10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(Mark One)

xANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year endedDecember 31, 2013

OR

oTRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _____to_____

Commission File Number: 1-1097

OKLAHOMA GAS AND ELECTRIC COMPANY

(Exact name of registrant as specified in its charter)

Oklahoma	73-0382390
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)

321 North Harvey

P.O. Box 321

Oklahoma City, Oklahoma 73101-0321

(Address of principal executive offices)

(Zip Code)

Registrant's telephone number, including area code:405-553-3000

Securities registered pursuant to Section 12(b) of the Act: None

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.

o  Yes   þ  No

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

o  Yes   þ  No

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.þ  Yes   o  No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, 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).þ  Yes   o  No

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) 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.þ

Indicate by check mark whether the registrant 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.

Large accelerated filer  o	Accelerated filer  þ
Non-accelerated filer    þ (Do not check if a smaller reporting company)	Smaller reporting company  o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).o  Yes   þ  No

AtJune 28, 2013, the last business day of the registrant's most recently completed second fiscal quarter, the aggregate market value of shares of common stock held by non-affiliates was$0. As of such date, 40,378,745 shares of common stock, par value $2.50 per share, were outstanding, all of which were held by OGE Energy Corp.

AtJanuary 31, 2014, there were40,378,745shares of common stock, par value$2.50per share, outstanding, all of which were held by OGE Energy Corp.  There were no other shares of capital stock of the registrant outstanding at such date.

DOCUMENTS INCORPORATED BY REFERENCE

None

Oklahoma Gas and Electric Company meets the conditions set forth in General Instruction I(1)(a) and (b) of Form 10-K and is therefore filing this form with the reduced disclosure format permitted by General Instruction I(2).

OKLAHOMA GAS AND ELECTRIC COMPANY

FORM 10-K

FOR THE YEAR ENDEDDECEMBER 31, 2013

TABLE OF CONTENTS

	Page
GLOSSARY OF TERMS	ii
FORWARD-LOOKING STATEMENTS	1
Part I
Item 1. Business	2
OG&E	2
Environmental Matters	9
Finance and Construction	9
Employees	12
Executive Officers	12
Access to Securities and Exchange Commission Filings	14
Item 1A. Risk Factors	14
Item 1B. Unresolved Staff Comments	20
Item 2. Properties	20
Item 3. Legal Proceedings	22
Item 4. Mine Safety Disclosures	22
Part II
Item 5. Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	22
Item 6. Selected Financial Data	23
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations	24
Item 7A. Quantitative and Qualitative Disclosures About Market Risk	45
Item 8. Financial Statements and Supplementary Data	47
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	89
Item 9A. Controls and Procedures	89
Item 9B. Other Information	92
Part III
Item 10. Directors, Executive Officers and Corporate Governance	92
Item 11. Executive Compensation	92
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	92
Item 13. Certain Relationships and Related Transactions, and Director Independence	92
Item 14. Principal Accounting Fees and Services	93
Part IV
Item 15. Exhibits, Financial Statement Schedules	94
Signatures	100

i

GLOSSARY OF TERMS

The following is a glossary of frequently used abbreviations that are found throughout this Form 10-K.

Abbreviation	Definition
401(k) Plan	Qualified defined contribution retirement plan
APSC	Arkansas Public Service Commission
BART	Best available retrofit technology
Code	Internal Revenue Code of 1986
Dry Scrubbers	Dry flue gas desulfurization units with spray dryer absorber
Enogex	Enogex Holdings LLC, collectively with its subsidiaries, a majority-owned subsidiary of OGE Energy
EPA	U.S. Environmental Protection Agency
Federal Clean Water Act	Federal Water Pollution Control Act of 1972, as amended
FERC	Federal Energy Regulatory Commission
FIP	Federal implementation plan
GAAP	Accounting principles generally accepted in the United States
MATS	Mercury and Air Toxics Standards
MMBtu	Million British thermal unit
MW	Megawatt
MWH	Megawatt-hour
NAAQS	National Ambient Air Quality Standards
NOX	Nitrogen oxide
NYMEX	New York Mercantile Exchange
OCC	Oklahoma Corporation Commission
Off-system sales	Sales to other utilities and power marketers
OG&E	Oklahoma Gas and Electric Company, wholly-owned subsidiary of OGE Energy
OGE Energy	OGE Energy Corp., parent company of OG&E
OSHA	Federal Occupational Safety and Health Act of 1970
Pension Plan	Qualified defined benefit retirement plan
PRM	Price risk management
QF	Qualified cogeneration facilities
QF contracts	Contracts with QFs and small power production producers
Restoration of Retirement Income Plan	Supplemental retirement plan to the Pension Plan
SIP	State implementation plan
SO2	Sulfur dioxide
SPP	Southwest Power Pool
System sales	Sales to OG&E's customers

ii

FORWARD-LOOKING STATEMENTS

Except for the historical statements contained herein, the matters discussed in this Form 10-K, including those matters discussed in "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," areforward-looking statements that are subject to certain risks, uncertainties and assumptions.  Such forward-looking statements are intended to be identified in this document bythe words "anticipate", "believe", "estimate", "expect", "intend", "objective", "plan", "possible", "potential", "project" and similar expressions.  Actual results may vary materiallyfrom those expressed in forward-looking statements. In addition to the specific risk factors discussed in "Item 1A. Risk Factors" and "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" herein, factorsthat could causeactual results to differ materiallyfrom the forward-looking statementsinclude, but are not limited to:

• general economic conditions, including the availability of credit, access to existing lines of credit,access to the commercial paper markets,actions of rating agencies and their impact on capital expenditures;

• the ability of OG&E and OGE Energy to access the capital markets and obtain financing on favorable terms as well as inflation rates and monetary fluctuations;

• prices and availability ofelectricity, coal and natural gas;

• business conditions in the energy industry;

• competitive factors including the extent and timing of the entry of additional competition in the markets served by OG&E;

• unusual weather;

• availability and prices of raw materials for current and future construction projects;

• Federal or state legislation and regulatory decisions and initiatives that affectcost and investment recovery, have an impact on rate structures or affect the speed and degree to which competition enters OG&E's markets;

• environmental laws and regulations that may impact OG&E's operations;

• changes in accounting standards, rules or guidelines;

• the discontinuance of accounting principles for certain types of rate-regulated activities;

• the cost of protecting assets against, or damage due to, terrorism or cyber attacks and other catastrophic events;

• advances in technology;

• creditworthiness of suppliers, customers and other contractual parties and

• other risk factors listed in the reports filed by OG&E with the Securities and Exchange Commission including those listed in"Item 1A.Risk Factors" and inExhibit 99.01 tothis Form 10-K.

OG&E undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

1

PART I

Item 1. Business.

Introduction

OG&Egenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. Its operationsare subject to regulation by the OCC, the APSC and the FERC.OG&E was incorporated in 1902 under the laws of the Oklahoma Territory. OG&E is the largest electric utility in Oklahoma and its franchised service territory includes the Fort Smith, Arkansas area. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.OG&E is a wholly-owned subsidiary of OGE Energy, an energy and energy services provider offering physical delivery and related services for both electricity and natural gas primarily in the south central United States. OG&E's principal executive offices are located at321 North Harvey, P.O. Box 321, Oklahoma City, Oklahoma 73101-0321; telephone405-553-3000.

OG&E Strategy

OGE Energy'smission is to fulfill its critical role in the nation's electric utility and natural gas midstream pipeline infrastructure and meet individual customers' needs for energy and related services focusing on safety, efficiency, reliability, customer service and risk management.OGE Energy'scorporate strategy is to continue to maintain its existing business mix and diversified asset position of its regulated electric utility business and unregulated natural gas midstream business while providing competitive energy products and services to customers primarily in the south central United States as well as seeking growth opportunities in both businesses.

OG&E is focused on increased investment to preserve system reliability and meet load growth by adding and maintaining infrastructure equipment and replacing aging transmission and distribution systems. OG&E expects to maintain a diverse generation portfolio while remaining environmentally responsible. OG&E is focused on maintaining strong regulatory and legislative relationships for the long-term benefit of its customers. In an effort to encourage more efficient use of electricity, OG&E is also providing energy management solutions to its customers through the Smart Grid program that utilizes newer technology to improve operational and environmental performance as well as allow customers to monitor and manage their energy usage, which should help reduce demand during critical peak times, resulting in lower capacity requirements.  If these initiatives are successful, OG&E believes it may be able to defer the construction or acquisition of any incremental fossil fuel generation capacity until 2020. The Smart Grid program also provides benefits to OG&E, including more efficient use of its resources and access to increased information about customer usage, which should enable OG&E to have better distribution system planning data, better response to customer usage questions and faster detection and restoration of system outages. As the Smart Grid platform matures, OG&E anticipates providing new products and services to its customers. In addition, OG&E is also pursuing additional transmission-related opportunities within the SPP.

General

OG&Egenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. OG&E furnishes retail electric service in268communities and their contiguous rural and suburban areas.During2013, oneother community andtworural electric cooperatives in Oklahoma and western Arkansas purchased electricity from OG&E for resale. The service area covers30,000square miles in Oklahoma and western Arkansas, including Oklahoma City, the largest city in Oklahoma, and Fort Smith, Arkansas, the second largest city in that state.Of the268communities that OG&E serves,242are located in Oklahoma and26in Arkansas.OG&E derived90 percentof its total electric operating revenues in2013from sales in Oklahoma and the remainder from sales in Arkansas.

OG&E's system control area peak demand in2013was6,341MWs onJune 27, 2013. OG&E's load responsibility peak demand was5,806MWs onJune 27, 2013. As reflected in the table below and in the operating statistics that follow, there were28.2 millionMWH system sales in2013, 28.0 millionMWH system sales in2012and28.5 millionMWH system sales in2011. Variations in system sales for the three years are reflected in the following table:

Year ended December 31	2013	2013 vs. 2012 Increase	2012	2012 vs. 2011 Decrease	2011
System sales - millions of MWHs	28.2	0.7%	28.0	(1.8)%	28.5

2

OG&E is subject to competition in various degrees from government-owned electric systems, municipally-owned electric systems, rural electric cooperatives and, in certain respects, from other private utilities, power marketers and cogenerators. Oklahoma law forbids the granting of an exclusive franchise to a utility for providing electricity.

Besides competition from other suppliers or marketers of electricity, OG&E competes with suppliers of other forms of energy. The degree of competition between suppliers may vary depending on relative costs and supplies of other forms of energy.

OKLAHOMA GAS AND ELECTRIC COMPANY
CERTAIN OPERATING STATISTICS
Year ended December 31	2013			2012			2011
ELECTRIC ENERGY (Millions of MWH)
Generation (exclusive of station use)	24.2			26.3			26.7
Purchased	6.3			5.0			4.9
Total generated and purchased	30.5			31.3			31.6
OG&E use, free service and losses	(1.9		)	(1.9		)	(2.1		)
Electric energy sold	28.6			29.4			29.5
ELECTRIC ENERGY SOLD (Millions of MWH)
Residential	9.4			9.1			9.9
Commercial	7.1			7.0			6.9
Industrial	3.9			4.0			3.9
Oilfield	3.4			3.3			3.2
Public authorities and street light	3.2			3.3			3.2
Sales for resale	1.2			1.3			1.4
System sales	28.2			28.0			28.5
Off-system sales	0.4			1.4			1.0
Total sales	28.6			29.4			29.5
ELECTRIC OPERATING REVENUES (In millions)
Residential	$	901.4		$	878.0		$	943.5
Commercial	554.2			523.5			531.3
Industrial	220.6			206.8			216.0
Oilfield	176.4			163.4			165.1
Public authorities and street light	214.3			202.4			207.4
Sales for resale	59.4			54.9			65.3
System sales revenues	2,126.3			2,029.0			2,128.6
Off-system sales revenues	14.7			36.5			36.2
Other	121.2			75.7			46.7
Total operating revenues	$	2,262.2		$	2,141.2		$	2,211.5
ACTUAL NUMBER OF ELECTRIC CUSTOMERS (At end of period)
Residential	690,390			683,214			675,806
Commercial	90,279			88,772			87,480
Industrial	2,921			2,957			2,991
Oilfield	6,431			6,426			6,451
Public authorities and street light	16,877			16,695			16,374
Sales for resale	42			46			44
Total	806,940			798,110			789,146
AVERAGE RESIDENTIAL CUSTOMER SALES
Average annual revenue	$	1,312.59		$	1,292.11		$	1,401.84
Average annual use (kilowatt-hour)	13,718			13,477			14,738
Average price per kilowatt-hour (cents)	$	9.57		$	9.59		$	9.51

3

Regulation and Rates

OG&E's retail electric tariffs are regulated by the OCC in Oklahoma and by the APSC in Arkansas.  The issuance of certain securities by OG&E is also regulated by the OCC and the APSC.  OG&E's wholesale electric tariffs, transmission activities, short-term borrowing authorization and accounting practices are subject to the jurisdiction of the FERC.  The Secretary of the U.S. Department of Energy has jurisdiction over some of OG&E's facilities and operations.In2013, 85 percentof OG&E's electric revenue was subject to the jurisdiction of the OCC,eight percentto the APSC andseven percentto the FERC.

The OCC issued an order in 1996 authorizing OG&E to reorganize into a subsidiary of OGE Energy.  The order required that, among other things, (i) OGE Energy permit the OCC access to the books and records of OGE Energy and its affiliates relating to transactions with OG&E, (ii) OGE Energy employ accounting and other procedures and controls to protect against subsidization of non-utility activities by OG&E's customers and (iii) OGE Energy refrain from pledging OG&E assets or income for affiliate transactions.  In addition, the Energy Policy Act of 2005 enacted the Public Utility Holding Company Act of 2005, which in turn granted to the FERC access to the books and records of OGE Energy and its affiliates as the FERC deems relevant to costs incurred by OG&E or necessary or appropriate for the protection of utility customers with respect to the FERC jurisdictional rates.

Completed Regulatory Matters

Crossroads Wind Farm

As previously reported, OG&E signed memoranda of understanding in February 2010 for approximately 197.8 megawatts of wind turbine generators and certain related balance of plant engineering, procurement and construction services associated with the Crossroads wind farm. Also as part of this project, on June 16, 2011, OG&E entered into an interconnection agreement with the SPP for the Crossroads wind farm which allowed the Crossroads wind farm to interconnect at 227.5 megawatts. On August 31, 2012, OG&E filed an application with the APSC requesting approval to recover the Arkansas portion of the costs of the Crossroads wind farm through a rider until such costs are included in OG&E's base rates as part of its next general rate proceeding. On April 15, 2013, the APSC issued an order authorizing OG&E to recover the Arkansas portion of the cost to construct the Crossroads wind farm, effective retroactively to August 1, 2012. The costs are being recovered through the Energy Cost Recovery Rider.

Fuel Adjustment Clause Review for Calendar Year 2011

The OCC routinely reviews the costs recovered from customers through OG&E’s fuel adjustment clause. On July 31, 2012, the OCC Staff filed an application for a public hearing to review and monitor OG&E's application of the 2011 fuel adjustment clause and for a prudence review of OG&E's electric generation, purchased power and fuel procurement processes and costs in calendar year 2011.  OG&E filed information and documents in response to the OCC's application on October 1, 2012.  On December 19, 2012, witnesses for the OCC Staff filed responsive testimony recommending that the OCC approve OG&E's fuel adjustment clause costs and recoveries for the calendar year 2011 and recommending that the OCC find that OG&E's electric generation, purchased power, fuel procurement and other fuel related practices, policies and decisions during calendar year 2011 were fair, just and reasonable and prudent. On April 9, 2013, the OCC administrative law judge recommended that the OCC find that for the calendar year 2011 OG&E's electric generation, purchased power and fuel procurement processes and costs were prudent. On June 18, 2013, the OCC issued an order approving the administrative law judge’s recommendation.

4

Pending Regulatory Matters

FERC Order No. 1000, Final Rule on Transmission Planning and Cost Allocation

On July 21, 2011, the FERC issued Order No. 1000, which revised the FERC's existing regulations governing the process for planning enhancements and expansions of the electric transmission grid in a particular region, along with the corresponding process for allocating the costs of such expansions. Order No. 1000 leaves to individual regions to determine whether a previously-approved project is subject to reevaluation and is therefore governed by the new rule.

Order No. 1000 requires, among other things, public utility transmission providers, such as the SPP, to participate in a process that produces a regional transmission plan satisfying certain standards, and requires that each such regional process consider transmission needs driven by public policy requirements (such as state or Federal policies favoring increased use of renewable energy resources). Order No. 1000 also directs public utility transmission providers to coordinate with neighboring transmission planning regions. In addition, Order No. 1000 establishes specific regional cost allocation principles and directs public utility transmission providers to participate in regional and interregional transmission planning processes that satisfy these principles.

On the issue of determining how entities are to be selected to develop and construct the specific transmission projects, Order No. 1000 directs public utility transmission providers to remove from the FERC-jurisdictional tariffs and agreements provisions that establish any Federal "right of first refusal" for the incumbent transmission owner (such as OG&E) regarding transmission facilities selected in a regional transmission planning process, subject to certain limitations. However, Order No. 1000 is not intended to affect the right of an incumbent transmission owner (such as OG&E) to build, own and recover costs for upgrades to its own transmission facilities, and Order No. 1000 does not alter an incumbent transmission owner's use and control of existing rights of way. Order No. 1000 also clarifies that incumbent transmission owners may rely on regional transmission facilities to meet their reliability needs or service obligations. The SPP currently has a "right of first refusal" for incumbent transmission owners and this provision has played a role in OG&E being selected by the SPP to build various transmission projects in Oklahoma. These changes to the "right of first refusal" apply only to "new transmission facilities," which are described as those subject to evaluation or reevaluation (under the applicable local or regional transmission planning process) subsequent to the effective date of the regulatory compliance filings required by the rule, which were filed on November 13, 2012. On May 29, 2013, the Governor signed House Bill 1932 into law which establishes a right of first refusal for Oklahoma incumbent transmission owners, including OG&E, to build new transmission projects with voltages under 300 kilovolts that interconnect to those incumbent entities' existing facilities. OG&E believes this law is consistent with the language of Order No. 1000.

On July 18, 2013, the FERC issued an order on the SPP's Order No. 1000 compliance filing.  This order accepted in part and rejected in part the SPP's plan for complying with Order No. 1000.  The FERC rejected the SPP's plan to retain the right of first refusal for projects that would operate between 100 kilovolts and 300 kilovolts.  However, the FERC clarified that a right of first refusal was appropriate in certain circumstances.  It is not clear how the FERC's order will relate to the recently enacted Oklahoma law addressing a right of first refusal for lower voltages.  On November 15, 2013, SPP made its FERC compliance filing, as required by the July 18, 2013 order. The SPP changes to its tariff and Membership Agreement included provisions that (i) clarify that facilities between 100 kilovolts and 300 kilovolts would be subject to the competitive selection process, (ii) only allow certain evidence, such as state laws (like House Bill 1932) and the holders of existing rights of way, to be considered during the competitive selection process and not earlier in the process; (iii) apply a right of first refusal to transmission projects needed for reliability within three years in certain situations; and (iv) revise the tariff’s competitive selection process, including changes to the criteria for identifying qualifying transmission owners, the requirements for submission of information by transmission owners seeking to participate in competitive selections, and the procedures that govern the competitive selection process.

OGE Energy cannot, at this time, determine the precise impact of Order No. 1000 on OG&E. OG&E has filed a petition for review in the D.C. Circuit relating to the same matter. Nevertheless, at the present time, OGE Energy has no reason to believe that the implementation of Order No. 1000 will impact OG&E's transmission projects currently under development and construction for which OG&E has received a notice to proceed from the SPP.

Fuel Adjustment Clause Review for Calendar Year 2012

On July 31, 2013, the OCC Staff filed an application to review OG&E's fuel adjustment clause for calendar year 2012, including the prudence of OG&E's electric generation, purchased power and fuel procurement costs. OG&E filed the necessary information and documents needed to satisfy the OCC's minimum filing requirement rules on October 9, 2013. A hearing on this matter is scheduled for April 24, 2014.

5

Request for Modification to Previous Orders

On August 2, 2013, OG&E filed an application at the OCC seeking to make minor modifications to three previous OCC orders. The purpose of the application was to address the timing of certain requirements contained in those orders. OG&E's application proposed to address these issues in OG&E's next general rate case thus avoiding the cost associated with a rate case filing now and benefiting customers by deferring the recovery of certain costs identified in the previous orders. On September 3, 2013, the PUD Staff filed a motion to dismiss OG&E's application. PUD Staff requested that the OCC dismiss OG&E's application and issue an order requiring OG&E to file a rate case for the 2012 test year.

On September 11, 2013, the PUD Staff withdrew their motion to dismiss OG&E's application and on September 12, 2013, filed an application requesting a public hearing, review and possible adjustment of the rates and charges of OG&E based on the 2012 test year. To date, no procedural schedule has been established for either the OG&E application or the PUD Staff application.

Energy Efficiency Program Filing

On October 9, 2013 OG&E filed an application with the APSC requesting approval of interim modifications to approved Energy Efficiency Programs, new tariff revisions and the waiver of certain provisions of the Commission’s Rules for Conservation and Energy Efficiency Programs.

Market-Based Rate Authority

On June 29, 2012, OG&E filed its triennial market power update with the FERC to retain its market-based rate authorization in the SPP's energy imbalance service market but to surrender its market-based rate authorization for any market-based rates sales outside of the SPP's energy imbalance service market. On May 2, 2013, the FERC issued an order accepting OG&E's June 2012 triennial market power update.

On December 30, 2013, OG&E submitted to the FERC a market-based rate change in status filing and a revised market-based rate tariff.  The revised tariff will authorize OG&E to (i) sell electric energy and capacity at market-based rates without geographic restriction, and (ii) sell ancillary services in the SPP and Midcontinent Independent System Operator, Inc. markets.  The primary goal of this filing was to implement the market-based rate authority OG&E needs to fully participate in SPP’s Integrated Marketplace.  OG&E requested that FERC issue an order on or before February 28, 2014 that accepts the revised market-based rate tariff to be effective on the date SPP’s Integrated Marketplace goes into operation, which is expected to be March 1, 2014.

Section 206 Complaint

On November 26, 2013, Arkansas Electric Cooperative Corporation filed a complaint at the FERC against OG&E, arguing that the wholesale formula rate contract between OG&E and Arkansas Electric Cooperative Corporation (formerly between OG&E and Arkansas Valley Electric Cooperative) is unjust and unreasonable with respect to several items.  After engaging in settlement discussions, OG&E and Arkansas Electric Cooperative Corporation have tentatively agreed to terms of a settlement and are jointly preparing an offer of settlement to be filed with FERC. OG&E believes the reduction in revenue will be less than$1.0 millionper year.

Regulatory Assets and Liabilities

OG&E, as a regulated utility, is subject to accounting principles for certain types of rate-regulated activities, which provide that certain actual or anticipated costs that would otherwise be charged to expense can be deferred as regulatory assets, based on the expected recovery from customers in future rates.  Likewise, certain actual or anticipated credits that would otherwise reduce expense can be deferred as regulatory liabilities, based on the expected flowback to customers in future rates.  Management's expected recovery of deferred costs and flowback of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment.

OG&E records certain actual or anticipated costs and obligations as regulatory assets or liabilities if it is probable, based on regulatory orders or other available evidence, that the cost or obligation will be included in amounts allowable for recovery or refund in future rates.

AtDecember 31, 2013and2012, OG&E had regulatory assets of$427.9 millionand$537.6 million, respectively, and regulatory liabilities of$254.4 millionand$386.2 million, respectively.See Note 1 of Notes toFinancial Statements for a further discussion.

6

Management continuously monitors the future recoverability of regulatory assets.When in management's judgment future recovery becomes impaired, the amount of the regulatory asset is adjusted, as appropriate.IfOG&Ewere required to discontinue the application of accounting principles for certain types of rate-regulated activities for some or all of its operations, it could result in writing off the related regulatory assets, which could have significant financial effects.

Rate Structures

Oklahoma

OG&E's standard tariff rates include a cost-of-service component (including an authorized return on capital) plus a fuel adjustment clause mechanism that allows OG&E to pass through to customers the actual cost of fuel and purchased power.

OG&E offers several alternate customer programs and rate options.  Under OG&E's Smart Grid enabled SmartHours® programs, "time-of-use" and "variable peak pricing" rates offer customers the ability to save on their electricity bills by shifting some of the electricity consumption to times when demand for electricity and costs are at their lowest. The guaranteed flat bill option for residential and small general service accounts allows qualifying customers the opportunity to purchase their electricity needs at a set monthly price for an entire year.  Budget-minded customers that desire a fixed monthly bill may benefit from the guaranteed flat bill option.  A second tariff rate option provides a "renewable energy" resource to OG&E's Oklahoma retail customers. This renewable energy resource is a Renewable Energy Credit purchase program and is available as a voluntary option to all of OG&E's Oklahoma retail customers.  OG&E's ownership and access to wind resources makes the renewable option a possible choice in meeting the renewable energy needs of our conservation-minded customers.  Another program being offered to OG&E's commercial and industrial customers is a voluntary load curtailment program called Load Reduction.  This program provides customers with the opportunity to curtail usage on a voluntary basis when OG&E's system conditions merit curtailment action. Customers that curtail their usage will receive payment for their curtailment response.  This voluntary curtailment program seeks customers that can curtail on most curtailment event days, but may not be able to curtail every time that a curtailment event is required.  OG&E also offers certain qualifying customers "day-ahead price" and "flex price" rate options which allow participating customers to adjust their electricity consumption based on price signals received from OG&E. The prices for the "day-ahead price" and "flex price" rate options are based on OG&E's projected next day hourly operating costs.

OG&E also has two rate classes, Public Schools-Demand and Public Schools Non-Demand, that provide OG&E with flexibility to provide targeted programs for load management to public schools and their unique usage patterns. OG&E also provides service level, seasonal and time period fuel charge differentiation that allows customers to pay fuel costs that better reflect the underlying costs of providing electric service.  Lastly, OG&E has a military base rider that demonstrates Oklahoma's continued commitment to our military partners.

The previously discussed rate options, coupled with OG&E's other rate choices, provide many tariff options for OG&E's Oklahoma retail customers.  The revenue impacts associated with these options are not determinable in future years because customers may choose to remain on existing rate options instead of volunteering for the alternative rate option choices.  Revenue variations may occur in the future based upon changes in customers' usage characteristics if they choose alternative rate options. OG&E's rate choices, reduction in cogeneration rates, acquisition of additional generation resources and overall low costs of production and deliverability are expected to provide valuable benefits for OG&E's customers for many years to come.

Arkansas

OG&E's standard tariff rates include a cost-of service component (including an authorized return on capital) plus an energy cost recovery mechanism that allows OG&E to pass through to customers the actual cost of fuel. OG&E offers several alternate customer programs and rate options. The "time-of-use" and "variable peak pricing" tariffs allow participating customers to save on their electricity bills by shifting some of the electricity consumption to times when demand for electricity is lowest. A second tariff rate option provides a "renewable energy" resource to OG&E's Arkansas retail customers. This renewable energy resource is a Renewable Energy Credit purchase program and is available as a voluntary option to all of OG&E's Arkansas retail customers.  OG&E's ownership and access to wind resources makes the renewable option a possible choice in meeting the renewable energy needs of our conservation-minded customers. OG&E offers its commercial and industrial customers a voluntary load curtailment program called Load Reduction. This program provides customers with the opportunity to curtail usage on a voluntary basis and receive a billing credit when OG&E's system conditions merit curtailment action. OG&E offers certain qualifying customers a "day-ahead price" rate option which allows participating customers to adjust their electricity consumption based on a price signal received from OG&E. The day-ahead price is based on OG&E's projected next day hourly operating costs.

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Fuel Supply and Generation

In2013, 53 percentof the OG&E-generated energy was produced by coal-fired units,40 percentby natural gas-fired units andseven percentby wind-powered units.Of OG&E's6,785total MW capability reflected in the table under Item 2. Properties,3,798MWs, or56 percent, are from natural gas generation,2,538MWs, or37 percent, are from coal generation and449MWs, orseven percent, are from wind generation. Though OG&E has a higher installed capability of generation from natural gas units, it has been more economical to generate electricity for our customers using lower priced coal. Over the last five years, the weighted average cost of fuel used, by type, was as follows:

Year ended December 31 (In Kilowatt-Hour - cents)	2013	2012	2011	2010	2009
Natural gas	3.905	2.930	4.328	4.638	3.696
Coal	2.273	2.310	2.064	1.911	1.747
Weighted average	2.784	2.437	2.897	3.012	2.474

The increase in the weighted average cost of fuel in 2013 as compared to 2012 was primarily due to higher gas prices. The decrease in the weighted average cost of fuel in 2012 as compared to 2011 was primarily due to lower natural gas prices. The decrease in the weighted average cost of fuel in 2011 as compared to 2010 was primarily due to lower natural gas prices and lower natural gas generation. The increase in the weighted average cost of fuel in 2010 as compared to 2009 was primarily due to higher natural gas prices and increased natural gas generation. These fuel costs are recovered through OG&E's fuel adjustment clauses that are approved by the OCC, the APSC and the FERC.

Coal

All of OG&E's coal-fired units, with an aggregate capability of2,538MWs, are designed to burn low sulfur western sub-bituminous coal. OG&E has contracted for approximately 55 percent of its forecasted annual coal usage via multi-year contracts that expire in2016and the remainder of its forecasted2014usage via one-year contracts that expire in2014. In2013, OG&E purchased7.8 milliontons of coal from various Wyoming suppliers. The combination of all coal has a weighted average sulfur content of0.21 percent. Based upon the average sulfur content and EPA certified emission data, OG&E's coal units have an approximate emission rate of0.5lbs. of SO2 per MMBtu.As discussed in "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Environmental Laws and Regulations," emission limits are expected to become more stringent.

See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Environmental Laws and Regulations" for a discussion of environmental matters which may affect OG&E in the future, including its utilization of coal.

Natural Gas

OG&E has entered into multiple month term natural gas contracts for31.5 percentof its 2014 annual forecasted natural gas requirements. Additional gas supplies to fulfill OG&E's remaining 2014 natural gas requirements will be acquired through additional requests for proposal in early to mid-2014, along with monthly and daily purchases, all of which are expected to be made at market prices.

OG&E utilizes natural gas storage service on Enable's and OneOK Gas Transmission's pipelines. The storage services allow OG&E to maximize the value of its generation assets. AtDecember 31, 2013, OG&E had2.1 millionMMBtu's in natural gas storage valued at$7.6 million.

Wind

OG&E's current wind power portfolio includes: (i) the120MW Centennial wind farm, (ii) the101MW OU Spirit wind farm, (iii) the227.5MW Crossroads wind farm, (iv) access to up to50MWs of electricity generated at a wind farm near Woodward, Oklahoma from a 15-year contract OG&E entered into with FPL Energy that expires in 2018, (v) access to up to150MWs of electricity generated at a wind farm in Woodward County, Oklahoma from a 20-year contract OG&E entered into with CPV Keenan that expires in 2030, (vi) access to up to130MWs of electricity generated at a wind farm in Dewey County, Oklahoma from a 20-year contract OG&E entered into with Edison Mission Energy that expires in 2030 and (vii) access to up to60MWs of electricity generated at a wind farm near Blackwell, Oklahoma from a 20-year contract OG&E entered into with NextEra Energy that expires in 2032.

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Safety and Health Regulation

OG&E is subject to a number of Federal and state laws and regulations, including OSHA, EPA and comparable state statutes, whose purpose is to protect the safety and health of workers.

In addition, the OSHA hazard communication standard, the EPA Emergency Planning and Community Right-to-Know regulations under Title III of the Federal Superfund Amendment and Reauthorization Act and comparable state statutes require that information be maintained concerning hazardous materials stored, used or produced in OG&E's operations and that this information be provided or made available to employees, state and local government authorities and citizens. OG&E believes that it is in material compliance with all applicable laws and regulations relating to worker safety and health.

ENVIRONMENTAL MATTERS

General

The activities ofOG&Eare subject to stringent and complex Federal, state and local laws and regulations governing environmental protection relating to air quality, water quality, waste management, wildlife conservation and natural resources. These laws and regulations can restrict or impact business activities in many ways, such as restricting the way it can handle or dispose of its wastes, requiring remedial action to mitigate environmental issues that may be caused by its operations or that are attributable to former operators, requiring changes in operations and requiring the installation and operation of pollution control equipment. Failure to comply with these laws and regulations could result in the assessment of administrative, civil and criminal penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations.

The trend in environmental regulation, however, is to place more restrictions and limitations on activities that may affect the environment. OG&E cannot assure that future events, such as changes in existing laws, the promulgation of new laws or regulations, or the development or discovery of new facts or conditions will not cause it to incur significant costs. Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

It is estimated that OG&E'stotal expenditures to comply with environmental laws, regulations and requirements for2014will be$72.6 million, of which$55.0 millionis for capital expenditures.It is estimated that OG&E'stotal expenditures to comply with environmental laws, regulations and requirements for2015will be$49.6 million, of which$31.3 millionis for capital expenditures.The amountsabove include capital expenditures for low NOX burners and activated carbon injection and exclude certain other capital expenditures as discussed in footnote D to the capital expenditures table in"Finance and Construction" below. OG&E's management believes that all of its operations are in substantial compliance with current Federal, state and local environmental standards.Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

For a further discussion of environmental matters that may affect OG&E, see "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations – Environmental Laws and Regulations."

FINANCE AND CONSTRUCTION

Future Capital Requirements and Financing Activities

Capital Requirements

OG&E'sprimary needs for capital are related to acquiring or constructing new facilities and replacing or expanding existing facilities.  Other working capital requirements are expected to be primarily related to maturing debt, operating lease obligations, fuel clause under and over recoveries and other general corporate purposes.OG&Egenerally meets its cash needs through a combination of cash generated from operations, short-term borrowings (through a combination of bank borrowings, commercial paperand borrowings from OGE Energy)and permanent financings.See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Liquidity and Capital Resources" for a discussion of OG&E's capital requirements.

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Capital Expenditures

OG&E'sestimates of capital expenditures for the years2014through2018are shown in the following table.These capital expenditures represent the base maintenance capital expenditures (i.e., capital expenditures to maintain and operateOG&E's business) plus capital expenditures for known and committed projects.

(In millions)	2014		2015		2016		2017		2018
Base Transmission	$	30	$	30	$	30	$	30	$	30
Base Distribution	175		175		175		175		175
Base Generation	140		75		75		75		75
Other	15		15		15		15		15
Total Base Transmission, Distribution, Generation and Other	360		295		295		295		295
Known and Committed Projects:
Transmission Projects:
Regionally Allocated Base Projects (A)	55		20		20		20		20
Balanced Portfolio 3E Projects (B)(C)	15		—		—		—		—
SPP Priority Projects (B)(C)	75		—		—		—		—
SPP Integrated Transmission Projects (B) (C)	15		25		30		25		10
Total Transmission Projects	160		45		50		45		30
Other Projects:
Smart Grid Program	25		10		10		—		—
Environmental - low NOX burners	35		20		15		10		—
Environmental - activated carbon injection	5		10		5		—		—
Total Other Projects	65		40		30		10		—
Total Known and Committed Projects	225		85		80		55		30
Total (D)	$	585	$	380	$	375	$	350	$	325

(A) Approximately 30% of revenue requirement allocated to SPP members other than OG&E.

(B) Approximately 85% of revenue requirement allocated to SPP members other than OG&E.

(C)	Project Type	Project Description	Estimated Cost (In millions)	Projected In-Service Date
	Balance Portfolio 3E	96 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to the Oklahoma /Texas Stateline to a companion transmission line to its Tuco substation	$110	Mid-2014
	Priority Project	99 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to the western Beaver County line to a companion transmission line to its Hitchland substation	$165	Mid-2014
	Priority Project	77 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to a companion transmission line at the Kansas border	$140	Late 2014
	Integrated Transmission Project	47 miles of transmission line from OG&E's Gracemont substation to an AEP companion transmission line to its Elk City substation	$45	Early 2018
	Integrated Transmission Project	126 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to OG&E's Cimarron substation; construction of the Mathewson substation on this transmission line	$180	Early 2021

(D) The capital expenditures above exclude any environmental expenditures associated with:

• Pollution control equipment related to controlling SO2 emissions under the regional haze requirements due to the uncertainty regarding the approach and timing for such pollution control equipment.The SO2 emissions standards in the EPA's FIP could require the installation of Dry Scrubbers or fuel switching. OG&E estimates that installing such Dry Scrubbers could cost more than$1.0 billion. The FIP is being challenged by OG&E and the state of Oklahoma. On June 22, 2012, OG&E was granted a stay of the FIP by the U.S. Court of Appeals for the Tenth Circuit.On July 19, 2013, the U.S. Court of Appeals for the Tenth Circuit by a 2 to 1 vote denied the petition for review and affirmed the EPA's issuance of the FIP. On January 2, 2014, the Tenth Circuit confirmed that the stay of the FIP has remained in place and continues

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until the Tenth Circuit issues the mandate. A Petition for Certiorari was filed by the State of Oklahoma, the Industrial Consumers and OG&E with the United States Supreme Court on January 29, 2014. The mandate from the Tenth Circuit has been stayed until the Supreme Court acts on the petition. If the Supreme Court elects not to hear the case, OG&E will have approximately 55 months from the effective date of the lifting of the stay to achieve compliance with the FIP.

• Installation of control equipment (other than activated carbon injection) for compliance with MATS by a deadline of April 16, 2016, which includes a one-year extension which was granted by the Oklahoma Department of Environmental Quality. As noted above, OG&E is currently planning to utilize activated carbon injection for the removal of mercury at each of its five coal-fired units, the capital costs of which are estimated to be approximately $20 million over a three year period and are included in the capital expenditures table in "Future Capital Requirements and Financing Activities" above. OG&E continues to review whether additional controls such as dry sorbent injection are needed for compliance with MATS. Current capital costs for installing the necessary control equipment for dry sorbent injection are estimated to be approximately$45 millionover a three year period, but due to the uncertainty as to whether or not dry sorbent injection is necessary, such costs are not included in the capital expenditures table in "Future Capital Requirements and Financing Activities" above.

OG&E is currently evaluating options to comply with environmental requirements. For further information, see"Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations -Environmental Laws and Regulations" below.

Additional capital expenditures beyond those identified in the table above, including additional incremental growth opportunities in electric transmission assets, will be evaluated based upon their impact upon achievingOG&E'sfinancial objectives.

Pension and Postretirement Benefit Plans

During both2013and2012, OGE Energy made contributions to its Pension Plan of$35 million, of whichnonein 2013 and$33 millionin 2012 was OG&E's portion,to help ensure that the Pension Plan maintains an adequate funded status.During2014, OGE Energy expects to contribute up to$26 millionto its Pension Plan, of which$1 millionis expected to be OG&E's portion.See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Liquidity and Capital Resources - Future Capital Requirements and Financing Activities" for a discussion of OGE Energy's pension and postretirement benefit plans.

Future Sources of Financing

Management expects that cash generated from operations, proceeds from the issuance of long and short-term debt and funds received from OGE Energy (fromproceeds from the sales ofitscommon stock to the public throughOGE Energy'sAutomatic Dividend Reinvestment and Stock Purchase Plan or other offerings) will be adequate over the next three years to meet anticipated cash needs and to fund future growth opportunities.OG&Eutilizes short-term borrowings (through a combination of bank borrowings, commercial paperand borrowings from OGE Energy)to satisfy temporary working capital needs and as an interim source of financing capital expenditures until permanent financing is arranged.

Short-Term Debt and Credit Facility

AtDecember 31, 2013there were$87.2 millionin net outstanding advances from OGE Energy as compared to$90.3 million in net outstanding advances to OGE Energy at December 31, 2012. OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to$400 millionof OGE Energy's revolving credit amount.This agreement has a termination date ofDecember 13, 2017.  AtDecember 31, 2013, there werenointercompany borrowings under this agreement.OG&E has a$400 millionrevolving credit facility which is available to back up OG&E's commercial paper borrowings and to provide revolving credit borrowings.This bank facility can also be used as a letter of credit facility.AtDecember 31, 2013, there was$2.1 millionsupporting letters of credit at a weighted-average interest rate of0.53 percent.  There werenooutstanding borrowings under this revolving credit agreement andnooutstanding commercial paper borrowings atDecember 31, 2013.  AtDecember 31, 2013, OG&E had$397.9 millionof net available liquidity under its revolving credit agreement.OG&E has the necessary regulatory approvals to incur up to$800 millionin short-term borrowings at any one time for a two-year period beginning January 1, 2013 and ending December 31, 2014.AtDecember 31, 2013, OG&E had less than$0.1 millionin cash and cash equivalents.See Note 10 of Notes to Financial Statements for a discussion of OG&E's short-term debt activity.

In December 2011,OG&E entered into an unsecured five-year revolving credit agreement for $400.0 million. This credit facility contains an option, which may be exercised up to two times, to extend the term for an additional year, subject to consent of a specified percentage of the lenders. Effective July 29, 2013,OG&E utilized one of these one-year extensions, and received consent from all of the lenders, to extend the maturity of its credit agreementsto December 13, 2017.

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Issuance of Long-Term Debt

On May 8, 2013, OG&E issued$250 millionof3.9%senior notes dueMay 1, 2043. The proceeds from the issuance were added to OG&E's general funds and were used to repay short-term debt, to fund capital expenditures, to pay general corporate expenses and for working capital purposes.

Expected Issuance of Long-Term Debt

OG&E expects to issue up to$250 millionof long-term debt during 2014, depending on market conditions, to fund capital expenditures, to repay short or long-term borrowings and for general corporate purposes.

EMPLOYEES

OG&E had1,885employees atDecember 31, 2013.

