10-K 1 duk-20141231x10k.htm FORM 10-K DUK-2014.12.31-10K



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.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
1A.
 
 
 
1B.
 
 
 
2.
 
 
 
3.
 
 
 
4.
 
 
 
PART II.
 
 
5.
 
 
 
6.
 
 
 
7.
 
 
 
7A.
 
 
 
8.
 
 
 
9.
 
 
 
9A.
 
 
 
PART III.
 
 
10.
 
 
 
11.
 
 
 
12.
 
 
 
13.
 
 
 
14.
 
 
 
PART IV.
 
 
15.
 
 





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.

10


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. 

11


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.”

12


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.

13


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.

14


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.

15


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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PART I

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


26


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.

27


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.

28


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.

29


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.

30


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