4(a) to registrant's Current Report on Form 8-K filed on November 5, 1999, File No. 1-03382).				X
4.6	Indenture (for [Subordinated] Debt Securities)(open ended) (incorporated by reference to Exhibit 4(a)(2) to Duke Energy Progress, Inc.'s (formerly Carolina Power & Light Company (d/b/a Progress Energy Carolinas, Inc.)) Registration Statement on Form S-3 filed on November 18, 2008, File No. 333-155418).				X
4.7	Indenture (for First Mortgage Bonds) between Duke Energy Florida, Inc. (formerly Florida Power Corporation) and The Bank of New York Mellon (as successor to Guaranty Trust Company of New York and The Florida National Bank of Jacksonville), as Trustee, dated as of January 1, 1944, (incorporated by reference to Exhibit B-18 to registrant's Form A-2, File No. 2-05293).					X
4.7.1	Seventh Supplemental Indenture (incorporated by reference to Exhibit 4(b) to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation) Registration Statement on Form S-3 filed on September 27, 1991, File No. 33-16788).					X
4.7.2	Eighth Supplemental Indenture (incorporated by reference to Exhibit 4(c) to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation) Registration Statement on Form S-3 filed on September 27, 1991, File No. 33-16788).					X
4.7.3	Sixteenth Supplemental Indenture (incorporated by reference to Exhibit 4(d) to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation) Registration Statement on Form S-3 filed on September 27, 1991, File No. 33-16788).					X
4.7.4	Twenty-ninth Supplemental Indenture (incorporated by reference to Exhibit 4(c) to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation) Registration Statement on Form S-3 filed on September 17, 1982, File No. 2-79832).					X
4.7.5	Thirty-eighth Supplemental Indenture, dated as of July 25, 1994, (incorporated by reference to exhibit 4(f) to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation) Registration Statement on Form S-3 filed on August 29, 1994, File No. 33-55273).					X
4.7.6	Forty-first Supplemental Indenture, dated as of February 1, 2003, (incorporated by reference to Exhibit 4 to Duke Energy Florida, Inc.'s (formerly Duke Energy Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Current Report on Form 8-K filed on February 21, 2003, File No. 1-03274).					X
4.7.7	Forty-second Supplemental Indenture, dated as of April 1, 2003, (incorporated by reference to Exhibit 4 to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Quarterly Report on Form 10-Q for the quarter ended June 30, 2003 filed on August 11, 2003, File No. 1-03274).					X
4.7.8	Forty-third Supplemental Indenture, dated as of November 1, 2003, (incorporated by reference to Exhibit 4 to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Current Report on Form 8-K filed on November 21, 2003, File No. 1-03274).					X
4.7.9	Forty-fourth Supplemental Indenture, dated as of August 1, 2004, (incorporated by reference to Exhibit 4(m) to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Annual Report on Form 10-K for the year ended December 31, 2004 filed on March 16, 2005, File No. 1-03274).					X		��
4.7.10	Forty-sixth Supplemental Indenture, dated as of September 1, 2007, (incorporated by reference to Exhibit 4 to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Current Report on Form 8-K filed on September 19, 2007, File No. 1-03274).					X
4.7.11	Forty-seventh Supplemental Indenture, dated as of December 1, 2007, (incorporated by reference to Exhibit 4 to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Current Report on Form 8-K filed on December 13, 2007, File No. 1-03274).					X
4.7.12	Forty-eighth Supplemental Indenture, dated as of June 1, 2008, (incorporated by reference to Exhibit 4 to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Current Report on Form 8-K filed on June 18, 2008, File No. 1-03274).					X
4.7.13	Forty-ninth Supplemental Indenture, dated as of March 1, 2010, (incorporated by reference to Exhibit 4 to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Current Report on Form 8-K filed on March 25, 2010, File No. 1-03274).					X
4.7.14	Fiftieth Supplemental Indenture, dated as of August 11, 2011, (incorporated by reference to Exhibit 4 to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Current Report on Form 8-K filed on August 18, 2011, File No. 1-03274).					X
4.7.15	Fifty-first Supplemental Indenture, dated as of November 1, 2012, (incorporated by reference to Exhibit 4.1 to Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Current Report on Form 8-K filed on November 20, 2012, File No. 1-03274).					X
4.8	Indenture (for Debt Securities) between Duke Energy Florida, Inc. (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) and The Bank of New York Mellon Trust Company, National Association (successor in interest to J.P. Morgan Trust Company, National Association), as Trustee, dated as of December 7, 2005, (incorporated by reference to Exhibit 4(a) to registrant's Current Report on Form 8-K filed on December 13, 2005, File No. 1-03274).					X
4.9	Indenture (for [Subordinated] Debt Securities)(open ended) (incorporated by reference to Exhibit 4(a)(2) Duke Energy Florida, Inc.'s (formerly Florida Power Corporation (d/b/a Progress Energy Florida, Inc.)) Registration Statement on Form S-3 filed on November 18, 2008, File No. 333-155418).					X