EXECUTIVE OFFICERS

The following persons were Executive Officers of the Registrant as ofFebruary 25, 2014:

Name	Age	Title
Peter B. Delaney	60	Chairman of the Board and Chief Executive Officer
Sean Trauschke	46	President and Chief Financial Officer
William J. Bullard	65	General Counsel
Scott Forbes	56	Controller and Chief Accounting Officer
Patricia D. Horn	55	Vice President - Governance and Corporate Secretary
Gary D. Huneryager	63	Vice President - Internal Audits
Jesse B. Langston	51	Vice President - Retail Energy
Jean C. Leger, Jr.	55	Vice President - Utility Operations
Cristina F. McQuistion	49	Vice President - Strategic Planning, Performance Improvement and Chief Information Officer
Jerry A. Peace	51	Chief Generation Planning and Procurement - OG&E
Paul L. Renfrow	57	Vice President - Public Affairs, HR, HS&E and Regulatory
Charles B. Walworth	39	Treasurer

No family relationship exists between any of the Executive Officers of the Registrant.Messrs. Delaney, Trauschke, Bullard, Forbes, Huneryager, Renfrow, Walworth and Ms. Horn are also officers of OGE Energy. Each Executive Officer is to hold office until the Board of Directors meeting following the next Annual Meeting of Shareowners of OGE Energy, currently scheduled forMay 15, 2014.

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The business experience of each of the Executive Officers of the Registrant for the past five years is as follows:

Name	Business Experience
Peter B. Delaney	2012 - Present:	Chairman of the Board, President and Chief Executive Officer of OGE Energy Corp.
	2013 - Present:	Director of Enable GP LLC
	2013 - Present:	Chairman of the Board and Chief Executive Officer of OG&E
	2012 - 2013:	Chairman of the Board, President and Chief Executive Officer of OG&E
	2010 - 2011:	Chairman of the Board and Chief Executive Officer of OGE Energy Corp. and OG&E
	2010 - 2013:	Chief Executive Officer of Enogex Holdings
	2009 - 2013:	Chief Executive Officer of Enogex LLC
	2009 - 2010:	Chairman of the Board, President and Chief Executive Officer of OGE Energy Corp. and OG&E
Sean Trauschke	2014 - Present:	Chief Financial Officer of OGE Energy Corp.
	2013 - Present:	Director of Enable GP LLC
	2013 - Present:	President and Chief Financial Officer of OG&E
	2013 - 2014:	Vice President and Chief Financial Officer of OGE Energy Corp.
	2013:	Acting Chief Financial Officer of Enable GP LLC
	2009 - 2013:	Vice President and Chief Financial Officer of OGE Energy Corp. and OG&E
	2010 - 2013:	Chief Financial Officer of Enogex Holdings
	2009 - 2013:	Chief Financial Officer of Enogex LLC
	2009:	Senior Vice President - Investor Relations and Financial Planning of Duke Energy (electric utility)
William J. Bullard	2010 - Present:	Assistant General Counsel of OGE Energy Corp.; General Counsel of OG&E
	2009 - 2010:	Assistant General Counsel of OGE Energy Corp. and OG&E
Scott Forbes	2009 - Present:	Controller and Chief Accounting Officer of OGE Energy Corp. and OG&E
	2009:	Interim Chief Financial Officer of OGE Energy Corp. and OG&E
Patricia D. Horn	2014 - Present:	Vice President - Governance and Corporate Secretary of OGE Energy Corp. and OG&E
	2012 - 2014:	Vice President - Governance, Environmental and Corporate Secretary of OGE Energy Corp. and OG&E
	2010 - 2013:	Secretary of Enogex Holdings and Corporate Secretary of Enogex LLC
	2010 - 2012:	Vice President - Governance, Environmental, Health & Safety; Corporate Secretary of OGE Energy Corp. and OG&E
	2009 - 2010:	Vice President - Legal, Regulatory, Environmental Health & Safety and General Counsel of Enogex LLC
	2009 - 2010:	Assistant General Counsel of OGE Energy Corp.
Gary D. Huneryager	2009 - Present:	Vice President - Internal Audits of OGE Energy Corp. and OG&E
Jesse B. Langston	2009 - Present:	Vice President - Retail Energy of OG&E
Jean C. Leger, Jr.	2009 - Present:	Vice President - Utility Operations of OG&E
Cristina F. McQuistion	2014 - Present:	Vice President - Strategic Planning, Performance Improvement and Chief Information Officer of OG&E
	2013 - 2014:	Vice President - Strategic Planning, Performance Improvement and Chief Information Officer of OGE Energy Corp. and OG&E
	2011 - 2013:	Vice President - Strategy and Performance Improvement of OGE Energy Corp. and OG&E
	2009 - 2011:	Vice President - Process and Performance Improvement of OGE Energy Corp. and OG&E
Jerry A. Peace	2014 - Present:	Chief Generation Planning and Procurement Officer of OG&E
	2009 - 2014:	Chief Risk Officer of OGE Energy Corp. and OG&E

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Paul L. Renfrow	2014 - Present:	Vice President - Public Affairs, HR, HS&E and Regulatory of OGE Energy Corp.
	2012 - 2014:	Vice President - Public Affairs, Human Resources and Health & Safety of OGE Energy Corp. and OG&E
	2011 - 2012:	Vice President - Public Affairs and Human Resources of OGE Energy Corp. and OG&E
	2009 - 2011:	Vice President - Public Affairs of OGE Energy Corp. and OG&E
Charles B. Walworth	2014 - Present:	Treasurer of OGE Energy Corp. and OG&E
	2012 - 2014:	Assistant Treasurer of OGE Energy Corp. and OG&E
	2010 - 2012:	Senior Manager Finance of OGE Energy Corp.
	2009 - 2010:	Manager Corporate Finance of OGE Energy Corp.

ACCESS TO SECURITIES AND EXCHANGE COMMISSION FILINGS

OGE Energy's web site address iswww.oge.com. Through OGE Energy's website under the heading "Investor Relations," "SEC Filings," OGE Energy makes available, free of charge, OGE Energy's and OG&E's annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as soon as reasonably practicable after such material is electronically filed with or furnished to the Securities and Exchange Commission. Our Internet website and the information contained therein or connected thereto are not intended to be incorporated into this Form 10-K and should not be considered a part of this Form 10-K.

Item 1A.  Risk Factors.

In the discussion of risk factors set forth below, unless the context otherwise requires, the terms "we," "our" and "us"refer to OG&E. In addition to the other information in this Form 10-K and other documents filed by uswith the Securities and Exchange Commission from time to time, the following factors should be carefully considered in evaluating OG&E.  Such factors could affect actual results and cause results to differ materially from those expressed in any forward-looking statements made by or on behalf of us.  Additional risks and uncertainties not currently known to us or that we currently view as immaterial may also impair our business operations.

REGULATORY RISKS

OG&E's profitability depends to a large extent on the ability to fully recover its costs from its customers and there may be changes in the regulatory environment that impair its ability to recover costs from its customers.

OG&E is subject to comprehensive regulation by several Federal and state utility regulatory agencies, which significantly influences its operating environment and its ability to fully recover its costs from utility customers.Recoverability of any under recovered amounts from OG&E's customers due to a rise in fuel costs is a significant risk.  The utility commissions in the states where OG&E operates regulate many aspects of its utility operations including siting and construction of facilities, customer service and the rates that OG&E can charge customers. The profitability of the utility operations is dependent on OG&E's ability to fully recover costs related to providing energy and utility services to its customers.

In recent years, the regulatory environments in which OG&E operates have received an increased amount of attention.  It is possible that there could be changes in the regulatory environment that would impair OG&E's ability to fully recover costs historically paid by OG&E's customers.  State utility commissions generally possess broad powers to ensure that the needs of the utility customers are being met.  OG&E cannot assure that the OCC, APSC and the FERC will grant rate increases in the future or in the amounts requested, and they could instead lower OG&E's rates.

OG&E is unable to predict the impact on its operating results from the future regulatory activities of any of the agencies that regulate OG&E.  Changes in regulations or the imposition of additional regulations could have an adverse impact on OG&E's results of operations.

OG&E's rates are subject to rate regulation by the states of Oklahoma and Arkansas, as well as by a Federal agency, whose regulatory paradigms and goals may not be consistent.

OG&E is currently a vertically integrated electric utility and most of its revenue results from the sale of electricity to retail customers subject to bundled rates that are approved by the applicable state utility commission and from the sale of electricity to wholesale customers subject to rates and other matters approved by the FERC.

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OG&E operates in Oklahoma and western Arkansas and is subject to rate regulation by the OCC and the APSC, in addition to the FERC.  Exposure to inconsistent state and Federal regulatory standards may limit our ability to operate profitably.  Further alteration of the regulatory landscape in which we operate, including a change in our return on equity, may harm our financial position and results of operations.

Costs of compliance with environmental laws and regulations are significant and the cost of compliance with future environmental laws and regulations may adversely affect our results of operations,financial position, or liquidity.

We are subject to extensive Federal, state and local environmental statutes, rules and regulations relating to air quality, water quality, waste management, wildlife conservation, natural resources and health and safety that could, among other things, restrict or limit the output of certain facilities or the use of certain fuels required for the production of electricity and/or require additional pollution control equipment and otherwise increase costs.  There are significant capital, operating and other costs associated with compliance with these environmental statutes, rules and regulations and those costs may be even more significant in the future.  As discussed in "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Environmental Laws and Regulations", in 2011, the EPA accepted a portion of the Oklahoma SIP for regional haze, which requires the installation of low NOX burners on OG&E's affected units within five years at a cost of approximately$80 million. The EPA rejected Oklahoma's SO2 BART determination with respect to the four affected coal-fired units at the Sooner and Muskogee generating stations and issued a FIP in its place.The SO2 emissions standards in the EPA's FIP could require the installation of Dry Scrubbers or fuel switching. OG&E estimates that installing such Dry Scrubbers could cost more than$1.0 billion. OG&E, the state of Oklahoma and other parties, filed an appeal to challenge this determination, which has delayed the implementation of the regional haze rule in Oklahoma.Although the court initially stayed implementation of EPA’s FIP, it ultimately issued a decision affirming the FIP, and unless the Supreme Court accepts an appeal of the case, the FIP will require installation of Dry Scrubbers or fuel switching with a deadline sometime in 2018 or 2019.

In response to recent regulatory and judicial decisions, emissions of greenhouse gases including, most significantly, carbon dioxide could be restricted in the future as a result of Federal or state legal requirements or litigation relating to greenhouse gas emissions.  If mandatory reductions of carbon dioxide and other greenhouse gases are required in the future, this could result in significant additional compliance costs that would affect our futurefinancial position, results of operations and cash flows if such costs are not recovered through regulated rates. The EPA has started a process to implement carbon dioxide emission limitations for existing electric generating units, and neither the outcome of the rule making process nor the timing of any required expenditures resulting from the EPA rule making process can be predicted with any certainty at this time.

There is inherent risk of the incurrence of environmental costs and liabilities in our operations due to our handling of natural gas, air emissions related to our operations and historical industry operations and waste disposal practices. These activities are subject to stringent and complex Federal, state and local laws and regulations that can restrict or impact OG&E'sbusiness activities in many ways, such as restricting the way it can handle or dispose of its wastes or requiring remedial action to mitigate pollution conditions that may be caused by its operations or that are attributable to former operators. OG&Emay be unable to recover these costs from insurance.  Moreover, the possibility exists that stricter laws, regulations or enforcement policies could significantly increase compliance costs and the cost of any remediation that may become necessary.

For a further discussion of environmental matters that may affect OG&E, see "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations – Environmental Laws and Regulations."

We may not be able to recover the costs of our substantial planned investment in capital improvements and additions.

OG&E's business plan calls for extensive investment in capital improvements and additions, including the installation of environmental upgrades and retrofits and modernizing existing infrastructure as well as other initiatives.  Significant portions of OG&E's facilities were constructed many years ago.  Older generation equipment, even if maintained in accordance with good engineering practices, may require significant capital expenditures to maintain efficiency, to comply with changing environmental requirements or to provide reliable operations. OG&E currently provides service at rates approved by one or more regulatory commissions.  If these regulatory commissions do not approve adjustments to the rates OG&E charges, it would not be able to recover the costs associated with its planned extensive investment.  This could adversely affect OG&E's financial position and results of operations.  While OG&E may seek to limit the impact of any denied recovery by attempting to reduce the scope of its capital investment, there can no assurance as to the effectiveness of any such mitigation efforts, particularly with respect to previously incurred costs and commitments.

Our jurisdictions have fuel clauses that permit us to recover fuel costs through rates without a general rate case.  While prudent capital investment and variable fuel costs each generally warrant recovery, in practical terms our regulators could limit

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the amount or timing of increased costs that we would recover through higher rates.  Any such limitation could adversely affect our results of operations and financial position.

The regional power market in which OG&E operates has changing transmission regulatory structures, which may affect the transmission assets and related revenues and expenses.

OG&E currently owns and operates transmission and generation facilities as part of a vertically integrated utility. OG&E is a member of the SPP regional transmission organization and has transferred operational authority (but not ownership) of OG&E's transmission facilities to the SPP. The SPP implemented a regional energy imbalance service market on February 1, 2007. OG&E participates in the SPP energy imbalance service market to aid in the optimization of its physical assets to serve OG&E's customers. OG&E has not participated in the SPP energy imbalance service market for any speculative trading activities. The SPP purchases and sales are not allocated to individual customers. OG&E records the hourly sales to the SPP at market rates in Operating Revenues and the hourly purchases from the SPP at market rates in Cost of Sales in itsFinancial Statements. OG&E's revenues, expenses, assets and liabilities may be adversely affected by changes in the organization, operation and regulation by the FERC or the SPP, including the forthcoming SPP integrated marketplace, which is scheduled to begin operation in March 2014.

Increased competition resulting from restructuring efforts could have a significant financial impact onOG&E and consequently decrease our revenue.

We have been and will continue to be affected by competitive changes to the utility and energy industries.  Significant changes already have occurred and additional changes have been proposed to the wholesale electric market.  Although retail restructuring efforts in Oklahoma and Arkansas have been postponed for the time being, if such efforts were renewed, retail competition and the unbundling of regulated energy service could have a significant financial impact on us due to possible impairments of assets, a loss of retail customers, lower profit margins and/or increased costs of capital.  Any such restructuring could have a significant impact on ourfinancial position, results of operations and cash flows. We cannot predict when we will be subject to changes in legislation or regulation, nor can we predict the impact of these changes on ourfinancial position, results of operations or cash flows.

Events that are beyond our control have increased the level of public and regulatory scrutiny of our industry.  Governmental and market reactions to these events may have negative impacts on our business,financial position, results of operations, cash flows and access to capital.

As a result of accounting irregularities at public companies in general, and energy companies in particular, and investigations by governmental authorities into energy trading activities, public companies, including those in the regulated and unregulated utility business, have been under an increased amount of public and regulatory scrutiny and suspicion.  The accounting irregularities have caused regulators and legislators to review current accounting practices, financial disclosures and relationships between companies and their independent auditors.  The capital markets and rating agencies also have increased their level of scrutiny.  We believe that we are complying with all applicable laws and accounting standards, but it is difficult or impossible to predict or control what effect these types of events may have on our business,financial position, cash flows or access to the capital markets.  It is unclear what additional laws or regulations may develop, and we cannot predict the ultimate impact of any future changes in accounting regulations or practices in general with respect to public companies, the energy industry or our operations specifically.  Any new accounting standards could affect the way we are required to record revenues, expenses, assets, liabilities and equity.  These changes in accounting standards could lead to negative impacts on reported earnings or decreases in assets or increases in liabilities that could, in turn, affect our results of operations and cash flows.

We are subject to substantial utility and energy regulation by governmental agencies.  Compliance with current and future utility and energy regulatory requirements and procurement of necessary approvals, permits and certifications may result in significant costs to us.

We are subject to substantial regulation from Federal, state and local regulatory agencies.  We are required to comply with numerous laws and regulations and to obtain permits, approvals and certificates from the governmental agencies that regulate various aspects of our businesses, including customer rates, service regulations, retail service territories, sales of securities, asset acquisitions and sales, accounting policies and practices and the operation of generating facilities.  We believe the necessary permits, approvals and certificates have been obtained for our existing operations and that our business is conducted in accordance with applicable laws; however, we are unable to predict the impact on our operating results from future regulatory activities of these agencies.

In compliance with the Energy Policy Act of 2005, the FERC approved the North American Electric Reliability Corporation as the national energy reliability organization. The North American Electric Reliability Corporation is responsible for the

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development and enforcement of mandatory reliability and cyber security standards for the wholesale electric power system. OG&E's plan is to comply with all applicable standards and to expediently correct a violation should it occur.  The North American Electric Reliability Corporation has authority to assess penalties up to$1.0 millionper day per violation for noncompliance. In order to comply with new or updated security regulations, we may be required to make changes to our current operations which could also result in additional expenses. OG&E is subject to a North American Electric Reliability Corporation compliance audit every three years as well as periodic spot check audits and cannot predict the outcome of those audits.

OPERATIONAL RISKS

Our results of operations may be impacted by disruptions beyond our control.

We are exposed to risks related to performance of contractual obligations by our suppliers.  We are dependent on coal and natural gas for much of our electric generating capacity.  We rely on suppliers to deliver coal and natural gas in accordance with short and long-term contracts.  We have certain supply contracts in place; however, there can be no assurance that the counterparties to these agreements will fulfill their obligations to supply coal and natural gas to us.  The suppliers under these agreements may experience financial or technical problems that inhibit their ability to fulfill their obligations to us.  In addition, the suppliers under these agreements may not be required to supply coal and natural gas to us under certain circumstances, such as in the event of a natural disaster.  Deliveries may be subject to short-term interruptions or reductions due to various factors, including transportation problems, weather and availability of equipment.  Failure or delay by our suppliers of coal and natural gas deliveries could disrupt our ability to deliver electricity and require us to incur additional expenses to meet the needs of our customers.

Also, because our generation and transmission systems are part of an interconnected regional grid, we face the risk of possible loss of business due to a disruption or black-out caused by an event (severe storm, generator or transmission facility outage) on a neighboring system or the actions of a neighboring utility.  Any such disruption could result in a significant decrease in revenues and significant additional costs to repair assets, which could have a material adverse impact on ourfinancial position, results of operations and cash flows.

OG&E's electric generating facilities are subject to operational risks that could result in unscheduled plant outages, unanticipated operation and maintenance expenses and increased power purchase costs.

OG&E owns and operates coal-fired, natural gas-fired and wind-powered generating facilities.  Operation of electric generating facilities involves risks that can adversely affect energy output and efficiency levels.  Included among these risks are:

• increased prices for fuel and fuel transportation as existing contracts expire;

• facility shutdowns due to a breakdown or failure of equipment or processes or interruptions in fuel supply;

• operator error or safety related stoppages;

• disruptions in the delivery of electricity; and

• catastrophic events such as fires, explosions, floods or other similar occurrences.

Economic conditions could negatively impact our business and our results of operations.

Our operations are affected by local, national and worldwide economic conditions. The consequences of a prolonged recession could include a lower level of economic activity and uncertainty regarding energy prices and the capital and commodity markets.  A lower level of economic activity could result in a decline in energy consumption, which could adversely affect our revenues and future growth.  Instability in the financial markets, as a result of recession or otherwise, also could affect the cost of capital and our ability to raise capital.

Current economic conditions may be exacerbated by insufficient financial sector liquidity leading to potential increased unemployment, which could impact the ability of our customers to pay timely, increase customer bankruptcies, and could lead to increased bad debt.  If such circumstances occur, we expect that commercial and industrial customers would be impacted first, with residential customers following.

In addition, economic conditions, particularly budget shortfalls, could lead to increased pressure on Federal, state and local governments to raise additional funds, including through increased corporate taxes and/or through delaying, reducing or eliminating tax credits, grants or other incentives, which could have a material adverse impact on our results of operations.

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We are subject to financial risks associated with climate change.

Climate change creates financial risk. Potential regulation associated with climate change legislation could pose financial risks to OG&E. In addition, to the extent that any climate change adversely affects the national or regional economic health through increased rates caused by the inclusion of additional regulatory imposed costs (carbon dioxide taxes or costs associated with additional regulatory requirements), OG&E may be adversely impacted. A declining economy could adversely impact the overall financial health of OG&E because of lack of load growth and decreased sales opportunities. To the extent financial markets view climate change and emissions of greenhouse gases as a financial risk, this could negatively affect our ability to access capital markets or cause us to receive less than ideal terms and conditions.

We are subject to cyber security risks and increased reliance on processes automated by technology.

In the regular course of our businesses, we handle a range of sensitive security and customer information. We are subject to laws and rules issued by different agencies concerning safeguarding and maintaining the confidentiality of this information. A security breach of our information systems such as theft or inappropriate release of certain types of information, including confidential customer information or system operating information, could have a material adverse impact on ourfinancial position, results of operations and cash flows.

OG&Eoperatesin a highly regulated industry that requires the continued operation of sophisticated information technology systems and network infrastructure. Despite implementation of security measures, the technology systems are vulnerable to disability, failures or unauthorized access. Such failures or breaches of the systems could impact the reliability of OG&E's generation, transmission and distribution systems (including smart grid)which may result in a loss of service to customers and also subjects OG&Eto financial harm due to the significant expense to repair security breaches or system damage.The implementation of OG&E's smart grid program further increases potential risks associated with cyber security attacks. If the technology systems were to fail or be breached and not recovered in a timely way, critical business functions could be impaired and sensitive confidential data could be compromised, which could have a material adverse impact on itsfinancial position, results of operations and cash flows.

Our security procedures, which include among others, virus protection software, cyber security and our business continuity planning, including disaster recovery policies and back-up systems, may not be adequate or implemented properly to fully address the adverse affect of cyber security attacks on our systems, which could adversely impact our operations.

Terrorist attacks, and the threat of terrorist attacks, have resulted in increased costs to our business. Continued hostilities in the Middle East or other sustained military campaigns may adversely impact ourfinancial position, results of operations and cash flows.

The long-term impact of terrorist attacks and the magnitude of the threat of future terrorist attacks on the electric utilityindustry in general, and on us in particular, cannot be known. Increased security measures taken by us as a precaution against possible terrorist attacks have resulted in increased costs to our business. Uncertainty surrounding continued hostilities in the Middle East or other sustained military campaigns may affect our operations in unpredictable ways, including disruptions of supplies and markets for our products, and the possibility that our infrastructure facilities could be direct targets of, or indirect casualties of, an act of terror. Changes in the insurance markets attributable to terrorist attacks may make certain types of insurance more difficult for us to obtain.  Moreover, the insurance that may be available to us may be significantly more expensive than existing insurance coverage.

Weather conditions such as tornadoes, thunderstorms, ice storms, wind storms, and prolonged droughts, as well as seasonal temperature variations may adversely affect ourfinancial position, results of operations and cash flows.

Weather conditions directly influence the demand for electric power.  In OG&E's service area, demand for power peaks during the hot summer months, with market prices also typically peaking at that time.  As a result, overall operating results may fluctuate on a seasonal and quarterly basis.  In addition, we have historically sold less power, and consequently received less revenue, when weather conditions are milder.  Unusually mild weather in the future could reduce our revenues, net income, available cash and borrowing ability.  Severe weather, such as tornadoes, thunderstorms, ice storms and wind storms, may cause outages and property damage which may require us to incur additional costs that are generally not insured and that may not be recoverable from customers.  The effect of the failure of our facilities to operate as planned, as described above, would be particularly burdensome during a peak demand period. In addition, prolonged droughts could cause a lack of sufficient water for use in cooling during the electricity generating process.

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FINANCIAL RISKS

Market performance, increased retirements, changes in retirement plan regulations and increasing costs associated with our Pension Plan, health care plans and other employee-related benefits may adversely affect ourfinancial position, results of operations or liquidity.

OGE Energy has a Pension Plan that covers asignificant amount ofouremployeeshired before December 1, 2009.  OGE Energy also has defined benefit postretirement plans that cover a significant amount of our employees hired prior to February 1, 2000.  Assumptions related to future costs, returns on investments, interest rates and other actuarial assumptions with respect to the defined benefit retirement and postretirement plans have a significant impact on our results of operations and funding requirements.  Based on our assumptions atDecember 31, 2013, OGE Energy expects to continue to make future contributions to maintain required funding levels.It has been OGE Energy's practice in the past to also make voluntary contributions to maintain more prudent funding levels than minimally required. We may continue to make voluntary contributions in the future.  These amounts are estimates and may change based on actual stock market performance, changes in interest rates and any changes in governmental regulations.

If the employees who participate in the Pension Plan retire when they become eligible for retirement over the next several years, or if our plan experiences adverse market returns on its investments, or if interest rates materially fall, our pension expense and contributions to the plans could rise substantially over historical levels. The timing and number of employees retiring and selecting the lump-sum payment option could result in pension settlement charges that could materially affect our results of operations if we are unable to recover these costs through our electric rates.  In addition, assumptions related to future costs, returns on investments, interest rates and other actuarial assumptions, including projected retirements, have a significant impact on ourfinancial position and results of operations.  Those factors are outside of our control.

In addition to the costs of our Pension Plan, the costs of providing health care benefits to our employees and retirees have increased substantially in recent years.  We believe that our employee benefit costs, including costs related to health care plans for our employees, will continue to rise.  The increasing costs and funding requirements with our Pension Plan, health care plans and other employee benefits may adversely affect ourfinancial position, results of operations or liquidity.

We face certain human resource risks associated with the availability of trained and qualified labor to meet our future staffing requirements.

Workforce demographic issues challenge employers nationwide and are of particular concern to the electric utilityindustry.The median age of utilityworkers is significantly higher than the national average.  Over the next three years,35 percentof our current employees will be eligible to retire with full pension benefits.  Failure to hire and adequately train replacement employees, including the transfer of significant internal historical knowledge and expertise to the new employees, may adversely affect our ability to manage and operate our business.

Wemay be able to incur substantially more indebtedness, which may increase the risks created by our indebtedness.

The terms of the indentures governing our debt securities do not fully prohibit usfrom incurring additional indebtedness. If weare in compliance with the financial covenants set forth in our revolving credit agreementand the indentures governing our debt securities, wemay be able to incur substantial additional indebtedness. If weincur additional indebtedness, the related risks that we and they now face may intensify.

Any reductions in our credit ratings could increase our financing costs and the cost of maintaining certain contractual relationships or limit our ability to obtain financing on favorable terms.

We cannot assure you that any of our current credit ratingswill remain in effect for any given period of time or that a rating will not be lowered or withdrawn entirely by a rating agency if, in its judgment, circumstances so warrant. Ourability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions.Pricing grids associated withOGE Energy's and OG&E'screditfacilitiescould cause annual fees and borrowing rates to increase if an adverse rating impact occurs. The impact of any future downgrade could include an increase in the costs ofourshort-term borrowings, but a reduction inourcredit ratings would not result in any defaults or accelerations. Any future downgradeof OGE Energy or OG&Ecould also lead to higher long-term borrowing costs and, if below investment grade, would requireusto post collateral or letters of credit.

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Our debt levels may limit our flexibility in obtaining additional financing and in pursuing other business opportunities.

We have a revolving credit agreementfor working capital, capital expenditures, including acquisitions, and other corporate purposes.  The levels of our debt could have important consequences, including the following:

• the ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired or the financing may not be available on favorable terms;

• a portion of cash flows will be required to make interest payments on the debt, reducing the funds that would otherwise be available for operations and future business opportunities; and

• our debt levels may limit our flexibility in responding to changing business and economic conditions.

We are exposed to the credit risk of our key customers and counterparties, and any material nonpayment or nonperformance by our key customers and counterparties could adversely affect ourfinancial position, results of operations and cash flows.

We are exposed to credit risks in our generation and retail distributionoperations.Credit risk includes the risk that counterparties that owe us money or energy will breach their obligations.If the counterparties to these arrangements fail to perform, we may be forced to enter into alternative arrangements.In that event, our financial results could be adversely affected and we could incur losses.

Item 1B.  Unresolved Staff Comments.

None.

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Item 2.  Properties.

OG&E owns and operates an interconnected electric generation, transmission and distribution system, located in Oklahoma and western Arkansas, which included10generating stations with an aggregate capability of6,785MWs atDecember 31, 2013. The following tables set forth information with respect to OG&E's electric generating facilities, all of which are located in Oklahoma.

						2013 Capacity Factor (A)			Unit Capability (MW)	Station Capability (MW)
		Year Installed		Fuel Capability	Unit Run Type
Station & Unit			Unit Design Type
Seminole	1	1971	Steam-Turbine	Gas	Base Load	20.2	%		486
	1GT	1971	Combustion-Turbine	Gas	Peaking	0.1	%	(B)	16
	2	1973	Steam-Turbine	Gas	Base Load	26.1	%		482
	3	1975	Steam-Turbine	Gas/Oil	Base Load	24.1	%		489	1,473
Muskogee	4	1977	Steam-Turbine	Coal	Base Load	39.3	%		491
	5	1978	Steam-Turbine	Coal	Base Load	51.0	%		506
	6	1984	Steam-Turbine	Coal	Base Load	59.3	%		500	1,497
Sooner	1	1979	Steam-Turbine	Coal	Base Load	68.7	%		520
	2	1980	Steam-Turbine	Coal	Base Load	61.2	%		521	1,041
Horseshoe Lake	6	1958	Steam-Turbine	Gas/Oil	Base Load	1.4	%		169
	7	1963	Combined Cycle	Gas/Oil	Base Load	17.1	%		193
	8	1969	Steam-Turbine	Gas	Base Load	10.1	%		394
	9	2000	Combustion-Turbine	Gas	Peaking	1.4	%	(B)	46
	10	2000	Combustion-Turbine	Gas	Peaking	1.8	%	(B)	45	847
Redbud (C)	1	2003	Combined Cycle	Gas	Base Load	48.6	%		149
	2	2003	Combined Cycle	Gas	Base Load	41.9	%		147
	3	2003	Combined Cycle	Gas	Base Load	46.7	%		147
	4	2003	Combined Cycle	Gas	Base Load	50.3	%		149	592
Mustang	1	1950	Steam-Turbine	Gas	Peaking	2.1	%	(B)	50
	2	1951	Steam-Turbine	Gas	Peaking	2.2	%	(B)	50
	3	1955	Steam-Turbine	Gas	Base Load	5.8	%		121
	4	1959	Steam-Turbine	Gas	Base Load	17.3	%		242
	5A	1971	Combustion-Turbine	Gas/Jet Fuel	Peaking	0.3	%	(B)	34
	5B	1971	Combustion-Turbine	Gas/Jet Fuel	Peaking	0.4	%	(B)	36	533
McClain (D)	1	2001	Combined Cycle	Gas	Base Load	75.7	%		353	353
Total Generating Capability (all stations, excluding wind stations) (E)										6,336
						2013 Capacity Factor (A)			Unit Capability (MW)	Station Capability (MW)
		Year Installed		Number of Units	Fuel Capability
Station			Location
Crossroads		2011	Canton, OK	98	Wind	44.3	%		2.32	227.5
Centennial		2007	Laverne, OK	80	Wind	36.9	%		1.5	120.0
OU Spirit		2009	Woodward, OK	44	Wind	40.6	%		2.3	101.2
Total Generating Capability (wind stations)										448.7

(A) 2013Capacity Factor =2013Net Actual Generation / (2013Net Maximum Capacity (Nameplate Rating in MWs) x Period Hours (8,760Hours)).

(B) Peaking units are used when additional short-term capacity is required.

(C) Represents OG&E's51 percentownership interest in the Redbud Plant.

(D) Represents OG&E's77 percentownership interest in the McClain Plant.

AtDecember 31, 2013, OG&E's transmission system included: (i)51substations with a total capacity of12.0 millionkilovolt-amps and4,589structure miles of lines in Oklahoma and (ii)sevensubstations with a total capacity of2.4 millionkilovolt-amps and278structure miles of lines in Arkansas.OG&E's distribution system included: (i)353substations with a total capacity of9.5 millionkilovolt-amps,29,144structure miles of overhead lines,2,239miles of underground conduit and10,617miles of underground conductors in Oklahoma and (ii)33substations with a total capacity of1.0 millionkilovolt-amps,2,775structure miles of overhead lines,232miles of underground conduit and696miles of underground conductors in Arkansas.

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OG&E owns140,133square feet of office space at its executive offices at321 North Harvey, Oklahoma City, Oklahoma 73102.In addition to its executive offices, OG&E owns numerous facilities throughout its service territory that support its operations. These facilities include, but are not limited to, service centers, fleet and equipment service facilities, operation support and other properties.

During the three years endedDecember 31, 2013, OG&E's gross property, plant and equipment (excluding construction work in progress) additions were$2.2 billionand gross retirements were$246.7 million. These additions were provided by cash generated from operations, short-term borrowings (through a combination of bank borrowings, commercial paperand borrowings from OGE Energy), long-term borrowings and permanent financings.The additions during this three-year period amounted to24.8 percentof gross property, plant and equipment (excluding construction work in progress) atDecember 31, 2013.

Item 3.  Legal Proceedings.

In the normal course of business,OG&Eis confronted with issues or events that may result in a contingent liability.These generally relate to lawsuits or claims made by third parties, including governmental agencies.When appropriate, management consults with legal counsel and other appropriate experts to assess the claim.If, in management's opinion,OG&Ehas incurred a probable loss as set forth by GAAP, an estimate is made of the loss and the appropriate accounting entries are reflected inOG&E'sFinancial Statements.At the present time, based on currently available information, except as set forth below, under "Environmental Laws and Regulations" in Item 7 of Part II of this Form 10-K and in Notes 12 and 13 of Notes toFinancial Statements,OG&Ebelieves that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect onOG&E'sfinancial position, results of operations or cash flows.

1.    Patent Infringement Case.On September 16, 2011, TransData, Inc., a Texas corporation, sued OG&E in the Western District of Oklahoma, accusing OG&E of infringing three of their U.S. patents by using OG&E's General Electric "smart" meters with Silver Spring Networks wireless modules. The complaint seeks a judgment of infringement, unspecified damages, a permanent injunction, costs and attorneys fees. OG&E was served with the complaint on September 21, 2011 and has notified both General Electric and Silver Springs Network of the lawsuit and its intent to seek indemnity from those companies for any damages that it may incur from this lawsuit. TransData, Inc. sought to consolidate its OG&E lawsuit with similar lawsuits in the Eastern District of Texas, however, on December 13, 2011, the TransData, Inc. cases were consolidated in the Western District of Oklahoma. OG&E has filed a motion for extension of time to answer the complaint. On December 30, 2011, OG&E and General Electric agreed to terms for General Electric to provide OG&E with an unqualified defense in the matter and to indemnify OG&E for costs, expenses and damages awarded against OG&E subject to a reservation of rights.While OG&E cannot predict the outcome of this lawsuit at this time, OG&E intends to vigorously defend this action and believes that its ultimate resolution will not be material to OG&E's financial position, results of operations or cash flows.

Item 4.  Mine Safety Disclosures.

Not Applicable.

PART II

Item 5. Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

Currently, all of OG&E's outstanding common stock is held by OGE Energy. Therefore, there is no public trading market for OG&E's common stock.

In2013and2012, OG&E declared dividends to OGE Energy of$170.0 millionand$75.0 million, respectively. In2011, OG&E declarednodividends to OGE Energy.

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Item 6. Selected Financial Data

HISTORICAL DATA

Year ended December 31	2013			2012			2011			2010			2009
SELECTED FINANCIAL DATA
(In millions)
Results of Operations Data:
Operating revenues	$	2,262.2		$	2,141.2		$	2,211.5		$	2,109.9		$	1,751.2
Cost of sales	965.9			879.1			1,013.5			1,000.2			796.3
Operating expenses	771.0			772.7			725.7			696.0			600.8
Operating income	525.3			489.4			472.3			413.7			354.1
Allowance for equity funds used during construction	6.6			6.2			20.4			11.4			15.1
Other income	8.1			8.2			8.5			6.6			21.5
Other expense	4.6			4.3			8.4			1.6			6.7
Interest expense	129.3			124.6			111.6			103.4			93.6
Income tax expense	113.5			94.6			117.9			111.0			90.0
Net income	$	292.6		$	280.3		$	263.3		$	215.7		$	200.4
Balance Sheet Data (at period end):
Property, plant and equipment, net	$	6,634.6		$	6,044.1		$	5,550.9		$	4,877.3		$	4,467.6
Total assets	$	7,694.9		$	7,222.4		$	6,620.9		$	5,898.1		$	5,478.1
Long-term debt	$	2,300.2		$	2,050.3		$	2,039.2		$	1,790.4		$	1,541.8
Total stockholder's equity	$	2,829.3		$	2,703.1		$	2,494.0		$	2,178.1		$	2,024.3
Capitalization Ratios (A)
Stockholder's equity	55.2		%	56.9		%	55.0		%	54.9		%	56.8		%
Long-term debt	44.8		%	43.1		%	45.0		%	45.1		%	43.2		%
Ratio of Earnings to Fixed Charges (B)
Ratio of earnings to fixed charges	3.96			3.87			4.01			3.90			3.71

(A) Capitalization ratios = [Total stockholder's equity / (Total stockholder's equity + Long-term debt + Long-term debt due within one year)] and [(Long-term debt + Long-term debt due within one year) / (Total stockholder's equity + Long-term debt + Long-term debt due within one year)].

(B) For purposes of computing the ratio of earnings to fixed charges, (i) earnings consist of pre-tax income plus fixed charges, less allowance for borrowed funds used during constructionand (ii) fixed charges consist of interest on long-term debt, related amortization, interest on short-term borrowings and a calculated portion of rents considered to be interest.

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Item 7.  Management's Discussion and Analysis of Financial Condition and Results of Operations.

Introduction

OG&Egenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. Its operationsare subject to regulation by the OCC, the APSC and the FERC.OG&E was incorporated in 1902 under the laws of the Oklahoma Territory. OG&E is the largest electric utility in Oklahoma and its franchised service territory includes the Fort Smith, Arkansas area. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.OG&E is a wholly-owned subsidiary of OGE Energy, an energy and energy services provider offering physical delivery and related services for both electricity and natural gas primarily in the south central United States.

Overview

OG&E Strategy

OGE Energy'smission is to fulfill its critical role in the nation's electric utility and natural gas midstream pipeline infrastructure and meet individual customers' needs for energy and related services focusing on safety, efficiency, reliability, customer service and risk management.OGE Energy'scorporate strategy is to continue to maintain its existing business mix and diversified asset position of its regulated electric utility business and unregulated natural gas midstream business while providing competitive energy products and services to customers primarily in the south central United States as well as seeking growth opportunities in both businesses.

OG&E is focused on increased investment to preserve system reliability and meet load growth by adding and maintaining infrastructure equipment and replacing aging transmission and distribution systems. OG&E expects to maintain a diverse generation portfolio while remaining environmentally responsible. OG&E is focused on maintaining strong regulatory and legislative relationships for the long-term benefit of its customers. In an effort to encourage more efficient use of electricity, OG&E is also providing energy management solutions to its customers through the Smart Grid program that utilizes newer technology to improve operational and environmental performance as well as allow customers to monitor and manage their energy usage, which should help reduce demand during critical peak times, resulting in lower capacity requirements.  If these initiatives are successful, OG&E believes it may be able to defer the construction or acquisition of any incremental fossil fuel generation capacity until 2020. The Smart Grid program also provides benefits to OG&E, including more efficient use of its resources and access to increased information about customer usage, which should enable OG&E to have better distribution system planning data, better response to customer usage questions and faster detection and restoration of system outages. As the Smart Grid platform matures, OG&E anticipates providing new products and services to its customers. In addition, OG&E is also pursuing additional transmission-related opportunities within the SPP.

Summary of Operating Results

2013compared to2012. OG&E reported net income of $292.6 million and $280.3 million, respectively, in 2013 and 2012, an increase of $12.3 million, or 4.4 percent, driven by higher gross margin primarily related to increased wholesale transmission revenue and lower other operation and maintenance expense, partially offset by higher interest expense related to the issuance of debt in May 2013

2012compared to2011. OG&E reported net income of $280.3 million and $263.3 million, respectively, in 2012 and 2011, an increase of $17.0 million, or 6.5 percent, primarily due to a higher gross margin primarily due to increased recovery of investments and increased transmission revenue partially offset by milder weather in OG&E's service territory. The increase in gross margin was partially offset by higher depreciation and amortization expense related to additional assets being placed in service and lower allowance for equity funds used during construction related to higher levels of construction costs for the Crossroads wind farm in 2011.

2014 Outlook

OG&E projectsto earn approximately $292 million to $303 million,in 2014and is based on the following assumptions:

• Normal weather patterns are experienced for the remainder of the year;

• Gross margin on revenues of approximately $1.355 billion to $1.345 billion based on sales growth of approximately 1.2 percent on a weather-adjusted basis;

• Approximately $115 million of gross margin is primarily attributed to regionally allocated transmission projects;

• Operating expenses of approximately $805 million to $815 million, with operation and maintenance expenses comprising 56 percent of the total;

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• Interest expense of approximately $141 million which assumes a $4 million allowance for borrowed funds used during construction reduction to interest expense and $250 million of long-term debt issued in the first half of 2014;

• Other income of approximately $14 million including approximately $11 million of AEFUDC; and

• An effective tax rate of approximately 28 percent.

OG&E has significant seasonality in its earnings. OG&E typically shows minimal earnings in the first and fourth quarters with a majority of earnings in the third quarter due to the seasonal nature of air conditioning demand.

Results of Operations

The following discussion and analysis presents factors that affected OG&E's results of operations for the years endedDecember 31, 2013, 2012and2011and OG&E's financial position atDecember 31, 2013and2012.  The following information should be read in conjunction with theFinancial Statements and Notes thereto.Known trends and contingencies of a material nature are discussed to the extent considered relevant.

Year ended December 31 (In millions)	2013		2012		2011
Operating income	$	525.3	$	489.4	$	472.3
Net income	$	292.6	$	280.3	$	263.3

In reviewing itsoperating results, OG&E believes that it is appropriate to focus on operating income as reported in its Statements of Income as those measures indicate the ongoing profitability of OG&E excluding the cost of capital and income taxes.

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Year ended December 31 (Dollars in millions)	2013		2012		2011
Operating revenues	$	2,262.2	$	2,141.2	$	2,211.5
Cost of sales	965.9		879.1		1,013.5
Other operation and maintenance	438.8		446.3		436.0
Depreciation and amortization	248.4		248.7		216.1
Taxes other than income	83.8		77.7		73.6
Operating income	525.3		489.4		472.3
Allowance for equity funds used during construction	6.6		6.2		20.4
Other income	8.1		8.2		8.5
Other expense	4.6		4.3		8.4
Interest expense	129.3		124.6		111.6
Income tax expense	113.5		94.6		117.9
Net income	$	292.6	$	280.3	$	263.3
Operating revenues by classification
Residential	$	901.4	$	878.0	$	943.5
Commercial	554.2		523.5		531.3
Industrial	220.6		206.8		216.0
Oilfield	176.4		163.4		165.1
Public authorities and street light	214.3		202.4		207.4
Sales for resale	59.4		54.9		65.3
System sales revenues	2,126.3		2,029.0		2,128.6
Off-system sales revenues	14.7		36.5		36.2
Other	121.2		75.7		46.7
Total operating revenues	$	2,262.2	$	2,141.2	$	2,211.5
Reconciliation of gross margin to revenue:
Operating revenues	2,262.2		2,141.2		2,211.5
Cost of sales	965.9		879.1		1,013.5
Gross Margin	1,296.3		1,262.1		1,198.0
MWH sales by classification (In millions)
Residential	9.4		9.1		9.9
Commercial	7.1		7.0		6.9
Industrial	3.9		4.0		3.9
Oilfield	3.4		3.3		3.2
Public authorities and street light	3.2		3.3		3.2
Sales for resale	1.2		1.3		1.4
System sales	28.2		28.0		28.5
Off-system sales	0.4		1.4		1.0
Total sales	28.6		29.4		29.5
Number of customers	806,940		798,110		789,146
Weighted-average cost of energy per kilowatt-hour - cents
Natural gas	3.905		2.930		4.328
Coal	2.273		2.310		2.064
Total fuel	2.784		2.437		2.897
Total fuel and purchased power	3.178		2.806		3.215
Degree days (A)
Heating - Actual	3,673		2,667		3,359
Heating - Normal	3,349		3,349		3,631
Cooling - Actual	2,106		2,561		2,776
Cooling - Normal	2,092		2,092		1,911

(A) Degree days are calculated as follows:  The high and low degrees of a particular day are added together and then averaged.  If the calculated average is above 65 degrees, then the difference between the calculated average and 65 is expressed as cooling degree days, with each degree of difference equaling one cooling degree day.  If the calculated average is below 65 degrees, then the difference between the calculated average and 65 is expressed as heating degree days, with each degree of difference equaling one heating degree day.  The daily calculations are then totaled for the particular reporting period.

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2013 compared to 2012.OG&E's operating income increased$35.9 million, or7.3 percent, in2013as compared to2012primarily due to a higher gross margin, lower other operation and maintenance expense and lower depreciation and amortization expense partially offset by higher taxes other than income.

Gross Margin

Gross Margin is defined by OG&E as operating revenues less fuel, purchased power and transmission expenses. Gross margin is a non-GAAP financial measure because it excludes depreciation and amortization, and other operation and maintenance expenses. Expenses for fuel, purchased power and transmission expenses are recovered through fuel adjustment clauses and as a result changes in these expenses are offset in operating revenues with no impact on net income. OG&E believes gross margin provides a more meaningful basis for evaluating its operations across periods than operating revenues because gross margin excludes the revenue effect of fluctuations in these expenses. Gross margin is used internally to measure performance against budget and in reports for management and the Board of Directors. OG&E's definition of gross margin may be different from similar terms used by other companies.

Operating revenues were$2,262.2 millionin2013as compared to$2,141.2 millionin2012, an increaseof$121.0 million, or5.7 percent. Cost of sales were$965.9 millionin2013as compared to$879.1 millionin2012, an increaseof$86.8 million, or9.9 percent. Gross margin was$1,296.3 millionin2013as compared to$1,262.1 millionin2012, an increaseof$34.2 million, or2.7 percentThe below factors contributed to the change in gross margin:

	$ Change
	(In millions)
Wholesale transmission revenue (A)	$	44.9
New customer growth	10.9
Non-residential demand and related revenues	0.1
Other	1.8
Price variance (B)	(17.1		)
Quantity variance (primarily weather)	(6.4		)
Change in gross margin	$	34.2

(A) Increased primarily due to higher investments related to certain FERC approved transmission projects included in formula rates.

(B) Decreased primarily due to sales and customer mix.

Cost of sales for OG&E consists of fuel used in electric generation, purchased power and transmission related charges. Fuel expense was$672.7 millionin2013as compared to$642.4 millionin2012, an increaseof$30.3 million, or4.7 percent, primarily due to higher natural gas prices. OG&E's electric generating capability is fairly evenly divided between coal and natural gas and provides for flexibility to use either fuel to the best economic advantage for OG&E and its customers.In2013, OG&E's fuel mix was53 percentcoal,40 percentnatural gas andseven percentwind. In2012, OG&E's fuel mix was52 percentcoal,42 percentnatural gas andsix percentwind. Purchased power costs were$267.6 millionin2013as compared to$223.0 millionin2012, an increaseof$44.6 million, or20.0 percent, primarily due to an increase in purchases in the energy imbalance service market and short-term power agreements.Transmission related charges were$25.6 millionin2013as compared to$13.7 millionin2012, an increaseof$11.9 million, or86.9 percent, primarily due to higher SPP charges for the base plan projects of other utilities.

Variances in the actual cost of fuel used in electric generation and certain purchased power costs, as compared to the fuel component included in the cost-of-service for ratemaking, are passed through to OG&E's customers through fuel adjustment clauses. The fuel adjustment clauses are subject to periodic review by the OCC, the APSC and the FERC. The OCC, the APSC and the FERC have authority to review the appropriateness of gas transportation charges or other fees OG&E pays to its affiliate, Enable.

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Operating Expenses

Other operation and maintenance expenses were$438.8 millionin2013as compared to$446.3 millionin2012, a decreaseof$7.5 million, or1.7 percent. The below factors contributed to the change in other operations and maintenance expense:

	$ Change
	(In millions)
Employee benefits (A)	$	(12.3	)
Total salaries and wages (B)	(6.5		)
Temporary labor	(2.3		)
Contract professional services (primarily smart grid) (C)	(1.7		)
Other	0.6
Other marketing and sales expense (primarily lower demand-side management initiatives) (C)	1.2
Administrative and assessment fees (primarily SPP Administration Fees)	2.2
Software expense (primarily smart grid) (C)	2.7
Capitalized labor	8.6
Change in other operation and maintenance expense	$	(7.5	)

(A) Decreased primarily due to lower recoverable amounts of pension expense and postretirement medical expense allowed in the August 2012 rate case, a decrease in medical expense, and a decrease in worker's compensation accruals.

(B) Decreased primarily due to lower salaries and wages as a result of lower headcount in 2013 and a decrease in incentive pay, partially offset by annual salary increases and an increase in overtime wages related to 2013 storms.

(C) Includes costs that are being recovered through a rider.

Depreciation and amortization expense was$248.4 millionin2013as compared to$248.7 millionin2012, a decreaseof$0.3 million, primarily due to the amortization of the deferred pension credits regulatory liability and a decrease in the amortization of the storm regulatory asset (see Note 1). These decreases in depreciation and amortization expense were partially offset by:

• increases in depreciation rates from the August 2012 rate case; and

• additional assets being placed in service throughout 2013 and 2012, including the Sooner-Rose Hill and Sunnyside-Hugo transmission projects, which were fully in service in April 2012, the smart grid project which was completed in late 2012 and the Cleveland to Sooner transmission project which was fully in service in February 2013.

Taxes other than income was$83.8 million in 2013 as compared to $77.7 million in 2012, an increase of $6.1 million, or 7.9 percent, primarily due to higher ad valorem taxes.

Additional Information

Interest Expense.Interest expense was$129.3 millionin2013as compared to$124.6 millionin2012, an increaseof$4.7 million, or3.8 percent, primarily due to a$6.4 millionincreasein interest on long term debt related to a $250 million debt issuance that occurred in May 2013, partially offset by a$2.0 milliondecreasein interest related to tax matters.

Income Tax Expense. Income tax expense was$113.5 millionin2013as compared to$94.6 millionin2012, an increaseof$18.9 million, or20.0 percent. primarily due tohigherpre-tax income and a reserve related to a portion of the Oklahoma investment tax credits generated in years prior to 2013 but not yet utilized.

2012 compared to 2011.OG&E's operating income increased $17.1 million, or 3.6 percent, in 2012 as compared to 2011 primarily due to a higher gross margin partially offset by higher other operation and maintenance expense and higher depreciation and amortization expense.

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Gross Margin

Operating revenues were $2,141.2 million in 2012 as compared to $2,211.5 million in 2011, a decrease of $70.3 million, or 3.2 percent. Fuel and purchased power was $879.1 million in 2012 as compared to $1,013.5 million in 2011, a decrease of $134.4 million, or 13.3 percent. Gross margin was $1,262.1 million in 2012 as compared to $1,198.0 million in 2011, an increase of $64.1 million, or 5.4 percent. The below factors contributed to the change in gross margin:

	$ Change
	(In millions)
Price variance (A)	$	54.1
Wholesale transmission revenue (B)	28.5
New customer growth	11.5
Non-residential demand and related revenues	4.9
Enogex transportation credit (C)	3.3
Arkansas rate increase	2.8
Oklahoma rate increase	2.7
Renewal of wholesale contract with customer	1.3
Other	0.3
Quantity variance (primarily weather)	(45.3		)
Change in gross margin	$	64.1

(A) Increased due to revenues from the recovery of investments, including the Crossroads wind farm and smart grid.

(B) Increased primarily due to the inclusion of construction work in progress in transmission rates for specific FERC approved projects that previously accrued allowance for funds used during construction.

(C) Increased due to a credit to OG&E's customers in 2011 related to the settlement of OG&E's 2009 fuel adjustment clause review.

Fuel expense was $642.4 million in 2012 as compared to $775.0 million in 2011, a decrease of $132.6 million, or 17.1 percent, primarily due to lower natural gas prices. OG&E's electric generating capability is fairly evenly divided between coal and natural gas and provides for flexibility to use either fuel to the best economic advantage for OG&E and its customers. In 2012, OG&E's fuel mix was 52 percent coal, 42 percent natural gas and six percent wind. In 2011, OG&E's fuel mix was 58 percent coal, 39 percent natural gas and three percent wind. Purchased power costs were $223.0 million in 2012 as compared to $230.7 million in 2011, a decrease of $7.7 million, or 3.3 percent, primarily due to a decrease in cogeneration purchases and purchases in the energy imbalance service market due to milder weather partially offset by an increase in short-term power purchases. Transmission related charges were $13.7 million in 2012 as compared to $7.8 million in 2011, an increase of $5.9 million, or 75.6 percent, primarily due to higher SPP charges for the base plan projects of other utilities.

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Operating Expenses

Other operation and maintenance expenses were $446.3 million in 2012 as compared to $436.0 million in 2011, an increase of $10.3 million, or 2.4 percent. The below factors contributed to the change in other operations and maintenance expense:

	$ Change
	(In millions)
Salaries and wages (A)	$	6.4
Contract professional and technical services (related to smart grid) (B)	4.2
Employee benefits (C)	3.4
Administration and assessment fees (primarily SPP and North American Electric Reliability Corporation)	3.4
Wind farm lease expense (primarily Crossroads) (B)	3.0
Injuries and damages	1.9
Ongoing maintenance at power plants (B)	1.9
Software (primarily smart grid) (B)	1.8
Other	0.2
Temporary labor	(1.7		)
Uncollectibles	(2.4		)
Vegetation management (primarily system hardening) (B)	(3.0		)
Allocations from holding company (primarily lower contract professional services and lower payroll and benefits)	(3.1		)
Capitalized labor	(5.7		)
Change in other operation and maintenance expense	$	10.3

(A) Increased primarily due to salary increases and an increase in incentive compensation expense partially offset by lower headcount in 2012 and a decrease in overtime expense.

(B) Includes costs that are being recovered through a rider.

(C) Increased primarily due to an increase in worker's compensation accruals, an increase in medical expense and an increase in postretirement medical expense partially offset by a decrease in pension expense.

Depreciation and amortization expense was $248.7 million in 2012 as compared to $216.1 million in 2011, an increase of $32.6 million, or 15.1 percent, primarily due to additional assets being placed in service throughout 2011 and 2012, including the Crossroads wind farm, which was fully in service in January 2012, the Sooner-Rose Hill and Sunnyside-Hugo transmission projects, which were fully in service in April 2012, and the smart grid project which was completed in late 2012.

Allowance for Equity Funds Used During Construction.Allowance for equity funds used during construction was $6.2 million in 2012 as compared to $20.4 million in 2011, a decrease of $14.2 million, or 69.6 percent, primarily due to higher levels of construction costs for the Crossroads wind farm in 2011.

Other Income.Other income was $8.0 million in both 2012 and 2011. Factors affecting other income included an increased margin of $8.8 million recognized in the guaranteed flat bill program in 2012 as a result of milder weather offset by a decrease of $8.9 million related to the benefit associated with the tax gross-up of allowance for equity funds used during construction.

Other Expense.Other expense was $4.3 million in 2012 as compared to $8.4 million in 2011, a decrease of $4.1 million, or 48.8 percent primarily due to a decrease in charitable contributions.

Interest Expense.Interest expense was $124.6 million in 2012 as compared to $111.6 million in 2011, an increase of $13.0 million, or 11.6 percent, primarily due to a $6.9 million increase in interest expense related to lower allowance for borrowed funds used during construction costs for the Crossroads wind farm in 2011 and a $5.5 million increase in interest expense related to the issuance of long-term debt in May 2011.

Income Tax Expense. Income tax expense was $94.6 million in 2012 as compared to $117.9 million in 2011, a decrease of $23.3 million, or 19.8 percent. The decrease in income tax expense was primarily due to an increase in the amount of Federal renewable energy tax credits recognized associated with the Crossroads wind farm and lower pre-tax income in 2012 as compared to 2011.

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Off-Balance Sheet Arrangement

Railcar Lease Agreement

OG&E has a noncancellable operating lease with purchase options, covering 1,389 coal rotary gondola railcars to transport coal from Wyoming to OG&E's coal-fired generation units.  Rental payments are charged to Fuel Expense and are recovered through OG&E's tariffs and fuel adjustment clauses. On December 15, 2010, OG&E renewed the lease agreement effective February 1, 2011.  At the end of the new lease term, which is February 1, 2016, OG&E has the option to either purchase the railcars at a stipulated fair market value or renew the lease.  If OG&E chooses not to purchase the railcars or renew the lease agreement and the actual fair value of the railcars is less than the stipulated fair market value, OG&E would be responsible for the difference in those values up to a maximum of$22.8 million. OG&E is also required to maintain all of the railcars it has under the operating lease and has entered into an agreement with a non-affiliated company to furnish this maintenance.

On January 11, 2012, OG&E executed a five-year lease agreement for 135 railcars to replace railcars that have been taken out of service or destroyed. OG&E has a unilateral right to terminate this lease upon a 6-month notice effective April 2015 and April 2016.

Liquidity and Capital Resources

Working Capital

Working capital is defined as the amount by which current assets exceed current liabilities. OG&E's working capital requirements are driven generally by changes in accounts receivable, accounts payable, commodity prices, credit extended to, and the timing of collections from, customers, the level and timing of spending for maintenance and expansion activity, inventory levels and fuel recoveries.

The balance of Accounts Receivable, Net and Accrued Unbilled Revenues was$238.1 millionand$218.9 millionatDecember 31, 2013and2012, respectively,an increase of $19.2 million, or8.8 percent, primarily due to higher transmission revenue, an increase in billings for reimbursable construction costs and an increase in billings to partners of jointly-owned power plants.

The balance of Accounts Payable was$239.0 millionand$187.4 millionatDecember 31, 2013and2012, respectively,an increaseof$51.6 million, or27.5 percent, primarily due tothe timing of vendor payments and an increase in accruals.

Cash Flows

										2013 vs. 2012					2012 vs. 2011
Year ended December 31 (In millions)	2013			2012			2011			$ Change			% Change		$ Change			% Change
Net cash provided from operating activities	$	545.1		$	737.4		$	549.3		$	(192.3	)	(26.1	)%	$	188.1		34.2	%
Net cash used in investing activities	(796.8		)	(676.3		)	(794.3		)	(120.5		)	(17.8	)%	118.0			(14.9	)%
Net cash provided from (used in) financing activities	251.7			(61.1		)	245.0			312.8			*		(306.1		)	*

* Percentage is greater than 100 percent.

Operating Activities

The decrease of $192.3 million, or 26.1 percent, in net cash provided from operating activities in2013as compared to2012was primarily due tofuel refundsin2013as compared to higher fuel recoveries in2012.

The increase of $188.1 million, or 34.2 percent, in net cash provided from operating activities in2012as compared to2011was primarily due to:

• higher fuel recoveriesin2012as compared to2011; and

• an increase in cash received in 2012 from transmission revenue and the recovery of investments including the Crossroads wind farm and smart grid partially offset by milder weather in 2012.

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Investing Activities

The increase of $120.5 million, or 17.8 percent, in net cash used in investing activities in2013as compared to2012 was primarily due to increased capital expendituresin 2013 related to various transmission projects.

The decrease of $118.0 million, or 14.9 percent, in net cash used in investing activities in 2012 as compared to 2011 primarily related to lower levels of capital expenditures in2012related to the Crossroads wind farm.  

Financing Activities

The increase of $312.8 million in net cash provided from financing activitiesin2013as compared to2012 was primarily due to:

• proceeds received from the issuance of long-term debt in May 2013; and

• an increase in net advances with OGE Energy 2013.

These increases in net cash provided from financing activities were partially offset by dividends payments in 2013.

The decrease of $306.1 million in net cash provided from financing activities in2012as compared to2011 was primarily due to:

• proceeds received from the issuance of long-term debt during 2011; and

• dividend payments in 2012; and

• a capital contribution from OGE Energy during 2011.

These decrease in net cash provided from financing activities were partially offset by an increase in net advances with OGE Energy during 2012.

Future Capital Requirements and Financing Activities

OG&E'sprimary needs for capital are related to acquiring or constructing new facilities and replacing or expanding existing facilities.  Other working capital requirements are expected to be primarily related to maturing debt, operating lease obligations, fuel clause under and over recoveries and other general corporate purposes.OG&Egenerally meets its cash needs through a combination of cash generated from operations, short-term borrowings (through a combination of bank borrowings, commercial paperand borrowings from OGE Energy)and permanent financings.

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Capital Expenditures

OG&E'sestimates of capital expenditures for the years2014through2018are shown in the following table.These capital expenditures represent the base maintenance capital expenditures (i.e., capital expenditures to maintain and operateOG&E's business) plus capital expenditures for known and committed projects.

(In millions)	2014		2015		2016		2017		2018
Base Transmission	$	30	$	30	$	30	$	30	$	30
Base Distribution	175		175		175		175		175
Base Generation	140		75		75		75		75
Other	15		15		15		15		15
Total Base Transmission, Distribution, Generation and Other	360		295		295		295		295
Known and Committed Projects:
Transmission Projects:
Regionally Allocated Base Projects (A)	55		20		20		20		20
Balanced Portfolio 3E Projects (B)(C)	15		—		—		—		—
SPP Priority Projects (B)(C)	75		—		—		—		—
SPP Integrated Transmission Projects (B) (C)	15		25		30		25		10
Total Transmission Projects	160		45		50		45		30
Other Projects:
Smart Grid Program	25		10		10		—		—
Environmental - low NOX burners	35		20		15		10		—
Environmental - activated carbon injection	5		10		5		—		—
Total Other Projects	65		40		30		10		—
Total Known and Committed Projects	225		85		80		55		30
Total (D)	$	585	$	380	$	375	$	350	$	325

(A) Approximately 30% of revenue requirement allocated to SPP members other than OG&E.

(B) Approximately 85% of revenue requirement allocated to SPP members other than OG&E.

(C)	Project Type	Project Description	Estimated Cost (In millions)	Projected In-Service Date
	Balance Portfolio 3E	96 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to the Oklahoma /Texas Stateline to a companion transmission line to its Tuco substation	$110	Mid-2014
	Priority Project	99 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to the western Beaver County line to a companion transmission line to its Hitchland substation	$165	Mid-2014
	Priority Project	77 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to a companion transmission line at the Kansas border	$140	Late 2014
	Integrated Transmission Project	47 miles of transmission line from OG&E's Gracemont substation to an AEP companion transmission line to its Elk City substation	$45	Early 2018
	Integrated Transmission Project	126 miles of transmission line from OG&E's Woodward District Extra High Voltage substation to OG&E's Cimarron substation; construction of the Mathewson substation on this transmission line	$180	Early 2021

(D) The capital expenditures above exclude any environmental expenditures associated with:

• Pollution control equipment related to controlling SO2 emissions under the regional haze requirements due to the uncertainty regarding the approach and timing for such pollution control equipment.The SO2 emissions standards in the EPA's FIP could require the installation of Dry Scrubbers or fuel switching. OG&E estimates that installing such Dry Scrubbers could cost more than$1.0 billion. The FIP is being challenged by OG&E and the state of Oklahoma. On June 22, 2012, OG&E was granted a stay of the FIP by the U.S. Court of Appeals for the Tenth Circuit.On July 19, 2013, the U.S. Court of Appeals for the Tenth Circuit by a 2 to 1 vote denied the petition for review and affirmed the EPA's issuance of the FIP. On January 2, 2014, the Tenth Circuit confirmed that the stay of the FIP has remained in place and continues until the Tenth Circuit issues the mandate. A Petition for Certiorari was filed by the State of Oklahoma, the Industrial

33

Consumers and OG&E with the United States Supreme Court on January 29, 2014. The mandate from the Tenth Circuit has been stayed until the Supreme Court acts on the petition. If the Supreme Court elects not to hear the case, OG&E will have approximately 55 months from the effective date of the lifting of the stay to achieve compliance with the FIP.

• Installation of control equipment (other than activated carbon injection) for compliance with MATS by a deadline of April 16, 2016, which includes a one-year extension which was granted by the Oklahoma Department of Environmental Quality. As noted above, OG&E is currently planning to utilize activated carbon injection for the removal of mercury at each of its five coal-fired units, the capital costs of which are estimated to be approximately $20 million over a three year period and are included in the capital expenditures table in "Future Capital Requirements and Financing Activities" above. OG&E continues to review whether additional controls such as dry sorbent injection are needed for compliance with MATS. Current capital costs for installing the necessary control equipment for dry sorbent injection are estimated to be approximately$45 millionover a three year period, but due to the uncertainty as to whether or not dry sorbent injection is necessary, such costs are not included in the capital expenditures table in "Future Capital Requirements and Financing Activities" above.

OG&E is currently evaluating options to comply with environmental requirements. For further information, see "Environmental Laws and Regulations" below.

Additional capital expenditures beyond those identified in the table above, including additional incremental growth opportunities in electric transmission assets, will be evaluated based upon their impact upon achievingOG&E'sfinancial objectives.

Contractual Obligations

The following table summarizes OG&E's contractual obligations atDecember 31, 2013.  See OG&E's Statements of Capitalization and Note 12 of Notes toFinancial Statements for additional information.

(In millions)	2014			2015-2016			2017-2018			After 2018			Total
Maturities of long-term debt (A)	$	0.2		$	110.4		$	375.2		$	1,819.9		$	2,305.7
Operating lease obligations
Railcars	3.8			30.4			—			—			34.2
Wind farm land leases	2.1			4.2			4.8			48.8			59.9
Total operating lease obligations	5.9			34.6			4.8			48.8			94.1
Other purchase obligations and commitments
Cogeneration capacity and fixed operation and maintenance payments	85.1			164.6			156.6			235.2			641.5
Expected cogeneration energy payments	61.1			136.6			168.9			352.5			719.1
Minimum fuel purchase commitments	451.8			820.3			385.1			—			1,657.2
Expected wind purchase commitments	58.0			118.7			120.3			368.9			665.9
Long-term service agreement commitments	70.5			5.3			21.7			187.9			285.4
Total other purchase obligations and commitments	726.5			1,245.5			852.6			1,144.5			3,969.1
Total contractual obligations	732.6			1,390.5			1,232.6			3,013.2			6,368.9
Amounts recoverable through fuel adjustment clause (B)	(574.7		)	(1,106.0		)	(674.3		)	(721.4		)	(3,076.4		)
Total contractual obligations, net	$	157.9		$	284.5		$	558.3		$	2,291.8		$	3,292.5

(A) Maturities of OG&E's long-term debt during the next five years consist of$0.2 million, $0.2 million, $110.2 million, $125.1 millionand$250.1 millionin years2014, 2015, 2016, 2017and2018, respectively.

(B) Includes expected recoveries of costs incurred for OG&E's railcar operating lease obligations, OG&E's expected cogeneration energy payments, OG&E's minimum fuel purchase commitments and OG&E's expected wind purchase commitments.

OG&E also has440MWs of QF contracts to meet its current and future expected customer needs.  OG&E will continue reviewing all of the supply alternatives to these QF contracts that minimize the total cost of generation to its customers, including exercising its options (if applicable) to extend these QF contracts at pre-determined rates.

The actual cost of fuel used in electric generation (which includes the operating lease obligations for OG&E's railcar leases shown above) and certain purchased power costs are passed through to OG&E's customers through fuel adjustment clauses.  Accordingly, while the cost of fuel related to operating leases and the vast majority of minimum fuel purchase commitments

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of OG&E noted above may increase capital requirements, such costs are recoverable through fuel adjustment clauses and have little, if any, impact on net capital requirements and future contractual obligations.  The fuel adjustment clauses are subject to periodic review by the OCC, the APSC and the FERC.

Pension and Postretirement Benefit Plans

AtDecember 31, 2013, 40.6 percentof the Pension Plan investments were in listed common stocks with the balance primarily invested in U.S Government securities, bonds, debentures and notes, a commingled fund and a common collective trust as presented in Note 11 of Notes toFinancial Statements.In2013, asset returns on the Pension Plan were12.5 percentdue to the gains in fixed income and equity investments.  During the same time, corporate bond yields, which are used in determining the discount rate for future pension obligations, increased.  During both2013and2012, OGE Energy made contributions to its Pension Plan of$35 millionof whichnonein 2013 and$33 millionin 2012 was OG&E's portion,to help ensure that the Pension Plan maintains an adequate funded status.The level of funding is dependent on returns on plan assets and future discount rates.During2014, OGE Energy expects to contribute up to$26 millionto its Pension Plan, of which$1 millionis expected to be OG&E's portion.OGE Energy could be required to make additional contributions if the value of its pension trust and postretirement benefit plan trust assets are adversely impacted by a major market disruption in the future.

The following table presents the status ofOG&E's portion of OGE Energy'sPension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans atDecember 31, 2013and2012. These amounts have been recorded in Accrued Benefit Obligations with the offsetrecorded as a regulatory asset in OG&E's Balance Sheet as discussed in Note 1of Notes toFinancial Statements. Theregulatory assetrepresents a net periodic benefit cost to be recognized in theStatements of Income in future periods.

	Pension Plan						Restoration of Retirement Income Plan						Postretirement Benefit Plans
December 31 (In millions)	2013			2012			2013			2012			2013			2012
Benefit obligations	$	(503.6	)	$	(574.6	)	$	(2.1	)	$	(2.2	)	$	(202.4	)	$	(236.4	)
Fair value of plan assets	516.5			519.0			—			—			56.7			55.5
Funded status at end of year	$	12.9		$	(55.6	)	$	(2.1	)	$	(2.2	)	$	(145.7	)	$	(180.9	)

In accordance with ASC Topic 715, "Compensation - Retirement Benefits," a one-time settlement charge is required to be recorded by an organization when lump sum payments or other settlements that relieve the organization from the responsibility for the pension benefit obligation during a plan year exceed the service cost and interest cost components of the organization’s net periodic pension cost. During 2013, OG&E experienced an increase in both the number of employees electing to retire and the amount of lump sum payments to be paid to such employees upon retirement. As a result, and based in part on OG&E's historical experience regarding eligible employees who elect to retire in the last quarter of a particular year, OG&E recorded pension settlement charges of$17.6 millionin the fourth quarter of 2013, of which$17.0 millionrelated to OG&E’s Oklahoma jurisdiction and has been included in the pension tracker. The pension settlement charge did not require a cash outlay by OG&E and did not increase OG&E’s total pension expense over time, as the charges were an acceleration of costs that otherwise would be recognized as pension expense in future periods.

Security Ratings

	Moody’s Investors Services	Standard & Poor's Ratings Services	Fitch Ratings
Senior Notes	A1	A-	A+

Access to reasonably priced capital is dependent in part on credit and security ratings.Generally, lower ratings lead to higher financing costs.Pricing grids associated withOGE Energy's and OG&E'screditfacilitiescould cause annual fees and borrowing rates to increase if an adverse rating impact occurs. The impact of any future downgrade could include an increase in the costs ofOGE Energy's and OG&E'sshort-term borrowings, but a reduction inOGE Energy's and OG&E'scredit ratings would not result in any defaults or accelerations. Any future downgradeof OGE Energy or OG&Ecould also lead to higher long-term borrowing costs and, if below investment grade, would requireOG&Eto post collateral or letters of credit.

On May 2, 2013, Standard & Poor's Ratings Services upgraded the long-term senior unsecured rating ofOG&E to A-.

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On November 8, 2013, Moody's Investors Services placed the credit ratings ofOG&E on review for possible upgrade. On January 31, 2014, Moody's upgraded the long-term senior unsecured rating ofOG&E to A1 primarily due to their more favorable view of the relative credit supportiveness of the U.S. regulatory environment.

A security rating is not a recommendation to buy, sell or hold securities. Such rating may be subject to revision or withdrawal at any time by the credit rating agency and each rating should be evaluated independently of any other rating.

Future financing requirements may be dependent, to varying degrees, upon numerous factors such as general economic conditions, abnormal weather, load growth, commodity prices,acquisitions of other businesses and/or development of projects, actions by rating agencies, inflation, changes in environmental laws or regulations, rate increases or decreases allowed by regulatory agencies, new legislation and market entry of competing electric power generators.

2013Capital Requirements, Sources of Financingand Financing Activities

Total capital requirements, consisting of capital expenditures and maturities of long-term debt, were$797.7 millionand contractual obligations, net of recoveries through fuel adjustment clauses, were$89.2 millionresulting in total net capital requirements and contractual obligations of$886.9 millionin2013, of which$42.0 millionwas to comply with environmental regulations. This compares to net capital requirements of$677.0 millionand net contractual obligations of$91.3 milliontotaling$768.3 millionin2012, of which$12.4 millionwas to comply with environmental regulations.

In2013, OG&E's sources of capital were cash generated from operations and proceeds from the issuance ofshort-term debt. Changes in working capital reflect the seasonal nature of OG&E's business, the revenue lag between billing and collection from customers and fuel inventories.  See "Working Capital" for a discussion of significant changes in net working capital requirements as it pertains to operating cash flow and liquidity.

Issuance of Long-Term Debt

On May 8, 2013, OG&E issued$250 millionof3.9%senior notes dueMay 1, 2043. The proceeds from the issuance were added to OG&E's general funds and were used to repay short-term debt, to fund capital expenditures, to pay general corporate expenses and for working capital purposes.

Potential Collateral Requirements

Derivative instruments are utilized in managing OG&E's commodity price exposures. On July 21, 2010, President Obama signed into law the Dodd-Frank Act. Among other things, the Dodd-Frank Act provides for a new regulatory regime for derivatives, including mandatory clearing of certain swaps and margin requirements. The Dodd-Frank Act contains provisions that should exempt certain derivatives end-users such as OG&E from much of the clearing requirements. The regulations require that the decision on whether to use the end-user exception from mandatory clearing for derivative transactions be reviewed and approved by an "appropriate committee" of the Board of Directors. The scope of the margin requirements and their potential direct impact on OG&E remain unclear because final rules have not been issued. Further, even if OG&E qualifies for the end-user exception to clearing and margin requirements are not imposed on end-users, its derivative counterparties may be subject to new capital, margin and business conduct requirements as a result of the new regulations, which may increase OG&E's transaction costs or make it more difficult to enter into derivative transactions on favorable terms. OG&E's inability to enter into derivative transactions on favorable terms, or at all, could increase operating expenses and put OG&E at increased exposure to risks of adverse changes in commodities prices. The impact of the provisions of the Dodd-Frank Act on OG&E cannot be fully determined at this time due to uncertainty over forthcoming regulations and potential changes to the derivatives markets arising from new regulatory requirements.

Future Sources of Financing

Management expects that cash generated from operations, proceeds from the issuance of long and short-term debt and funds received from OGE Energy (fromproceeds from the sales ofitscommon stock to the public throughOGE Energy'sAutomatic Dividend Reinvestment and Stock Purchase Plan or other offerings) will be adequate over the next three years to meet anticipated cash needs and to fund future growth opportunities.OG&Eutilizes short-term borrowings (through a combination of bank borrowings, commercial paperand borrowings from OGE Energy)to satisfy temporary working capital needs and as an interim source of financing capital expenditures until permanent financing is arranged.

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Short-Term Debt and Credit Facility

AtDecember 31, 2013 , there were$87.2 millionin net outstanding advances from OGE Energy as compared to$90.3 million in net outstanding advances from OGE Energy at December 31, 2012. OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to$400 millionof OGE Energy's revolving credit amount.This agreement has a termination date ofDecember 13, 2017.  AtDecember 31, 2013, there werenointercompany borrowings under this agreement.OG&E has a$400 millionrevolving credit facility which is available to back up OG&E's commercial paper borrowings and to provide revolving credit borrowings.This bank facility can also be used as a letter of credit facility.AtDecember 31, 2013, there was$2.1 millionsupporting letters of credit at a weighted-average interest rate of0.53 percent.  There werenooutstanding borrowings under this revolving credit agreement andnooutstanding commercial paper borrowings atDecember 31, 2013.  AtDecember 31, 2013, OG&E had$397.9 millionof net available liquidity under its revolving credit agreement.OG&E has the necessary regulatory approvals to incur up to$800 millionin short-term borrowings at any one time for a two-year period beginning January 1, 2013 and ending December 31, 2014.AtDecember 31, 2013, OG&E had less than$0.1 millionin cash and cash equivalents.See Note 10 of Notes to Financial Statements for a discussion of OG&E's short-term debt activity.

In December 2011,OG&E entered into an unsecured five-year revolving credit agreement for $400.0 million. This credit facility contains an option, which may be exercised up to two times, to extend the term for an additional year, subject to consent of a specified percentage of the lenders. Effective July 29, 2013,OG&E utilized one of these one-year extensions, and received consent from all of the lenders, to extend the maturity of its credit agreementsto December 13, 2017.

Expected Issuance of Long-Term Debt

OG&E expects to issue up to$250 millionof long-term debt during 2014, depending on market conditions, to fund capital expenditures, to repay short or long-term borrowings and for general corporate purposes.

Critical Accounting Policies and Estimates

TheFinancial Statements and Notes toFinancial Statements contain information that is pertinent to Management's Discussion and Analysis.In preparing theFinancial Statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and contingent liabilities at the date of theFinancial Statements and the reported amounts of revenues and expenses during the reporting period.  Changes to these assumptions and estimates could have a material effect onOG&E'sFinancial Statements.  However,OG&Ebelieves it has taken reasonable positions where assumptions and estimates are used in order to minimize the negative financial impact toOG&Ethat could result if actual results vary from the assumptions and estimates.  In management's opinion, the areas ofOG&Ewhere the most significant judgment is exercisedincludes the determination of Pension Plan assumptions,impairment estimates of long-lived assets (including intangible assets), income taxes,contingency reserves, asset retirement obligations, assets and depreciable lives of property, plant and equipment, the existence of regulatory assets and liabilities and unbilled revenues. The selection, application and disclosure of the following critical accounting estimates have been discussed with OGE Energy's Audit Committee. OG&E discusses its significant accounting policies, including those that do not require management to make difficult, subjective, or complex judgments or estimates, in Note 1 of Notes toFinancial Statements.

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Pension and Postretirement Benefit Plans

OGE Energy hasa Pension Plan that covers asignificant amount of OG&E's employeeshired before December 1, 2009. Also, effective December 1, 2009, OGE Energy's Pension Plan is no longer being offered to employees hired on or after December 1, 2009.  OGE Energy also has defined benefit postretirement plans that cover a significant amount of its employees.  Pension and other postretirement plan expenses and liabilities are determined on an actuarial basis and are affected by the market value of plan assets, estimates of the expected return on plan assets, assumed discount rates and the level of funding.  Actual changes in the fair market value of plan assets and differences between the actual return on plan assets and the expected return on plan assets could have a material effect on the amount of pension expense ultimately recognized.  The pension plan rate assumptions are shown in Note 11 of Notes toFinancial Statements.The assumed return on plan assets is based on management's expectation of the long-term return on the plan assets portfolio.  The discount rate used to compute the present value of plan liabilities is based generally on rates of high-grade corporate bonds with maturities similar to the average period over which benefits will be paid.The level of funding is dependent on returns on plan assets and future discount rates.Higher returns on plan assets and an increase in discount rates will reduce funding requirements to the Pension Plan.  The following table indicates the sensitivity of the Pension Plan funded status to these variables.

	Change	Impact on Funded Status
Actual plan asset returns	+/- 1 percent	+/- $6.5 million
Discount rate	+/- 0.25 percent	+/- $18.3 million
Contributions	+/- $10 million	+/- $10 million

Income Taxes

OG&E uses the asset and liability method of accounting for income taxes. Under this method, a deferred tax asset or liability is recognized for the estimated future tax effects attributable to temporary differences between the financial statement basis and the tax basis of assets and liabilities as well as tax credit carry forwards and net operating loss carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period of the change.

The application of income tax law is complex. Laws and regulations in this area are voluminous and often ambiguous. Interpretations and guidance surrounding income tax laws and regulations change over time. Accordingly, it is necessary to make judgments regarding income tax exposure. As a result, changes in these judgments can materially affect amounts OG&E recognized in itsfinancial statements.Tax positions taken by OG&E on its income tax returns that are recognized in the financial statements must satisfy a more likely than not recognition threshold, assuming that the position will be examined by taxing authorities with full knowledge of all relevant information.

Commitments and Contingencies

In the normal course of business,OG&Eis confronted with issues or events that may result in a contingent liability.These generally relate to lawsuits or claims made by third parties, including governmental agencies.When appropriate, management consults with legal counsel and other appropriate experts to assess the claim.If, in management's opinion,OG&Ehas incurred a probable loss as set forth by GAAP, an estimate is made of the loss and the appropriate accounting entries are reflected inOG&E'sFinancial Statements.

Except as disclosed otherwise in this Form 10-K,OG&Ebelieves that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect onOG&E'sfinancial position, results of operations or cash flows.See Notes 12 and 13 of Notes to Financial Statements and Item 3 of Part I in this Form 10-K for a discussion of OG&E's commitments and contingencies.

Asset Retirement Obligations

OG&Ehas previously recorded asset retirement obligations that are being amortized over their respective lives ranging from20to74years.The inputs used in the valuation of asset retirement obligations include the assumed life of the asset placed into service, the average inflation rate, market risk premium, the credit-adjusted risk free interest rate and the timing of incurring costs related to the retirement of the asset.

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Hedging Policies

From time to time, OG&Emay engage in cash flow and fair value hedge transactionsto modify interest rate exposure and not to modify the overall leverage of the debt portfolio.

Hedges are evaluated prior to execution with respect to the impact on the volatility of forecasted earnings and are evaluated at least quarterly after execution for the impact on earnings.

Regulatory Assets and Liabilities

OG&E, as a regulated utility, is subject to accounting principles for certain types of rate-regulated activities, which provide that certain actual or anticipated costs that would otherwise be charged to expense can be deferred as regulatory assets, based on the expected recovery from customers in future rates.  Likewise, certain actual or anticipated credits that would otherwise reduce expense can be deferred as regulatory liabilities, based on the expected flowback to customers in future rates.  Management's expected recovery of deferred costs and flowback of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment.

OG&E records certain actual or anticipated costs and obligations as regulatory assets or liabilities if it is probable, based on regulatory orders or other available evidence, that the cost or obligation will be included in amounts allowable for recovery or refund in future rates.The benefit obligations regulatory asset is comprised of expenses recorded which are probable of future recovery and that have not yet been recognized as components of net periodic benefit cost, including net loss, prior service cost and net transition obligation.

Unbilled Revenues

OG&E reads its customers' meters and sends bills to its customers throughout each month.  As a result, there is a significant amount of customers' electricity consumption that has not been billed at the end of each month.  Unbilled revenue is presented in Accrued Unbilled Revenues on theBalance Sheets and in Operating Revenues on theStatements of Income based on estimates of usage and prices during the period.AtDecember 31, 2013, if the estimated usage or price used in the unbilled revenue calculation were to increase or decrease byone percent, this would cause a change in the unbilled revenues recognized of$0.3 million.  AtDecember 31, 2013and2012, Accrued Unbilled Revenues were$58.7 millionand$57.4 million, respectively.  The estimates that management uses in this calculation could vary from the actual amounts to be paid by customers.

Allowance for Uncollectible Accounts Receivable

Customerbalances are generally written off if not collected within six months after the final billing date. The allowance for uncollectible accounts receivable for OG&E is calculated by multiplying the last six months of electric revenue by the provision rate.  The provision rate is based on a 12-month historical average of actual balances written off.  To the extent the historical collection rates are not representative of future collections, there could be an effect on the amount of uncollectible expense recognized.  Also, a portion of the uncollectible provision related to fuel within the Oklahoma jurisdiction is being recovered through the fuel adjustment clause.AtDecember 31, 2013, if the provision rate were to increase or decrease by10 percent, this would cause a change in the uncollectible expense recognized of$0.2 million. The allowance for uncollectible accounts receivable is a reduction to Accounts Receivable on theBalance Sheets and is included in Other Operation and Maintenance Expense on theStatements of Income.The allowance for uncollectible accounts receivable was$1.9 millionand$2.6 millionatDecember 31, 2013and2012, respectively.

Accounting Pronouncements

See Note 2 of Notes toFinancial Statements for discussion of a current accounting pronouncementsthat is applicable to OG&E.

Commitments and Contingencies

In the normal course of business,OG&Eis confronted with issues or events that may result in a contingent liability.These generally relate to lawsuits or claims made by third parties, including governmental agencies.When appropriate, management consults with legal counsel and other appropriate experts to assess the claim.If, in management's opinion,OG&Ehas incurred a probable loss as set forth by GAAP, an estimate is made of the loss and the appropriate accounting entries are reflected inOG&E'sFinancial Statements.At the present time, based on currently available information, except as disclosed otherwise in this Form 10-K,OG&Ebelieves that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened

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lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect onOG&E'sfinancial position, results of operations or cash flows.See Notes 12 and 13 of Notes to Financial Statements and Item 3 of Part I in this Form 10-K for a discussion of OG&E's commitments and contingencies.