4.10	Original Indenture (Unsecured Debt Securities) between Duke Energy Ohio, Inc. (formerly The Cincinnati Gas & Electric Company) and The Bank of New York Mellon Trust Company, N.A., as Successor Trustee, dated as of May 15, 1995, (incorporated by reference to Exhibit 3 to registrant's Form 8-A filed on July 27, 1995, File No. 1-01232).						X
4.10.1	First Supplemental Indenture, dated as of June 1, 1995, (incorporated by reference to Exhibit 4 B to Duke Energy Ohio, Inc.'s (formerly The Cincinnati Gas & Electric Company) Quarterly Report on Form 10-Q for the quarter ended June 30, 1995 filed on August 11, 1995, File No. 1-01232).						X
4.10.2	Seventh Supplemental Indenture, dated as of June 15, 2003, (incorporated by reference to Exhibit 4.1 to Duke Energy Ohio, Inc.'s (formerly The Cincinnati Gas & Electric Company) Quarterly Report on Form 10-Q for the quarter ended June 30, 2003 filed on August 13, 2003, File No. 1-01232).						X
4.11	Original Indenture (First Mortgage Bonds) between Duke Energy Ohio, Inc. (formerly The Cincinnati Gas & Electric Company) and The Bank of New York Mellon Trust Company, N.A., as Successor Trustee, dated as of August 1, 1936, (incorporated by reference to an exhibit to registrant's Registration Statement No. 2-2374).						X
4.11.1	Fortieth Supplemental Indenture, dated as of March 23, 2009, (incorporated by reference to Exhibit 4.1 to Duke Energy Ohio, Inc.’s (formerly The Cincinnati Gas & Electric Company) Current Report on Form 8-K filed on March 24, 2009, File No. 1-01232).						X
4.11.2	Forty-second Supplemental Indenture, dated as of September 6, 2013, (incorporated by reference to Exhibit 4.1 to Duke Energy Ohio, Inc.’s (formerly The Cincinnati Gas & Electric Company) Current Report on Form 8-K filed on September 6, 2013, File No. 1-01232).						X
4.12	Indenture between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and The Bank of New York Mellon Trust Company, N.A., as Successor Trustee, dated as of November 15, 1996, (incorporated by reference to Exhibit 4(v) to registrant's Annual Report on Form 10-K for the year ended December 31, 1996 filed on March 27, 1997, File No. 1-03543).								X
4.12.1	Third Supplemental Indenture, dated as of March 15, 1998, (incorporated by reference to Exhibit 4 to Duke Energy Indiana, Inc.'s (formerly PSI Energy, Inc.) Annual Report on Form 10-K for the year ended December 31, 1997 filed on March 27, 1998, File No. 1-03543).								X
4.12.2	Eighth Supplemental Indenture, dated as of September 23, 2003, (incorporated by reference to Exhibit 4.2 to Duke Energy Indiana, Inc.'s (formerly PSI Energy, Inc.) Quarterly Report on Form 10-Q for the quarter ended September 30, 2003 filed on November 13, 2003,  File No. 1-03543).								X
4.12.3	Ninth Supplemental Indenture, dated as of October 21, 2005, (incorporated by reference to Exhibit 4.7.3 to Duke Energy Indiana, Inc.'s (formerly PSI Energy, Inc.) Registration Statement on Form S-3 filed on September 29, 2010, File No. 333-169633).								X
4.12.4	Tenth Supplemental Indenture, dated as of June 9, 2006, (incorporated by reference to Exhibit 4.1 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Current Report on Form 8-K filed on June 15, 2006, File No. 1-03543).								X
4.13	Original Indenture (First Mortgage Bonds) between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and Deutsche Bank National Trust Company, as Successor Trustee, dated as of September 1, 1939, (filed as an exhibit in File No. 70-258).								X
4.13.1	Tenth Supplemental Indenture, dated as of July 1, 1952, (filed as an exhibit in File No. 2-9687).								X
4.13.2	Twenty-third Supplemental Indenture, dated as of January 1, 1977, (filed as an exhibit in File No. 2-57828).								X
4.13.3	Twenty-fifth Supplemental Indenture, dated as of September 1, 1978, (filed as an exhibit in File No. 2-62543).								X
4.13.4	Twenty-sixth Supplemental Indenture, dated as of September 1, 1978, (filed as an exhibit in File No. 2-62543).								X
4.13.5	Thirtieth Supplemental Indenture, dated as of August 1, 1980, (filed as an exhibit in File No. 2-68562).								X
4.13.6	Thirty-fifth Supplemental Indenture, dated as of March 30, 1984, (filed as an exhibit to registrant's Annual Report on Form 10-K for the year ended December 31, 1984, File No. 1-03543).								X
4.13.7	Forty-sixth Supplemental Indenture, dated as of June 1, 1990, (filed as an exhibit to registrant's Annual Report on Form 10-K for the year ended December 31, 1991, File No. 1-03543).								X
4.13.8	Forty-seventh Supplemental Indenture, dated as of July 15, 1991, (filed as an exhibit to registrant's Annual Report on Form 10-K for the year ended December 31, 1991, File No. 1-03543).								X
4.13.9	Forty-eighth Supplemental Indenture, dated as of July 15, 1992, (filed as an exhibit to registrant's Annual Report on Form 10-K for the year ended December 31, 1992, File No. 1-03543).								X
4.13.10	Fifty-second Supplemental Indenture, dated as of April 30, 1999, (incorporated by reference to Exhibit 4 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Quarterly Report on Form 10-Q for the quarter ended March 31, 1999 filed on May 13, 1999, File No. 1-03543).								X
4.13.11	Fifty-seventh Supplemental Indenture, dated as of August 21, 2008, (incorporated by reference to Exhibit 4.1 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Current Report Form 8-K filed on August 21, 2008, File No. 1-03543).								X
4.13.12	Fifty-eighth Supplemental Indenture, dated as of December 19, 2008, (incorporated by reference to Exhibit 4.8.12 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Registration Statement on Form S-3 filed on September 29, 2010, File No. 333-169633-02).								X
4.13.13	Fifty-ninth Supplemental Indenture, dated as of March 23, 2009, (incorporated by reference to Exhibit 4.1 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Current Report on Form 8-K filed on March 24, 2009, File No. 1-03543).								X
4.13.14	Sixtieth Supplemental Indenture, dated as of June 1, 2009, (incorporated by reference to Exhibit 4.8.14 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Registration Statement on Form S-3 filed on September 29, 2010, File No. 333-169633-02).								X
4.13.15	Sixty-first Supplemental Indenture, dated as of October 1, 2009, (incorporated by reference to Exhibit 4.8.15 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Registration Statement on Form S-3 filed on September 29, 2010, File No. 333-169633-02).								X
4.13.16	Sixty-second Supplemental Indenture, dated as of July 9, 2010, (incorporated by reference to Exhibit 4.1 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Current Report on Form 8-K filed on July 9, 2010, File No. 1-03543).								X
4.13.17	Sixty-third Supplemental Indenture, dated as of September 23, 2010, (incorporated by reference to Exhibit 4.8.17 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Registration Statement on Form S-3 filed on September 29, 2010, File No. 333-169633-02).								X
4.13.18	Sixty-fourth Supplemental Indenture, dated as of December 1, 2011, (incorporated by reference to Exhibit 4(d)(2)(xviii) to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Registration Statement on Form S-3 filed on September 30, 2013, File No.333-191462-03).								X
4.13.19	Sixty-fifth Supplemental Indenture, dated as of March 15, 2012, (incorporated by reference to Exhibit 4.1 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Current Report on Form 8-K filed on March 15, 2012, File No. 1-03543).								X
4.13.20	Sixty-sixth Supplemental Indenture, dated as of July 11, 2013, (incorporated by reference to Exhibit 4.1 to Duke Energy Indiana, Inc.’s (formerly PSI Energy, Inc.) Current Report on Form 8-K filed on July 11, 2013, File No. 1-03543).								X
4.14	Repayment Agreement between Duke Energy Ohio, Inc. (formerly The Cincinnati Gas & Electric Company) and The Dayton Power and Light Company, dated as of December 23, 1992, (filed with registrant's Annual Report on Form 10-K for the year ended December 31, 1992, File No. 1-01232).						X
4.15	Unsecured Promissory Note between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and the Rural Utilities Service, dated as of October 14, 1998, (incorporated by reference to Exhibit 4 to registrant's Annual Report on Form 10-K for the year ended December 31, 1998 filed on March 8, 1999, File No. 1-03543).								X
4.16	6.302% Subordinated Note between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and Cinergy Corp., dated as of February 5, 2003, (incorporated by reference to Exhibit 4 (yyy) to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2003 filed on May 12,2003, File No. 1-03543).								X
4.17	6.403% Subordinated Note between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and Cinergy Corp., dated as of February 5, 2003, (incorporated by reference to Exhibit 4 (zzz) to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2003 filed on May 12, 2003, File No. 1-03543).								X
4.18	Form of Duke Energy InterNote (Fixed Rate), dated as of November 13, 2012, (incorporated by reference to Exhibit 4.1 to Duke Energy Corporation's Current Report on Form 8-K filed on November 14, 2012, File No. 1-32853).	X
4.19	Form of Duke Energy InterNote (Floating Rate), dated as of November 13, 2012, (incorporated by reference to Exhibit 4.2 to Duke Energy Corporation's Current Report on Form 8-K filed on November 14, 2012, File No. 1-32853).	X
4.20	Contingent Value Obligation Agreement between Progress Energy, Inc. (formerly CP&L Energy, Inc.) and The Chase Manhattan Bank, as Trustee, dated as of November 30, 2000, (incorporated by reference to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on December 1, 2000, File No. 1-03382).			X
4.21	Forty-second Supplemental Indenture between Duke Energy Ohio, Inc. (formerly The Cincinnati Gas & Electric Company) and The Bank of New York Mellon Trust Company, N.A., as Trustee, dated as of September 6, 2013, (incorporated by reference to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on September 6, 2013, File No. 1-01232).						X
4.22	Sixty-sixth Supplemental Indenture between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and Deutsche Bank National Trust Company, as Trustee, dated as of July 11, 2013, (incorporated by reference to Exhibit 4.1 to registrant's Current Report on Form 8-K filed on July 11, 2013, File No. 1-03543).								X