Environmental Laws and Regulations

The activities ofOG&Eare subject to stringent and complex Federal, state and local laws and regulations governing environmental protection relating to air quality, water quality, waste management, wildlife conservation and natural resources. These laws and regulations can restrict or impact business activities in many ways, such as restricting the way it can handle or dispose of its wastes, requiring remedial action to mitigate environmental issues that may be caused by its operations or that are attributable to former operators, requiring changes in operations and requiring the installation and operation of pollution control equipment. Failure to comply with these laws and regulations could result in the assessment of administrative, civil and criminal penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations.

Environmental regulation can increase the cost of planning, design, initial installation and operation of OG&E's facilities. Historically, OG&E's total expenditures for environmental control facilities and for remediation have not been significant in relation to itsfinancial position or results of operations.OG&Ebelieves, however, that it is reasonably likely that the trend in environmental legislation and regulations will continue towards more restrictive standards.  Compliance with these standards is expected to increase the cost of conducting business. Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

OG&E expects that environmental capital expenditures necessary to comply with the environmental laws and regulations discussed below will qualify as part of a regulatory plan to handle state and Federally mandated environmental upgrades which will be recoverable in Oklahoma from OG&E's retail customers under House Bill 1910, which was enacted into law in May 2005.

It is estimated that OG&E'stotal expenditures to comply with environmental laws, regulations and requirements for2014will be$72.6 million, of which$55.0 millionis for capital expenditures.It is estimated that OG&E'stotal expenditures to comply with environmental laws, regulations and requirements for2015will be$49.6 million, of which$31.3 millionis for capital expenditures.The amountsabove include capital expenditures for low NOX burners and activated carbon injection and exclude certain other capital expenditures as discussed in footnote D to the capital expenditures table in"Future Capital Requirements and Financing Activities" above.

Air

Federal Clean Air Act Overview

OG&E’soperations are subject to the Federal Clean Air Act, as amended, and comparable state laws and regulations. These laws and regulations regulate emissions of air pollutants from various industrial sources, including electric generating units,and also impose various monitoring and reporting requirements.Such laws and regulations may require that OG&Eobtain pre-approval for the construction or modification of certain projects or facilities expected to produce air emissions or result in the increase of existing air emissions, obtain and strictly comply with air permits containing various emissions and operational limitations or install emission control equipment.OG&Elikely will be required to incur certain capital expenditures in the future for air pollution control equipment and technology in connection with obtaining and maintaining operating permits and approvals for air emissions.

Regional Haze Control Measures

On June 15, 2005, the EPA issued final amendments to its 1999 regional haze rule. Regional haze is visibility impairment caused by the cumulative air pollutant emissions from numerous sources over a wide geographic area.

As required by the Federal regional haze rule, the state of Oklahoma evaluated the installation of BART to reduce emissions that cause or contribute to regional haze from certain sources within the state that were built between 1962 and 1977. On February 18, 2010, Oklahoma submitted its SIP to the EPA, which set forth the state's plan for compliance with the Federal regional haze rule. The SIP was subject to the EPA's review and approval.

The Oklahoma SIP included requirements for reducing emissions of NOX and SO2 from OG&E's seven BART-eligible units at the Seminole, Muskogee and Sooner generating stations. The SIP also included a waiver from BART requirements for all eligible units at the Horseshoe Lake generating station based on air modeling that showed no significant impact on visibility in nearby national parks and wilderness areas. The SIP concluded that BART for reducing NOX emissions at all of the subject

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units should be the installation of low NOX burners with overfire air (flue gas recirculation was also required on two of the units) and set forth associated NOX emission rates and limits. OG&E preliminarily estimates that the total capital cost of installing and operating these NOX controls on all covered units, based on recent industry experience and past projects, will be approximately$80 million.  With respect to SO2 emissions, the SIP included an agreement between the Oklahoma Department of Environmental Quality and OG&E that established BART for SO2 control at the four affected coal-fired units located at OG&E's Sooner and Muskogee generating stations as the continued use of low sulfur coal (along with associated emission rates and limits). The SIP specifically rejected the installation and operation of Dry Scrubbers as BART for SO2 control from these units because the state determined that Dry Scrubbers were not cost effective on these units.

On December 28, 2011, the EPA issued a final rule in which it rejected portions of the Oklahoma SIP and issued a FIP in their place. While the EPA accepted Oklahoma's BART determination for NOX in the final rule, it rejected Oklahoma's SO2 BART determination with respect to the four coal-fired units at the Sooner and Muskogee generating stations. The EPA is instead requiring that OG&E meet an SO2 emission rate of 0.06pounds per MMBtu within five years. OG&E could meet the proposed standard by either installing and operating Dry Scrubbers or fuel switching at the four affected units. OG&E estimates that installing Dry Scrubbers on these units would include capital costs to OG&E of more than$1.0 billion.  OG&E and the state of Oklahoma filed an administrative stay request with the EPA on February 24, 2012. The EPA has not yet responded to this request. OG&E and other parties also filed a petition for review of the FIP in the U.S. Court of Appeals for the Tenth Circuit on February 24, 2012 and a stay request on April 4, 2012. On June 22, 2012, the U.S. Court of Appeals for the Tenth Circuit granted the stay request.On July 19, 2013, the U.S. Court of Appeals for the Tenth Circuit by a 2 to 1 vote denied the petition for review and affirmed the EPA's issuance of the FIP. On January 2, 2014, the Tenth Circuit confirmed that the stay of the FIP has remained in place and continues until the Tenth Circuit issues the mandate. A Petition for Certiorari was filed by the State of Oklahoma, the Industrial Consumers and OG&E with the United States Supreme Court on January 29, 2014. The mandate from the Tenth Circuit has been stayed until the Supreme Court acts on the petition. If the Supreme Court elects not to hear the case, OG&E will have approximately 55 months from the effective date of the lifting of the stay to achieve compliance with the FIP.

Cross-State Air Pollution Rule

As previously reported, on July 7, 2011, the EPA finalized its Cross-State Air Pollution Rule to replace the former Clean Air Interstate Rule that was remanded by a Federal court as a result of legal challenges. The final rule would require27states to reduce power plant emissions that contribute to ozone and particulate matter pollution in other states. On December 27, 2011, the EPA published a supplemental rule, which would makesixadditional states, including Oklahoma, subject to the Cross-State Air Pollution Rule for NOX emissions during the ozone-season from May 1 through September 30. Under the rule, OG&E would have been required to reduce ozone-season NOX emissions from its electrical generating units within the state beginning in 2012. The Cross-State Air Pollution Rule was challenged in court by numerous states and power generators. On December 30, 2011, the U.S. Court of Appeals issued a stay of the rule, which includes the supplemental rule, pending a decision on the merits. By order dated August 21, 2012, the U.S. Court of Appeals vacated the Cross-State Air Pollution Rule and ordered the EPA to promulgate a replacement rule. On June 24, 2013, the U.S. Supreme Court agreed to review the decision by the U.S. Court of Appeals, with a decision expected during the first half of 2014. OG&E cannot predict the outcome of such challenges.

Hazardous Air Pollutants Emission Standards

On April 16, 2012, regulations governing emissions of certain hazardous air pollutants from electric generating units were published as the final MATS rule. This rule includes numerical standards for particulate matter (as a surrogate for toxic metals), hydrogen chloride and mercury emissions from coal-fired boilers. In addition, the regulations include work practice standards for dioxins and furans. Compliance with the MATS rule is required within three years after the effective date of the rulewith the possibility of a one-year extension. OG&E requested and was granted a one-year extension by the Oklahoma Department of Environmental Quality resulting in a compliance date of April 16, 2016 for OG&E.To comply with this rule,OG&E is currently planning to utilize activated carbon injection for the removal of mercury at each of its five coal-fired units, the capital costs of which are estimated to be approximately $20 million over a three year period and are included in the capital expenditures table in "Future Capital Requirements and Financing Activities" above. OG&E continues to review whether additional controls such as dry sorbent injection are needed for compliance with MATS. Current capital costs for installing the necessary control equipment for dry sorbent injection are estimated to be approximately$45 millionover a three year period, but due to the uncertainty as to whether or not dry sorbent injection is necessary, such costs are not included in the capital expenditures table in "Future Capital Requirements and Financing Activities" above.OG&E is evaluating the results of field testing to finalize its plans and cost estimates. The final MATS rule has been appealed by several parties. OG&E is not a party to the appeals and cannot predict the outcome of any such appeals.

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Federal Clean Air Act New Source Review Litigation

As previously reported, in July 2008, OG&E received a request for information from the EPA regarding Federal Clean Air Act compliance at OG&E's Muskogee and Sooner generating plants. In recent years, the EPA has issued similar requests to numerous other electric utilities seeking to determine whether various maintenance, repair and replacement projects should have required permits under the Federal Clean Air Act's new source review process. In January 2012, OG&E received a supplemental request for an update of the previously provided information and for some additional information not previously requested. On May 1, 2012, OG&E responded to the EPA's supplemental request for information. On April 26, 2011, the EPA issued a notice of violation alleging that 13 projects occurred at OG&E's Muskogee and Sooner generating plants between 1993 and 2006 without the required new source review permits. The notice of violation also alleges that OG&E's visible emissions at its Muskogee and Sooner generating plants are not in accordance with applicable new source performance standards.

In March 2013, the DOJ informed OG&E that it was prepared to initiate enforcement litigation concerning the matters identified in the notice of violation. OG&E subsequently met with EPA and DOJ representatives regarding the notice of violation and proposals for resolving the matter without litigation. On July 8, 2013, the United States, at the request of the EPA, filed a complaint for declaratory relief against OG&E in United States District Court for the Western District of Oklahoma (Case No. CIV-13-690-D) alleging that OG&E did not follow the Federal Clean Air Act procedures for projecting emission increases attributable to eight projects that occurred between 2003 and 2006. This complaint seeks to have OG&E submit a new assessment of whether the projects were likely to result in a significant emissions increase. The Sierra Club has intervened in this proceeding and has asserted claims for declaratory relief that are similar to those requested by the United States. OG&E expects to vigorously defend against these claims, but OG&E cannot predict the outcome of such litigation. On August 12, 2013, the Sierra Club filed a complaint against OG&E in the United States District Court for the Eastern District of Oklahoma (Case No. 13-CV-00356) alleging that OG&E modifications made at Unit 6 of the Muskogee generating plant in 2008 were made without obtaining a prevention of significant deterioration permit and that the plant has exceeded emissions limits for opacity and particulate matter. The Sierra Club seeks a permanent injunction preventing OG&E from operating the Muskogee generating plant. At this time, OG&E continues to believe that it has acted in compliance with the Federal Clean Air Act.

If OG&E does not prevail in these proceedings and if a new assessment of the projects were to conclude that they caused a significant emissions increase, the EPA and the Sierra Club could seek to require OG&E to install additional pollution control equipment, including scrubbers, baghouses and selective catalytic reduction systems with capital costs in excess of$1.0 billionand pay fines and significant penalties as a result of the allegations in the notice of violation. Section 113 of the Federal Clean Air Act (along with the Federal Civil Penalties Inflation Adjustment Act of 1996) provides for civil penalties as much as$37,500per day for each violation. The cost of any required pollution control equipment could also be significant. OG&E cannot predict at this time whether it will be legally required to incur any of these costs.

National Ambient Air Quality Standards

The EPA is required to set NAAQS for certain pollutants considered to be harmful to public health or the environment. The Clean Air Act requires the EPA to review each NAAQS every five years. As a result of these reviews, the EPA periodically has taken action to adopt more stringent NAAQS for those pollutants. If any areas of Oklahoma were to be designated as not attaining the NAAQS for a particular pollutant, OG&E could be required to install additional emission controls on its facilities to help the state achieve attainment with the NAAQS. As of the end of 2013, no areas of Oklahoma had been designated as non-attainment for pollutants that are likely to affect OG&E's operations. Several processes are under way to designate areas in Oklahoma as attaining or not attaining revised NAAQS. OG&E is monitoring those processes and their possible impact on its operations but, at this time, cannot determine with any certainty whether they will cause a material impact to OG&E's financial results.

Acid Rain Program

The Federal Clean Air Act includes an Acid Rain Program. The goal of the Acid Rain Program is to achieve environmental and public health benefits through reductions in SO2 and NOX emissions, which are the primary causes of acid rain. To achieve this goal, the program employs both traditional and market-based approaches for reducing emissions.

The Acid Rain Program introduces an allowance trading system that uses the free market to reduce emissions. Under this system, affected utility units are allocated allowances based on their historic fuel consumption and a specific emissions rate. Each allowance permits a unit to emit one ton of SO2 during or after a specified year. For each ton of SO2 emitted in a given year, one allowance is retired, that is, it can no longer be used. Allowances may be bought, sold or banked.

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During Phase II of the program (now in effect), the Federal Clean Air Act set a permanent ceiling (or cap) of8.95 milliontotal annual allowances allocated to utilities. This cap firmly restricts emissions and ensures that environmental benefits will be achieved and maintained. Due to OG&E's earlier decision to burn low sulfur coal, these restrictions have had no significant financial impact.

The Acid Rain Program also focuses on one set of sources that emit NOX, coal-fired electric utility boilers. As with the SO2 emission reduction requirements, the NOX program was implemented in two phases, beginning in 1996 and 2000. The NOX program embodies many of the same principles of the SO2 trading program. However, it does not cap NOX emissions as the SO2 program does, nor does it utilize an allowance trading system.

Emission limitations for NOX focus on the emission rate to be achieved (expressed in pounds of NOX per MMBtu of heat input). In general, two options for compliance with the emission limitations are provided: compliance with an individual emission rate for a boiler; or averaging of emission rates over two or more units to meet an overall emission rate limitation.

Since becoming subject to the Acid Rain Program, OG&E has met all obligations and limitations requirements.

Climate Change and Greenhouse Gas Emissions

There is continuing discussion and evaluation of possible global climate change in certain regulatory and legislative arenas. The focus is generally on emissions of greenhouse gases, including carbon dioxide, sulfur hexafluoride and methane, and whether these emissions are contributing to the warming of the Earth's atmosphere.  There are various international agreements that restrict greenhouse gas emissions, but none of them have a binding effect on sources located in the United States. The U.S. Congress has not passed legislation to reduce emissions of greenhouse gases and the future prospects for any such legislation are uncertain, but the EPA believes it has existing authority under the Clean Air Act to regulate greenhouse gas emissions from stationary sources. Several states have passed laws, adopted regulations or undertaken regulatory initiatives to reduce the emission of greenhouse gases, primarily through the planned development of greenhouse gas emission inventories and/or regional greenhouse gas cap and trade programs.Oklahoma and Arkansasare not among them. If legislation or regulations are passed at the Federal or state levels in the future requiring mandatory reductions of carbon dioxide and other greenhouse gases on OG&E's facilities, this could result in significant additional compliance costs that would affect OG&E’s future financial position, results of operations and cash flows if such costs are not recovered through regulated rates.

In 2009, the EPA adopted a comprehensive national system for reporting emissions of carbon dioxide and other greenhouse gases produced by major sources in the United States. The reporting requirements apply to large direct emitters of greenhouse gases with emissions equal to or greater than a threshold of25,000metric tons per year, which includes certain OG&E facilities. OG&E also reports quarterly its carbon dioxide emissions from generating units subject to the Federal Acid Rain Program. OG&E has submitted the reports required by the applicable reporting rules.

Following from the Supreme Court's interpretation of the Clean Air Act's applicability to greenhouse gases in Massachusetts v. EPA, the EPA has proposed regulations for new power plants.  In 2010, the EPA also issued a final rule that makes certain existing sources subject to permitting requirements for greenhouse gas emissions. This rule requires sources that emit greater than100,000tons per year of greenhouse gases to obtain a permit for those emissions, even if they are not otherwise required to obtain a new or modified permit. Such sources that undergo construction or modification may have to install best available control technology to control greenhouse gas emissions. Although these rules currently do not have a material impact on OG&E's existing facilities, they ultimately could result in significant changes to OG&E's operations, significant capital expenditures by OG&E and a significant increase in OG&E's cost of conducting business. In October 2013, the U.S. Supreme Court granted certiorari to review EPA's greenhouse gas regulations, including the Tailoring Rule which limits the sources subject to greenhouse gas permitting requirements to the largest fossil-fueled power plants. It is conceivable that the Court could invalidate EPA's prevention of significant deterioration and Title V Tailoring Rule, but still leave power plants subject to anticipated new and existing source performance standards for greenhouse gas emissions described below.

In January 2014, the EPA issued new proposed New Source Performance Standards that specify permissible levels of greenhouse gas emissions from newly-constructed fossil fuel-fired electric generating units. The proposed New Source Performance Standards sets separate standards for natural gas combined cycle units and coal-fired generating units. As directed by President Obama's June 25, 2013, Climate Action Plan, the EPA also announced plans to establish, pursuant to Section 111(d) of the Clean Air Act, carbon dioxide emissions standards for existing fossil fuel fired electric generating units. EPA plans to publish the proposed standards for existing units by June 1, 2014, and finalize those guidelines by June 1, 2015. States must then submit their individual plans for reducing power plants' greenhouse gas emissions to EPA by June 30, 2016.

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OG&E is continuing to review and evaluate available options for reducing, avoiding, offsetting or sequestering its greenhouse gas emissions.

OG&E also seeks to utilize renewable energy sources that do not emit greenhouse gases.OG&E's service territory is in central Oklahoma and borders one of the nation's best wind resource areas.  OG&E has leveraged its advantageous geographic position to develop renewable energy resources and transmission to deliver the renewable energy.  The SPP has begun to authorize the construction of transmission lines capable of bringing renewable energy out of the wind resource area in western Oklahoma, the Texas Panhandle and western Kansas to load centers by planning for more transmission to be built in the area. In addition to significantly increasing overall system reliability, these new transmission resources should provide greater access to additional wind resources that are currently constrained due to existing transmission delivery limitations.

Endangered Species

Certain Federal laws, including the Bald and Golden Eagle Protection Act, the Migratory Bird Treaty Act and the Endangered Species Act, provide special protection to certain designated species. These laws and any state equivalents provide for significant civil and criminal penalties for unpermitted activities that result in harm to or harassment of certain protected animals and plants, including damage to their habitats.  If such species are located in an area in which OG&E conducts operations, or if additional species in those areas become subject to protection, OG&E’s operations and development projects, particularly transmission or wind projects, could be restricted or delayed, or OG&E could be required to implement expensive mitigation measures. The U.S. Fish and Wildlife Service announced a proposed rule to list the lesser prairie chicken as threatened on November 30, 2012. A final decision regarding listing is anticipated to be completed by March 30, 2014. Although the lesser prairie chicken and its habitat are located in potential development areas of OG&E, the impact of a final decision to list this species as threatened cannot be determined at this time.

Waste

OG&E'soperations generate wastes that are subject to the Federal Resource Conservation and Recovery Act of 1976 as well as comparable state laws which impose detailed requirements for the handling, storage, treatment and disposal of waste.

For OG&E, these laws impose strict requirements on waste generators regarding their treatment, storage and disposal of waste.  OG&E routinely generates small quantities of hazardous waste throughout its system. These wastes are treated, stored and disposed at facilities that are permitted to manage them.

In June 2010, the EPA proposed new rules under Federal Resource Conservation and Recovery Act of 1976 that could make the management of coal ash more costly. The extent to which the EPA intends to regulate coal ash is uncertain. The EPA continues to consider numerous comments received on the proposal. On January 29, 2014, the EPA entered into a consent decree directing them, by December 19, 2014, to sign for publication in the Federal Register a notice taking final action on the EPA's proposed Subtitle D option for coal ash which set performance standards for waste management, to be administered by the states.

OG&E has sought and will continue to seek pollution prevention opportunities and to evaluate the effectiveness of its waste reduction, reuse and recycling efforts.In2013, OG&E obtained refunds of$3.5 millionfrom the recycling of scrap metal, salvaged transformers and used transformer oil.  This figure does not include the additional savings gained through the reduction and/or avoidance of disposal costs and the reduction in material purchases due to the reuse of existing materials.  Similar savings are anticipated in future years.

Water

OG&E'soperations are subject to the Federal Clean Water Act, and analogous state laws and regulations. These laws and regulations impose detailed requirements and strict controls regarding the discharge of pollutants into state and Federal waters. The discharge of pollutants, including discharges resulting from a spill or leak, is prohibited unless authorized by a permit or other agency approval. The Federal Clean Water Act and regulations implemented thereunder also prohibit discharges of dredged and fill material in wetlands and other waters of the United States unless authorized by an appropriately issued permit. Existing cooling water intake structures are regulated under the Federal Clean Water Act to minimize their impact on the environment.

With respect to cooling water intake structures, Section 316(b) of the Federal Clean Water Act requires that their location, design, construction and capacity reflect the best available technology for minimizing their adverse environmental impact via the impingement and entrainment of aquatic organisms. In March 2011, the EPA proposed rules to implement Section 316(b). Recently, the EPA announced that it will issue a final rule by April 17, 2014. In the interim, the state of Oklahoma requires OG&E to implement best management practices related to the operation and maintenance of its existing cooling water intake structures as

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a condition of renewing its discharge permits. Once the EPA promulgates the final rules, OG&E may incur additional capital and/or operating costs to comply with them. The costs of complying with the final water intake standards are not currently determinable, but could be significant.

Site Remediation

The Comprehensive Environmental Response, Compensation and Liability Act of 1980 and comparable state laws impose liability, without regard to the legality of the original conduct, on certain classes of persons responsible for the release of hazardous substances into the environment. Because OG&Eutilizesvarious products and generate wastes that are considered hazardous substances for purposes of the Comprehensive Environmental Response, Compensation and Liability Act of 1980, OG&Ecould be subject to liability for the costs of cleaning up and restoring sites where those substances have been released to the environment.  At this time, it is not anticipated that any associated liability will cause a significant impact to OG&E.

For a further discussion regarding contingencies relating to environmental laws and regulations, see Note 12 of Notes toFinancial Statements.

Item 7A.  Quantitative and Qualitative Disclosures About Market Risk.

Market risks are, in most cases, risks that are actively traded in a marketplace and have been well studied in regards to quantification.  Market risks include, but are not limited to, changes in interest rates and commodity prices.  OG&E's exposure to changes in interest rates relates primarily to short-term variable-rate debt and commercial paper. OG&E is exposed to commodity prices in its operations.

Risk Oversight Committee

Management monitors market risks using a risk committee structure.   OG&E's Risk Oversight Committee, which consists primarily of corporate officers, is responsible for the overall development, implementation and enforcement of strategies and policies for all market risk management activities of OG&E.  This committee's emphasis is a holistic perspective of risk measurement and policies targeting OG&E's overall financial performance.On a quarterly basis, the Risk Oversight Committee reports to the Audit Committee of OGE Energy's Board of Directorson OGE Energy's risk profile affecting anticipated financial results, including any significant risk issues.

OG&E also has a Corporate Risk Management Department. This group, in conjunction with the aforementioned committees, is responsible for establishing and enforcing OG&E's risk policies.

Risk Policies

Management utilizes risk policies to control the amount of market risk exposure.  These policies are designed to provide the Audit Committee of OGE Energy's Board of Directors and senior executives of OG&E with confidence that the risks taken on by OG&E's business activities are in accordance with their expectations for financial returns and that the approved policies and controls related to market risk management are being followed.

Interest Rate Risk

OG&E'sexposure to changes in interest rates primarily relates to short-term variable-rate debt and commercial paper.OG&Emanages its interest rate exposure by monitoring and limiting the effects of market changes in interest rates.OG&Emay utilize interest rate derivatives to alter interest rate exposure in an attempt to reduce the effects of these changes.  Interest rate derivatives are used solelyto modify interest rate exposure and not to modify the overall leverage of the debt portfolio.

The fair value of OG&E's long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturitiesor bycalculating the net present value of the monthly payments discounted by OG&E's .current borrowing rate.The following table shows OG&E's long-term debt maturities and the weighted-average interest rates by maturity date.

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Year ended December 31 (Dollars in millions)	2014			2015			2016			2017			2018			Thereafter			Total			12/31/13 Fair Value
Fixed-rate debt (A)
Principal amount	$	0.2		$	0.2		$	110.2		$	125.1		$	250.1		$	1,684.5		$	2,170.3		$	2,414.1
Weighted-average interest rate	2.95		%	2.95		%	5.15		%	6.50		%	6.35		%	6.03		%	6.05		%
Variable-rate debt (B)
Principal amount	$	—		$	—		$	—		$	—		$	—		$	135.4		$	135.4		$	135.4
Weighted-average interest rate	—			—			—			—			—			0.13		%	0.13		%

(A) Prior to or when these debt obligations mature, OG&E may refinance all or a portion of such debt at then-existing market interest rates which may be more or less than the interest rates on the maturing debt.

(B) A hypothetical change of 100 basis points in the underlying variable interest rate incurred by OG&E would change interest expense by$1.4 millionannually.

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Item 8.  Financial Statements and Supplementary Data.

OKLAHOMA GAS AND ELECTRIC COMPANY

STATEMENTS OF INCOME

Year ended December 31 (In millions)	2013			2012			2011
OPERATING REVENUES	$	2,262.2		$	2,141.2		$	2,211.5
COST OF SALES	965.9			879.1			1,013.5
OPERATING EXPENSES
Other operation and maintenance	438.8			446.3			436.0
Depreciation and amortization	248.4			248.7			216.1
Taxes other than income	83.8			77.7			73.6
Total operating expenses	771.0			772.7			725.7
OPERATING INCOME	525.3			489.4			472.3
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction	6.6			6.2			20.4
Other income	8.1			8.2			8.5
Other expense	(4.6		)	(4.3		)	(8.4		)
Net other income (expense)	10.1			10.1			20.5
INTEREST EXPENSE
Interest on long-term debt	130.6			124.2			118.7
Allowance for borrowed funds used during construction	(3.4		)	(3.5		)	(10.4		)
Interest on short-term debt and other interest charges	2.1			3.9			3.3
Interest expense	129.3			124.6			111.6
INCOME BEFORE TAXES	406.1			374.9			381.2
INCOME TAX EXPENSE	113.5			94.6			117.9
NET INCOME	$	292.6		$	280.3		$	263.3

The accompanying Notes toFinancial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

STATEMENTS OF COMPREHENSIVE INCOME

Year ended December 31 (In millions)	2013		2012		2011
Net income	$	292.6	$	280.3	$	263.3
Other comprehensive income (loss), net of tax
Deferred commodity contracts hedging (gains) losses reclassified in net income, net of tax of $0.8, $0.7 and ($0.1), respectively	1.3		1.2		(0.4		)
Comprehensive income (loss)	$	293.9	$	281.5	$	262.9

The accompanying Notes toFinancial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

STATEMENTS OF CASH FLOWS

Year ended December 31 (In millions)	2013			2012			2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	292.6		$	280.3		$	263.3
Adjustments to reconcile net income to net cash provided from operating activities
Depreciation and amortization	248.4			248.7			216.1
Deferred income taxes and investment tax credits, net	116.1			103.3			95.0
Allowance for equity funds used during construction	(6.6		)	(6.2		)	(20.4		)
Stock-based compensation expense	2.3			2.6			3.0
Regulatory assets	26.8			20.3			14.0
Regulatory liabilities	(32.5		)	(14.8		)	(1.9		)
Other assets	10.0			(4.5		)	2.0
Other liabilities	(6.2		)	(28.7		)	(62.9		)
Change in certain current assets and liabilities
Accounts receivable, net	(17.9		)	20.9			(40.1		)
Accrued unbilled revenues	(1.3		)	1.9			(2.5		)
Fuel, materials and supplies inventories	(2.3		)	6.5			54.0
Fuel clause under recoveries	(26.2		)	1.8			(0.8		)
Other current assets	2.7			(6.6		)	(7.5		)
Accounts payable	49.4			9.7			13.4
Accounts payable - affiliates	1.1			(0.6		)	(3.1		)
Income taxes payable - parent	2.9			(7.1		)	23.0
Fuel clause over recoveries	(108.8		)	101.5			(22.2		)
Other current liabilities	(5.4		)	8.4			26.9
Net Cash Provided from Operating Activities	545.1			737.4			549.3
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(797.6		)	(704.4		)	(844.5		)
Reimbursement of capital expenditures	—			27.5			49.6
Proceeds from sale of assets	0.8			0.6			0.6
Net Cash Used in Investing Activities	(796.8		)	(676.3		)	(794.3		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	247.4			—			246.3
Changes in advances with parent	124.4			14.0			(51.3		)
Capital contribution from OGE Energy	—			—			50.0
Payment of long-term debt	(0.1		)	(0.1		)	—
Dividends paid on common stock	(120.0		)	(75.0		)	—
Net Cash Provided from (Used in) Financing Activities	251.7			(61.1		)	245.0
NET CHANGE IN CASH AND CASH EQUIVALENTS	—			—			—
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	—			—			—
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	—		$	—		$	—

The accompanying Notes toFinancial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

BALANCE SHEETS

December 31 (In millions)	2013		2012
ASSETS
CURRENT ASSETS
Accounts receivable, less reserve of $1.9 and $2.6, respectively	$	179.4	$	161.5
Accrued unbilled revenues	58.7		57.4
Advances to parent	—		90.3
Fuel inventories	74.4		76.8
Materials and supplies, at average cost	79.4		74.7
Deferred income taxes	189.2		138.7
Fuel clause under recoveries	26.2		—
Other	31.9		34.6
Total current assets	639.2		634.0
OTHER PROPERTY AND INVESTMENTS	2.6		2.7
PROPERTY, PLANT AND EQUIPMENT
In service	9,036.4		8,498.3
Construction work in progress	462.8		251.4
Total property, plant and equipment	9,499.2		8,749.7
Less accumulated depreciation	2,864.6		2,705.6
Net property, plant and equipment	6,634.6		6,044.1
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	379.1		510.6
Other	39.4		31.0
Total deferred charges and other assets	418.5		541.6
TOTAL ASSETS	$	7,694.9	$	7,222.4

The accompanying Notes toFinancial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

BALANCE SHEETS (Continued)

December 31 (In millions)	2013		2012
LIABILITIES AND STOCKHOLDER'S EQUITY
CURRENT LIABILITIES
Accounts payable - affiliates	$	1.8	$	0.7
Accounts payable - other	237.2		186.7
Advances from parent	87.2		—
Customer deposits	70.9		68.5
Accrued taxes	38.0		35.0
Accrued interest	42.8		43.2
Accrued compensation	30.0		33.2
Fuel clause over recoveries	0.4		109.2
Other	46.8		56.0
Total current liabilities	555.1		532.5
LONG-TERM DEBT	2,300.2		2,050.3
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	149.0		240.9
Deferred income taxes	1,545.2		1,377.8
Deferred investment tax credits	1.9		3.9
Regulatory liabilities	234.2		245.1
Other	80.0		68.8
Total deferred credits and other liabilities	2,010.3		1,936.5
Total liabilities	4,865.6		4,519.3
COMMITMENTS AND CONTINGENCIES (NOTE 12)
STOCKHOLDER'S EQUITY
Common stockholder's equity	1,016.3		1,014.0
Retained earnings	1,813.0		1,690.4
Accumulated other comprehensive loss, net of tax	—		(1.3		)
Total stockholder's equity	2,829.3		2,703.1
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY	$	7,694.9	$	7,222.4

The accompanying Notes toFinancial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

STATEMENTS OF CAPITALIZATION

December 31 (In millions)		2013			2012
STOCKHOLDER'S EQUITY
Common stock, par value $2.50 per share; authorized 100.0 shares; and outstanding 40.4 and 40.4 shares, respectively		$	100.9		$	100.9
Premium on common stock		915.4			913.1
Retained earnings		1,813.0			1,690.4
Accumulated other comprehensive loss, net of tax		—			(1.3		)
Total stockholder's equity		2,829.3			2,703.1
LONG-TERM DEBT
SERIES	DUE DATE
Senior Notes
5.15%	Senior Notes, Series Due January 15, 2016	110.0			110.0
6.50%	Senior Notes, Series Due July 15, 2017	125.0			125.0
6.35%	Senior Notes, Series Due September 1, 2018	250.0			250.0
8.25%	Senior Notes, Series Due January 15, 2019	250.0			250.0
6.65%	Senior Notes, Series Due July 15, 2027	125.0			125.0
6.50%	Senior Notes, Series Due April 15, 2028	100.0			100.0
6.50%	Senior Notes, Series Due August 1, 2034	140.0			140.0
5.75%	Senior Notes, Series Due January 15, 2036	110.0			110.0
6.45%	Senior Notes, Series Due February 1, 2038	200.0			200.0
5.85%	Senior Notes, Series Due June 1, 2040	250.0			250.0
5.25%	Senior Notes, Series Due May 15, 2041	250.0			250.0
3.90%	Senior Notes, Series Due May 1, 2043	250.0			—
3.70%	Tinker Debt, Due August 31, 2062	10.3			10.7
Other Bonds
0.18% - 0.34%	Garfield Industrial Authority, January 1, 2025	47.0			47.0
0.10% - 0.39%	Muskogee Industrial Authority, January 1, 2025	32.4			32.4
0.10% - 0.30%	Muskogee Industrial Authority, June 1, 2027	56.0			56.0
Unamortized discount		(5.5		)	(5.8		)
Total long-term debt		2,300.2			2,050.3
Total Capitalization		$	5,129.5		$	4,753.4

The accompanying Notes toFinancial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

STATEMENTS OF CHANGES IN STOCKHOLDER'S EQUITY

(In millions)	Common Stock		Premium on Common Stock		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total
Balance at December 31, 2010	$	100.9	$	857.5	$	1,221.8		$	(2.1	)	$	2,178.1
Net income	—		—		263.3			—			263.3
Other comprehensive income (loss), net of tax	—		—		—			(0.4		)	(0.4		)
Stock-based compensation	—		3.0		—			—			3.0
Capital contribution from OGE Energy	—		50.0		—			—			50.0
Balance at December 31, 2011	$	100.9	$	910.5	$	1,485.1		$	(2.5	)	$	2,494.0
Net income	—		—		280.3			—			280.3
Other comprehensive income (loss), net of tax	—		—		—			1.2			1.2
Dividends declared on common stock	—		—		(75.0		)	—			(75.0		)
Stock-based compensation and other	—		2.6		—			—			2.6
Balance at December 31, 2012	$	100.9	$	913.1	$	1,690.4		$	(1.3	)	$	2,703.1
Net income	—		—		292.6			—			292.6
Other comprehensive income (loss), net of tax	—		—		—			1.3			1.3
Dividends declared on common stock	—		—		(170.0		)	—			(170.0		)
Stock-based compensation	—		2.3		—			—			2.3
Balance at December 31, 2013	$	100.9	$	915.4	$	1,813.0		$	—		$	2,829.3

The accompanying Notes toFinancial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

NOTES TOFINANCIAL STATEMENTS

1. Summary of Significant Accounting Policies

Organization

OG&Egenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. Its operationsare subject to regulation by the OCC, the APSC and the FERC.OG&E was incorporated in 1902 under the laws of the Oklahoma Territory. OG&E is the largest electric utility in Oklahoma and its franchised service territory includes the Fort Smith, Arkansas area. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.OG&E is a wholly-owned subsidiary of OGE Energy, an energy and energy services provider offering physical delivery and related services for both electricity and natural gas primarily in the south central United States.

Basis of Presentation

In the opinion of management, all adjustments necessary to fairly present thefinancial position of OG&E atDecember 31, 2013and2012and the results of its operations and cash flows for the years endedDecember 31, 2013, 2012and2011, have been included and are of a normal recurring nature except as otherwise disclosed.

Accounting Records

The accounting records of OG&E are maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the OCC and the APSC.  Additionally,OG&E, as a regulated utility, is subject to accounting principles for certain types of rate-regulated activities, which provide that certain actual or anticipated costs that would otherwise be charged to expense can be deferred as regulatory assets, based on the expected recovery from customers in future rates.  Likewise, certain actual or anticipated credits that would otherwise reduce expense can be deferred as regulatory liabilities, based on the expected flowback to customers in future rates.  Management's expected recovery of deferred costs and flowback of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment.

OG&E records certain actual or anticipated costs and obligations as regulatory assets or liabilities if it is probable, based on regulatory orders or other available evidence, that the cost or obligation will be included in amounts allowable for recovery or refund in future rates.

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The following table is a summary of OG&E's regulatory assets and liabilities at:

December 31 (In millions)	2013		2012
Regulatory Assets
Current
Fuel clause under recoveries	$	26.2	$	—
Oklahoma demand program rider under recovery (A)	10.6		9.2
Crossroads wind farm rider under recovery (A)	4.7		14.9
Other (A)	7.3		2.9
Total Current Regulatory Assets	$	48.8	$	27.0
Non-Current
Benefit obligations regulatory asset	$	227.4	$	370.6
Income taxes recoverable from customers, net	56.5		54.7
Smart Grid	44.2		42.8
Deferred storm expenses	21.6		12.7
Unamortized loss on reacquired debt	11.8		13.0
Pension tracker	1.4		—
Other	16.2		16.8
Total Non-Current Regulatory Assets	$	379.1	$	510.6
Regulatory Liabilities
Current
Smart Grid rider over recovery (B)	$	16.7	$	24.1
Fuel clause over recoveries	0.4		109.2
Other (B)	3.1		7.8
Total Current Regulatory Liabilities	$	20.2	$	141.1
Non-Current
Accrued removal obligations, net	$	227.7	$	218.2
Deferred pension credits	6.5		17.7
Pension tracker	—		9.2
Total Non-Current Regulatory Liabilities	$	234.2	$	245.1

(A) Included in Other Current Assets on theBalance Sheets.

(B) Included in Other Current Liabilities on theBalance Sheets.

OG&E recovers a return on the capital expenditures along with operation and maintenance expense and depreciation expense related to the Crossroads wind farm through riders established by the OCC and APSC. OG&E began recovery in the fourth quarter of 2011 in Oklahoma and June of 2013 in Arkansas, and believes the rider will continue until new rates are implemented in OG&E's next general rate case in each jurisdiction.

OG&E recovers program costs related to the Demand and Energy Efficiency Program. An extension of the demand program rider was approved in December 2012, which allows for the recovery of demand program costs, lost revenues associated with certain achieved energy, demand savings and performance based incentives and the recovery of costs associated with research and development investments through December 2015.

Fuel clause under recoveries are generated from under recoveries from OG&E's customers when OG&E's cost of fuel exceeds the amount billed to its customers.  Fuel clause over recoveries are generated from over recoveries from OG&E's customers when the amount billed to its customers exceeds OG&E's cost of fuel.OG&E's fuel recovery clauses are designed to smooth the impact of fuel price volatility on customers' bills.As a result, OG&E under recovers fuel costs in periods of rising fuel prices above the baseline charge for fuel and over recovers fuel costs when prices decline below the baseline charge for fuel. Provisions in the fuel clauses are intended to allow OG&E to amortize under and over recovery balances.

The benefit obligations regulatory asset is comprised of expenses recorded which are probable of future recovery and that have not yet been recognized as components of net periodic benefit cost, including net loss, prior service cost and net transition obligation.These expenses are recorded as a regulatory asset as OG&E had historically recovered and currently recovers pension and postretirement benefit plan expense in its electric rates. If, in the future, the regulatory bodies indicate a change in policy related to the recovery of pension and postretirement benefit plan expenses, this could cause the benefit obligations regulatory asset balance to be reclassified to Accumulated other comprehensive income.

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The following table is a summary of the components of the benefit obligations regulatory asset at:

December 31 (In millions)	2013			2012
Pension Plan and Restoration of Retirement Income Plan
Net loss	$	178.4		$	278.6
Prior service cost	2.5			4.5
Postretirement Benefit Plans
Net loss	79.9			134.6
Prior service cost	(33.4		)	(47.1		)
Total	$	227.4		$	370.6

The following amounts in the benefit obligations regulatory asset atDecember 31, 2013are expected to be recognized as components of net periodic benefit cost in2014: 

(In millions)
Pension Plan and Restoration of Retirement Income Plan
Net loss	$	11.4
Prior service cost	2.0
Postretirement Benefit Plans
Net loss	11.0
Prior service cost	(13.7		)
Total	$	10.7

Income taxes recoverable from customers, which represents income tax benefits previously used to reduce OG&E's revenues, are treated as regulatory assets and liabilities and are being amortized over the estimated remaining life of the assets to which they relate.  These amounts are being recovered in rates as the temporary differences that generated the income tax benefit turn around.  The income tax related regulatory assets and liabilities are netted in Income taxes recoverable from customers, net in the regulatory assets and liabilities table above.

OG&E recovers the cost of system-wide deployment of smart grid technology and implementing the smart grid pilot program, the incremental costs for web portal access, education and providing home energy reports and stranded costs associated with OG&E's existing meters.The costs recoverable from Oklahoma customers for system-wide deployment of smart grid technology and implementing the smart grid pilot program were capped at$366.4 million(inclusive of the U.S. Department of Energy grant award of$130.0 million) subject to an offset for any recovery of those costs from Arkansas customers. These amounts are currently being recovered through a rider which will remain in effect until the smart grid project costs are included in base rates in OG&E's next general rate case. Costs not included in the rider arethe incremental costs for web portal access, education and home energy reports, which are capped at$6.9 million, and the stranded costs associated with OG&E's existing meters, which have been replaced by smart meters, which were accumulated during the smart grid deployment and have been included in the Smart Grid asset in the table above. These costs are expected to be recovered in base rates in OG&E's next general rate case.

OG&E defers annual Oklahoma storm-related operation and maintenance expenses in excess of$2.7 millionand expenses any Oklahoma storm-related operation and maintenance expenses up to$2.7 million. OG&E will recover the deferred amounts over afive-year period ending in August 2017.

Unamortized loss on reacquired debt is comprised of unamortized debt issuance costs related to the early retirement of OG&E's long-term debt.  These amounts are recorded in interest expenses and are being amortized over the term of the long-term debt which replaced the previous long-term debt.  The unamortized loss on reacquired debt is not included in OG&E's rate base and does not otherwise earn a rate of return.