10.1	Purchase and Sale Agreement between Duke Energy Americas, LLC and LSP Bay II Harbor Holding, LLC, dated as of January 8, 2006, (incorporated by reference to Exhibit 10.2 to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2006 filed on May 10, 2006, File No. 1-32853).	X	X
10.1.1	Amendment to Purchase and Sale Agreement between Duke Energy Americas, LLC, LS Power Generation, LLC (formerly LSP Bay II Harbor Holding, LLC), LSP Gen Finance Co, LLC, LSP South Bay Holdings, LLC, LSP Oakland Holdings, LLC, and LSP Morro Bay Holdings, LLC, dated as of May 4, 2006, (incorporated by reference to Exhibit 10.2.1 to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2006 filed on May 10, 2006, File No.1-32853).	X	X
10.2**	Directors’ Charitable Giving Program (incorporated by reference to Exhibit 10-P to Duke Energy Carolinas, LLC's Annual Report on Form 10-K for the year ended December 31, 1992, File No. 1-04928).	X
10.2.1**	Amendment to Directors’ Charitable Giving Program, dated as of  June 18, 1997, (incorporated by reference to Exhibit 1-1.1 to Duke Energy Carolinas, LLC's Annual Report on Form 10-K for the year ended December 31, 2003 filed on March 15, 2004, File No. 1-04928).	X
10.2.2**	Amendment to Directors’ Charitable Giving Program, dated as of July 28, 1997, (incorporated by reference to Exhibit 10-1.2 to Duke Energy Carolinas, LLC's Annual Report on Form 10-K for the year ended December 31, 2003 filed on March 15, 2004, File No. 1-04928).	X
10.2.3**	Amendment to Directors’ Charitable Giving Program, dated as of February 18, 1998, (incorporated by reference to Exhibit 10-1.3 to Duke Energy Carolinas, LLC's Annual Report on Form 10-K for the year ended December 31, 2003 filed on March 15, 2004, File No. 1-04928).	X
10.3	Agreements with Piedmont Electric Membership Corporation, Rutherford Electric Membership Corporation and Blue Ridge Electric Membership Corporation to provide wholesale electricity and related power scheduling services from September 1, 2006 through December 31, 2021 (incorporated by reference to Exhibit 10.15 to Duke Energy Corporation's Quarterly Report on Form 10-Q for the quarter ended June 30, 2006 filed on August 9, 2006, File No. 1-32853).	X
10.4	Asset Purchase Agreement between Saluda River Electric Cooperative, Inc., as Seller, and Duke Energy Carolinas, LLC, as Purchaser, dated as of December 20, 2006, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on December 27, 2006, File No. 1-04928).		X
10.5	Settlement between Duke Energy Corporation, Duke Energy Carolinas, LLC and the U.S. Department of Justice resolving Duke Energy's used nuclear fuel litigation against the U.S. Department of Energy, dated as of March 6, 2007, (incorporated by reference to Item 8.01 to registrant's Current Report on Form 8-K filed on March 12, 2007, File No. 1-04928).		X
10.6	Engineering, Procurement and Construction Agreement between Duke Energy Carolinas, LLC and Stone & Webster National Engineering P.C., dated as of July 11, 2007, (incorporated by reference to Exhibit 10.1 to registrant's Quarterly Report on Form 10-Q for the quarter ended September 30, 2007 filed on November 12, 2007, File No. 1-04928). (Portions of the exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended.)		X
10.7	Amended and Restated Engineering, Procurement and Construction Agreement between Duke Energy Carolinas, LLC and Stone & Webster National Engineering P.C., dated as of February 20, 2008, (incorporated by reference to Exhibit 10.1 to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2008 filed on May 14, 2008, File No. 1-04928). (Portions of the exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended).		X
10.8	Asset Purchase Agreement between Cinergy Capital & Trading, Inc. (Capital & Trading), CinCap Madison, LLC and Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.), dated as of February 5, 2003, (incorporated by reference to Exhibit 10(tt) to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2003 filed on May 12, 2003, File No. 1-03543).								X
10.9	Amended and Restated Engineering and Construction Agreement between Duke Energy Carolinas, LLC and Shaw North Carolina, Inc., dated as of December 21, 2009, (incorporated by reference to Item 1.01 to registrant's Current Report on Form 8-K filed on December 28, 2009, File No. 1-04928).		X
10.10	Asset Purchase Agreement between Capital & Trading., CinCap VII, LLC and Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.), dated as of February 5, 2003, (incorporated by reference to Exhibit 10(uu) to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2003 filed on May 12, 2003, File No. 1-03543).								X
10.11	Asset Purchase Agreement between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and Duke Energy Ohio, Inc. (formerly The Cincinnati Gas & Electric Company) and Allegheny Energy Supply Company, LLC, Allegheny Energy Supply Wheatland Generating Facility, LLC and Lake Acquisition Company, L.L.C., dated as of May 6, 2005, (incorporated by reference to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 filed on August 4, 2005, File No. 1-01232).						X
10.12	Asset Purchase Agreement between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and CG&E and Allegheny Energy Supply Company, LLC, Allegheny Energy Supply Wheatland Generating Facility, LLC and Lake Acquisition Company, L.L.C., dated as of May 6, 2005, (incorporated by reference to Exhibit 10(kkkk) to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 filed on August 4, 2005, File No. 1-03543).								X
10.13	Keepwell Agreement between Duke Capital LLC and Duke Energy Ohio, Inc. (formerly The Cincinnati Gas & Electric Company), dated as of April 10, 2006, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on April 14, 2006, File No. 1-01232).						X
10.14	Agreements between Piedmont Electric Membership Corporation, Rutherford Electric Membership Corporation and Blue Ridge Electric Membership Corporation to provide wholesale electricity and related power scheduling services from September 1, 2006 through December 31, 2021 (incorporated by reference to Exhibit 10.15 to Duke Energy Corporation's Quarterly Report on Form 10-Q for the quarter ended June 30, 2006 filed on August 9, 2006, File No. 1-32853).	X
10.15	Asset Purchase Agreement between Duke Energy Indiana, Inc., (formerly PSI Energy, Inc.), as Seller, and Wabash Valley Power Association, Inc., as Buyer, dated as of December 1, 2006, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on December 7, 2006, File No. 1-03543).								X
10.16	Purchase and Sale Agreement between Cinergy Capital & Trading, Inc., as Seller, and Fortis Bank, S.A./N.V., as Buyer, dated as of June 26, 2006, (incorporated by reference to Exhibit 10.1 to Duke Energy Corporation's Current Report on Form 8-K filed on June 30, 2006, File No. 1-32853).	X
10.17	Engineering, Procurement and Construction Management Agreement between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and Bechtel Power Corporation, dated as of December 15, 2008, (incorporated by reference to Exhibit 10.16 to registrant's Annual Report on Form 10-K for the year ended December 31, 2008 filed on March 13, 2009, File No. 1-03543). (Portions of the exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended).								X
10.18	Formation and Sale Agreement between Duke Ventures, LLC, Crescent Resources, LLC, Morgan Stanley Real Estate Fund V U.S. L.P., Morgan Stanley Real Estate Fund V Special U.S., L.P., Morgan Stanley Real Estate Investors V U.S., L.P., MSP Real Estate Fund V, L.P., and Morgan Stanley Strategic Investments, Inc., dated as of September 7, 2006, (incorporated by reference to Exhibit 10.3 to Duke Energy Corporation's Quarterly Report on Form 10-Q for the quarter ended September 30, 2006 filed on November 9, 2006, File No. 1-32853).	X
10.19	Engineering, Procurement and Construction Agreement between Duke Energy Carolinas, LLC and Stone & Webster National Engineering P.C., dated as of July 11, 2007, (incorporated by reference to Exhibit 10.2 to Duke Energy Corporation's Quarterly Report on Form 10-Q for the quarter ended September 30, 2007 filed on November 9, 2007, File No. 1-32853). (Portions of the exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended).	X
10.20	Amended and Restated Engineering, Procurement and Construction Agreement between Duke Energy Carolinas, LLC and Stone & Webster National Engineering P.C., dated as of February 20, 2008, (incorporated by reference to Exhibit 10.1 to Duke Energy Corporation's Quarterly Report on Form 10-Q for the quarter ended March 31, 2008 filed on May 9, 2008, File No. 1-32853). (Portions of the exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended).	X
10.21	Agreement and Plan of Merger between DEGS Wind I, LLC, DEGS Wind Vermont, Inc., Catamount Energy Corporation, dated as of June 25, 2008, (incorporated by reference to Exhibit 10.2 to Duke Energy Corporation's Quarterly Report on Form 10-Q for the quarter ended June 30, 2008 filed on August 11, 2008, File No. 1-32853).	X
10.22	Amended and Restated Engineering and Construction Agreement between Duke Energy Carolinas, LLC and Shaw North Carolina, Inc., dated as of December 21, 2009, (incorporated by reference to Exhibit 10.41 to Duke Energy Corporation's Annual Report on Form 10-K for the year ended December 31, 2009 filed on February 26, 2010, File No.1-32853).	X
10.23	Operating Agreement of Pioneer Transmission, LLC (incorporated by reference to Exhibit 10.1 to Duke Energy Corporation's Quarterly Report on Form 10-Q for the quarter ended September 30, 2008 filed on November 7, 2008, File No. 1-32853).	X
10.24**	Amended and Restated Duke Energy Corporation Directors' Saving Plan, dated as of January 1, 2014, (incorporated by reference to Exhibit 10.32 to Duke Energy Corporation's Annual Report on Form 10-K for the year ended December 31, 2013 filed on February 28, 2014, File No. 1-32853).	X
10.25	Engineering, Procurement and Construction Management Agreement between Duke Energy Indiana, Inc. (formerly PSI Energy, Inc.) and Bechtel Power Corporation, dated as of December 15, 2008, (incorporated by reference to Item 1.01 to registrant's Current Report on Form 8-K filed on December 19, 2008, File Nos. 1-32853 and 1-03543). (Portions of the exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended).	X							X
10.26	Amended and Restated Engineering and Construction Agreement between Duke Energy Carolinas, LLC and Shaw North Carolina, Inc., dated as of March 8, 2010, (incorporated by reference to Exhibit 10.1 to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2010 filed on May 7, 2010, File Nos. 1-32853 and 1-04928).	X	X