OG&E recovers specific amounts of pension and postretirement medical costs in rates approved in its Oklahoma rate cases. In accordance with approved orders, OG&E defers the difference between actual pension and postretirement medical expenses and the amount approved in its last Oklahoma rate case as a regulatory asset or regulatory liability. These amounts have been recorded in the Pension tracker in the regulatory assets and liabilities table above.

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In September 2011, OG&E was allowed to include postretirement medical expenses in its pension tracker. In August 2012, OG&E was allowed to recover pension and postretirement medical expenses over a two-year period ending July 2014 which is included in Deferred pension credits in the regulatory assets and liabilities table above.

Accrued removal obligations represent asset retirement costs previously recovered from ratepayers for other than legal obligations.

Management continuously monitors the future recoverability of regulatory assets.When in management's judgment future recovery becomes impaired, the amount of the regulatory asset is adjusted, as appropriate.IfOG&Ewere required to discontinue the application of accounting principles for certain types of rate-regulated activities for some or all of its operations, it could result in writing off the related regulatory assets, which could have significant financial effects.

Use of Estimates

In preparing theFinancial Statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and contingent liabilities at the date of theFinancial Statements and the reported amounts of revenues and expenses during the reporting period.  Changes to these assumptions and estimates could have a material effect onOG&E'sFinancial Statements.  However,OG&Ebelieves it has taken reasonable positions where assumptions and estimates are used in order to minimize the negative financial impact toOG&Ethat could result if actual results vary from the assumptions and estimates.  In management's opinion, the areas ofOG&Ewhere the most significant judgment is exercisedincludes the determination of Pension Plan assumptions,impairment estimates of long-lived assets (including intangible assets), income taxes,contingency reserves, asset retirement obligations, assets and depreciable lives of property, plant and equipment, the existence of regulatory assets and liabilities and unbilled revenues.

Cash and Cash Equivalents

For purposes of theFinancial Statements, OG&E considers all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents.  These investments are carried at cost, which approximates fair value.

Allowance for Uncollectible Accounts Receivable

Customer balances are generally written off if not collected within six months after the final billing date. The allowance for uncollectible accounts receivable for OG&E is calculated by multiplying the last six months of electric revenue by the provision rate.  The provision rate is based on a 12-month historical average of actual balances written off.  To the extent the historical collection rates are not representative of future collections, there could be an effect on the amount of uncollectible expense recognized.  Also, a portion of the uncollectible provision related to fuel within the Oklahoma jurisdiction is being recovered through the fuel adjustment clause.The allowance for uncollectible accounts receivable was$1.9 millionand$2.6 millionatDecember 31, 2013 and 2012, respectively.

New business customers are required to provide a security deposit in the form of cash, bond or irrevocable letter of credit that is refunded when the account is closed.  New residential customers, whose outside credit scores indicate an elevated risk, are required to provide a security deposit that is refunded based on customer protection rules defined by the OCC and the APSC.  The payment behavior of all existing customers is continuously monitored and, if the payment behavior indicates sufficient risk within the meaning of the applicable utility regulation, customers will be required to provide a security deposit.

Fuel Inventories

Fuel inventories for the generation of electricity consist of coal, natural gas and oil.  OG&E uses the weighted-average cost method of accounting for inventory that is physically added to or withdrawn from storage or stockpiles.  The amount of fuel inventory was$74.4 millionand$76.8 millionatDecember 31, 2013and2012, respectively.

Gas Imbalances

Gas imbalances occur when the actual amounts of natural gas delivered from or received byOG&Ediffer from the amounts scheduled to be delivered or received.OG&Evalues all imbalances at an average of current market indices applicable toOG&E's operations, not to exceed net realizable value.

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Property, Plant and Equipment

All property, plant and equipment is recorded at cost.  Newly constructed plant is added to plant balances at cost which includes contracted services, direct labor, materials, overhead, transportation costs and the allowance for funds used during construction.  Replacements of units of property are capitalized as plant.  For assets that belong to a common plant account, the replaced plant is removed from plant balances and the cost of such property is charged to Accumulated Depreciation.  For assets that do not belong to a common plant account, the replaced plant is removed from plant balances with the related accumulated depreciation and the remaining balance net of any salvage proceeds is recorded as a loss in theStatements of Income as Other Expense.  Repair and replacement of minor items of property are included in theStatements of Income as Other Operation and Maintenance Expense.

The table below presents OG&E's ownership interest in the jointly-owned McClain Plant and the jointly-owned Redbud Plant, and, as disclosed below, only OG&E's ownership interest is reflected in the property, plant and equipment and accumulated depreciation balances in these tables.  The owners of the remaining interests in the McClain Plant and the Redbud Plant are responsible for providing their own financing of capital expenditures.  Also, only OG&E's proportionate interests of any direct expenses of the McClain Plant and the Redbud Plant such as fuel, maintenance expense and other operating expenses are included in the applicable financial statement captions in theStatement of Income.

December 31, 2013 (In millions)	Percentage Ownership		Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)	77	%	$	180.8	$	62.1	$	118.7
Redbud Plant (A)(B)	51	%	$	498.9	$	89.7	$	409.2

(A) Construction work in progress was$0.1 millionand$39.5 millionfor the McClain and Redbud Plants, respectively.

(B) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$28.8 million.

December 31, 2012 (In millions)	Percentage Ownership		Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)	77	%	$	182.1	$	56.3	$	125.8
Redbud Plant (A)(B)	51	%	$	458.5	$	69.5	$	389.0

(A) Construction work in progress was$0.1 millionand$0.3 millionfor the McClain and Redbud Plants, respectively.

(B) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$23.3 million.

OG&E's property, plant and equipment and related accumulated depreciation are divided into the following major classes at:

December 31, 2013 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
Distribution assets	$	3,403.8	$	1,028.2	$	2,375.6
Electric generation assets (A)	3,551.0		1,306.1		2,244.9
Transmission assets (B)	2,163.7		385.0		1,778.7
Intangible plant	50.5		27.1		23.4
Other property and equipment	330.2		118.2		212.0
Total property, plant and equipment	$	9,499.2	$	2,864.6	$	6,634.6

(A) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$28.8 million.

(B) This amount includes a plant acquisition adjustment of$3.3 millionand accumulated amortization of$0.3 million.

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December 31, 2012 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
Distribution assets	$	3,222.7	$	969.6	$	2,253.1
Electric generation assets (A)	3,446.6		1,242.4		2,204.2
Transmission assets (B)	1,712.6		359.8		1,352.8
Intangible plant	50.2		25.0		25.2
Other property and equipment	317.6		108.8		208.8
Total property, plant and equipment	$	8,749.7	$	2,705.6	$	6,044.1

(A) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$23.3 million.

(B) This amount includes a plant acquisition adjustment of$3.3 millionand accumulated amortization of$0.3 million.

The unamortized computer software costs were$16.8 millionand$17.6 millionatDecember 31, 2013and2012, respectively. In2013, 2012and2011, amortization expense for computer software costs was$4.0 million, $4.2 millionand$1.8 million, respectively.

Depreciation and Amortization

The provision for depreciation, which was2.8 percentand3.0 percent, respectively, of the average depreciable utility plant for2013and2012, is provided on a straight-line method over the estimated service life of the utility assets.  Depreciation is provided at the unit level for production plant and at the account or sub-account level for all other plant, and is based on the average life group method. In2014, the provision for depreciation is projected to be2.8 percentof the average depreciable utility plant. Amortization of intangible assets is computed using the straight-line method. Of the remaining amortizable intangible plant balance atDecember 31, 2013, 93.5 percentwill be amortized over9.30years with6.5 percentof the remaining amortizable intangible plant balance atDecember 31, 2013being amortized over25.6years.Amortization of plant acquisition adjustments is provided on a straight-line basis over the estimated remaining service life of the acquired asset.  Plant acquisition adjustments include$148.3 millionfor the Redbud Plant, which are being amortized over a27-yearlife and$3.3 millionfor certain substation facilities in OG&E's service territory, which are being amortized over a26to59-yearperiod.

Asset Retirement Obligations

OG&Ehas previously recorded asset retirement obligations that are being amortized over their respective lives ranging from20to74years.

The following table summarizes changes to OG&E's asset retirement obligations during theyears endedDecember 31, 2013and2012.

(In millions)	2013			2012
Balance at January 1	$	53.6		$	24.8
Accretion expense	2.3			1.9
Revisions in estimated cash flows (A)	(0.7		)	26.9
Balance at December 31	$	55.2		$	53.6

(A) Due to changes to OG&E's asset retirement obligations related to its wind farms as a result of changes in the assumption related to the timing of removal used in the valuation of the asset retirement obligations.

Allowance for Funds Used During Construction

For OG&E, allowance for funds used during construction is calculated according to the FERC pronouncements for the imputed cost of equity and borrowed funds.  Allowance for funds used during construction, a non-cash item, is reflected as an increase to net other income and a reduction to interest expense in theStatements of Income and as an increase to Construction Work in Progress in theBalance Sheets.Allowance for funds used during construction rates, compounded semi-annually, were8.33 percent, 8.93 percentand8.71 percentfor the years endedDecember 31, 2013, 2012and2011, respectively.Thedecreasein the allowance for funds used during construction rates in 2013 was primarily due to two factors. First, a decrease in the common equity cost rate caused the equity portion of allowance for equity funds used during construction to decrease. Second, an increase in the average daily balance of short term debt allowed the fixed commercial paper fees to be lower per dollar of short term debt, resulting in a lower short term debt rate, which caused the debt portion of allowance for funds used during construction to decrease.

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Collection of Sales Tax

In the normal course of its operations, OG&E collects sales tax from its customers.  OG&E records a current liability for sales taxes when it bills its customers and eliminates this liability when the taxes are remitted to the appropriate governmental authorities.  OG&E excludes the sales tax collected from its operating revenues.

Revenue Recognition

General

OG&E reads its customers' meters and sends bills to its customers throughout each month.  As a result, there is a significant amount of customers' electricity consumption that has not been billed at the end of each month.  Unbilled revenue is presented in Accrued Unbilled Revenues on theBalance Sheets and in Operating Revenues on theStatements of Income based on estimates of usage and prices during the period.The estimates that management uses in this calculation could vary from the actual amounts to be paid by customers.

SPP Purchases and Sales

OG&E participates in the SPP energy imbalance service market in a dual role as a load serving entity and as a generation owner.  The energy imbalance service market requires cash settlements for over or under schedules of generation and load. Market participants, including OG&E, are required to submit resource plans and can submit offer curves for each resource available for dispatch.  A function of interchange accounting is to match participants' MWH entitlements (generation plus scheduled bilateral purchases) against their MWH obligations (load plus scheduled bilateral sales) during every hour of every day. If the net result during any given hour is an entitlement, the participant is credited with a spot-market sale to the SPP at the respective market price for that hour; if the net result is an obligation, the participant is charged with a spot-market purchase from the SPP at the respective market price for that hour. The SPP purchases and sales are not allocated to individual customers.  OG&E records the hourly sales to the SPP at market rates in Operating Revenues and the hourly purchases from the SPP at market rates in Cost of Sales in itsFinancial Statements.

Fuel Adjustment Clauses

Variances in the actual cost of fuel used in electric generation and certain purchased power costs, as compared to the fuel component included in the cost-of-service for ratemaking, are passed through to OG&E's customers through fuel adjustment clauses. The fuel adjustment clauses are subject to periodic review by the OCC, the APSC and the FERC. The OCC, the APSC and the FERC have authority to review the appropriateness of gas transportation charges or other fees OG&E pays to its affiliate, Enable.

Income Taxes

OG&E isa member of an affiliated group thatfilesconsolidated income tax returns in the U.S. Federal jurisdiction and various state jurisdictions. Income taxesaregenerally allocated to each company in the affiliated group based on its stand-alone taxable income or loss.Federal investment tax credits previously claimed on electric utility property have been deferred and are being amortized to income over the life of the related property.  OG&E uses the asset and liability method of accounting for income taxes. Under this method, a deferred tax asset or liability is recognized for the estimated future tax effects attributable to temporary differences between the financial statement basis and the tax basis of assets and liabilities as well as tax credit carry forwards and net operating loss carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period of the change. OG&E recognizes interest related to unrecognized tax benefits in interest expense and recognizes penalties in other expense.

Accrued Vacation

OG&E accrues vacation pay monthly by establishing a liability for vacation earned. Vacation may be taken as earned and is charged against the liability. At the end of each year, the liability represents the amount of vacation earned, but not taken. OGE employees can carryover no more than 80 hours to be used in future years.

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Accumulated Other Comprehensive Loss

The balance of Accumulated Other Comprehensive Loss was $1.3 million at December 31,2012 related to deferred commodity contracts hedging activity. There was no balance in Accumulated Other Comprehensive Loss at December 31, 2013.

Environmental Costs

Accruals for environmental costs are recognized when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated.  Costs are charged to expenseor deferred as a regulatory asset based on expected recovery from customers in future rates,if they relate to the remediation of conditions caused by past operations or if they are not expected to mitigate or prevent contamination from future operations.  Where environmental expenditures relate to facilities currently in use, such as pollution control equipment, the costs may be capitalized and depreciated over the future service periods.  Estimated remediation costs are recorded at undiscounted amounts, independent of any insuranceor raterecovery, based on prior experience, assessments and current technology.  Accrued obligations are regularly adjusted as environmental assessments and estimates are revised, and remediation efforts proceed.For sites whereOG&E has been designated as one of several potentially responsible parties, the amount accrued representsOG&E'sestimated share of the cost.  OG&E had$6.2 millionand$5.8 millioninaccrued environmental liabilities atDecember 31, 2013and2012, respectively, which are included in the summary of asset retirement obligations above.

2. Accounting Pronouncements

In July 2013, the Emerging Issues Task Force issued "Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward or Tax Credit Carryforward Exists." The new standard requires entities to present an unrecognized tax benefit, or a portion of an unrecognized tax benefit, in the statement of financial position as a reduction to a deferred tax asset for a net operating loss carryforward or a tax credit carryforward, except as follows: to the extent that a net operating loss carryforward or tax credit carryforward at the reporting date is not available under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position, the unrecognized tax benefit would be presented in the statement of financial position as a liability. The new standard is applicable for all entities that have unrecognized tax benefits when a net operating loss carryforward or a tax credit carryforward exists. The new standard is effective for interim and annual reporting periods beginning after December 15, 2013 and does not require any new financial statement disclosures. This new standard may be applied retrospectively or prospectively with early adoption permitted. OG&E retrospectively adopted this new standard effective January 1, 2013.

In February 2013, the Financial Accounting Standards Board issued "Comprehensive Income: Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income." The new standard requires an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, the new standard requires an entity to present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items in net income but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. The new standard is applicable for all entities that issue financial statements that are presented in conformity with U.S. GAAP and that report items of other comprehensive income. The new standard is effective forinterim andannual reporting periods for fiscal years beginning afterDecember 15, 2012and is required to be applied prospectively. OG&E adoptedthis new standard effectiveJanuary 1, 2013.

3. Related Party Transactions

OGE Energy charged operating costs to OG&E of$120.1 million, $118.4 millionand$129.7 millionin2013, 2012and2011, respectively.OGE Energy charges operating costs to its subsidiaries and unconsolidated affiliate based on several factors. Operating costs directly related to specific subsidiaries or unconsolidated affiliate are assigned to those subsidiaries or unconsolidated affiliate.Where more than one subsidiary or unconsolidated affiliate benefits from certain expenditures, the costs are shared between those subsidiaries and unconsolidated affiliate receiving the benefits.  Operating costs incurred for the benefit of all subsidiaries and unconsolidated affiliate are allocated among the subsidiaries and unconsolidated affiliate, either as overhead based primarily on labor costs or using the "Distrigas" method.  The Distrigas method is a three-factor formula that uses an equal weighting of payroll, net operating revenues and gross property, plant and equipment.  OGE Energy adopted the Distrigas method in January 1996 as a result of a recommendation by the OCC Staff.  OGE Energy believes this method provides a reasonable basis for allocating common expenses.

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The following table summarizes related party transactions between OG&E and its affiliate, Enable, during 2013, 2012 and 2011.

	December 31,
(In millions)	2013		2012		2011
Operating Revenues:
Electricity to power electric compression assets	$	10.2	$	12.4	$	8.1
Cost of Sales:
Natural gas transportation services	$	34.8	$	34.8	$	34.8
Natural gas storage services	12.9		12.9		12.7
Natural gas purchases	22.4		20.4		34.7

In2013and2012, OG&E declared dividends to OGE Energy of$170.0 millionand$75.0 million, respectively. In2011, OG&E declarednodividends to OGE Energy.

In June 2011, OGE Energy made a capital contribution to OG&E for$50.0 million.

4. Fair Value Measurements

OG&E had nofinancial instruments measured at fair value on a recurring basis atDecember 31, 2013 and December 31, 2012.

The following table summarizes the fair value and carrying amount of OG&E's financial instruments atDecember 31, 2013 and December 31, 2012.

	2013				2012
December 31 (In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-Term Debt
Senior Notes	$	2,154.5	$	2,405.0	$	1,904.2	$	2,401.6
Industrial Authority Bonds	135.4		135.4		135.4		135.4
Tinker Debt	10.3		9.1		10.7		10.0

The carrying value of the financial instruments included in theBalance Sheets approximates fair value except for long-term debt which is valued at the carrying amount.The fair value of OG&E's long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturitiesand is classified as Level 2 in the fair value hierarchy.

5. Stock-Based Compensation

In 2013,OGE Energyadopted, and its shareowners approved, the 2013 Stock Incentive Plan. The 2013 Plan replaced the 2008 Plan and no further awards will be granted under the 2008 Plan.Under the 2013 Stock Incentive Plan, restricted stock, restricted stock units, stock options,stock appreciation rightsand performance units may be granted to officers, directors and other key employeesof OGE Energy and its subsidiaries. OGE Energy has authorized the issuance of up to7,400,000shares under the 2013 Stock Incentive Plan.

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The following table summarizes OG&E's pre-tax compensation expense and related income tax benefit for the years endedDecember 31, 2013, 2012and2011related toperformance units and restricted stockfor OG&E employees.

Year ended December 31 (In millions)	2013		2012		2011
Performance units
Total shareholder return	$	1.7	$	1.7	$	1.6
Earnings per share	0.5		0.9		1.1
Total performance units	2.2		2.6		2.7
Restricted stock	0.1		0.1		0.2
Net compensation expense	$	2.3	$	2.7	$	2.9
Income tax benefit	$	0.9	$	1.2	$	1.2

OGE Energyhas issued new shares to satisfy stock option exercises, restricted stock grants and payouts of earned performance units.In2013, 2012and2011, there were139,706shares, 205,838sharesand113,602shares, respectively, of new common stock issuedto OG&E's employees pursuant to OGE Energy'sstock incentive plans related to exercised stock options, restricted stock grants (net of forfeitures) and payouts of earned performance units. In2013, there were692shares of restricted stockreturned toOGE Energyto satisfy tax liabilities.

Performance Units

Under the 2008 Stock Incentive Plan,OGE Energyhas issued performance units which represent the value of one share ofOGE Energy'scommon stock.  The performance units provide for accelerated vesting if there is a change in control (as defined in the 2008 Stock Incentive Plan).  Each performance unit is subject to forfeiture if the recipient terminates employment withOGE Energyor a subsidiary prior to the end of the three-year award cycle for any reason other than death, disability or retirement.  In the event of death, disability or retirement, a participant will receive a prorated payment based on such participant's number of full months of service during the award cycle, further adjusted based on the achievement of the performance goals during the award cycle.

The performance units granted based on total shareholder return are contingently awarded and will be payable in shares ofOGE Energy'scommon stock subject to the condition that the number of performance units, if any, earned by the employees upon the expiration of a three-year award cycle (i.e., three-year cliff vesting period) is dependent onOGE Energy'stotal shareholder return ranking relative to a peer group of companies.  The performance units granted based on earnings per share are contingently awarded and will be payable in shares ofOGE Energy'scommon stock based onOGE Energy'searnings per share growth over a three-year award cycle (i.e., three-year cliff vesting period) compared to a target set at the time of the grant by the Compensation Committee ofOGE Energy'sBoard of Directors. All of theseperformance units are classified as equity inOGE Energy'sConsolidated Balance Sheet.  If there is no or only a partial payout for the performance units at the end of the award cycle, the unearned performance units are cancelled. Payout requires approval of the Compensation Committee ofOGE Energy'sBoard of Directors. Payouts, if any, are all made in common stock and are considered made when the payout is approved by the Compensation Committee.

Performance Units – Total Shareholder Return

The fair value of the performance units based on total shareholder return was estimated on the grant date using a lattice-based valuation model that factors in information, including the expected dividend yield, expected price volatility, risk-free interest rate and the probable outcome of the market condition, over the expected life of the performance units.  Compensation expense for the performance units is a fixed amount determined at the grant date fair value and is recognized over the three-year award cycle regardless of whether performance units are awarded at the end of the award cycle.  Dividends are not accrued or paid during the performance period and, therefore, are not included in the fair value calculation.  Expected price volatility is based on the historical volatility ofOGE Energy'scommon stock for the past three years and was simulated using the Geometric Brownian Motion process.  The risk-free interest rate for the performance unit grants is based on the three-year U.S. Treasury yield curve in effect at the time of the grant.  The expected life of the units is based on the non-vested period since inception of the award cycle.  There are no post-vesting restrictions related toOGE Energy'sperformance units based on total shareholder return.The number of performance units granted based on total shareholder return and the assumptions used to calculate the grant date fair value of the performance units based on total shareholder return are shown in the following table.

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	2013			2012			2011
Number of units granted to OG&E employees	71,850			81,122			86,604
Fair value of units granted	$	25.89		$	25.91		$	23.05
Expected dividend yield	2.8		%	3.0		%	3.2		%
Expected price volatility	20.0		%	22.0		%	33.0		%
Risk-free interest rate	0.37		%	0.38		%	1.40		%
Expected life of units (in years)	2.84			2.87			2.87

Performance Units – Earnings Per Share

The fair value of the performance units based on earnings per share is based on grant date fair value which is equivalent to the price of one share ofOGE Energy'scommon stock on the date of grant.  The fair value of performance units based on earnings per share varies as the number of performance units that will vest is based on the grant date fair value of the units and the probable outcome of the performance condition.OGE Energyreassesses at each reporting date whether achievement of the performance condition is probable and accrues compensation expense if and when achievement of the performance condition is probable.  As a result, the compensation expense recognized for these performance units can vary from period to period.  There are no post-vesting restrictions related toOGE Energy'sperformance units based on earnings per share.The number of performance units granted based on earnings per share and the grant date fair value are shown in the following table.

	2013		2012		2011
Number of units granted to OG&E employees	23,952		27,038		28,862
Fair value of units granted	$	26.73	$	23.82	$	20.81

Restricted Stock

Under the 2008 Stock Incentive Plan and beginning in 2008, OGE Energyissued restricted stock to certain existing non-officer employees as well as other executives upon hire to attract and retain individuals to be competitive in the marketplace. The restricted stock vests in one-third annual increments.  Prior to vesting, each share of restricted stock is subject to forfeiture if the recipient ceases to render substantial services toOGE Energyor a subsidiary for any reason other than death, disability or retirement. These shares may not be sold, assigned, transferred or pledged and are subject to a risk of forfeiture.

The fair value of the restricted stock was based on the closing market price ofOGE Energy'scommon stock on the grant date. Compensation expense for the restricted stock is a fixed amount determined at the grant date fair value and is recognized as services are rendered by employees over a three-year vesting period. Also, OG&E treats its restricted stock as multiple separate awards by recording compensation expense separately for each tranche whereby a substantial portion of the expense is recognized in the earlier years in the requisite service period. Dividends are accrued and paid during the vesting period and, therefore, are included in the fair value calculation. The expected life of the restricted stock is based on the non-vested period since inception of the three-year award cycle.  There are no post-vesting restrictions related toOGE Energy'srestricted stock.The number of shares of restricted stock grantedrelated to OG&E employeesand the grant date fair value are shown in the following table.

	2013		2012		2011
Shares of restricted stock granted to OG&E employees	3,824		2,216		4,468
Fair value of restricted stock granted	$	29.71	$	26.93	$	23.61

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A summary of the activity forOGE Energy'sperformance units and restricted stockapplicable to OG&E'S employeesatDecember 31, 2013and changes in2013are shown in the following table.

	Performance Units
	Total Shareholder Return					Earnings Per Share					Restricted Stock
(dollars in millions)	Number of Units			Aggregate Intrinsic Value		Number of Units			Aggregate Intrinsic Value		Number of Shares		Aggregate Intrinsic Value
Units/Shares Outstanding at 12/31/12	224,012					74,670					6,046
Granted	71,850		(A)			23,952		(A)			3,824
Converted	(75,452	)	(B)	$	4.4	(25,152	)	(B)	$	1.5	N/A
Vested	N/A					N/A					(3,038	)	$	0.1
Forfeited	(7,940	)				(2,648	)				(884	)
Employee migration	(5,644	)	(C)			(1,884	)	(C)			—
Units/Shares Outstanding at 12/31/13	206,826			$	9.9	68,938			$	2.7	5,948		$	0.2
Units/Shares Fully Vested at 12/31/13	68,750			$	3.7	22,914			$	1.6

(A) For performance units, this represents the target number of performance units granted.  Actual number of performance units earned, if any, is dependent upon performance and may range from0 percentto200 percentof the target.

(B) These amounts represent performance units that vested atDecember 31, 2012which were settled in February 2013.

(C) Due to certain employees transferring betweenOG&Eand its affiliates.

A summary of the activity forOGE Energy'snon-vested performance units and restricted stockapplicable to OG&E'S employeesatDecember 31, 2013and changes in2013are shown in the following table.

	Performance Units
	Total Shareholder Return					Earnings Per Share					Restricted Stock
	Number of Units			Weighted-Average Grant Date Fair Value		Number of Units			Weighted-Average Grant Date Fair Value		Number of Shares		Weighted-Average Grant Date Fair Value
Units/Shares Non-Vested at 12/31/12	148,560			$	24.51	49,518			$	22.34	6,046		$	24.62
Granted	71,850		(A)	$	25.89	23,952		(A)	$	26.73	3,824		$	29.71
Vested	(68,750	)		$	23.05	(22,914	)		$	20.81	(3,038	)	$	23.51
Forfeited	(7,940	)		$	25.23	(2,648	)		$	24.03	(884	)	$	28.31
Employee migration	(5,644	)	(B)	$	24.74	(1,884	)	(B)	$	23.23	—		$	—
Units/Shares Non-Vested at 12/31/13	138,076			$	25.90	46,024			$	25.25	5,948		$	27.91
Units/Shares Expected to Vest	126,390		(C)			42,130		(C)			5,948

(A) For performance units, this represents the target number of performance units granted.  Actual number of performance units earned, if any, is dependent upon performance and may range from0 percentto200 percentof the target.

(B) Due to certain employees transferring betweenOG&Eand its affiliates.

(C) The intrinsic value of the performance units based on total shareholder return and earnings per share is$5.6 million and $1.1 million, respectively.

Fair Value of Vested Performance Units and Restricted Stock

A summary of OG&E's fair value for its vested performance units and restricted stock is shown in the following table.

Year ended December 31 (In millions)	2013		2012		2011
Performance units
Total shareholder return	$	1.6	$	1.4	$	1.2
Earnings per share	1.0		0.8		0.6
Restricted stock	0.1		0.1		0.3

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Unrecognized Compensation Cost

A summary of OG&E's unrecognized compensation cost for its non-vested performance units and restricted stock and the weighted-average periods over which the compensation cost is expected to be recognized are shown in the following table.

December 31, 2013	Unrecognized Compensation Cost (in millions)		Weighted Average to be Recognized (in years)
Performance units
Total shareholder return	$	1.7	1.63
Earnings per share	0.3		1.52
Total performance units	2.0
Restricted stock	0.1		2.17
Total	$	2.1

Stock Options

OGE Energy last issued stock options in2004and as ofDecember 31, 2006, all stock options were fully vested and expensed. All stock options have a contractual life of10years.A summary of the activity for OGE Energy's stock optionsapplicable to OG&E'S employeesatDecember 31, 2013and changes during2013are shown in the following table.

(dollars in millions)	Number of Options		Weighted-Average Exercise Price			Aggregate Intrinsic Value		Weighted-Average Remaining Contractual Term
Options Outstanding at 12/31/12	7,000		$	9.62
Exercised	(7,000	)	$	(9.62	)	$	0.2
Options Outstanding at 12/31/13	—		$	—		$	—	0.00	years
Options Fully Vested and Exercisable at 12/31/13	—		$	—		$	—	0.00	years

A summary of the activity for OG&E's exercised stock options in2013, 2012and2011are shown in the following table.

Year ended December 31 (In millions)	2013		2012		2011
Intrinsic value (A)	$	0.2	$	0.2	$	0.3

(A) The difference between the market value on the date of exercise and the option exercise price.

6. Supplemental Cash Flow Information

The following table discloses information about investing and financing activities that affected recognized assets and liabilities but which did not result in cash receipts or payments.  Also disclosed in the table iscash paid for interest, net of interest capitalized, and cash paid for income taxes, net of income tax refunds.

Year ended December 31 (In millions)	2013			2012			2011
NON-CASH INVESTING AND FINANCING ACTIVITIES
Installment payments for Tinker electric distribution system	$	—		$	10.6		$	—
Power plant long-term service agreement	9.7			—			1.7
SUPPLEMENTAL CASH FLOW INFORMATION
Cash Paid During the Period for
Interest (net of interest capitalized) (A)	$	127.5		$	122.1		$	108.2
Income taxes (net of income tax refunds)	(5.5		)	(1.2		)	4.5

(A) Net of interest capitalized of$3.4 million, $3.5 millionand$10.4 millionin2013, 2012and2011, respectively.

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7. Income Taxes

The items comprising income tax expense are as follows:

Year ended December 31 (In millions)	2013			2012			2011
Provision (Benefit) for Current Income Taxes
Federal	$	(3.2	)	$	(9.0	)	$	23.4
State	0.6			0.3			(0.5		)
Total Provision (Benefit) for Current Income Taxes	(2.6		)	(8.7		)	22.9
Provision for Deferred Income Taxes, net
Federal	106.4			111.4			98.0
State	11.7			(5.9		)	0.3
Total Provision for Deferred Income Taxes, net	118.1			105.5			98.3
Deferred Federal Investment Tax Credits, net	(2.0		)	(2.2		)	(3.3		)
Total Income Tax Expense	$	113.5		$	94.6		$	117.9

OG&E isa member of an affiliated group thatfilesconsolidated income tax returns in the U.S. Federal jurisdiction and various state jurisdictions. With few exceptions, OG&E is no longer subject to U.S. Federal tax examinations by tax authorities for years prior to2010or state and local tax examinations by tax authorities for years prior to2009.  Income taxesaregenerally allocated to each company in the affiliated group based on its stand-alone taxable income or loss.Federal investment tax credits previously claimed on electric utility property have been deferred and are being amortized to income over the life of the related property.OG&E earns both Federal and Oklahoma state tax credits associated with production from its wind farms and earns Oklahoma state tax credits associated with its investments inelectric generatingfacilities which further reduce OG&E's effective tax rate.The following schedule reconciles the statutory Federal tax rate to the effective income tax rate:

Year ended December 31	2013		2012		2011
Statutory Federal tax rate	35.0	%	35.0	%	35.0	%
Amortization of net unfunded deferred taxes	0.8		1.0		0.9
Medicare Part D subsidy	—		—		0.4
Federal investment tax credits, net	(0.5	)	(0.6	)	(0.9	)
State income taxes, net of Federal income tax benefit	—		(0.7	)	0.1
Federal renewable energy credit (A)	(9.2	)	(9.4	)	(4.4	)
Uncertain tax positions	2.0		—		—
Other	(0.2	)	(0.1	)	(0.2	)
Effective income tax rate	27.9	%	25.2	%	30.9	%

(A) Represents credits associated with the production from OG&E's wind farms.

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The deferred tax provisions are recognized as costs in the ratemaking process by the commissions having jurisdiction over the rates charged by OG&E.The components of Deferred Income Taxes atDecember 31, 2013and2012, respectively, were as follows:

December 31 (In millions)	2013			2012
Current Deferred Income Tax Assets
Net operating losses	$	168.7		$	113.8
Accrued liabilities	9.0			14.0
Federal tax credits	8.0			6.0
Accrued vacation	2.8			3.1
Uncollectible accounts	0.7			1.0
Derivative instruments	—			0.8
Total Current Deferred Income Tax Assets	$	189.2		$	138.7
Non-Current Deferred Income Tax Liabilities
Accelerated depreciation and other property related differences	$	1,747.0		$	1,648.5
OG&E pension plan	84.7			102.2
Regulatory asset	26.0			18.8
Income taxes refundable to customers, net	21.9			21.2
Bond redemption-unamortized costs	3.6			4.0
Total Non-Current Deferred Income Tax Liabilities	1,883.2			1,794.7
Non-Current Deferred Income Tax Assets
Federal tax credits	(101.9		)	(69.5		)
State tax credits	(86.1		)	(78.1		)
Regulatory liabilities	(61.3		)	(71.4		)
Postretirement medical and life insurance benefits	(45.2		)	(42.1		)
Asset retirement obligations	(20.8		)	—
Net operating losses	(17.6		)	(150.0		)
Deferred Federal investment tax credits	(0.7		)	(1.5		)
Other	(4.4		)	(4.3		)
Total Non-Current Deferred Income Tax Assets	(338.0		)	(416.9		)
Non-Current Deferred Income Tax Liabilities, net	$	1,545.2		$	1,377.8

As of December 31, 2013, OG&E has classified $7.8 million of unrecognized tax benefits as a reduction of deferred tax assets recorded. Management is currently unaware of any issues under review that could result in significant additional payments, accruals, or other material deviation from this amount.

Following is a reconciliation of the OG&E’s total gross unrecognized tax benefits as of the years ended December 31, 2013, 2012, and 2011.

(Millions)	2013		2012		2011
Balance at January 1	$	—	$	—	$	—
Tax positions related to current year:
Additions	2.7		—		—
Tax positions related to prior years:
Additions	5.1		—		—
Balance at December 31	$	7.8	$	—	$	—

Where applicable, OG&E classifies income tax-related interest and penalties as interest expense and selling general and administrative expense, respectively. During the year ended December 31, 2013, there were no income tax-related interest or penalties recorded with regard to uncertain tax positions. The total amount of unrecognized tax benefits that would impact the effective tax rate, if recognized, was $7.8 million as of December 31, 2013.

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As previously reported, in January 2013, OG&E determined that a portion of certain Oklahoma investment tax credits previously recognized but not yet utilized may not be available for utilization in future years. During the first quarter of 2013, OG&E recorded a reserve of$7.8 million ($5.1 millionafter tax) related to a portion of the Oklahoma investment tax credits generated in years prior to 2013 but not yet utilized due to management's determination that it is more likely than not that it will be unable to utilize these credits. An additional reserve of$4.1 million ($2.7 millionafter tax) was established with regard to these credits generated in the current year.

Prior to2013 , OG&E had a Federal tax operating loss primarily caused by the accelerated tax "bonus" depreciation provision contained within the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 which allowed OG&E to record a current income tax deduction for100 percentof the cost of certain property placed into service in 2011 and50 percentfor certain property placed into service in 2012. During 2013, OG&E began to utilize these net operating losses

On January 2, 2013, the American Taxpayer Relief Act of 2012 was signed into law. Among other things, the law included an extension of bonus depreciation for one year for property generally placed in service before January 1, 2014. The impact of the new law was reflected in OG&E's 2013Financial Statements as an increase in Deferred Tax Liabilities with a corresponding increase in Deferred Tax Assets related to the net operating loss.

In June 2010, new legislation was passed in Oklahoma that created a moratorium, from July 1, 2010 through June 30, 2012, on 30 income tax credits. For income tax purposes, credits affected by the moratorium could not be claimed for any event, transaction, investment, expenditure or other act for which the credits would otherwise be allowable. During this two-year period, affected credits generated by OG&E were deferred and will be utilized at a future date. For financial accounting purposes, OG&E is receiving the benefits as most of these credits did not expire if they were not utilized in the period they were generated.

Other

OG&E sustained Federal and state tax operating losses through2012caused primarily by bonus depreciation and other book verses tax temporary differences. As a result, OG&E had accrued Federal and state income tax benefits carrying into2013. As OG&E can no longer carry these losses back to prior periods, these losses are being carried forward for utilization in future years.In addition to the operating losses, OG&E was unable to utilize the various tax credits that were generating during these years.These tax losses and credits are being carried as deferred tax assets and will be utilized in future periods.Under current law, OG&E anticipates future taxable income will be sufficient to utilize all of the losses and credits before they begin to expire, accordingly no valuation allowance is considered necessary.The following table summarizes these carry forwards:

(In millions)	Carry Forward Amount		Deferred Tax Asset		Earliest Expiration Date
Net operating losses
State operating loss	$	656.3	$	24.2	2030
Federal operating loss	463.1		162.1		2030
Federal tax credits	109.9		109.9		2029
State tax credits
Oklahoma investment tax credits	96.3		62.6		N/A
Oklahoma capital investment board credits	7.3		7.3		N/A
Oklahoma zero emission tax credits	24.1		16.2		2020

OG&E projects full utilization of all Federal operating losses in 2014 as well as partial utilization of State operating loss carryforwards. Accordingly, a current deferred tax asset of $168.7 million has been reflected on the balance sheet.

8. Common Stock and Cumulative Preferred Stock

There were no new shares of common stock issued in 2013, 2012 or 2011.  

9. Long-Term Debt

A summary of OG&E's long-term debt is included in theStatements of Capitalization.AtDecember 31, 2013, OG&E was in compliance with all of its debt agreements.

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Industrial Authority Bonds

OG&E has tax-exempt pollution control bonds with optional redemption provisions that allow the holders to request repayment of the bonds on any business day.  The bonds, which can be tendered at the option of the holder during the next 12 months, are as follows:

SERIES			DATE DUE	AMOUNT
				(In millions)
0.18%	-	0.34%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.10%	-	0.39%	Muskogee Industrial Authority, January 1, 2025	32.4
0.10%	-	0.30%	Muskogee Industrial Authority, June 1, 2027	56.0
Total (redeemable during next 12 months)				$	135.4

All of these bonds are subject to an optional tender at the request of the holders, at100 percentof the principal amount, together with accrued and unpaid interest to the date of purchase.  The bond holders, on any business day, can request repayment of the bond by delivering an irrevocable notice to the tender agent stating the principal amount of the bond, payment instructions for the purchase price and the business day the bond is to be purchased.  The repayment option may only be exercised by the holder of a bond for the principal amount.  When a tender notice has been received by the trustee, a third party remarketing agent for the bonds will attempt to remarket any bonds tendered for purchase.  This process occurs once per week.  Since the original issuance of these series of bonds in 1995 and 1997, the remarketing agent has successfully remarketed all tendered bonds.  If the remarketing agent is unable to remarket any such bonds, OG&E is obligated to repurchase such unremarketed bonds.  As OG&E has both the intent and ability to refinance the bonds on a long-term basis and such ability is supported by an ability to consummate the refinancing, the bonds are classified as long-term debt in OG&E's Financial Statements. OG&E believes that it has sufficient liquidity to meet these obligations.

Issuance of Long-Term Debt

On May 8, 2013, OG&E issued$250 millionof3.9%senior notes dueMay 1, 2043. The proceeds from the issuance were added to OG&E's general funds and were used to repay short-term debt, fund capital expenditures, general corporate expenses and for working capital purposes. OG&E expects to issue additional long-term debt from time to time when market conditions are favorable and when the need arises.

Long-Term Debt Maturities

Maturities of OG&E's long-term debt during the next five years consist of$0.2 million, $0.2 million, $110.2 million, $125.1 millionand$250.1 millionin years2014, 2015, 2016, 2017and2018, respectively.

OG&E has previously incurred costs related to debt refinancings.Unamortized loss on reacquired debt is classified asa Non-Current Regulatory Asset,unamortized debt expense is classified asDeferred Charges and Other Assets and the unamortized premium and discount on long-term debt is classified as Long-Term Debt, respectively, in theBalance Sheets and are being amortized over the life of the respective debt.

10. Short-Term Debt and Credit Facility

At December 31, 2013, there were$87.2 millionin net outstanding advances from OGE Energy as compared to$90.3 million in net outstanding advances to OGE Energy at December 31, 2012. OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $400 million of OGE Energy's revolving credit amount.  Effective July 29, 2013, OG&E extended the termination date of this agreement to December 13, 2017.   At December 31, 2013, there were no intercompany borrowings under this agreement.  OG&E has a $400 million unsecured five-year revolving credit facility which is available to back up OG&E's commercial paper borrowings and to provide revolving credit borrowings.  This bank facility can also be used as a letter of credit facility. At December 31, 2013, there was $2.1 million supporting letters of credit at a weighted-average interest rate of0.53 percent.  There were no outstanding borrowings under this revolving credit agreement and no outstanding commercial paper borrowings at December 31, 2013.  At December 31, 2013, OG&E had less than $0.1 million in cash and cash equivalents.

In December 2011,OG&E entered into an unsecured five-year revolving credit agreement for $400.0 million. This credit facility containan option, which may be exercised up to two times, to extend the term for an additional year, subject to consent

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of a specified percentage of the lenders. Effective July 29, 2013,OG&E utilized one of these one-year extensions, and received consent from all of the lenders, to extend the maturity of its credit agreementsto December 13, 2017.

OGE Energy's and OG&E'sability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions.Pricing grids associated withOGE Energy's and OG&E'screditfacilitiescould cause annual fees and borrowing rates to increase if an adverse rating impact occurs. The impact of any future downgrade could include an increase in the costs ofOGE Energy's and OG&E'sshort-term borrowings, but a reduction inOGE Energy's and OG&E'scredit ratings would not result in any defaults or accelerations. Any future downgradeof OGE Energy or OG&Ecould also lead to higher long-term borrowing costs and, if below investment grade, would requireOG&Eto post collateral or letters of credit.

OG&E must obtain regulatory approval from the FERC in order to borrow on a short-term basis.OG&E has the necessary regulatory approvals to incur up to$800 millionin short-term borrowings at any one time for a two-year period beginning January 1, 2013 and ending December 31, 2014.

11. Retirement Plans and Postretirement Benefit Plans

Pension Plan and Restoration of Retirement Income Plan

OG&E's employees participate inOGE Energy'sPension Plan and Restoration of Retirement Income Plan.