10.27**	Form of Performance Award Agreement of Duke Energy Corporation (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on February 22, 2011, File No. 1-32853).	X
10.28**	Form of Phantom Stock Award of Duke Energy Corporation (incorporated by reference to Exhibit 10.2 to registrant's Current Report on Form 8-K filed on February 22, 2011, File No. 1-32853).	X
10.29**	Duke Energy Corporation Executive Severance Plan (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on January 10, 2011, File No. 1-32853).	X
10.30	$6,000,000,000 Five-Year Credit Agreement between Duke Energy Corporation, Duke Energy Carolinas, LLC, Duke Energy Ohio, Inc., Duke Energy Indiana, Inc., Duke Energy Kentucky, Inc., Carolina Power and Light Company d/b/a Duke Energy Progress, Inc. and Florida Power Corporation, d/b/a Duke Energy Florida, Inc., as Borrowers, the lenders listed therein, Wells Fargo Bank, National Association, as Administrative Agent, Bank of America, N.A. and The Royal Bank of Scotland plc, as Co-Syndication Agents and Bank of China, New York Branch, Barclays Bank PLC, Citibank, N.A., Credit Suisse AG, Cayman Islands Branch, Industrial and Commercial Bank of China Limited, New York Branch, JPMorgan Chase Bank, N.A. and UBS Securities LLC, as Co-Documentation Agents, dated as of November 18, 2011, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on November 25, 2011, File Nos. 1-32853, 1-04928, 1-01232 and 1-03543).	X	X				X		X
10.31**	Form of Performance Award Agreement of Duke Energy Corporation under the Duke Energy Corporation 2010 Long-Term Incentive Plan (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on February 22, 2011, File No. 1-32853).	X
10.32**	Form of Phantom Stock Award Agreement of Duke Energy Corporation under the Duke Energy Corporation 2010 Long-Term Incentive Plan (incorporated by reference to Exhibit 10.2 to registrant's Current Report on Form 8-K filed on February 22, 2011, File No. 1-32853).	X
10.33**	Duke Energy Corporation 2010 Long-term Incentive Plan (incorporated by reference to Appendix A to registrant's Form DEF 14A filed on March 22, 2010, File No. 1-32853).	X
10.33.1**	Amendment to Duke Energy Corporation 2010 Long-Term Incentive Plan (incorporated by reference to Exhibit 10.3 to registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2012 filed on August 8, 2012, File No. 1-32853).	X
10.34	Settlement Agreement between Duke Energy Corporation, the North Carolina Utilities Commission Staff and the North Carolina Public Staff, dated as of November 28, 2012, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on November 29, 2012, File No. 1-32853).	X
10.35	Settlement Agreement between Duke Energy Corporation and the North Carolina Attorney General, dated as of December 3, 2012, (incorporated by reference Item 7.01 to registrant's Current Report on Form 8-K filed on December 3, 2012, File No. 1-32853).	X
10.36**	Retention Award Agreement between Duke Energy Corporation and Lloyd Yates, dated as of July 9, 2012, (incorporated by reference to Exhibit 10.56 to registrant's Annual Report on Form 10-K for the year ended December 31, 2012 filed on March 1, 2013, File No. 1-32853).	X
10.37**	Form of Change-in-Control Agreement (incorporated by reference to Exhibit 10.58 to Duke Energy Corporation's Annual Report on Form 10-K for the year ended December 31, 2012 filed on March 1, 2013, File No. 1-32853).	X
10.38**	Form of Performance Share Award (incorporated by reference to Exhibit 10.64 to Duke Energy Corporation's Annual Report on Form 10-K for the year ended December 31, 2012 filed on March 1, 2013, File No. 1-32853).	X
10.39**	Amended and Restated Duke Energy Corporation Executive Cash Balance Plan, dated as of January 1, 2014, (incorporated by reference to Exhibit 10.52 to Duke Energy Corporation's Annual Report on Form 10-K for the year ended December 31, 2013 filed on February 28, 2014, File No. 1-32852).	X
10.40	Purchase, Construction and Ownership Agreement, dated as of July 30, 1981, between Duke Energy Progress, Inc. (formerly Carolina Power & Light Company) and North Carolina Municipal Power Agency Number 3 and Exhibits, together with resolution, dated as of December 16, 1981, changing name to North Carolina Eastern Municipal Power Agency, amending letter, dated as of February 18, 1982, and amendment, dated as of February 24, 1982, (incorporated by reference to Exhibit 10(a) to registrant's File No. 33-25560).				X
10.41	Operating and Fuel Agreement, dated as of July 30, 1981, between Duke Energy Progress, Inc. (formerly Carolina Power & Light Company) and North Carolina Municipal Power Agency Number 3 and Exhibits, together with resolution, dated as of December 16, 1981, changing name to North Carolina Eastern Municipal Power Agency, amending letters, dated as of August 21, 1981 and December 15, 1981, and amendment, dated as of February 24, 1982, (incorporated by reference to Exhibit 10(b) to registrant's File No. 33-25560).				X
10.42	Power Coordination Agreement, dated as of July 30, 1981, between Duke Energy Progress, Inc. (formerly Carolina Power & Light Company) and North Carolina Municipal Power Agency Number 3 and Exhibits, together with resolution, dated as of December 16, 1981, changing name to North Carolina Eastern Municipal Power Agency and amending letter, dated as of January 29, 1982, (incorporated by reference to Exhibit 10(c) to registrant's File No. 33-25560).				X
10.43	Amendment, dated as of December 16, 1982, to Purchase, Construction and Ownership Agreement, dated as of July 30, 1981, between Duke Energy Progress, Inc. (formerly Carolina Power & Light Company) and North Carolina Eastern Municipal Power Agency (incorporated by reference to Exhibit 10(d) to registrant's File No. 33-25560).				X
10.44+	Amended and Restated Broad-Based Performance Share Sub-Plan, Exhibit B to the 2002 Progress Energy, Inc. Equity Incentive Plan, effective January 1, 2007, (incorporated by reference to Exhibit 10c(6) to registrant's Annual Report on Form 10-K for the year ended December 31, 2006 filed on March 1, 2007, File Nos. 1-15929, 1-03382 and 1-03274).			X	X	X
10.45+	Amended and Restated Executive and Key Manager Performance Share Sub-Plan, Exhibit A to the 2002 Progress Energy, Inc. Equity Incentive Plan, effective January 1, 2007, (incorporated by reference to Exhibit 10(c)(7) to registrant's Annual Report on Form 10-K for the year ended December 31, 2006 filed on March 1, 2007, File Nos. 1-15929, 1-03382 and 1-03274).			X	X	X
10.46+	Progress Energy, Inc. 2007 Equity Incentive Plan (incorporated by reference to Exhibit C to registrant's Form DEF 14A filed on March 30, 2007, File No. 1-15929).			X
10.47+	Executive and Key Manager 2007 Performance Share Sub-Plan, Exhibit A to the 2007 Equity Incentive Plan, effective January 1, 2007, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on July 16, 2007, File Nos. 1- 15929, 1-03382 and 1-03274).			X	X	X
10.48+	Form of Executive and Key Manager 2008 Performance Share Sub-Plan (incorporated by reference to Exhibit 10(a) to registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2008 filed on May 12, 2008, File No. 1-15929, 1-03382 and 1-03274).			X	X	X
10.49+	Form of Letter Agreement executed by certain officers of Progress Energy, Inc., waiving certain rights under Progress Energy, Inc.’s Management Change-in-Control Plan and their employment agreements, dated as of January 8, 2011, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on January 8, 2011, File No. 1-15929).			X
10.50+	Executive and Key Manager 2009 Performance Share Sub-Plan, Exhibit A to 2007 Equity Incentive Plan, Amended and Restated, effective July 12, 2011, (incorporated by reference to Exhibit 10(b) to registrant's Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 filed on November 8, 2011, File Nos. 1-15929, 1-03382 and 1-03274.			X	X	X
10.51+	Progress Energy, Inc. Management Change-in-Control Plan, Amended and Restated, effective July 13, 2011, (incorporated by reference to Exhibit 10(d) to registrant's Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 filed on November 8, 2011, File Nos. 1-15929, 1-03382 and 1-03274).			X	X	X
10.52+	Form of Progress Energy, Inc. Restricted Stock Unit Award Agreement (Graded Vesting), effective September 15, 2011.			X	X	X
10.53+	Form of Progress Energy, Inc. Restricted Stock Unit Award Agreement (Cliff Vesting), effective September 15, 2011.			X	X	X
10.54	Precedent and Related Agreements between Duke Energy Florida, Inc. (formerly Florida Power Corporation d/b/a Progress Energy Florida, Inc. (“PEF”)), Southern Natural Gas Company, Florida Gas Transmission Company (“FGT”), and BG LNG Services, LLC (“BG”), including: a) Precedent Agreement between Southern Natural Gas Company and PEF, dated as of December 2, 2004; b) Gas Sale and Purchase Contract between BG and PEF, dated as of December 1, 2004; c) Interim Firm Transportation Service Agreement by and between FGT and PEF, dated as of December 2, 2004; d) Letter Agreement between FGT and PEF, dated as of December 2, 2004 and Firm Transportation Service Agreement between FGT and PEF to be entered into upon satisfaction of certain conditions precedent; e) Discount Agreement between FGT and PEF, dated as of December 2, 2004; f) Amendment to Gas Sale and Purchase Contract between BG and PEF, dated as of January 28, 2005; and g) Letter Agreement between FGT and PEF, dated as of January 31, 2005, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K/A filed on March 15, 2005, File Nos. 1-15929 and 1-03274). (Portions of the exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended).			X		X
10.55	Engineering, Procurement and Construction Agreement between Duke Energy Florida, Inc. (formerly Florida Power Corporation d/b/a/ Progress Energy Florida, Inc.), as owner, and a consortium consisting of Westinghouse Electric Company LLC and Stone & Webster, Inc., as contractor, for a two-unit AP1000 Nuclear Power Plant, dated as of December 31, 2008, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on March 2, 2009, File Nos. 1-15929 and 1-03274). (Portions of the exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment pursuant to Rule 24b-2 under the Securities Exchange Act of 1934, as amended).			X		X
10.56	Amendment No. 1 and Consent between Duke Energy Corporation, Duke Energy Carolinas, LLC, Duke Energy Ohio, Inc., Duke Energy Indiana, Inc., Duke Energy Kentucky, Inc., Duke Energy Progress, Inc., Duke Energy Florida, Inc., and Wells Fargo Bank, National Association, dated as of December 18, 2013, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on December 23, 2013, File Nos. 1-32853, 1-04928, 1-03382, 1-03274, 1-01232 and 1-03543).	X	X		X	X	X		X