Employees hired or rehired on or after December 1, 2009 do not participate in the Pension Plan but are eligible to participate in the 401(k) Plan where, for each pay period,OGE Energycontributes to the 401(k) Plan, on behalf of each participant,200 percentof the participant's contributions up tofive percentof compensation.

It isOGE Energy'spolicyto fund the Pension Plan on a current basis based on the net periodic pension expense as determined byOGE Energy'sactuarial consultants.During both2013and2012, OGE Energy made contributions to its Pension Plan of$35 millionof whichnonein 2013 and$33 millionin 2012 was OG&E's portion,to help ensure that the Pension Plan maintains an adequate funded status.Such contributions are intended to provide not only for benefits attributed to service to date, but also for those expected to be earned in the future.During2014, OGE Energy expects to contribute up to$26 millionto its Pension Plan, of which$1 millionis expected to be OG&E's portion.The expected contribution to the Pension Plan during 2014 would be a discretionary contribution, anticipated to be in the form of cash, and is not required to satisfy the minimum regulatory funding requirement specified by the Employee Retirement Income Security Act of 1974, as amended.OGE Energy could be required to make additional contributions if the value of its pension trust and postretirement benefit plan trust assets are adversely impacted by a major market disruption in the future.

In accordance with ASC Topic 715, "Compensation - Retirement Benefits," a one-time settlement charge is required to be recorded by an organization when lump sum payments or other settlements that relieve the organization from the responsibility for the pension benefit obligation during a plan year exceed the service cost and interest cost components of the organization’s net periodic pension cost. During 2013, OG&E experienced an increase in both the number of employees electing to retire and the amount of lump sum payments to be paid to such employees upon retirement. As a result, and based in part on OG&E's historical experience regarding eligible employees who elect to retire in the last quarter of a particular year, OG&E recorded pension settlement charges of$17.6 millionin the fourth quarter of 2013, of which$17.0 millionrelated to OG&E’s Oklahoma jurisdiction and has been included in the pension tracker. The pension settlement charge did not require a cash outlay by OG&E and did not increase OG&E’s total pension expense over time, as the charges were an acceleration of costs that otherwise would be recognized as pension expense in future periods.

OGE Energy provides a Restoration of Retirement Income Plan to those participants inOGE Energy'sPension Plan whose benefits are subject to certain limitations of the Code.  Participants in the Restoration of Retirement Income Planreceive the same benefits that they would have received underOGE Energy'sPension Plan in the absence of limitations imposed by the Federal tax laws.The Restoration of Retirement Income Plan is intended to be an unfunded plan.

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The following table presents the status ofOG&E's portion of OGE Energy'sPension Plan and Restoration of Retirement Income Plan atDecember 31, 2013and2012. These amounts have been recorded in Accrued Benefit Obligations with the offsetrecorded as a regulatory asset in OG&E's Balance Sheet as discussed in Note 1. Theregulatory assetrepresents a net periodic benefit cost to be recognized in theStatements of Income in future periods.

	Pension Plan						Restoration of Retirement Income Plan
December 31 (In millions)	2013			2012			2013			2012
Benefit obligations	$	(503.6	)	$	(574.6	)	$	(2.1	)	$	(2.2	)
Fair value of plan assets	516.5			519.0			—			—
Funded status at end of year	$	12.9		$	(55.6	)	$	(2.1	)	$	(2.2	)

The following table summarizes the benefit payments OG&E expects to pay related to its Pension Plan and Restoration of Retirement Income Plan.These expected benefits are based on the same assumptions used to measure OGE Energy's benefit obligation at the end of the year and include benefits attributable to estimated future employee service.

(In millions)	Projected Benefit Payments
2014	$	75.4
2015	65.1
2016	59.9
2017	53.1
2018	49.1
After 2018	183.3

Plan Investments, Policies and Strategies

The Pension Plan assets are held in a trust which follows an investment policy and strategy designed to reduce the funded status volatility of the Plan by utilizing liability driven investing. The purpose of liability driven investing is to structure the asset portfolio to more closely resemble the pension liability and thereby more effectively hedge against changes in the liability. The investment policy follows a glide path approach that shifts a higher portfolio weighting to fixed income as the Plan's funded status increases. The table below sets forth the targeted fixed income and equity allocations at different funded status levels.

Projected Benefit Obligation Funded Status Thresholds	<90%	95%	100%	105%	110%	115%	120%
Fixed income	50%	58%	65%	73%	80%	85%	90%
Equity	50%	42%	35%	27%	20%	15%	10%
Total	100%	100%	100%	100%	100%	100%	100%

Within the portfolio's overall allocation to equities, the funds are allocated according to the guidelines in the table below.

Asset Class	Target Allocation	Minimum	Maximum
Domestic All-Cap/Large Cap Equity	50%	50%	60%
Domestic Mid-Cap Equity	15%	5%	25%
Domestic Small-Cap Equity	15%	5%	25%
International Equity	20%	10%	30%

OGE Energy has retained an investment consultant responsible for the general investment oversight, analysis, monitoring investment guideline compliance and providing quarterly reports to certain of OG&E's members and OGE Energy's Investment Committee.The various investment managers used by the trust operate within the general operating objectives as established in the investment policy and within the specific guidelines established for each investment manager's respective portfolio.

The portfolio is rebalanced on an annual basis to bring the asset allocations of various managers in line with the target asset allocation listed above.  More frequent rebalancing may occur if there are dramatic price movements in the financial markets which may cause the trust's exposure to any asset class to exceed or fall below the established allowable guidelines.

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To evaluate the progress of the portfolio, investment performance is reviewed quarterly.It is, however, expected that performance goals will be met over a full market cycle, normally defined as athreetofiveyear period.Analysis of performance is within the context of the prevailing investment environment and the advisors' investment style.The goal of the trust is to provide a rate of return consistently fromthree percenttofive percentover the rate of inflation (as measured by the national Consumer Price Index) on a fee adjusted basis over a typical market cycle of no less thanthreeyears and no more thanfiveyears.Each investment manager is expected to outperform its respective benchmark.  Below is a list of each asset class utilized with appropriate comparative benchmark(s) each manager is evaluated against:

Asset Class	Comparative Benchmark(s)
Core Fixed Income	Barclays Capital Aggregate Index
Interest Rate Sensitive Fixed Income	Barclays Capital Aggregate Index
Long Duration Fixed Income	Barclays Long Government/Credit
Equity Index	Standard & Poor's 500 Index
All-Cap Equity	Russell 3000 Index
	Russell 3000 Value Index
Mid-Cap Equity	Russell Midcap Index
	Russell Midcap Value Index
Small-Cap Equity	Russell 2000 Index
	Russell 2000 Value Index
International Equity	Morgan Stanley Capital Investment ACWI ex-US

The fixed income manager is expected to use discretion over the asset mix of the trust assets in its efforts to maximize risk-adjusted performance.  Exposure to any single issuer, other than the U.S. government, its agencies, or its instrumentalities (which have no limits) is limited tofive percentof the fixed income portfolio as measured by market value.  At least75 percentof the invested assets must possess an investment grade rating at or above Baa3 or BBB- by Moody's Investors Services, Standard & Poor's Ratings Services or Fitch Ratings.  The portfolio may invest up to10 percentof the portfolio's market value in convertible bonds as long as the securities purchased meet the quality guidelines.The purchase of any of OGE Energy's equity, debt or other securities is prohibited.

The domestic value equity managers focus on stocks that the manager believes are undervalued in price and earn an average or less than average return on assets, and often pays out higher than average dividend payments. The domestic growth equity manager will invest primarily in growth companies which consistently experience above average growth in earnings and sales, earn a high return on assets, and reinvest cash flow into existing business.  The domestic mid-cap equity portfolio manager focuses on companies with market capitalizations lower than the average company traded on the public exchanges with the following characteristics: price/earnings ratio at or near the Russell Midcap Index, small dividend yield, return on equity at or near the Russell Midcap Index and an earnings per share growth rate at or near the Russell Midcap Index.  The domestic small-cap equity manager will purchase shares of companies with market capitalizations lower than the average company traded on the public exchanges with the following characteristics: price/earnings ratio at or near the Russell 2000, small dividend yield, return on equity at or near the Russell 2000 and an earnings per share growth rate at or near the Russell 2000.  The international global equity manager invests primarily in non-dollar denominated equity securities. Investing internationally diversifies the overall trust across the global equity markets.  The manager is required to operate under certain restrictions including: regional constraints, diversification requirements and percentage of U.S. securities. The Morgan Stanley Capital International All Country World ex-US Index is the benchmark for comparative performance purposes. The Morgan Stanley Capital International All Country World ex-US Index is a market value weighted index designed to measure the combined equity market performance of developed and emerging markets countries, excluding the United States. All of the equities which are purchased for the international portfolio are thoroughly researched.  Only companies with a market capitalization in excess of$100 millionare allowable.  No more thanfive percentof the portfolio can be invested in any one stock at the time of purchase. All securities are freely traded on a recognized stock exchange and there are no 144-A securities and no over-the-counter derivatives.  The following investment categories are excluded: options (other than traded currency options), commodities, futures (other than currency futures or currency hedging), short sales/margin purchases, private placements, unlisted securities and real estate (but not real estate shares).

For all domestic equity investment managers, no more thaneight percent (five percentfor mid-cap and small-cap equity managers) can be invested in any one stock at the time of purchase and no more than16 percent (10 percentfor mid-cap and small-cap equity managers) after accounting for price appreciation. Options or financial futures may not be purchased unless prior approval of OGE Energy's Investment Committee is received.  The purchase of securities on margin is prohibited as is securities lending.  Private placement or venture capital may not be purchased.  All interest and dividend payments must be swept on a daily

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basis into a short-term money market fund for re-deployment.  The purchase of any of OGE Energy's equity, debt or other securities is prohibited.  The purchase of equity or debt issues of the portfolio manager's organization is also prohibited.  The aggregate positions in any company may not exceedone percentof the fair market value of its outstanding stock.

Plan Investments

The following tables summarizeOG&E's portion of OGE Energy'sPension Plan's investments that are measured at fair value on a recurring basis atDecember 31, 2013and2012.  There werenoLevel 3 investments held by the Pension Plan atDecember 31, 2013and2012. 

(In millions)	December 31, 2013			Level 1		Level 2
Common stocks
U.S. common stocks	$	236.8		$	236.8	$	—
Foreign common stocks	39.3			39.3		—
U.S. Government obligations
U.S. treasury notes and bonds (A)	159.8			159.8		—
Mortgage-backed securities	50.3			—		50.3
Bonds, debentures and notes (B)
Corporate fixed income and other securities	110.6			—		110.6
Mortgage-backed securities	22.3			—		22.3
Commingled fund (C)	29.2			—		29.2
Common/collective trust (D)	26.0			—		26.0
Foreign government bonds	4.0			—		4.0
U.S. municipal bonds	2.0			—		2.0
Interest-bearing cash	0.1			0.1		—
Forward contracts
Receivable (foreign currency)	1.1			—		1.1
Payable (foreign currency)	(1.1		)	—		(1.1		)
Total Plan investments	$	680.4		$	436.0	$	244.4
Receivable from broker for securities sold	11.5
Interest and dividends receivable	3.2
Payable to broker for securities purchased	(40.2		)
Plan investments attributable to affiliates	(138.4		)
Total Plan assets	$	516.5

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(In millions)	December 31, 2012			Level 1		Level 2
Common stocks
U.S. common stocks	$	232.2		$	232.2	$	—
Foreign common stocks	39.9			39.9		—
U.S. Government obligations
U.S. treasury notes and bonds (A)	138.6			138.6		—
Mortgage-backed securities	55.8			—		55.8
Bonds, debentures and notes (B)
Corporate fixed income and other securities	98.4			—		98.4
Mortgage-backed securities	13.5			—		13.5
Commingled fund (C)	34.9			—		34.9
Common/collective trust (D)	25.6			—		25.6
Foreign government bonds	3.9			—		3.9
U.S. municipal bonds	0.8			—		0.8
Interest-bearing cash	0.2			0.2		—
Forward contracts
Receivable (foreign currency)	0.4			—		0.4
Payable (foreign currency)	(0.4		)	—		(0.4		)
Total Plan investments	$	643.8		$	410.9	$	232.9
Receivable from broker for securities sold	0.8
Interest and dividends receivable	2.8
Payable to broker for securities purchased	(21.4		)
Plan investments attributable to affiliates	(107.0		)
Total Plan assets	$	519.0

(A) This category represents U.S. treasury notes and bonds with a Moody's Investors Services rating of Aaa and Government Agency Bonds with a Moody's Investors Services rating of A1 or higher.

(B) This category primarily represents U.S. corporate bonds with an investment grade rating at or above Baa3 or BBB- by Moody's Investors Services, Standard & Poor's Ratings Services or Fitch Ratings.

(C) This category represents units of participation in a commingled fund that primarily invested in stocks of international companies and emerging markets.

(D) This category represents units of participation in an investment pool which primarily invests in foreign or domestic bonds, debentures, mortgages, equipment or other trust certificates, notes, obligations issued or guaranteed by the U.S. Government or its agencies, bank certificates of deposit, bankers' acceptances and repurchase agreements, high grade commercial paper and other instruments with money market characteristics with a fixed or variable interest rate. There are no restrictions on redemptions in the common/collective trust.

The three levels defined in the fair value hierarchy and examples of each are as follows:

Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessibleby the Pension Planat the measurement date.Instruments classified as Level 1 include investments in common and preferred stocks, U.S. treasury notes and bonds, mutual funds and interest-bearing cash.

Level 2 inputs are inputs other than quoted prices in active markets included within Level 1 that are either directly or indirectly observable at the reporting date for the asset or liability for substantially the full term of the asset or liability.  Level 2 inputs include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.Instruments classified as Level 2 include corporate fixed income and other securities, mortgage-backed securities, other U.S. Government obligations, commingled fund, a common/collective trust, U.S. municipal bonds, foreign government bonds, a repurchase agreement, money market fund and forward contracts.

Level 3 inputs are prices or valuation techniques for the asset or liability that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity).Unobservable inputs reflect thePlan'sown assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk).

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Postretirement Benefit Plans

In addition to providing pension benefits,OGE Energyprovides certain medical and life insurance benefits for eligible retired members.  Regular, full-time, active employees hired prior to February 1, 2000 whose age and years of credited service total or exceed 80 or have attained at least age 55 with 10 or more years of service at the time of retirement are entitled to postretirement medical benefits while employees hired on or after February 1, 2000 are not entitled to postretirement medical benefits.Eligible retirees must contribute such amount asOGE Energyspecifies from time to time toward the cost of coverage for postretirement benefits.  The benefits are subject to deductibles, co-payment provisions and other limitations.OG&Echarges to expense the postretirement benefit costsand includes an annual amount as a component of the cost-of-service in future ratemaking proceedings.

OGE Energy'scontribution to the medical costs for pre-65 aged eligible retirees are fixed at the 2011 level andOGE Energycovers future annual medical inflationary cost increases up tofive percent. Increases in excess offive percentannually are covered by the pre-65 aged retiree in the form of premium increases.OGE Energyprovides Medicare-eligible retirees and their Medicare-eligible spouses an annual fixed contribution toOGE Energy'ssponsoredhealth reimbursement arrangement.OGE Energy'sMedicare-eligible retirees are able to purchase individual insurance policies supplemental to Medicare through a third-party administrator and use their health reimbursement arrangement funds for reimbursement of medical premiums and other eligible medical expenses.

Plan Investments

The following tables summarizeOG&E's portion of OGE Energy'spostretirement benefit plans investments that are measured at fair value on a recurring basis atDecember 31, 2013and2012.  There werenoLevel 2 investments held by the postretirement benefit plans atDecember 31, 2013and2012.

(In millions)	December 31, 2013			Level 1		Level 3
Group retiree medical insurance contract (A)	$	53.1		$	—	$	53.1
Mutual funds investment
U.S. equity investments	7.9			7.9		—
Money market funds investment	0.4			0.4		—
Total Plan investments	$	61.4		$	8.3	$	53.1
Plan investments attributable to affiliates	(4.7		)
Total Plan assets	$	56.7

(In millions)	December 31, 2012			Level 1		Level 3
Group retiree medical insurance contract (A)	$	53.3		$	—	$	53.3
Mutual funds investment
U.S. equity investments	6.0			6.0		—
Money market funds investment	0.3			0.3		—
Total Plan investments	$	59.6		$	6.3	$	53.3
Plan investments attributable to affiliates	(4.1		)
Total Plan assets	$	55.5

(A) This category represents a group retiree medical insurance contract which invests in a pool of common stocks, bonds and money market accounts, of which a significant portion is comprised of mortgage-backed securities.

The postretirement benefit plans Level 3 investment includes an investment in a group retiree medical insurance contract. The unobservable input included in the valuation of the contract includes the approach for determining the allocation of the postretirement benefit plans pro-rata share of the total assets in the contract.

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The following table summarizes the postretirement benefit plans investments that are measured at fair value on a recurring basis using significant unobservable inputs (Level 3).

Year ended December 31 (In millions)	2013
Group retiree medical insurance contract
Beginning balance	$	53.3
Net unrealized gains related to instruments held at the reporting date	(0.5		)
Interest income	1.1
Dividend income	0.6
Realized gains	0.4
Administrative expenses and charges	(0.1		)
Claims paid	(1.7		)
Ending balance	$	53.1

The following table presents the status ofOG&E's portion of OGE Energy'spostretirement benefit plans atDecember 31, 2013and2012. These amounts have been recorded in Accrued Benefit Obligations with the offsetrecorded as a regulatory asset in OG&E's Balance Sheet as discussed in Note 1. Theregulatory assetrepresents a net periodic benefit cost to be recognized in theStatements of Income in future periods.

December 31 (In millions)	2013			2012
Benefit obligations	$	(202.4	)	$	(236.4	)
Fair value of plan assets	56.7			55.5
Funded status at end of year	$	(145.7	)	$	(180.9	)

The assumed health care cost trend rates have a significant effect on the amounts reported for postretirement medical benefit plans.  Future health care cost trend rates are assumed to be8.35 percentin2014with the rates trending downward to4.48 percentby2028.  A one-percentage point change in the assumed health care cost trend rate would have the following effects:

ONE-PERCENTAGE POINT INCREASE
Year ended December 31 (In millions)	2013		2012		2011
Effect on aggregate of the service and interest cost components	$	—	$	—	$	—
Effect on accumulated postretirement benefit obligations	0.1		0.1		0.1

ONE-PERCENTAGE POINT DECREASE
Year ended December 31 (In millions)	2013		2012		2011
Effect on aggregate of the service and interest cost components	$	—	$	0.1	$	0.1
Effect on accumulated postretirement benefit obligations	0.4		0.7		0.4

Medicare Prescription Drug, Improvement and Modernization Act of 2003

The Medicare Prescription Drug, Improvement and Modernization Act of 2003 expanded coverage for prescription drugs.  The following table summarizes the gross benefit payments OG&E expects to pay related to its postretirement benefit plans, including prescription drug benefits.

(In millions)	Gross Projected Postretirement Benefit Payments
2014	$	13.1
2015	13.5
2016	13.8
2017	14.0
2018	14.3
After 2018	71.6

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Obligations and Funded Status

The following table presents the status ofOG&E's portion of OGE Energy'sPension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans for2013and2012. OG&E's portion of the benefit obligation for OGE Energy'sPension Plan and the Restoration of Retirement Income Plan represents the projected benefit obligation, while the benefit obligation for the postretirement benefit plans represents the accumulated postretirement benefit obligation. The accumulated postretirement benefit obligation forOGE Energy'sPension Plan and Restoration of Retirement Income Plan differs from the projected benefit obligation in that the former includes no assumption about future compensation levels. The accumulated postretirement benefit obligation for the Pension Plan and the Restoration of Retirement Income Plan atDecember 31, 2013was$483.0 millionand$1.9 million, respectively. The accumulated postretirement benefit obligation for the Pension Plan and the Restoration of Retirement Income Plan atDecember 31, 2012was$549.3 millionand$2.1 million, respectively. The details of the funded status of the Pension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans and the amounts included in theBalance Sheets are as follows:

	Pension Plan						Restoration of Retirement Income Plan						Postretirement Benefit Plans
December 31 (In millions)	2013			2012			2013			2012			2013			2012
Change in Benefit Obligation
Beginning obligations	$	(574.6	)	$	(546.9	)	$	(2.2	)	$	(2.2	)	$	(236.4	)	$	(223.1	)
Service cost	(11.6		)	(10.9		)	(0.1		)	(0.1		)	(2.9		)	(2.7		)
Interest cost	(20.4		)	(23.5		)	(0.1		)	(0.1		)	(8.1		)	(9.4		)
Participants' contributions	49.9			—			—			—			(2.5		)	(2.5		)
Medicare subsidies received	—			—			—			—			—			(0.5		)
Actuarial gains (losses)	39.8			(43.7		)	0.2			(0.4		)	35.4			(9.4		)
Benefits paid	13.3			50.4			0.1			0.6			12.1			11.2
Ending obligations	$	(503.6	)	$	(574.6	)	$	(2.1	)	$	(2.2	)	$	(202.4	)	$	(236.4	)
Change in Plans' Assets
Beginning fair value	$	519.0		$	485.9		$	—		$	—		$	55.5		$	57.2
Actual return on plans' assets	60.7			50.5			—			—			3.4			4.3
Employer contributions	—			33.0			0.1			0.6			7.4			2.2
Participants' contributions	(49.9		)	—			—			—			2.5			2.5
Medicare subsidies received	—			—			—			—			—			0.5
Benefits paid	(13.3		)	(50.4		)	(0.1		)	(0.6		)	(12.1		)	(11.2		)
Ending fair value	$	516.5		$	519.0		$	—		$	—		$	56.7		$	55.5
Funded status at end of year	$	12.9		$	(55.6	)	$	(2.1	)	$	(2.2	)	$	(145.7	)	$	(180.9	)

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Net Periodic Benefit Cost

	Pension Plan									Restoration of Retirement Income Plan						Postretirement Benefit Plans
Year ended December 31 (In millions)	2013			2012			2011			2013		2012		2011		2013			2012			2011
Service cost	$	11.6		$	10.9		$	10.8		$	0.1	$	0.1	$	0.1	$	2.9		$	2.7		$	2.4
Interest cost	20.4			23.5			26.2			0.1		0.1		0.1		8.1			9.4			10.0
Expected return on plan assets	(38.9		)	(38.2		)	(37.3		)	—		—		—		(2.4		)	(2.8		)	(4.9		)
Amortization of transition obligation	—			—			—			—		—		—		—			2.5			2.6
Amortization of net loss	20.7			19.3			15.6			—		0.1		0.1		18.2			17.4			15.5
Amortization of unrecognized prior service cost (A)	1.9			2.2			2.5			0.1		0.2		0.2		(13.7		)	(13.6		)	(13.7		)
Settlement	17.6			—			—			—		0.3		—		—			—			—
Net periodic benefit cost (B)	$	33.3		$	17.7		$	17.8		$	0.3	$	0.8	$	0.5	$	13.1		$	15.6		$	11.9

(A) Unamortized prior service cost is amortized on a straight-line basis over the average remaining service period to the first eligibility age of participants who are expected to receive a benefit and are active at the date of the plan amendment.

(B) In addition to the$46.7 million, $34.1 millionand$30.2 millionof net periodic benefit cost recognized in2013, 2012and2011, respectively, OG&E recognized the following:

• an increase in pension expense in2013, 2012 and 2011 of $5.8 million, $8.3 millionand$10.8 million, respectively,to maintain the allowable amount to be recovered for pension expense in the Oklahoma jurisdiction, which are included in the Pension tracker regulatory asset or liability (see Note 1); and

• an increase in postretirement medical expense in2013and2012of$0.6 millionand$0.8 millionrespectively, to maintain the allowable amount to be recovered for postretirement medical expense in the Oklahoma jurisdiction which are included in the Pension tracker regulatory asset or liability (see Note 1);

• a deferral of pension expense in 2013 of$17.0 million which includes a portion of OGE Energy's pension settlement charge, related to the pension settlement charge of$17.6 million which is included in the Pension tracker regulatory account (see Note 1).

The capitalized portion of the net periodic pension benefit cost was$4.2 million, $5.5 millionand$5.3 millionatDecember 31, 2013, 2012and2011, respectively.  The capitalized portion of the net periodic postretirement benefit cost was$3.4 million, $4.7 millionand$3.3 millionatDecember 31, 2013, 2012and2011, respectively.

Rate Assumptions

	Pension Plan and Restoration of Retirement Income Plan						Postretirement Benefit Plans
Year ended December 31	2013		2012		2011		2013		2012		2011
Discount rate	4.60	%	3.70	%	4.50	%	4.60	%	3.60	%	4.50	%
Rate of return on plans' assets	8.00	%	8.00	%	8.00	%	4.00	%	4.00	%	6.50	%
Compensation increases	4.20	%	4.20	%	4.40	%	N/A		N/A		N/A
Assumed health care cost trend:
Initial trend	N/A		N/A		N/A		8.35	%	8.55	%	8.75	%
Ultimate trend rate	N/A		N/A		N/A		4.48	%	4.48	%	4.48	%
Ultimate trend year	N/A		N/A		N/A		2028		2028		2028

N/A - not applicable

The overall expected rate of return on plan assets assumption remained at8.00 percentin2012and2013in determining net periodic benefit cost due to recent returns onOGE Energy'slong-term investment portfolio. The rate of return on plan assets assumption is the average long-term rate of earnings expected on the funds currently invested and to be invested for the purpose of providing benefits specified by the Pension Plan or postretirement benefit plans.  This assumption is reexamined at least annually and updated as necessary.  The rate of return on plan assets assumption reflects a combination of historical return analysis, forward-looking return expectations and the plans' current and expected asset allocation.

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Post-Employment Benefit Plan

Disabled employees receiving benefits fromOGE Energy'sGroup Long-Term Disability Plan are entitled to continue participating inOGE Energy'sMedical Plan along with their dependents.  The post-employment benefit obligation represents the actuarial present value of estimated future medical benefits that are attributed to employee service rendered prior to the date as of which such information is presented.  The obligation also includes future medical benefits expected to be paid to current employees participating inOGE Energy'sGroup Long-Term Disability Plan and their dependents, as defined inOGE Energy'sMedical Plan.

The post-employment benefit obligation is determined by an actuary on a basis similar to the accumulated postretirement benefit obligation.  The estimated future medical benefits are projected to grow with expected future medical cost trend rates and are discounted for interest at the discount rate and for the probability that the participant will discontinue receiving benefits fromOGE Energy'sGroup Long-Term Disability Plan due to death, recovery from disability, or eligibility for retiree medical benefits.  OG&E's post-employment benefit obligation was$1.4 millionand$2.2 millionatDecember 31, 2013and2012, respectively.

401(k) Plan

OGE Energyprovides a 401(k) Plan.  Each regular full-time employee ofOGE Energyor a participating affiliate is eligible to participate in the 401(k) Plan immediately.  All other employees ofOGE Energyor a participating affiliate are eligible to become participants in the 401(k) Plan after completing one year of service as defined in the 401(k) Plan.Participants may contribute each pay period any whole percentage betweentwo percentand19 percentof their compensation, as defined in the 401(k) Plan, for that pay period.Participants who have attained age 50 before the close of a year are allowed to make additional contributions referred to as "Catch-Up Contributions," subject to certain limitations of the Code.Participants may designate, at their discretion, all or any portion of their contributions as: (i) a before-tax contribution under Section 401(k) of the Code subject to the limitations thereof; or (ii) a contribution made on an after-tax basis.The 401(k) Plan also includes an eligible automatic contribution arrangement and provides for a qualified default investment alternative consistent with the U.S. Department of Labor regulations. Participants may elect, in accordance with the 401(k) Plan procedures, to have his or her future salary deferral rate to be automatically increased annually on a date and in an amount as specified by the participant in such election.

NoOGE Energycontributions are made with respect to a participant's Catch-Up Contributions, rollover contributions, or with respect to a participant's contributions based on overtime payments, pay-in-lieu of overtime for exempt personnel, special lump-sum recognition awards and lump-sum merit awards included in compensation for determining the amount of participant contributions.Once made,OGE Energy'scontribution may be directed to any available investment option in the 401(k) Plan.OGE Energymatch contributions vest over athree-year period.Aftertwoyears of service, participants become20 percentvested in theirOGE Energycontribution account and become fully vested on completingthreeyears of service. In addition, participants fully vest when they are eligible for normal or early retirement under the Pension Plan, in the event of their termination due to death or permanent disability or upon attainment of age 65 while employed byOGE Energyor its affiliates.  OG&E contributed$7.8 million, $7.6 millionand$7.0 millionin2013, 2012and2011, respectively, to the 401(k) Plan.

Deferred Compensation Plan

OGE Energyprovides a nonqualified deferred compensation plan which is intended to be an unfunded plan.  The plan's primary purpose is to provide a tax-deferred capital accumulation vehicle for a select group of management, highly compensated employees and non-employee members of the Board of Directors ofOGE Energyand to supplement such employees' 401(k) Plan contributions as well as offering this plan to be competitive in the marketplace.

Eligible employees who enroll in the plan have the following deferral options: (i) eligible employees may elect to defer up to a maximum of70 percentof base salary and100 percentof annual bonus awards or (ii) eligible employees may elect a deferral percentage of base salary and bonus awards based on the deferral percentage elected for a year under the 401(k) Plan with such deferrals to start when maximum deferrals to the qualified 401(k) Plan have been made because of limitations in that plan. Eligible directors who enroll in the plan may elect to defer up to a maximum of100 percentof directors' meeting fees and annual retainers.OGE Energymatches employee (but not non-employee director) deferrals to make up for any match lost in the 401(k) Plan because of deferrals to the deferred compensation plan, and to allow for a match that would have been made under the 401(k) Plan on that portion of either the firstsix percentof total compensation or the firstfive percentof total compensation, depending on the option the participant elected under the choice provided to eligible employees in the qualified 401(k) Plan discussed above, deferred that exceeds the limits allowed in the 401(k) Plan. Matching credits vest based on years of service, with full vesting afterthreeyears or, if earlier, on retirement, disability, death, a change in control ofOGE Energyor termination of the plan.Deferrals, plus anyOGE Energymatch, are credited to a recordkeeping account in the participant's name. Earnings on the deferrals are

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indexed to the assumed investment funds selected by the participant.In2013, those investment optionsincludedan OGE EnergyCommon Stock fund, whose value was determined based on the stock price ofOGE Energy'sCommon Stock.

Supplemental Executive Retirement Plan

OGE Energy provides a supplemental executive retirement plan in order to attract and retain lateral hires or other executives designated by the Compensation Committee ofOGE Energy'sBoard of Directors who may not otherwise qualify for a sufficient level of benefits underOGE Energy'sPension Plan and Restoration of Retirement Income Plan.The supplemental executive retirement plan is intended to be an unfunded plan and not subject to the benefit limitations of the Code.

12. Commitments and Contingencies

Operating Lease Obligations

OG&E has operating lease obligations expiring at various dates, primarily forrailcar leases and wind farm land leases. Future minimum payments for noncancellable operating leasesare as follows:

Year ended December 31 (In millions)	2014		2015		2016		2017		2018		After 2018		Total
Operating lease obligations
Railcars	$	3.8	$	3.1	$	27.3	$	—	$	—	$	—	$	34.2
Wind farm land leases	2.1		2.1		2.1		2.4		2.4		48.8		59.9
Total operating lease obligations	$	5.9	$	5.2	$	29.4	$	2.4	$	2.4	$	48.8	$	94.1

Payments for operating lease obligations were$5.7 million, $5.8 millionand$4.2 millionfor the years endedDecember 31, 2013, 2012and2011, respectively.

Railcar Lease Agreement

OG&E has a noncancellable operating lease with purchase options, covering 1,389 coal rotary gondola railcars to transport coal from Wyoming to OG&E's coal-fired generation units.  Rental payments are charged to Fuel Expense and are recovered through OG&E's tariffs and fuel adjustment clauses. On December 15, 2010, OG&E renewed the lease agreement effective February 1, 2011.  At the end of the new lease term, which is February 1, 2016, OG&E has the option to either purchase the railcars at a stipulated fair market value or renew the lease.  If OG&E chooses not to purchase the railcars or renew the lease agreement and the actual fair value of the railcars is less than the stipulated fair market value, OG&E would be responsible for the difference in those values up to a maximum of$22.8 million. OG&E is also required to maintain all of the railcars it has under the operating lease and has entered into an agreement with a non-affiliated company to furnish this maintenance.

On January 11, 2012, OG&E executed a five-year lease agreement for 135 railcars to replace railcars that have been taken out of service or destroyed. OG&E has a unilateral right to terminate this lease upon a 6-month notice effective April 2015 and April 2016.

Wind Farm Land Lease Agreements

OG&E has wind farm land operating leases for its Centennial, OU Spirit and Crossroads wind farms expiring at various dates. The Centennial lease has rent escalations which increase annually based on the Consumer Price Index. The OU Spirit and Crossroads leases have rent escalations which increase after five and 10 years. Although the leases are cancellable, OG&E is required to make annual lease payments as long as the wind turbines are located on the land. OG&E does not expect to terminate the leases until the wind turbines reach the end of their economic life.

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Other Purchase Obligations and Commitments

OG&E's other future purchase obligations and commitments estimated for the next five years are as follows:

(In millions)	2014		2015		2016		2017		2018		Total
Other purchase obligations and commitments
Cogeneration capacity and fixed operation and maintenance payments	$	85.1	$	82.7	$	81.9	$	79.6	$	77.0	$	406.3
Expected cogeneration energy payments	61.1		60.9		75.7		81.5		87.4		366.6
Minimum fuel purchase commitments	451.8		451.8		368.5		385.1		—		1,657.2
Expected wind purchase commitments	58.0		58.9		59.8		60.8		59.5		297.0
Long-term service agreement commitments	70.5		2.8		2.5		2.6		19.1		97.5
Total other purchase obligations and commitments	$	726.5	$	657.1	$	588.4	$	609.6	$	243.0	$	2,824.6

Public Utility Regulatory Policy Act of 1978

AtDecember 31, 2013, OG&E has QF contracts having terms of15to32years.  These contracts were entered into pursuant to the Public Utility Regulatory Policy Act of 1978.  Stated generally, the Public Utility Regulatory Policy Act of 1978 and the regulations thereunder promulgated by the FERC require OG&E to purchase power generated in a manufacturing process from a QF.  The rate for such power to be paid by OG&E was approved by the OCC.  The rate generally consists of two components: one is a rate for actual electricity purchased from the QF by OG&E; the other is a capacity charge, which OG&E must pay the QF for having the capacity available.  However, if no electrical power is made available to OG&E for a period of time (generally three months), OG&E's obligation to pay the capacity charge is suspended.  The total cost of cogeneration payments is recoverable in rates from customers.  For the320MW AES-Shady Point, Inc. QF contract and the120MW PowerSmith Cogeneration Project, L.P. QF contract, OG&E purchases100 percentof the electricity generated by the QFs.

For the years endedDecember 31, 2013, 2012and2011, OG&E made total payments to cogenerators of$134.8 million, $135.1 millionand$140.7 million, respectively, of which$74.4 million, $77.1 millionand$78.0 million, respectively, represented capacity payments.  All payments for purchased power, including cogeneration, are included in theStatements of Income as Cost of Sales.

Minimum Fuel Purchase Commitments

OG&E purchased necessary fuel supplies of coal and natural gas for its generating units of$680.8 million, $653.7 millionand$729.8 millionfor the years endedDecember 31, 2013, 2012and2011, respectively.OG&E has coal contracts for purchases from through December 2016.OG&E has entered into multiple month term natural gas contracts for31.5 percentof its 2014 annual forecasted natural gas requirements. Additional gas supplies to fulfill OG&E's remaining 2014 natural gas requirements will be acquired through additional requests for proposal in early to mid-2014, along with monthly and daily purchases, all of which are expected to be made at market prices.

Wind Purchase Commitments

OG&E's current wind power portfolio includes: (i) the120MW Centennial wind farm, (ii) the101MW OU Spirit wind farm, (iii) the227.5MW Crossroads wind farm, (iv) access to up to50MWs of electricity generated at a wind farm near Woodward, Oklahoma from a 15-year contract OG&E entered into with FPL Energy that expires in 2018, (v) access to up to150MWs of electricity generated at a wind farm in Woodward County, Oklahoma from a 20-year contract OG&E entered into with CPV Keenan that expires in 2030, (vi) access to up to130MWs of electricity generated at a wind farm in Dewey County, Oklahoma from a 20-year contract OG&E entered into with Edison Mission Energy that expires in 2030 and (vii) access to up to60MWs of electricity generated at a wind farm near Blackwell, Oklahoma from a 20-year contract OG&E entered into with NextEra Energy that expires in 2032.

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The following table summarizes OG&E's wind power purchases for the years endedDecember 31, 2013, 2012and2011. 

Year ended December 31 (In millions)	2013		2012		2011
CPV Keenan	$	30.9	$	25.1	$	24.5
Edison Mission Energy	20.6		20.2		8.5
FPL Energy	3.3		3.4		3.7
NextEra Energy	7.2		0.8		—
Total wind power purchased	$	62.0	$	49.5	$	36.7

Long-Term Service Agreement Commitments

OG&E has a long-term parts and service maintenance contract for the upkeep of the McClain Plant.  The existing contract will expire on January 1, 2015. In May 2013, a new contract was signed that is expected to run for the earlier of128,000factored-fired hours or3,600factored-fired starts. Based on historical usage and current expectations for future usage, this contract is expected to run until 2030. The contract requires payments based on both a fixed and variable cost component, depending on how much the McClain Plant is used.

OG&E has a long-term parts and service maintenance contract for the upkeep of the Redbud Plant. In March 2013, the contract was amended to extend the contract coverage for an additional24,000factored-fired hours resulting in a maximum of the earlier of144,000factored-fired hours or4,500factored-fired starts. Based on historical usage and current expectations for future usage, this contract is expected to run until 2031. The contract requires payments based on both a fixed and variable cost component, depending on how much the Redbud Plant is used.

Wind Energy Purchased Power Lawsuit

In 2009, OG&E entered into a wind energy purchase power agreement with CPV Keenan for the purchase of all the energy output from its150MW wind farm in Woodward County, Oklahoma. In August of 2013, CPV Keenan filed suit against OG&E for the non-payment of curtailment charges.In December 2013, OG&E settled its current case with CPV Keenan and recorded additional purchased power expense of$4.3 million, which will be recovered through the fuel adjustment clause.

Enable Gas Transportation and Storage Agreement

OG&E contracts with Enable for gas transportation and storage services. The stated term of this contract expired April 30, 2009, but remained in effect from year-to-year thereafter. On January 31, 2014, in anticipation of entering into a new, five-year contract, OG&E provided written notice of termination of the contract, effective April 30, 2014. Negotiations regarding the new contract are ongoing, and there can be no assurance that the new contract will be agreed upon, or if agreed upon, that the terms of the new contract will be as favorable to us as the expiring contract.

Environmental Laws and Regulations

The activities ofOG&Eare subject to stringent and complex Federal, state and local laws and regulations governing environmental protection relating to air quality, water quality, waste management, wildlife conservation and natural resources. These laws and regulations can restrict or impact business activities in many ways, such as restricting the way it can handle or dispose of its wastes, requiring remedial action to mitigate environmental issues that may be caused by its operations or that are attributable to former operators, requiring changes in operations and requiring the installation and operation of pollution control equipment. Failure to comply with these laws and regulations could result in the assessment of administrative, civil and criminal penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations.

Environmental regulation can increase the cost of planning, design, initial installation and operation of OG&E's facilities. Historically, OG&E's total expenditures for environmental control facilities and for remediation have not been significant in relation to itsfinancial position or results of operations.OG&Ebelieves, however, that it is reasonably likely that the trend in environmental legislation and regulations will continue towards more restrictive standards.  Compliance with these standards is expected to increase the cost of conducting business. Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

OG&E is managing several significant uncertainties about the scope and timing for the acquisition, installation and operation of additional pollution control equipment and compliance costs for a variety of the EPA rules that are being challenged

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in court.OG&E is unable to predict the financial impact of these matters with certainty at this time.See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Environmental Laws and Regulations" for a discussion of OG&E's environmental matters.

Federal Clean Air Act New Source Review Litigation

As previously reported, in July 2008, OG&E received a request for information from the EPA regarding Federal Clean Air Act compliance at OG&E's Muskogee and Sooner generating plants. In recent years, the EPA has issued similar requests to numerous other electric utilities seeking to determine whether various maintenance, repair and replacement projects should have required permits under the Federal Clean Air Act's new source review process. In January 2012, OG&E received a supplemental request for an update of the previously provided information and for some additional information not previously requested. On May 1, 2012, OG&E responded to the EPA's supplemental request for information. On April 26, 2011, the EPA issued a notice of violation alleging that 13 projects occurred at OG&E's Muskogee and Sooner generating plants between 1993 and 2006 without the required new source review permits. The notice of violation also alleges that OG&E's visible emissions at its Muskogee and Sooner generating plants are not in accordance with applicable new source performance standards.

In March 2013, the DOJ informed OG&E that it was prepared to initiate enforcement litigation concerning the matters identified in the notice of violation. OG&E subsequently met with EPA and DOJ representatives regarding the notice of violation and proposals for resolving the matter without litigation. On July 8, 2013, the United States, at the request of the EPA, filed a complaint for declaratory relief against OG&E in United States District Court for the Western District of Oklahoma (Case No. CIV-13-690-D) alleging that OG&E did not follow the Federal Clean Air Act procedures for projecting emission increases attributable to eight projects that occurred between 2003 and 2006. This complaint seeks to have OG&E submit a new assessment of whether the projects were likely to result in a significant emissions increase. The Sierra Club has intervened in this proceeding and has asserted claims for declaratory relief that are similar to those requested by the United States. OG&E expects to vigorously defend against these claims, but OG&E cannot predict the outcome of such litigation. On August 12, 2013, the Sierra Club filed a complaint against OG&E in the United States District Court for the Eastern District of Oklahoma (Case No. 13-CV-00356) alleging that OG&E modifications made at Unit 6 of the Muskogee generating plant in 2008 were made without obtaining a prevention of significant deterioration permit and that the plant has exceeded emissions limits for opacity and particulate matter. The Sierra Club seeks a permanent injunction preventing OG&E from operating the Muskogee generating plant. At this time, OG&E continues to believe that it has acted in compliance with the Federal Clean Air Act.