10.57**	Employment Agreement between Duke Energy Corporation and Lynn J. Good, dated as of June 17, 2013, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8-K filed on June 18, 2013, File No. 1-32853).	X
10.58**	Duke Energy Corporation Executive Short-Term Incentive Plan, effective February 25, 2013, (incorporated by reference to Exhibit 10.1 to registrant's Current Report on Form 8- filed on May 7, 2013, File No. 1-32853).	X
10.59**	Duke Energy Corporation 2013 Director Compensation Program Summary (incorporated by reference to Exhibit 10.81 To Duke Energy Corporation's Annual Report on Form 10-K for the year ended December 31, 2013 filed on February 28, 2014, File No. 1-32853).	X
10.60**	Amended and Restated Duke Energy Corporation Executive Savings Plan, dated as of January 1, 2014, (incorporated by reference to Exhibit 10.82 to Duke Energy Corporation's Annual Report on Form 10-K for the year ended December 31, 2013 filed on February 28, 2014, File No. 1-32853).	X
*10.61	Agreement between Duke Energy SAM, LLC, Duke Energy Ohio, Inc., Duke Energy Commercial Enterprise, Inc. and Dynegy Resource I, LLC, dated as of August 21, 2014.	X					X
*10.62	Asset Purchase Agreement between Duke Energy Progress, Inc. and North Carolina Eastern Municipal Power Agency, dated as of September 5, 2014.	X			X
10.63	Change in Control Agreement between Duke Energy Corporation and Lloyd M. Yates, dated as of April 30, 2014, (incorporated by reference to Exhibit 10.1 to Duke Energy Corporation's Current Report on Form 8-K filed on May 6, 2014, File No. 1-32853).	X
*12.1	Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY CORPORATION	X
*12.2	Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY CAROLINAS, LLC		X
*12.3	Computation of Ratio of Earnings to Fixed Charges - PROGRESS ENERGY, INC			X
*12.4	Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY PROGRESS, INC				X
*12.5	Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY FLORIDA, INC					X
*12.6	Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY OHIO, INC.						X
*12.7	Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY INDIANA, INC.								X
*21	List of Subsidiaries	X
*23.1.1	Consent of Independent Registered Public Accounting Firm.	X
*23.1.2	Consent of Independent Registered Public Accounting Firm.		X
*23.1.3	Consent of Independent Registered Public Accounting Firm.			X
*23.1.4	Consent of Independent Registered Public Accounting Firm.				X
*23.1.5	Consent of Independent Registered Public Accounting Firm.					X
*23.1.6	Consent of Independent Registered Public Accounting Firm.						X
*23.1.7	Consent of Independent Registered Public Accounting Firm.								X
*24.1	Power of attorney authorizing Lynn J. Good and others to sign the annual report on behalf of the registrant and certain of its directors and officers.	X
*24.2	Certified copy of resolution of the Board of Directors of the registrant authorizing power of attorney.	X
*31.1.1	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.	X
*31.1.2	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.		X
*31.1.3	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.			X
*31.1.4	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.				X
*31.1.5	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.					X
*31.1.6	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.						X
*31.1.7	Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.								X
*31.2.1	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.	X
*31.2.2	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.		X
*31.2.3	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.			X
*31.2.4	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.				X
*31.2.5	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.					X
*31.2.6	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.						X
*31.2.7	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.								X
*32.1.1	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.	X
*32.1.2	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.		X
*32.1.3	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.			X
*32.1.4	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.				X
*32.1.5	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.					X
*32.1.6	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.						X
*32.1.7	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.								X
*32.2.1	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.	X
*32.2.2	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.		X
*32.2.3	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.			X
*32.2.4	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.				X
*32.2.5	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.					X
*32.2.6	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.						X
*32.2.7	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.								X
*101.INS	XBRL Instance Document	X	X	X	X	X	X		X
*101.SCH	XBRL Taxonomy Extension Schema Document	X	X	X	X	X	X		X
*101.CAL	XBRL Taxonomy Calculation Linkbase Document	X	X	X	X	X	X		X
*101.LAB	XBRL Taxonomy Label Linkbase Document	X	X	X	X	X	X		X
*101.PRE	XBRL Taxonomy Presentation Linkbase Document	X	X	X	X	X	X		X
*101.DEF	XBRL Taxonomy Definition Linkbase Document	X	X	X	X	X	X		X

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

E-1