If OG&E does not prevail in these proceedings and if a new assessment of the projects were to conclude that they caused a significant emissions increase, the EPA and the Sierra Club could seek to require OG&E to install additional pollution control equipment, including scrubbers, baghouses and selective catalytic reduction systems with capital costs in excess of$1.0 billionand pay fines and significant penalties as a result of the allegations in the notice of violation. Section 113 of the Federal Clean Air Act (along with the Federal Civil Penalties Inflation Adjustment Act of 1996) provides for civil penalties as much as$37,500per day for each violation. The cost of any required pollution control equipment could also be significant. OG&E cannot predict at this time whether it will be legally required to incur any of these costs.

Other

In the normal course of business,OG&Eis confronted with issues or events that may result in a contingent liability.These generally relate to lawsuits or claims made by third parties, including governmental agencies.When appropriate, management consults with legal counsel and other appropriate experts to assess the claim.If, in management's opinion,OG&Ehas incurred a probable loss as set forth by GAAP, an estimate is made of the loss and the appropriate accounting entries are reflected inOG&E'sFinancial Statements.At the present time, based on currently available information, except as otherwise stated above, in Note 13 below, in Item 3 of Part I and under "Environmental Laws and Regulations" in Item 7 of Part IIof this Form 10-K, OG&Ebelieves that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect onOG&E'sfinancial position, results of operations or cash flows.

13. Rate Matters and Regulation

Regulation and Rates

OG&E's retail electric tariffs are regulated by the OCC in Oklahoma and by the APSC in Arkansas.  The issuance of certain securities by OG&E is also regulated by the OCC and the APSC.  OG&E's wholesale electric tariffs, transmission activities, short-term borrowing authorization and accounting practices are subject to the jurisdiction of the FERC.  The Secretary of the

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U.S. Department of Energy has jurisdiction over some of OG&E's facilities and operations.In2013, 85 percentof OG&E's electric revenue was subject to the jurisdiction of the OCC,eight percentto the APSC andseven percentto the FERC.

The OCC issued an order in 1996 authorizing OG&E to reorganize into a subsidiary of OGE Energy.  The order required that, among other things, (i) OGE Energy permit the OCC access to the books and records of OGE Energy and its affiliates relating to transactions with OG&E, (ii) OGE Energy employ accounting and other procedures and controls to protect against subsidization of non-utility activities by OG&E's customers and (iii) OGE Energy refrain from pledging OG&E assets or income for affiliate transactions.  In addition, the Energy Policy Act of 2005 enacted the Public Utility Holding Company Act of 2005, which in turn granted to the FERC access to the books and records of OGE Energy and its affiliates as the FERC deems relevant to costs incurred by OG&E or necessary or appropriate for the protection of utility customers with respect to the FERC jurisdictional rates.

Completed Regulatory Matters

Crossroads Wind Farm

As previously reported, OG&E signed memoranda of understanding in February 2010 for approximately 197.8 megawatts of wind turbine generators and certain related balance of plant engineering, procurement and construction services associated with the Crossroads wind farm. Also as part of this project, on June 16, 2011, OG&E entered into an interconnection agreement with the SPP for the Crossroads wind farm which allowed the Crossroads wind farm to interconnect at 227.5 megawatts. On August 31, 2012, OG&E filed an application with the APSC requesting approval to recover the Arkansas portion of the costs of the Crossroads wind farm through a rider until such costs are included in OG&E's base rates as part of its next general rate proceeding. On April 15, 2013, the APSC issued an order authorizing OG&E to recover the Arkansas portion of the cost to construct the Crossroads wind farm, effective retroactively to August 1, 2012. The costs are being recovered through the Energy Cost Recovery Rider.

Fuel Adjustment Clause Review for Calendar Year 2011

The OCC routinely reviews the costs recovered from customers through OG&E’s fuel adjustment clause. On July 31, 2012, the OCC Staff filed an application for a public hearing to review and monitor OG&E's application of the 2011 fuel adjustment clause and for a prudence review of OG&E's electric generation, purchased power and fuel procurement processes and costs in calendar year 2011.  OG&E filed information and documents in response to the OCC's application on October 1, 2012.  On December 19, 2012, witnesses for the OCC Staff filed responsive testimony recommending that the OCC approve OG&E's fuel adjustment clause costs and recoveries for the calendar year 2011 and recommending that the OCC find that OG&E's electric generation, purchased power, fuel procurement and other fuel related practices, policies and decisions during calendar year 2011 were fair, just and reasonable and prudent. On April 9, 2013, the OCC administrative law judge recommended that the OCC find that for the calendar year 2011 OG&E's electric generation, purchased power and fuel procurement processes and costs were prudent. On June 18, 2013, the OCC issued an order approving the administrative law judge’s recommendation.

Pending Regulatory Matters

FERC Order No. 1000, Final Rule on Transmission Planning and Cost Allocation

On July 21, 2011, the FERC issued Order No. 1000, which revised the FERC's existing regulations governing the process for planning enhancements and expansions of the electric transmission grid in a particular region, along with the corresponding process for allocating the costs of such expansions. Order No. 1000 leaves to individual regions to determine whether a previously-approved project is subject to reevaluation and is therefore governed by the new rule.

Order No. 1000 requires, among other things, public utility transmission providers, such as the SPP, to participate in a process that produces a regional transmission plan satisfying certain standards, and requires that each such regional process consider transmission needs driven by public policy requirements (such as state or Federal policies favoring increased use of renewable energy resources). Order No. 1000 also directs public utility transmission providers to coordinate with neighboring transmission planning regions. In addition, Order No. 1000 establishes specific regional cost allocation principles and directs public utility transmission providers to participate in regional and interregional transmission planning processes that satisfy these principles.

On the issue of determining how entities are to be selected to develop and construct the specific transmission projects, Order No. 1000 directs public utility transmission providers to remove from the FERC-jurisdictional tariffs and agreements provisions that establish any Federal "right of first refusal" for the incumbent transmission owner (such as OG&E) regarding transmission facilities selected in a regional transmission planning process, subject to certain limitations. However, Order No. 1000 is not intended to affect the right of an incumbent transmission owner (such as OG&E) to build, own and recover costs for

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upgrades to its own transmission facilities, and Order No. 1000 does not alter an incumbent transmission owner's use and control of existing rights of way. Order No. 1000 also clarifies that incumbent transmission owners may rely on regional transmission facilities to meet their reliability needs or service obligations. The SPP currently has a "right of first refusal" for incumbent transmission owners and this provision has played a role in OG&E being selected by the SPP to build various transmission projects in Oklahoma. These changes to the "right of first refusal" apply only to "new transmission facilities," which are described as those subject to evaluation or reevaluation (under the applicable local or regional transmission planning process) subsequent to the effective date of the regulatory compliance filings required by the rule, which were filed on November 13, 2012. On May 29, 2013, the Governor signed House Bill 1932 into law which establishes a right of first refusal for Oklahoma incumbent transmission owners, including OG&E, to build new transmission projects with voltages under 300 kilovolts that interconnect to those incumbent entities' existing facilities. OG&E believes this law is consistent with the language of Order No. 1000.

On July 18, 2013, the FERC issued an order on the SPP's Order No. 1000 compliance filing.  This order accepted in part and rejected in part the SPP's plan for complying with Order No. 1000.  The FERC rejected the SPP's plan to retain the right of first refusal for projects that would operate between 100 kilovolts and 300 kilovolts.  However, the FERC clarified that a right of first refusal was appropriate in certain circumstances.  It is not clear how the FERC's order will relate to the recently enacted Oklahoma law addressing a right of first refusal for lower voltages.  On November 15, 2013, SPP made its FERC compliance filing, as required by the July 18, 2013 order. The SPP changes to its tariff and Membership Agreement included provisions that (i) clarify that facilities between 100 kilovolts and 300 kilovolts would be subject to the competitive selection process, (ii) only allow certain evidence, such as state laws (like House Bill 1932) and the holders of existing rights of way, to be considered during the competitive selection process and not earlier in the process; (iii) apply a right of first refusal to transmission projects needed for reliability within three years in certain situations; and (iv) revise the tariff’s competitive selection process, including changes to the criteria for identifying qualifying transmission owners, the requirements for submission of information by transmission owners seeking to participate in competitive selections, and the procedures that govern the competitive selection process.

OGE Energy cannot, at this time, determine the precise impact of Order No. 1000 on OG&E. OG&E has filed a petition for review in the D.C. Circuit relating to the same matter. Nevertheless, at the present time, OGE Energy has no reason to believe that the implementation of Order No. 1000 will impact OG&E's transmission projects currently under development and construction for which OG&E has received a notice to proceed from the SPP.

Fuel Adjustment Clause Review for Calendar Year 2012

On July 31, 2013, the OCC Staff filed an application to review OG&E's fuel adjustment clause for calendar year 2012, including the prudence of OG&E's electric generation, purchased power and fuel procurement costs. OG&E filed the necessary information and documents needed to satisfy the OCC's minimum filing requirement rules on October 9, 2013. A hearing on this matter is scheduled for April 24, 2014.

Request for Modification to Previous Orders

On August 2, 2013, OG&E filed an application at the OCC seeking to make minor modifications to three previous OCC orders. The purpose of the application was to address the timing of certain requirements contained in those orders. OG&E's application proposed to address these issues in OG&E's next general rate case thus avoiding the cost associated with a rate case filing now and benefiting customers by deferring the recovery of certain costs identified in the previous orders. On September 3, 2013, the PUD Staff filed a motion to dismiss OG&E's application. PUD Staff requested that the OCC dismiss OG&E's application and issue an order requiring OG&E to file a rate case for the 2012 test year.

On September 11, 2013, the PUD Staff withdrew their motion to dismiss OG&E's application and on September 12, 2013, filed an application requesting a public hearing, review and possible adjustment of the rates and charges of OG&E based on the 2012 test year. To date, no procedural schedule has been established for either the OG&E application or the PUD Staff application.

Energy Efficiency Program Filing

On October 9, 2013 OG&E filed an application with the APSC requesting approval of interim modifications to approved Energy Efficiency Programs, new tariff revisions and the waiver of certain provisions of the Commission’s Rules for Conservation and Energy Efficiency Programs.

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Market-Based Rate Authority

On June 29, 2012, OG&E filed its triennial market power update with the FERC to retain its market-based rate authorization in the SPP's energy imbalance service market but to surrender its market-based rate authorization for any market-based rates sales outside of the SPP's energy imbalance service market. On May 2, 2013, the FERC issued an order accepting OG&E's June 2012 triennial market power update.

On December 30, 2013, OG&E submitted to the FERC a market-based rate change in status filing and a revised market-based rate tariff.  The revised tariff will authorize OG&E to (i) sell electric energy and capacity at market-based rates without geographic restriction, and (ii) sell ancillary services in the SPP and Midcontinent Independent System Operator, Inc. markets.  The primary goal of this filing was to implement the market-based rate authority OG&E needs to fully participate in SPP’s Integrated Marketplace.  OG&E requested that FERC issue an order on or before February 28, 2014 that accepts the revised market-based rate tariff to be effective on the date SPP’s Integrated Marketplace goes into operation, which is expected to be March 1, 2014.

Section 206 Complaint

On November 26, 2013, Arkansas Electric Cooperative Corporation filed a complaint at the FERC against OG&E, arguing that the wholesale formula rate contract between OG&E and Arkansas Electric Cooperative Corporation (formerly between OG&E and Arkansas Valley Electric Cooperative) is unjust and unreasonable with respect to several items.  After engaging in settlement discussions, OG&E and Arkansas Electric Cooperative Corporation have tentatively agreed to terms of a settlement and are jointly preparing an offer of settlement to be filed with FERC. OG&E believes the reduction in revenue will be less than$1.0 millionper year.

14. Quarterly Financial Data (Unaudited)

Due to the seasonal fluctuations and other factors of OG&E's business, the operating results for interim periods are not necessarily indicative of the results that may be expected for the year.In OG&E's opinion, the following quarterly financial data includes all adjustments, consisting of normal recurring adjustments, necessary to fairly present such amounts.Summarizedquarterly unaudited financial data is as follows:

Quarter ended (In millions)		March 31		June 30		September 30		December 31		Total
Operating revenues	2013	$	455.5	$	574.6	$	723.2	$	508.9	$	2,262.2
	2012	$	426.7	$	528.0	$	721.0	$	465.5	$	2,141.2
Operating income	2013	$	52.9	$	138.1	$	261.0	$	73.3	$	525.3
	2012	$	39.8	$	127.8	$	258.0	$	63.8	$	489.4
Net income	2013	$	13.0	$	79.0	$	171.5	$	29.1	$	292.6
	2012	$	12.1	$	73.4	$	167.2	$	27.6	$	280.3

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholder

Oklahoma Gas and Electric Company

We have audited the accompanyingbalance sheets and statements of capitalizationofOklahoma Gas and Electric Companyas ofDecember 31, 2013and2012, and the relatedstatements of income, comprehensive income, cash flowsandchanges instockholder's equityfor each of the three years in the period endedDecember 31, 2013. Our audits also included the financial statement schedule listed in the Index at Item 15(a).These financial statementsand scheduleare the responsibility of the Company's management.Our responsibility is to express an opinion on these financial statementsand schedulebased on our audits.

We conducted our audits in accordance withthe standards of the Public Company Accounting Oversight Board (United States).Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement.An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements.An audit also includesassessing theaccounting principles used andsignificantestimates made by management, as well as evaluating the overallfinancial statementpresentation. We believe that our auditsprovide a reasonable basis for our opinion.

In our opinion,the financial statements referred to above present fairly, in all material respects, thefinancial position ofOklahoma Gas and Electric CompanyatDecember 31, 2013and2012, and theresults of its operations and its cash flows for each of the three years in the period endedDecember 31, 2013, in conformity with U.S. generally accepted accounting principles.Also, in our opinion, the related financial statement schedule, when considered in relation to the basic financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States),Oklahoma Gas and Electric Company'sinternal control over financial reporting as ofDecember 31, 2013, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (1992 framework) and our report datedFebruary 25, 2014expressed an unqualified opinion thereon.

/s/  Ernst & Young LLP

      Ernst & Young LLP

Oklahoma City, Oklahoma

February 25, 2014

88

Item 9.  Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.

None.

Item 9A.  Controls and Procedures.

OG&E maintains a set of disclosure controls and procedures designed to ensure that information required to be disclosed by OG&E in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission rules and forms.  In addition, the disclosure controls and procedures ensure that information required to be disclosed is accumulated and communicated to management, including the chief executive officer and chief financial officer, allowing timely decisions regarding required disclosure.As of the end of the period covered by this report, based on an evaluation carried out under the supervision and with the participation of OG&E's management, including the chief executive officer and chief financial officer, of the effectiveness of OG&E's disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15(d)-15(e) under the Securities Exchange Act of 1934), the chief executive officer and chief financial officer have concluded that OG&E's disclosure controls and procedures are effective.

No change in OG&E's internal control over financial reporting has occurred during OG&E's most recently completed fiscal quarter that has materially affected, or is reasonably likely to materially affect, OG&E's internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934).

89

Management's Report on Internal Control Over Financial Reporting

The management of OG&E is responsible for establishing and maintaining adequate internal control over financial reporting. OG&E's internal control system was designed to provide reasonable assurance to OG&E's management and Board of Directors regarding the preparation and fair presentation of published financial statements. All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

OG&E management assessed the effectiveness of OG&E's internal control over financial reporting as ofDecember 31, 2013. In making this assessment, it used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control-Integrated Framework (1992).Based on our assessment, we believe that, as ofDecember 31, 2013,OG&E's internal control over financial reporting is effective based on those criteria.

OG&E's independent auditors have issued an attestation report on OG&E's internal control over financial reporting. This report appears on the following page.

/s/ Peter B. Delaney	/s/ Scott Forbes
Peter B. Delaney, Chairman of the Board, President	Scott Forbes, Controller
and Chief Executive Officer	and Chief Accounting Officer
/s/ Sean Trauschke
Sean Trauschke, President
and Chief Financial Officer

90

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Stockholder

Oklahoma Gas and Electric Company

We have auditedOklahoma Gas and Electric Company'sinternal control over financial reporting as ofDecember 31, 2013, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (1992 framework) (the COSO criteria).Oklahoma Gas and Electric Company'smanagement is responsible for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the company's internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

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

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion,Oklahoma Gas and Electric Companymaintained, in all material respects, effective internal control over financial reporting as ofDecember 31, 2013, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), thebalance sheets and statements of capitalization ofOklahoma Gas and Electric Companyas ofDecember 31, 2013and2012, and the relatedstatements of income, comprehensive income, cash flows and changes in stockholder's equity for each of the three years in the period endedDecember 31, 2013ofOklahoma Gas and Electric Companyand our report datedFebruary 25, 2014expressed an unqualified opinion thereon.

/s/ Ernst & Young LLP

      Ernst & Young LLP

Oklahoma City, Oklahoma

February 25, 2014

91

Item 9B. Other Information.

None.

PART III

Item 10.  Directors, Executive Officers and Corporate Governance.

Code of Ethics Policy

OGE Energy maintains a code of ethics for our chief executive officer and senior financial officers, including the chief financial officer and chief accounting officer, which is available for public viewing on OGE Energy's web site address www.oge.com under the heading "Investor Relations", "Corporate Governance."  The code of ethics will be provided, free of charge, upon request.  OGE Energy intends to satisfy the disclosure requirements under Section 5, Item 5.05 of Form 8-K regarding an amendment to, or waiver from, a provision of the code of ethics by posting such information on its web site at the location specified above.  OGE Energy will also include in its proxy statement information regarding the Audit Committee financial experts.

Under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K, the information otherwise required by Item 10 has been omitted.

Item 11.  Executive Compensation.

Under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K, the information otherwise required by Item 11 has been omitted.

Item 12.  Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.

Under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K, the information otherwise required by Item 12 has been omitted.

Item 13.  Certain Relationships and Related Transactions, and Director Independence.

Under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K, the information otherwise required by Item 13 has been omitted.

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Item 14.  Principal Accounting Fees and Services.

The following discussion relates to the audit fees paid by OGE Energy to its principal independent accountants for the services provided to OGE Energy and its subsidiaries, including OG&E

Fees for Principal Independent Accountants

Year ended December 31	2013		2012
Integrated audit of OGE Energy and its subsidiaries financial statements and internal control over financial reporting	$	1,063,300	$	1,610,000
Services in support of debt and stock offerings	65,000		7,500
Other (A)	431,750		447,100
Total audit fees (B)	1,560,050		2,064,600
Employee benefit plan audits	124,000		120,000
Other (C)	142,224		130,665
Total audit-related fees	266,224		250,665
Assistance with examinations and other return issues	351,670		175,215
Review of Federal and state tax returns	30,000		27,500
Total tax preparation and compliance fees	381,670		202,715
Total tax fees	381,670		202,715
Total fees	$	2,207,944	$	2,517,980

(A) Includes reviews of the financial statements included in OGE Energy's and OG&E's Quarterly Reports on Form 10-Q, audits of OGE Energy's subsidiaries, preparation for Audit Committee meetings and fees for consulting with OGE Energy's and OG&E's executives regarding accounting issues.

(B) The aggregate audit fees include fees billed for the audit of OGE Energy's and OG&E's annual financial statements and for the reviews of the financial statements included in OGE Energy's and OG&E's Quarterly Reports on Form 10-Q.  For2013, this amount includes estimated billings for the completion of the2013audit, which services were rendered after year-end.

(C) Includes the U.S. Department of Energy Smart Grid grant audits.

All Other Fees

There were no other fees billed by the principal independent accountants to OGE Energy in2013and2012for other services.

Audit Committee Pre-Approval Procedures

Rules adopted by the Securities and Exchange Commission in order to implement requirements of the Sarbanes-Oxley Act of 2002 require public company audit committees to pre-approve audit and non-audit services.  OGE Energy's Audit Committee follows procedures pursuant to which audit, audit-related and tax services, and all permissible non-audit services are pre-approved by category of service.  The fees are budgeted, and actual fees versus the budget are monitored throughout the year.  During the year, circumstances may arise when it may become necessary to engage the principal independent accountants for additional services not contemplated in the original pre-approval.  In those instances, OGE Energy will obtain the specific pre-approval of the Audit Committee before engaging the principal independent accountants.  The procedures require the Audit Committee to be informed of each service, and the procedures do not include any delegation of the Audit Committee's responsibilities to management.  The Audit Committee may delegate pre-approval authority to one or more of its members.  The member to whom such authority is delegated will report any pre-approval decisions to the Audit Committee at its next scheduled meeting.

For2013, 100 percent of the audit fees, audit-related fees and tax fees were pre-approved by the Audit Committee or the Chairman of the Audit Committee pursuant to delegated authority.

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PART IV

Item 15.  Exhibits, Financial Statement Schedules.

(a) 1.  Financial Statements

The followingFinancial Statements are included in Part II, Item 8 of this Annual Report:

• Statements of Income for the years ended December 31, 2013, 2012 and 2011

• Statements of Comprehensive Income for the years ended December 31, 2013, 2012 and 2011

• Statements of Cash Flows for the years ended December 31, 2013, 2012 and 2011

• Balance Sheets at December 31, 2013 and 2012

• Statements of Capitalization at December 31, 2013 and 2012

• Statements of Changes in Stockholder's Equity for the years ended December 31, 2013, 2012 and 2011

• Notes toFinancial Statements

• Report of Independent Registered Public Accounting Firm (Audit of Financial Statements)

• Management's Report on Internal Control Over Financial Reporting

• Report of Independent Registered Public Accounting Firm (Audit of Internal Control)

2.  Financial Statement Schedule (included in Part IV)

• Schedule II - Valuation and Qualifying Accounts

All other schedules have been omitted since the required information is not applicable or is not material, or because the information required is included in the respectiveFinancial Statements or Notes thereto.

94

3.  Exhibits

Exhibit No.	Description
2.01	Asset Purchase Agreement, dated as of August 18, 2003 by and between OG&E and NRG McClain LLC.  (Certain exhibits and schedules were omitted and registrant agrees to furnish supplementally a copy of such omitted exhibits and schedules to the Commission upon request) (Filed as Exhibit 2.01 to OGE Energy's Form 8-K filed August 20, 2003 (File No. 1-12579) and incorporated by reference herein)
2.02	Amendment No. 1 to Asset Purchase Agreement, dated as of October 22, 2003 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.03 to OGE Energy's Form 10-K for the year ended December 31, 2003 (File No. 1-12579) and incorporated by reference herein)
2.03	Amendment No. 2 to Asset Purchase Agreement, dated as of October 27, 2003 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.04 to OGE Energy's Form 10-K for the year ended December 31, 2003 (File No. 1-12579) and incorporated by reference herein)
2.04	Amendment No. 3 to Asset Purchase Agreement, dated as of November 25, 2003 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.05 to OGE Energy's Form 10-K for the year ended December 31, 2003 (File No. 1-12579) and incorporated by reference herein)
2.05	Amendment No. 4 to Asset Purchase Agreement, dated as of January 28, 2004 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.06 to OGE Energy's Form 10-K for the year ended December 31, 2003 (File No. 1-12579) and incorporated by reference herein)
2.06	Amendment No. 5 to Asset Purchase Agreement, dated as of February 13, 2004 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.07 to OGE Energy's Form 10-K for the year ended December 31, 2003 (File No. 1-12579) and incorporated by reference herein)
2.07	Amendment No. 6 to Asset Purchase Agreement, dated as of March 12, 2004 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.01 to OGE Energy's Form 10-Q for the quarter ended March 31, 2004 (File No. 1-12579) and incorporated by reference herein)
2.08	Amendment No. 7 to Asset Purchase Agreement, dated as of April 15, 2004 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.02 to OGE Energy's Form 10-Q for the quarter ended March 31, 2004 (File No. 1-12579) and incorporated by reference herein)
2.09	Amendment No. 8 to Asset Purchase Agreement, dated as of May 15, 2004 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.01 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein)
2.10	Amendment No. 9 to Asset Purchase Agreement, dated as of June 2, 2004 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.02 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein)
2.11	Amendment No. 10 to Asset Purchase Agreement, dated as of June 17, 2004 by and between OG&E and NRG McClain LLC. (Filed as Exhibit 2.03 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein)
2.12	Purchase and Sale Agreement, dated as of January 21, 2008, entered into by and among Redbud Energy I, LLC, Redbud Energy II, LLC and Redbud Energy III, LLC and OG&E. (Certain exhibits and schedules hereto have been omitted and the registrant agrees to furnish supplementally a copy of such omitted exhibits and schedules to the Commission upon request) (Filed as Exhibit 2.01 to OGE Energy's Form 8-K filed January 25, 2008 (File No. 1-12579) and incorporated by reference herein)
2.13	Asset Purchase Agreement, dated as of January 21, 2008, entered into by and among OG&E, the Oklahoma Municipal Power Authority and the Grand River Dam Authority. (Certain exhibits and schedules hereto have been omitted and the registrant agrees to furnish supplementally a copy of such omitted exhibits and schedules to the Commission upon request) (Filed as Exhibit 2.01 to OGE Energy's Form 8-K filed January 25, 2008 (File No. 1-12579) and incorporated by reference herein)
3.01	Copy of Restated Oklahoma Gas and Electric Company Certificate of Incorporation. (Filed as Exhibit 3.01 to OG&E's Form 8-K filed May 19, 2011 (File No. 1-1097) and incorporated by reference herein)
3.02	Copy of Amended Oklahoma Gas and Electric Company By-laws dated May 19, 2011. (Filed as Exhibit 3.02 to OG&E's Form 8-K filed May 19, 2011 (File No. 1-1097) and incorporated by reference herein)
4.01	Trust Indenture dated October 1, 1995, from OG&E to Boatmen's First National Bank of Oklahoma, Trustee. (Filed as Exhibit 4.29 to Registration Statement No. 33-61821 and incorporated by reference herein)
4.02	Supplemental Indenture No. 2, dated as of July 1, 1997, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed July 17, 1997 (File No. 1-1097) and incorporated by reference herein)
4.03	Supplemental Indenture No. 3, dated as of April 1, 1998, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed April 16, 1998 (File No. 1-1097) and incorporated by reference herein)

95

4.04	Supplemental Indenture No. 5 dated as of October 24, 2001, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.06 to Registration Statement No. 333-104615 and incorporated by reference herein)
4.05	Supplemental Indenture No. 6 dated as of August 1, 2004, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.02 to OG&E's Form 8-K filed August 6, 2004 (File No 1-1097) and incorporated by reference herein)
4.06	Supplemental Indenture No. 7 dated as of January 1, 2006 being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.08 to OG&E's Form 8-K filed January 6, 2006 (File No. 1-1097) and incorporated by reference herein)
4.07	Supplemental Indenture No. 8 dated as of January 15, 2008 being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed January 31, 2008 (File No. 1-1097) and incorporated by reference herein)
4.08	Supplemental Indenture No. 9 dated as of September 1, 2008 being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed September 9, 2008 (File No. 1-1097) and incorporated by reference herein)
4.09	Supplemental Indenture No. 10 dated as of December 1, 2008 being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed December 11, 2008 (File No. 1-1097) and incorporated by reference herein)
4.10	Supplemental Indenture No. 11 dated as of June 1, 2010 being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed June 8, 2010 (File No. 1-1097) and incorporated by reference herein)
4.11	Supplemental Indenture No. 12 dated as of May 15, 2011 being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed May 27, 2011 (File No. 1-1097) and incorporated by reference herein)
4.12	Supplemental Indenture No. 13 dated as of May 1, 2013 between OG&E and UMB Bank, N.A., as trustee, creating the Senior Notes. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed May 13, 2013 (File No. 1-1097) and incorporated by reference herein)
10.01*	OGE Energy's 1998 Stock Incentive Plan. (Filed as Exhibit 10.07 to OGE Energy's Form 10-K for the year ended December 31, 1998 (File No. 1-12579) and incorporated by reference herein)
10.02*	OGE Energy's 2003 Stock Incentive Plan.  (Filed as Annex A to OGE Energy's Proxy Statement for the 2003 Annual Meeting of Shareowners (File No. 1-12579) and incorporated by reference herein)
10.03	Copy of Settlement Agreement with Oklahoma Corporation Commission Staff, the Oklahoma Attorney General and others relating to OG&E's rate case. (Filed as Exhibit 99.02 to OGE Energy's Form 8-K filed July 9, 2012 (File No. 1-12579) and incorporated by reference herein)
10.04	Amended and Restated Facility Operating Agreement for the McClain Generating Facility dated as of July 9, 2004 between OG&E and the Oklahoma Municipal Power Authority. (Filed as Exhibit 10.03 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein)
10.05	Amended and Restated Ownership and Operation Agreement for the McClain Generating Facility dated as of July 9, 2004 between OG&E and the Oklahoma Municipal Power Authority. (Filed as Exhibit 10.04 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein)
10.06	Operating and Maintenance Agreement for the Transmission Assets of the McClain Generating Facility dated as of August 25, 2003 between OG&E and the Oklahoma Municipal Power Authority. (Filed as Exhibit 10.05 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein)
10.07*	Amendment No. 1 to OGE Energy's 2003 Stock Incentive Plan.  (Filed as Exhibit 10.23 to OGE Energy's Form 10-K for the year ended December 31, 2004 (File No. 1-12579) and incorporated by reference herein)
10.08	Intrastate Firm No-Notice, Load Following Transportation and Storage Services Agreement dated as of May 1, 2003 between OG&E and Enogex.  [Confidential treatment has been requested for certain portions of this exhibit.] (Filed as Exhibit 10.24 to OGE Energy's Form 10-K for the year ended December 31, 2004 (File No. 1-12579) and incorporated by reference herein)
10.10*	Form of Split Dollar Agreement. (Filed as Exhibit 10.32 to OGE Energy's Form 10-K for the year ended December 31, 2004 (File No. 1-12579) and incorporated by reference herein)
10.11	Credit agreement dated as of December 13, 2011, by and between OG&E, the Lenders thereto, Wells Fargo Bank, National Association, as Administrative Agent, JPMorgan Chase Bank, N.A., as Syndication Agent, Mizuho Corporate Bank, Ltd., The Royal Bank of Scotland PLC, UBS Securities LLC and Union Bank, N.A., as Co-Documentation Agents. (Filed as Exhibit 99.02 to OGE Energy's Form 8-K filed December 19, 2011 (File No. 1-12579) and incorporated by reference herein)
10.12*	Amendment No. 1 to OGE Energy's 1998 Stock Incentive Plan. (Filed as Exhibit 10.26 to OGE Energy's Form 10-K for the year ended December 31, 2006 (File No. 1-12579) and incorporated by reference herein)
10.13*	Amendment No. 2 to OGE Energy's 2003 Stock Incentive Plan. (Filed as Exhibit 10.27 to OGE Energy's Form 10-K for the year ended December 31, 2006 (File No. 1-12579) and incorporated by reference herein)

96

10.14*	OGE Energy Supplemental Executive Retirement Plan, as amended and restated. (Filed as Exhibit 10.03 to OGE Energy's Form 10-Q for the quarter ended March 31, 2008 (File No. 1-12579) and incorporated by reference herein)
10.15*	OGE Energy Restoration of Retirement Income Plan, as amended and restated. (Filed as Exhibit 10.04 to OGE Energy's Form 10-Q for the quarter ended March 31, 2008 (File No. 1-12579) and incorporated by reference herein)
10.16*	OGE Energy Deferred Compensation Plan, as amended and restated. (Filed as Exhibit 10.05 to OGE Energy's Form 10-Q for the quarter ended March 31, 2008 (File No. 1-12579) and incorporated by reference herein)
10.17*	Amendment No. 3 to OGE Energy's 2003 Stock Incentive Plan. (Filed as Exhibit 10.06 to OGE Energy's Form 10-Q for the quarter ended March 31, 2008 (File No. 1-12579) and incorporated by reference herein)
10.18*	Amendment No. 2 to OGE Energy's 1998 Stock Incentive Plan. (Filed as Exhibit 10.07 to OGE Energy's Form 10-Q for the quarter ended March 31, 2008 (File No. 1-12579) and incorporated by reference herein)
10.19*	OGE Energy's 2008 Stock Incentive Plan.  (Filed as Annex A to OGE Energy's Proxy Statement for the 2008 Annual Meeting of Shareowners (File No. 1-12579) and incorporated by reference herein)
10.20*	OGE Energy's 2008 Annual Incentive Compensation Plan.  (Filed as Annex B to OGE Energy's Proxy Statement for the 2008 Annual Meeting of Shareowners (File No. 1-12579) and incorporated by reference herein)
10.21	Form of Employment Agreement for all existing and future officers of OG&E relating to change of control. (Filed as Exhibit 10.28 to OGE Energy's Form 10-K for the year ended December 31, 2011 (File No. 1-12579) and incorporated by reference herein)
10.22*	Form of Restricted Stock Agreement under OGE Energy's 2008 Stock Incentive Plan. (Filed as Exhibit 10.01 to OGE Energy's Form 10-Q for the quarter ended September 30, 2008 (File No. 1-12579) and incorporated by reference herein)
10.23	Agreement, dated February 17, 2010, between OG&E and Oklahoma Department of Environmental Quality. (Filed as Exhibit 99.01 to OGE Energy's Form 8-K filed February 23, 2010 (File No. 1-12579) and incorporated by reference herein)
10.24*	Amendment No. 1 to OGE Energy's Restoration of Retirement Income Plan. (Filed as Exhibit 10.40 to OGE Energy's Form 10-K for the year ended December 31, 2009 (File No. 1-12579) and incorporated by reference herein)
10.25*	Amendment No. 1 to OGE Energy's Deferred Compensation Plan. (Filed as Exhibit 10.33 to OGE Energy's Form 10-K for the year ended December 31, 2011 (File No. 1-12579) and incorporated by reference herein)
10.26	Copy of Settlement Agreement with Oklahoma Corporation Commission Staff, the Oklahoma Attorney General and others relating to OG&E's Smart Grid application. (Filed as Exhibit 99.02 to OGE Energy's Form 8-K filed June 1, 2010 (File No. 1-12579) and incorporated by reference herein)
10.27	Copy of Settlement Agreement with Oklahoma Corporation Commission Staff, the Oklahoma Attorney General and others relating to OG&E's Crossroads wind farm application. (Filed as Exhibit 99.01 to OGE Energy's Form 8-K filed July 1, 2010 (File No. 1-12579) and incorporated by reference herein)
10.28	Copy of Settlement Agreement with Arkansas Public Service Commission Staff, the Arkansas Attorney General and others relating to OG&E's rate case. (Filed as Exhibit 99.01 to OGE Energy's Form 8-K filed May 19, 2011 (File No. 1-12579) and incorporated by reference herein)
10.29	Copy of Settlement Agreement with Arkansas Public Service Commission Staff, the Arkansas Attorney General and others relating to OG&E's Smart Grid application. (Filed as Exhibit 99.01 to OGE Energy's Form 8-K filed June 28, 2011 (File No. 1-12579) and incorporated by reference herein)
10.30*	Amendment No. 2 to OGE Energy's Deferred Compensation Plan. (Filed as Exhibit 10.41 to OGE Energy's Form 10-K for the year ended December 31, 2009 (File No. 1-12579) and incorporated by reference herein)
10.31*	Amendment No. 3 to OGE Energy's Deferred Compensation Plan. (Filed as Exhibit 10.39 to OGE Energy's Form 10-K for the year ended December 31, 2011 (File No. 1-12579) and incorporated by reference herein)
10.32*	Amendment No. 1 to OGE Energy's 2008 Stock Incentive Plan. (Filed as Exhibit 10.40 to OGE Energy's Form 10-K for the year ended December 31, 2011 (File No. 1-12579) and incorporated by reference herein)
10.33*	Director Compensation. (Filed as Exhibit 10.38 to OGE Energy's Form 10-K for the year ended December 31, 2012 (File No. 1-12579) and incorporated by reference herein)
10.34*	Executive Officer Compensation. (Filed as Exhibit 10.39 to OGE Energy's Form 10-K for the year ended December 31, 2012 (File No. 1-12579) and incorporated by reference herein)
10.35*	OGE Energy's 2013 Stock Incentive Plan. (Filed as Annex B to OGE Energy's Proxy Statement for the 2013 Annual Meeting of Shareowners (File No. 1-12579) and incorporated by reference herein)
10.36*	OGE Energy's 2013 Annual Incentive Compensation Plan. (Filed as Annex C to OGE Energy's Proxy Statement for the 2013 Annual Meeting of Shareowners (File No. 1-12579) and incorporated by reference herein)

97

10.37	Letter of extension dated as of July 29, 2013 for OG&E's credit agreement dated as of December 13,2011, by and between OG&E, the Lenders thereto, Wells Fargo Bank, National Association, as Administrative Agent, JPMorgan Chase Bank, N.A., as Syndication Agent, Mizuho Corporate Bank, Ltd., The Royal Bank of Scotland PLC, UBS Securities LLC and Union Bank, N.A., as Co-Documentation Agents (Filed as Exhibit 10.02 to OGE Energy's Form 8-K filed August 2, 2013 (File No. 1-12579) and incorporated by reference herein)
10.38*	Amendment No. 4 to the Company's Deferred Compensation Plan (Filed as Exhibit 10.01 to OGE Energy's Form 10-Q filed November 6, 2013 (File No. 1-12579) and incorporated by reference herein)
12.01	Calculation of Ratio of Earnings to Fixed Charges.
23.01	Consent of Ernst & Young LLP.
24.01	Power of Attorney.
31.01	Certifications Pursuant to Rule 13a-14(a)/15d-14(a) As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.01	Certification Pursuant to 18 U.S.C. Section 1350 As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
99.01	Cautionary Statement for Purposes of the "Safe Harbor" Provisions of the Private Securities Litigation Reform Act of 1995.
99.02	Copy of APSC order with Arkansas Public Service Commission Staff, the Arkansas Attorney General and others relating to OG&E's rate case. (Filed as Exhibit 99.02 to OGE Energy's Form 8-K filed June 22, 2011 (File No. 1-12579) and incorporated by reference herein)
99.03	Copy of OCC Order with Oklahoma Corporation Commission Staff, the Oklahoma Attorney General and others relating to OG&E's Smart Grid application. (Filed as Exhibit 99.02 to OGE Energy's Form 8-K filed July 7, 2010 (File No. 1-12579) and incorporated by reference herein)
99.04	Copy of OCC Order with Oklahoma Corporation Commission Staff, the Oklahoma Attorney General and others relating to OG&E's Crossroads wind farm application. (Filed as Exhibit 99.04 to OGE Energy's Form 10-Q for the quarter ended June 30, 2010 (File No. 1-12579) and incorporated by reference herein)
101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Schema Document.
101.PRE	XBRL Taxonomy Presentation Linkbase Document.
101.LAB	XBRL Taxonomy Label Linkbase Document.
101.CAL	XBRL Taxonomy Calculation Linkbase Document.
101.DEF	XBRL Definition Linkbase Document.
* Represents executive compensation plans and arrangements.

98

OKLAHOMA GAS AND ELECTRIC COMPANY

SCHEDULE II - Valuation and Qualifying Accounts

			Additions
Description	Balance at Beginning of Period		Charged to Costs and Expenses		Deductions (A)		Balance at End of Period
(In millions)
Balance at December 31, 2011
Reserve for Uncollectible Accounts	$	1.6	$	5.8	$	3.7	$	3.7
Balance at December 31, 2012
Reserve for Uncollectible Accounts	$	3.7	$	3.3	$	4.4	$	2.6
Balance at December 31, 2013
Reserve for Uncollectible Accounts	$	2.6	$	2.5	$	3.2	$	1.9

(A) Uncollectible accounts receivable written off, net of recoveries.

99

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, as amended, the Registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Oklahoma City, and State of Oklahoma on the25th day of February,2014.

OKLAHOMA GAS AND ELECTRIC COMPANY
(Registrant)
By /s/	Peter B. Delaney
	Peter B. Delaney
	Chairman of the Board, President
	and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, this Report has been signed below by the following persons on behalf of the Registrant in the capacities and on the dates indicated.

Signature	Title	Date
/s/ Peter B. Delaney
Peter B. Delaney	Principal Executive
	Officer and Director;	February 25, 2014
/s/ Sean Trauschke
Sean Trauschke	Principal Financial Officer; and	February 25, 2014
/s/ Scott Forbes
Scott Forbes	Principal Accounting Officer.	February 25, 2014
James H. Brandi	Director;
Wayne H. Brunetti	Director;
Luke R. Corbett	Director;
John D. Groendyke	Director;
Kirk Humphreys	Director;
Robert Kelley	Director;
Robert O. Lorenz	Director;
Judy R. McReynolds	Director;
Leroy C. Richie	Director. and
Sheila G. Talton	Director

/s/ Peter B. Delaney
By Peter B. Delaney (attorney-in-fact)	February 25, 2014

100

Supplemental Information to Be Furnished With Reports Filed Pursuant to Section 15(d) of the Act by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Act.

The Registrant has not sent, and does not expect to send, an annual report or proxy statement to its security holders.

101

EX-12.01

Exhibit 12.01

Oklahoma Gas and Electric Company

Ratio of Earnings to Fixed Charges

Year ended December 31 (In millions)	2013		2012		2011		2010		2009
Earnings:
Pre-tax income	$	406.1	$	374.9	$	381.2	$	326.7	$	290.4
Add: Fixed charges	136.0		129.6		123.3		110.9		104.0
Subtotal	542.1		504.5		504.5		437.6		394.4
Subtract:
Allowance for borrowed funds used during construction	3.4		3.5		10.4		5.5		8.3
Total earnings	538.7		501.0		494.1		432.1		386.1
Fixed Charges:
Interest on long-term debt	130.6		124.2		118.7		104.7		96.5
Interest on short-term debt and other interest charges	2.1		3.9		3.3		4.2		5.4
Calculated interest on leased property	3.3		1.5		1.3		2.0		2.1
Total fixed charges	$	136.0	$	129.6	$	123.3	$	110.9	$	104.0
Ratio of Earnings to Fixed Charges	3.96		3.87		4.01		3.90		3.71

EX-23.01

Exhibit 23.01

Consent of Independent Registered Public Accounting Firm

We consent to the incorporation by reference in the Registration Statement (Form S-3ASR No. 333-188309-01) pertaining to debt securities, of our reports dated February 25, 2014, with respect to thefinancial statements and schedule ofOklahoma Gas and Electric Company, and the effectiveness of internal control over financial reporting ofOklahoma Gas and Electric Company, included in this Annual Report (Form 10-K) for the year endedDecember 31, 2013.

/s/  Ernst & Young LLP

      Ernst & Young LLP

Oklahoma City, Oklahoma

February 25, 2014

EX-24.01

Exhibit 24.01

Power of Attorney

WHEREAS, OKLAHOMA GAS AND ELECTRIC COMPANY, an Oklahoma corporation (herein referred to as the "Company"), is about to file with the Securities and Exchange Commission, under the provisions of the Securities Exchange Act of 1934, as amended, its annual report on Form 10-K for the year endedDecember 31, 2013; and

WHEREAS, each of the undersigned holds the office or offices in the Company herein-below set opposite his or her name, respectively;

NOW, THEREFORE, each of the undersigned hereby constitutes and appoints PETER B. DELANEY, SEAN TRAUSCHKE and SCOTT FORBES and each of them individually, his or her attorney with full power to act for him or her and in his or her name, place and stead, to sign his name in the capacity or capacities set forth below to said Form 10-K and to any and all amendments thereto, and hereby ratifies and confirms all that said attorney may or shall lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned have hereunto set their hands this24thday ofFebruary, 2014.

Peter B. Delaney, Chairman, Principal Executive Officer and Director	/s/	Peter B. Delaney
James H. Brandi, Director	/s/	James H. Brandi
Wayne H. Brunetti, Director	/s/	Wayne H. Brunetti
Luke R. Corbett, Director	/s/	Luke R. Corbett
John D. Groendyke, Director	/s/	John D. Groendyke
Kirk Humphreys, Director	/s/	Kirk Humphreys
Robert Kelley, Director	/s/	Robert Kelley
Robert O. Lorenz, Director	/s/	Robert O. Lorenz
Judy R. McReynolds, Director	/s/	Judy R. McReynolds
Leroy C. Richie, Director	/s/	Leroy C. Richie
Sheila G. Talton	/s/	Sheila G. Talton
Sean Trauschke, Principal Financial Officer	/s/	Sean Trauschke
Scott Forbes, Principal Accounting Officer	/s/	Scott Forbes

STATE OF OKLAHOMA	)
	)	SS
COUNTY OF OKLAHOMA	)

On the date indicated above, before me,Kelly Hamilton-Coyer, Notary Public in and for said County and State, the above named directors and officers of OKLAHOMA GAS AND ELECTRIC COMPANY, an Oklahoma corporation, known to me to be the persons whose names are subscribed to the foregoing instrument, severally acknowledged to me that they executed the same as their own free act and deed.

IN WITNESS WHEREOF, I have hereunto set my hand and affixed my official seal on the24thday ofFebruary, 2014.

/s/ Kelly Hamilton-Coyer

By: Kelly Hamilton-Coyer

Notary Public

My commission expires:

July 6, 2017

EX-31.01

Exhibit 31.01

CERTIFICATIONS

I, Peter B. Delaney, certify that:

1. I have reviewed this annual report on Form 10-K ofOklahoma Gas and Electric Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: February 25, 2014

  /s/ Peter B. Delaney

Peter B. Delaney

Chairman of the Board

and Chief Executive Officer

Exhibit 31.01

CERTIFICATIONS

I, Sean Trauschke, certify that:

1. I have reviewed this annual report on Form 10-K ofOklahoma Gas and Electric Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: February 25, 2014

  /s/ Sean Trauschke

Sean Trauschke

President and Chief Financial Officer

EX-32.01

Exhibit 32.01

Certification Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Annual Report of OG&E on Form 10-K for the period endedDecember 31, 2013, as filed with the Securities and Exchange Commission (the "Report"), each of the undersigned does hereby certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

February 25, 2014

          /s/ Peter B. Delaney

               Peter B. Delaney

Chairman of the Board and Chief Executive Officer

          /s/ Sean Trauschke

               Sean Trauschke

President

and Chief Financial Officer

EX-99.01

Exhibit 99.01

Oklahoma Gas and Electric Company Cautionary Factors

The Private Securities Litigation Reform Act of 1995 provides a "safe harbor" for forward-looking statements to encourage such disclosures without the threat of litigation providing those statements are identified as forward-looking and are accompanied by meaningful, cautionary statements identifying important factors that could cause the actual results to differ materially from those projected in the statement. Forward-looking statements have been and will be made in written documents and oral presentations of OG&E.  Such statements are based on management's beliefs as well as assumptions made by and information currently available to management. When used in OG&E's documents or oral presentations,the words "anticipate", "believe", "estimate", "expect", "intend", "objective", "plan", "possible", "potential", "project" and similar expressionsare intended to identify forward-looking statements. In addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements, factors that could cause OG&E's actual results to differ materiallyfrom the forward-looking statementsinclude, but are not limited to:

• Increased competition in the utility industry, including effects of decreasing margins as a result of competitive pressures; industry restructuring initiatives; transmission system operation and/or administration initiatives; recovery of investments made under traditional regulation; nature of competitors entering the industry; retail wheeling; a new pricing structure; and former customers entering the generation market;

• Factors affecting utility operations such as unusual weather conditions; catastrophic weather-related damage; unscheduled generation outages, unusual maintenance or repairs; unanticipated changes to fossil fuel, natural gas or coal supply costs or availability due to higher demand, shortages, transportation problems or other developments; environmental incidents; or electric transmission or gas pipeline system constraints;

• Rate-setting policies or procedures of regulatory entities, including environmental externalities;

• Approval of future regulatory filings with the OCC or the APSC;

• Discontinuance of accounting principles for certain types of rate-regulated activities

• Changing market conditions and a variety of other factors associated with physical energy and financial trading activities including, but not limited to, price, basis, credit, liquidity, volatility, capacity, transmission, currency, interest rate and warranty risks;

• Risks associated with PRM strategies intended to mitigate exposure to adverse movement in the prices of natural gas on both a global and regional basis, including commodity price changes, market supply shortages, interest rate changes and counterparty default;

• General economic conditions, including the availability of credit, access to existing lines of credit, access to the commercial paper markets, actions of rating agencies and their impact on capital expenditures and our ability to access the capital markets, inflation rates and monetary fluctuations;

• Customer business conditions including demand for their products or services and supply of labor and materials used in creating their products and services currently and in the future;

• Financial or regulatory accounting principles or policies imposed by the Financial Accounting Standards Board, the Securities and Exchange Commission, the FERC, state public utility commissions; the regional state committee which regulates the SPP; state entities which regulate natural gas transmission, gathering and processing and similar entities with regulatory oversight;

• Environmental laws, safety laws or other regulations passed by the EPA, the Oklahoma Department of Environmental Quality or other governing agencies that may impact the cost of operations or restrict or change the way OG&E operates its facilities;

• Availability or cost of capital, including changes in interest rates, market perceptions of the utility and energy-related industries, OG&E or security ratings;

• Employee workforce factors including changes in key executives and employee retention;

• Social attitudes regarding the utility, natural gas and power industries;

• Identification of suitable investment opportunities to enhance shareowner returns and achieve long-term financial objectives through business acquisitions and divestitures;

• Some future investments made by OG&E could take the form of noncontrolling interests which would limit OG&E's ability to control the development or operation of an investment;

• Increased pension and healthcare costs;

• Costs and other effects of legal and administrative proceedings, settlements, investigations, claims and matters, including but not limited to those described in Note 12 of Notes toFinancial Statements in this Form 10-K;

• Technological developments, changing markets and other factors that result in competitive disadvantages and create the potential for impairment of existing assets;

• The cost of protecting assets against, or damage due to, terrorism or cyber attacks and other catastrophic events; and

• Other business or investment considerations that may be disclosed from time to time in OG&E's Securities and Exchange Commission filings or in other publicly disseminated written documents.

OG&E undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

XML

Summary of Significant Accounting Policies Accounting Records (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Components of Benefit Obligation Regulatory Asset	$ 227.4	$ 370.6
Smart Grid Project [Member]
Smart Grid Cost Cap	366.4
U.S. Department of Energy Funds	130.0
Operations and Maintenance Expenses [Member]
Deferred Storm and Property Reserve Deficiency, Current	2.7
Regulatory Asset [Member]
Components of Net Periodic Benefit Costs to be Recognized in Next Fiscal Year	10.7
Pension Plans [Member] | Defined Benefit Plans Income Loss [Member]
Components of Benefit Obligation Regulatory Asset	178.4	278.6
Components of Net Periodic Benefit Costs to be Recognized in Next Fiscal Year	11.4
Pension Plans [Member] | Prior Service Cost [Member]
Components of Benefit Obligation Regulatory Asset	2.5	4.5
Components of Net Periodic Benefit Costs to be Recognized in Next Fiscal Year	2.0
Other Postretirement Benefit Plans, Defined Benefit [Member] | Defined Benefit Plans Income Loss [Member]
Components of Benefit Obligation Regulatory Asset	79.9	134.6
Components of Net Periodic Benefit Costs to be Recognized in Next Fiscal Year	11.0
Other Postretirement Benefit Plans, Defined Benefit [Member] | Prior Service Cost [Member]
Components of Benefit Obligation Regulatory Asset	(33.4)	(47.1)
Components of Net Periodic Benefit Costs to be Recognized in Next Fiscal Year	(13.7)
OKLAHOMA | Web Portal Access and Education [Member] | Smart Grid Project [Member]
Smart Grid Costs to be Recovered	$ 6.9

XML

Common Stock and Cumulative Preferred Stock (Details) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Common Stock, Shares, Issued	0	0	0

XML

Related-Party Transactions (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]
Dividends, Common Stock	$ 170.0	$ 75.0
Operating Costs Charged [Member] | Og and E [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	120.1	118.4	129.7
Og and E [Member] | Enogex [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	10.2	12.4	8.1
Og and E [Member] | Natural Gas Transportation [Member] | Enogex [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	34.8	34.8	34.8
Og and E [Member] | Natural Gas Storage [Member] | Enogex [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	12.9	12.9	12.7
Og and E [Member] | Natural Gas Purchases [Member] | Enogex [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	22.4	20.4	34.7
Retained Earnings [Member]
Related Party Transaction [Line Items]
Dividends, Common Stock	(170.0)	(75.0)
Additional Paid-in Capital [Member]
Related Party Transaction [Line Items]
Dividends, Common Stock	$ 0	$ 0

XML

Long-Term Debt (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
Total long-term debt	$ 2,300.2	$ 2,050.3
Percent of Principal Amount Subject to Optional Tender	100.00%
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	0.2
Long-term Debt, Maturities, Repayments of Principal in Year Two	0.2
Long-term Debt, Maturities, Repayments of Principal in Year Three	110.2
Long-term Debt, Maturities, Repayments of Principal in Year Four	125.1
Long-term Debt, Maturities, Repayments of Principal in Year Five	250.1
Garfield Industrial Authority Bond, Due January 1, 2025 [Member]
Debt Instrument [Line Items]
Date Due	Jan. 01, 2025
Muskogee Industrial Authority Bond, Due January 1, 2025 [Member]
Debt Instrument [Line Items]
Date Due	Jan. 01, 2025
Muskogee Industrial Authority Bond, Due June 1, 2027 [Member]
Debt Instrument [Line Items]
Date Due	Jun. 01, 2027
Redeemable during the next 12 months [Member]
Debt Instrument [Line Items]
Total long-term debt	135.4
Redeemable during the next 12 months [Member] | Garfield Industrial Authority Bond, Due January 1, 2025 [Member]
Debt Instrument [Line Items]
Series Minimum	0.18%
Series Maximum	0.34%
Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond, Due January 1, 2025 [Member]
Debt Instrument [Line Items]
Series Minimum	0.10%
Series Maximum	0.39%
Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond, Due June 1, 2027 [Member]
Debt Instrument [Line Items]
Series Minimum	0.10%
Series Maximum	0.30%
OG&E [Member] | Redeemable during the next 12 months [Member] | Garfield Industrial Authority Bond, Due January 1, 2025 [Member]
Debt Instrument [Line Items]
Long term debt, gross	47.0	47.0
OG&E [Member] | Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond, Due January 1, 2025 [Member]
Debt Instrument [Line Items]
Long term debt, gross	32.4	32.4
OG&E [Member] | Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond, Due June 1, 2027 [Member]
Debt Instrument [Line Items]
Long term debt, gross	56.0	56.0
Senior Notes [Member] | OG&E [Member] | Series due May 1, 2043 [Member]
Debt Instrument [Line Items]
Long term debt, gross	$ 250.0	$ 0
Debt Instrument, Interest Rate, Stated Percentage	3.90%
Date Due	May 01, 2043

XML

Summary of Significant Accounting Policies Accumulated Other Comprehensive Loss (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ 0	$ (1.3)

XML

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2013

Long-term Debt, Unclassified [Abstract]

Schedule of Long-term Debt Instruments [Table Text Block]

OG&E has tax-exempt pollution control bonds with optional redemption provisions that allow the holders to request repayment of the bonds on any business day.  The bonds, which can be tendered at the option of the holder during the next 12 months, are as follows:

SERIES			DATE DUE	AMOUNT
				(In millions)
0.18%	-	0.34%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.10%	-	0.39%	Muskogee Industrial Authority, January 1, 2025	32.4
0.10%	-	0.30%	Muskogee Industrial Authority, June 1, 2027	56.0
Total (redeemable during next 12 months)				$	135.4

XML

Retirement Plans and Postretirement Benefit Plans (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Cost Recognized			$ 7.8		$ 7.6		$ 7.0
Estimated Future Employer Contributions in Next Fiscal Year	26.0
Fair Value of Plan Assets	61.4		59.6
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	75.4
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	65.1
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	59.9
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	53.1
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	49.1
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	183.3
Effect of One Percentage Point Increase on Service and Interest Cost Components	0		0		0
Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	0.1		0.1		0.1
Effect of One Percentage Point Decrease on Service and Interest Cost Components	0		0.1		0.1
Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	0.4		0.7		0.4
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	59.6
Fair Value of Plan Assets, Ending	61.4		59.6
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Contributions by Employer	35.0		35.0
Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	8.3		6.3
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	8.3		6.3
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	53.1		53.3
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	53.1		53.3
U.S. common stocks [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	236.8		232.2
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	236.8		232.2
U.S. common stocks [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	236.8		232.2
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	236.8		232.2
U.S. common stocks [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
Foreign common stocks [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	39.3		39.9
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	39.3		39.9
Foreign common stocks [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	39.3		39.9
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	39.3		39.9
Foreign common stocks [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
U.S. treasury notes and bonds [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	159.8	[1]	138.6	[1]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	159.8	[1]	138.6	[1]
U.S. treasury notes and bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	159.8	[1]	138.6	[1]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	159.8	[1]	138.6	[1]
U.S. treasury notes and bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0	[1]	0	[1]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0	[1]	0	[1]
Mortgage-backed Securities [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	50.3		55.8
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	50.3		55.8
Mortgage-backed Securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
Mortgage-backed Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	50.3		55.8
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	50.3		55.8
Corporate fixed income and other securities [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	110.6	[2]	98.4	[2]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	110.6	[2]	98.4	[2]
Corporate fixed income and other securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0	[2]	0	[2]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0	[2]	0	[2]
Corporate fixed income and other securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	110.6	[2]	98.4	[2]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	110.6	[2]	98.4	[2]
Mortgage-backed securities [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	22.3	[2]	13.5	[2]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	22.3	[2]	13.5	[2]
Mortgage-backed securities [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0	[2]	0	[2]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0	[2]	0	[2]
Mortgage-backed securities [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	22.3	[2]	13.5	[2]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	22.3	[2]	13.5	[2]
Commingled fund [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	29.2	[3]	34.9	[3]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	29.2	[3]	34.9	[3]
Commingled fund [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0	[3]	0	[3]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0	[3]	0	[3]
Commingled fund [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	29.2	[3]	34.9	[3]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	29.2	[3]	34.9	[3]
Common/collective trust [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	26.0	[4]	25.6	[4]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	26.0	[4]	25.6	[4]
Common/collective trust [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0	[4]	0	[4]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0	[4]	0	[4]
Common/collective trust [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	26.0	[4]	25.6	[4]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	26.0	[4]	25.6	[4]
Foreign government bonds [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	4.0		3.9
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	4.0		3.9
Foreign government bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
Foreign government bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	4.0		3.9
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	4.0		3.9
U.S. municipal bonds [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	2.0		0.8
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	2.0		0.8
U.S. municipal bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
U.S. municipal bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	2.0		0.8
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	2.0		0.8
Interest-bearing cash [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0.1		0.2
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0.1		0.2
Interest-bearing cash [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0.1		0.2
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0.1		0.2
Interest-bearing cash [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
Receivable (foreign currency) [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	1.1		0.4
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	1.1		0.4
Receivable (foreign currency) [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
Receivable (foreign currency) [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	1.1		0.4
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	1.1		0.4
Payable (foreign currency) [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	(1.1)		(0.4)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	(1.1)		(0.4)
Payable (foreign currency) [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
Payable (foreign currency) [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	(1.1)		(0.4)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	(1.1)		(0.4)
Total Plan investments [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	680.4		643.8
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	680.4		643.8
Total Plan investments [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	436.0		410.9
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	436.0		410.9
Total Plan investments [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	244.4		232.9
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	244.4		232.9
Receivable from broker for securities sold [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	11.5		0.8
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	11.5		0.8
Interest and dividends receivable [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	3.2		2.8
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	3.2		2.8
Payable to broker for securities purchased [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	(40.2)		(21.4)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	(40.2)		(21.4)
Plan investments attributable to affiliates [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	(138.4)		(107.0)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	(138.4)		(107.0)
Total Plan assets [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	516.5		519.0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	516.5		519.0
Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Settlements	17.6
Fair Value of Plan Assets	516.5		519.0		485.9
Funded Status of Plan	12.9		(55.6)
Accumulated Benefit Obligation	483.0		549.3
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	(574.6)		(546.9)
Service cost	(11.6)		(10.9)		(10.8)
Interest cost	(20.4)		(23.5)		(26.2)
Participants' contributions	49.9		0
Medicare subsidies received	0		0
Actuarial gains (losses)	39.8		(43.7)
Benefits paid	13.3		50.4
Benefit Obligation, Ending	(503.6)		(574.6)		(546.9)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	519.0		485.9
Actual return on plans' assets	60.7		50.5
Participants' contributions	(49.9)		0
Medicare subsidies received	0		0
Benefits paid	(13.3)		(50.4)
Fair Value of Plan Assets, Ending	516.5		519.0		485.9
Funded Status of Plan	12.9		(55.6)
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	11.6		10.9		10.8
Interest cost	20.4		23.5		26.2
Expected return on plan assets	(38.9)		(38.2)		(37.3)
Amortization of transition obligation	0		0		0
Amortization of net loss	20.7		19.3		15.6
Amortization of unrecognized prior service cost	1.9	[5]	2.2	[5]	2.5	[5]
Settlement	17.6		0		0
Net Periodic Benefit Cost	33.3	[6]	17.7	[6]	17.8	[6]
Assumptions Used Calculating Benefit Obligation, Discount Rate	4.60%		3.70%		4.50%
Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	8.00%		8.00%		8.00%
Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	4.20%		4.20%		4.40%
Defined Benefit Plan, Contributions by Employer	0		33.0
Pension Plan [Member] | OKLAHOMA
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Settlements	17.0
Pension Plan [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets			0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending			0		0
Restoration of Retirement Income Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0		0
Funded Status of Plan	(2.1)		(2.2)
Accumulated Benefit Obligation	1.9		2.1
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	(2.2)		(2.2)
Service cost	(0.1)		(0.1)		(0.1)
Interest cost	(0.1)		(0.1)		(0.1)
Participants' contributions	0		0
Medicare subsidies received	0		0
Actuarial gains (losses)	0.2		(0.4)
Benefits paid	0.1		0.6
Benefit Obligation, Ending	(2.1)		(2.2)		(2.2)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	0		0
Actual return on plans' assets	0		0
Participants' contributions	0		0
Medicare subsidies received	0		0
Benefits paid	(0.1)		(0.6)
Fair Value of Plan Assets, Ending	0		0		0
Funded Status of Plan	(2.1)		(2.2)
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0.1		0.1		0.1
Interest cost	0.1		0.1		0.1
Expected return on plan assets	0		0		0
Amortization of transition obligation	0		0		0
Amortization of net loss	0		0.1		0.1
Amortization of unrecognized prior service cost	0.1	[5]	0.2	[5]	0.2	[5]
Settlement	0		0.3		0
Net Periodic Benefit Cost	0.3	[6]	0.8	[6]	0.5	[6]
Defined Benefit Plan, Contributions by Employer	0.1		0.6
Pension Plans [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Net Periodic Benefit Cost	46.7		34.1		30.2
Capitalized Portion of Net Periodic Benefit Cost	4.2		5.5		5.3
Pension Plans [Member] | OKLAHOMA
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Additional Pension Expense to Meet State Requirements	5.8		8.3		10.8
Postretirement Benefit Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	56.7		55.5		57.2
Funded Status of Plan	(145.7)		(180.9)
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	(236.4)		(223.1)
Service cost	(2.9)		(2.7)		(2.4)
Interest cost	(8.1)		(9.4)		(10.0)
Participants' contributions	(2.5)		(2.5)
Medicare subsidies received	0		(0.5)
Actuarial gains (losses)	35.4		(9.4)
Benefits paid	12.1		11.2
Benefit Obligation, Ending	(202.4)		(236.4)		(223.1)
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	55.5		57.2
Actual return on plans' assets	3.4		4.3
Participants' contributions	2.5		2.5
Medicare subsidies received	0		0.5
Benefits paid	(12.1)		(11.2)
Fair Value of Plan Assets, Ending	56.7		55.5		57.2
Funded Status of Plan	(145.7)		(180.9)
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	2.9		2.7		2.4
Interest cost	8.1		9.4		10.0
Expected return on plan assets	(2.4)		(2.8)		(4.9)
Amortization of transition obligation	0		2.5		2.6
Amortization of net loss	18.2		17.4		15.5
Amortization of unrecognized prior service cost	(13.7)	[5]	(13.6)	[5]	(13.7)	[5]
Settlement	0		0		0
Net Periodic Benefit Cost	13.1	[6]	15.6	[6]	11.9	[6]
Capitalized Portion of Net Periodic Benefit Cost	3.4		4.7		3.3
Assumptions Used Calculating Benefit Obligation, Discount Rate	4.60%		3.60%		4.50%
Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	4.00%		4.00%		6.50%
Health Care Cost Trend Rate Assumed for Next Fiscal Year	8.35%		8.55%		8.75%
Ultimate Health Care Cost Trend Rate	4.48%		4.48%		4.48%
Year that Rate Reaches Ultimate Trend Rate	2028		2028		2028
Defined Benefit Plan, Contributions by Employer	7.4		2.2
Postretirement Benefit Plan [Member] | OKLAHOMA
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Additional Postretirement Medical Expense to Meet State Requirements	0.6		0.8
Postretirement Benefit Plan [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Ending	0		0
Less Than 90% [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	50.00%
Projected Benefit Obligation Funded Status Thresholds Equity	50.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
95% [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	58.00%
Projected Benefit Obligation Funded Status Thresholds Equity	42.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
100% [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	65.00%
Projected Benefit Obligation Funded Status Thresholds Equity	35.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
105% [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	73.00%
Projected Benefit Obligation Funded Status Thresholds Equity	27.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
110% [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	80.00%
Projected Benefit Obligation Funded Status Thresholds Equity	20.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
115% [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	85.00%
Projected Benefit Obligation Funded Status Thresholds Equity	15.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
120% [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	90.00%
Projected Benefit Obligation Funded Status Thresholds Equity	10.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
Domestic All-Cap/Large Cap Equity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target Plan Asset Allocations	50.00%
Target Plan Asset Allocations Range Minimum	50.00%
Target Plan Asset Allocations Range Maximum	60.00%
Domestic Mid-Cap Equity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target Plan Asset Allocations	15.00%
Target Plan Asset Allocations Range Minimum	5.00%
Target Plan Asset Allocations Range Maximum	25.00%
Domestic Small-Cap Equity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target Plan Asset Allocations	15.00%
Target Plan Asset Allocations Range Minimum	5.00%
Target Plan Asset Allocations Range Maximum	25.00%
International Equity [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Target Plan Asset Allocations	20.00%
Target Plan Asset Allocations Range Minimum	10.00%
Target Plan Asset Allocations Range Maximum	30.00%
OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension Contributions			0		33.0
Estimated Future Employer Contributions in Next Fiscal Year	1.0
Fair Value of Plan Assets	56.7		55.5
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	55.5
Fair Value of Plan Assets, Ending	$ 56.7		$ 55.5

[1] This category represents U.S. treasury notes and bonds with a Moody's Investors Services rating of Aaa and Government Agency Bonds with a Moody's Investors Services rating of A1 or higher.

[2] This category primarily represents U.S. corporate bonds with an investment grade rating at or above Baa3 or BBB- by Moody's Investors Services, Standard & Poor's Ratings Services or Fitch Ratings.

[3] This category represents units of participation in a commingled fund that primarily invested in stocks of international companies and emerging markets.

[4] This category represents units of participation in an investment pool which primarily invests in foreign or domestic bonds, debentures, mortgages, equipment or other trust certificates, notes, obligations issued or guaranteed by the U.S. Government or its agencies, bank certificates of deposit, bankers' acceptances and repurchase agreements, high grade commercial paper and other instruments with money market characteristics with a fixed or variable interest rate. There are no restrictions on redemptions in the common/collective trust.

[5] Unamortized prior service cost is amortized on a straight-line basis over the average remaining service period to the first eligibility age of participants who are expected to receive a benefit and are active at the date of the plan amendment.

[6] In addition to the $46.7 million, $34.1 million and $30.2 million of net periodic benefit cost recognized in 2013, 2012 and 2011, respectively, OG&E recognized the following: •an increase in pension expense in 2013, 2012 and 2011 of $5.8 million, $8.3 million and $10.8 million, respectively, to maintain the allowable amount to be recovered for pension expense in the Oklahoma jurisdiction, which are included in the Pension tracker regulatory asset or liability (see Note 1); and•an increase in postretirement medical expense in 2013 and 2012 of $0.6 million and $0.8 million respectively, to maintain the allowable amount to be recovered for postretirement medical expense in the Oklahoma jurisdiction which are included in the Pension tracker regulatory asset or liability (see Note 1);•a deferral of pension expense in 2013 of $17.0 million which includes a portion of OGE Energy's pension settlement charge, related to the pension settlement charge of $17.6 million which is included in the Pension tracker regulatory account (see Note 1).

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Schedule II

12 Months Ended

Dec. 31, 2013

Schedule II [Abstract]

Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]

OKLAHOMA GAS AND ELECTRIC COMPANY

SCHEDULE II - Valuation and Qualifying Accounts

			Additions
Description	Balance at Beginning of Period		Charged to Costs and Expenses		Deductions (A)		Balance at End of Period
(In millions)
Balance at December 31, 2011
Reserve for Uncollectible Accounts	$	1.6	$	5.8	$	3.7	$	3.7
Balance at December 31, 2012
Reserve for Uncollectible Accounts	$	3.7	$	3.3	$	4.4	$	2.6
Balance at December 31, 2013
Reserve for Uncollectible Accounts	$	2.6	$	2.5	$	3.2	$	1.9

(A) Uncollectible accounts receivable written off, net of recoveries.

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Fair Value Measurements (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Carrying Amount	$ 2,300.2	$ 2,050.3
OG&E Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Carrying Amount	2,154.5	1,904.2
Long-term Debt, Fair Value	2,405.0	2,401.6
OG&E Industrial Authority Bonds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Carrying Amount	135.4	135.4
Long-term Debt, Fair Value	135.4	135.4
OG&E Tinker Debt [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Carrying Amount	10.3	10.7
Long-term Debt, Fair Value	$ 9.1	$ 10.0

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Summary of Significant Accounting Policies Property, Plant and Equipment (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 9,499.2		$ 8,749.7
Accumulated Depreciation	2,864.6		2,705.6
Property, Plant and Equipment, Net	6,634.6		6,044.1
OG&E [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	9,499.2		8,749.7
Accumulated Depreciation	2,864.6		2,705.6
Property, Plant and Equipment, Net	6,634.6		6,044.1
Capitalized Computer Software, Gross	16.8		17.6
Capitalized Computer Software, Amortization	4.0		4.2		1.8
Electric Transmission and Distribution Equipment [Member] | OG&E [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	3,403.8		3,222.7
Accumulated Depreciation	1,028.2		969.6
Property, Plant and Equipment, Net	2,375.6		2,253.1
Electric Generation Equipment [Member] | OG&E [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	3,551.0	[1]	3,446.6	[2]
Accumulated Depreciation	1,306.1	[1]	1,242.4	[2]
Property, Plant and Equipment, Net	2,244.9	[1]	2,204.2	[2]
Amount of Acquisition Adjustments	148.3		148.3
Public Utilities, Property, Plant and Equipment, Amount of Acquisition Adjustments, Related Accumulated Depreciation	28.8		23.3
Transmission Equipment [Member] | OG&E [Member]
Property, Plant and Equipment [Line Items]
Amount of Acquisition Adjustments	3.3		3.3
Amount of Acquistion Adjustments Related Accumulated Amortization	0.3		0.3
Electric Transmission [Member] | OG&E [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	2,163.7	[3]	1,712.6	[4]
Accumulated Depreciation	385.0	[3]	359.8	[4]
Property, Plant and Equipment, Net	1,778.7	[3]	1,352.8	[4]
Finite-Lived Intangible Assets, Major Class Name [Domain] | OG&E [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	50.5		50.2
Accumulated Depreciation	27.1		25.0
Property, Plant and Equipment, Net	23.4		25.2
Property, Plant and Equipment, Other Types [Member] | OG&E [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	330.2		317.6
Accumulated Depreciation	118.2		108.8
Property, Plant and Equipment, Net	212.0		208.8
McClain Plant [Member]
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	0.1		0.1
Jointly Owned Utility Plant, Proportionate Ownership Share	77.00%		77.00%	[5]
Property, Plant and Equipment, Gross	180.8		182.1	[5]
Accumulated Depreciation	62.1		56.3	[5]
Property, Plant and Equipment, Net	118.7	[6]	125.8	[5]
Redbud Plant [Member]
Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	39.5		0.3
Jointly Owned Utility Plant, Proportionate Ownership Share	51.00%	[7]	51.00%
Property, Plant and Equipment, Gross	498.9	[6],[7]	458.5	[5],[8]
Accumulated Depreciation	89.7	[6],[7]	69.5	[5],[8]
Property, Plant and Equipment, Net	409.2	[6],[7]	389.0	[5],[8]
Amount of Acquisition Adjustments	148.3		148.3
Public Utilities, Property, Plant and Equipment, Amount of Acquisition Adjustments, Related Accumulated Depreciation	$ 28.8		$ 23.3

[1] This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of

[2] This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $23.3 million

[3] This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $0.3 million

[4] This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $0.3 million.

[5] Construction work in progress was $0.1 million and $0.3 million for the McClain and Redbud Plants, respectively.

[6] Construction work in progress was $0.1 million and $39.5 million for the McClain and Redbud Plants, respectively.

[7] This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $28.8 million.

[8] This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $23.3 million.

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Schedule II (Tables)

12 Months Ended

Dec. 31, 2013

Valuation and Qualifying Accounts Disclosure [Line Items]

Schedule II Valuation and Qualifying Accounts [Table Text Block]

SCHEDULE II - Valuation and Qualifying Accounts

			Additions
Description	Balance at Beginning of Period		Charged to Costs and Expenses		Deductions (A)		Balance at End of Period
(In millions)
Balance at December 31, 2011
Reserve for Uncollectible Accounts	$	1.6	$	5.8	$	3.7	$	3.7
Balance at December 31, 2012
Reserve for Uncollectible Accounts	$	3.7	$	3.3	$	4.4	$	2.6
Balance at December 31, 2013
Reserve for Uncollectible Accounts	$	2.6	$	2.5	$	3.2	$	1.9

(A) Uncollectible accounts receivable written off, net of recoveries.

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Supplemental Cash Flow Information (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
NON-CASH INVESTING AND FINANCING ACTIVITIES
Installment payments for Tinker electric distribution system	$ 0	$ 10.6	$ 0
Power plant long-term service agreement	9.7	0	1.7
SUPPLEMENTAL CASH FLOW INFORMATION
Interest (net of interest capitalized)	127.5	122.1	108.2
Income taxes (net of income tax refunds)	(5.5)	(1.2)	4.5
Interest costs capitalized	$ 3.4	$ 3.5	$ 10.4

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Quarterly Financial Data (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating revenues	$ 508.9	$ 723.2	$ 574.6	$ 455.5	$ 465.5	$ 721.0	$ 528.0	$ 426.7	$ 2,262.2	$ 2,141.2	$ 2,211.5
Operating income	73.3	261.0	138.1	52.9	63.8	258.0	127.8	39.8	525.3	489.4	472.3
Net income	$ 29.1	$ 171.5	$ 79.0	$ 13.0	$ 27.6	$ 167.2	$ 73.4	$ 12.1	$ 292.6	$ 280.3	$ 263.3

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Summary of Significant Accounting Policies Environmental Costs (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Site Contingency [Line Items]
Accrued Environmental Loss Contingencies, Noncurrent	$ 6.2	$ 5.8

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STATEMENTS OF CAPITALIZATION (Parenthetical) (USD $) In Millions, except Per Share data, unless otherwise specified			12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013 Garfield Industrial Authority Bond, Due January 1, 2025 [Member] Debentures Subject to Mandatory Redemption [Member]	Dec. 31, 2013 Muskogee Industrial Authority Bond, Due January 1, 2025 [Member] Debentures Subject to Mandatory Redemption [Member]	Dec. 31, 2013 Muskogee Industrial Authority Bond, Due June 1, 2027 [Member] Debentures Subject to Mandatory Redemption [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due January 15, 2016 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due July 15, 2017 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due September 1, 2018 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due January 15, 2019 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due July 15, 2027 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due April 15, 2028 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due August 1, 2034 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due January 15, 2036 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due February 1, 2038 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Series Due June 1, 2040 [Member]	Dec. 31, 2013 Senior Notes [Member] OG&E [Member] Senior Notes due May 15, 2041 [Member]	Dec. 31, 2013 Long-term Debt [Member] OG&E [Member] Due August 31, 2062 [Member]
Common Stock, Par or Stated Value Per Share	$ 2.50	$ 2.50
Common Stock, Shares Authorized	100
Common Stock, Shares, Outstanding	40.4	40.4
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum			0.18%	0.10%	0.10%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum			0.34%	0.39%	0.30%
Debt Instrument, Maturity Date						Jan. 15, 2016	Jul. 15, 2017	Sep. 01, 2018	Jan. 15, 2019	Jul. 15, 2027	Apr. 15, 2028	Aug. 01, 2034	Jan. 15, 2036	Feb. 01, 2038	Jun. 01, 2040	May 15, 2041	Aug. 31, 2062

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Schedule II (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Beginning Balance	$ 2.6	$ 3.7	$ 1.6
Valuation Allowances and Reserves, Charged to Cost and Expense	2.5	3.3	5.8
Valuation Allowances and Reserves, Deductions	3.2	4.4	3.7
Valuation Allowances and Reserves, Ending Balance	$ 1.9	$ 2.6	$ 3.7

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Summary of Significant Accounting Policies Depreciation and Amortization (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Provision for Depreciation Rate	2.80%	3.00%
Projected Provision for Depreciation in Next Fiscal Year	2.80%
Percent Of Intangible Plant Balance Amortizable	93.50%
Percent of Intangible Plant Balance Amortizable Thereafter	6.50%
Transmission Equipment [Member] | OG&E [Member]
Amount of Acquisition Adjustments	$ 3.3	$ 3.3

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Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2013

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair Value, by Balance Sheet Grouping [Table Text Block]

The following table summarizes the fair value and carrying amount of OG&E's financial instruments atDecember 31, 2013 and December 31, 2012.

	2013				2012
December 31 (In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-Term Debt
Senior Notes	$	2,154.5	$	2,405.0	$	1,904.2	$	2,401.6
Industrial Authority Bonds	135.4		135.4		135.4		135.4
Tinker Debt	10.3		9.1		10.7		10.0

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Related-Party Transactions (Tables)

12 Months Ended

Dec. 31, 2013

Related Party Transaction [Line Items]

Schedule of Related Party Transactions [Table Text Block]

The following table summarizes related party transactions between OG&E and its affiliate, Enable, during 2013, 2012 and 2011.

	December 31,
(In millions)	2013		2012		2011
Operating Revenues:
Electricity to power electric compression assets	$	10.2	$	12.4	$	8.1
Cost of Sales:
Natural gas transportation services	$	34.8	$	34.8	$	34.8
Natural gas storage services	12.9		12.9		12.7
Natural gas purchases	22.4		20.4		34.7

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Short-Term Debt and Credit Facility Short-Term Debt and Credit Facility (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2013
Line of Credit Facility [Line Items]
Advances from parent	$ 87.2	$ 0
Advances to parent	0	90.3
OG&E [Member]
Line of Credit Facility [Line Items]
Intercomany Borrowings, Maximum Borrowing Capacity	400.0
Intercompany Borrowing Agreement, Expiration Date		Dec. 13, 2017
Outstanding Intercompany Borrowings			0
Line of Credit Facility, Maximum Borrowing Capacity	400.0
Letters of Credit Outstanding, Amount	2.1
Short-term Debt, Weighted Average Interest Rate	0.53%
Line of Credit Facility, Amount Outstanding	0
Commercial Paper	0
Period For Which Regulatory Approval Has Been Given to Acquire Short Term Debt	2 years
Short Term Borrowing Capacity That Has Regulatory Approval	800
Maximum [Member]
Line of Credit Facility [Line Items]
Cash	$ 0.1

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Summary of Significant Accounting Policies Asset Retirement Obligations (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at January 1	$ 53.6	$ 24.8
Accretion expense	2.3	1.9
Revisions in estimated cash flows	(0.7)	26.9
Balance at December 31	$ 55.2	$ 53.6

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Stock-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2013

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Disclosure of Share-based Compensation Arrangements by Share-based Payment Award [Table Text Block]

The following table summarizes OG&E's pre-tax compensation expense and related income tax benefit for the years endedDecember 31, 2013, 2012and2011related toperformance units and restricted stockfor OG&E employees.

Year ended December 31 (In millions)	2013		2012		2011
Performance units
Total shareholder return	$	1.7	$	1.7	$	1.6
Earnings per share	0.5		0.9		1.1
Total performance units	2.2		2.6		2.7
Restricted stock	0.1		0.1		0.2
Net compensation expense	$	2.3	$	2.7	$	2.9
Income tax benefit	$	0.9	$	1.2	$	1.2

Performance Units Total Shareholder Return Valuation Assumptions [Table Text Block]

The number of performance units granted based on total shareholder return and the assumptions used to calculate the grant date fair value of the performance units based on total shareholder return are shown in the following table.

	2013			2012			2011
Number of units granted to OG&E employees	71,850			81,122			86,604
Fair value of units granted	$	25.89		$	25.91		$	23.05
Expected dividend yield	2.8		%	3.0		%	3.2		%
Expected price volatility	20.0		%	22.0		%	33.0		%
Risk-free interest rate	0.37		%	0.38		%	1.40		%
Expected life of units (in years)	2.84			2.87			2.87

Performance Units Earnings Per Share Valuation Assumptions [Table Text Block]

The number of performance units granted based on earnings per share and the grant date fair value are shown in the following table.

	2013		2012		2011
Number of units granted to OG&E employees	23,952		27,038		28,862
Fair value of units granted	$	26.73	$	23.82	$	20.81

Restricted Stock

Restricted Stock Valuation Assumptions [Table Text Block]

The number of shares of restricted stock grantedrelated to OG&E employeesand the grant date fair value are shown in the following table.

	2013		2012		2011
Shares of restricted stock granted to OG&E employees	3,824		2,216		4,468
Fair value of restricted stock granted	$	29.71	$	26.93	$	23.61

Schedule of Share-based Compensation, Activity [Table Text Block]

A summary of the activity forOGE Energy'sperformance units and restricted stockapplicable to OG&E'S employeesatDecember 31, 2013and changes in2013are shown in the following table.

	Performance Units
	Total Shareholder Return					Earnings Per Share					Restricted Stock
(dollars in millions)	Number of Units			Aggregate Intrinsic Value		Number of Units			Aggregate Intrinsic Value		Number of Shares		Aggregate Intrinsic Value
Units/Shares Outstanding at 12/31/12	224,012					74,670					6,046
Granted	71,850		(A)			23,952		(A)			3,824
Converted	(75,452	)	(B)	$	4.4	(25,152	)	(B)	$	1.5	N/A
Vested	N/A					N/A					(3,038	)	$	0.1
Forfeited	(7,940	)				(2,648	)				(884	)
Employee migration	(5,644	)	(C)			(1,884	)	(C)			—
Units/Shares Outstanding at 12/31/13	206,826			$	9.9	68,938			$	2.7	5,948		$	0.2
Units/Shares Fully Vested at 12/31/13	68,750			$	3.7	22,914			$	1.6

(A) For performance units, this represents the target number of performance units granted.  Actual number of performance units earned, if any, is dependent upon performance and may range from0 percentto200 percentof the target.

(B) These amounts represent performance units that vested atDecember 31, 2012which were settled in February 2013.

(C) Due to certain employees transferring betweenOG&Eand its affiliates.

Schedule of Nonvested Share Activity [Table Text Block]

A summary of the activity forOGE Energy'snon-vested performance units and restricted stockapplicable to OG&E'S employeesatDecember 31, 2013and changes in2013are shown in the following table.

	Performance Units
	Total Shareholder Return					Earnings Per Share					Restricted Stock
	Number of Units			Weighted-Average Grant Date Fair Value		Number of Units			Weighted-Average Grant Date Fair Value		Number of Shares		Weighted-Average Grant Date Fair Value
Units/Shares Non-Vested at 12/31/12	148,560			$	24.51	49,518			$	22.34	6,046		$	24.62
Granted	71,850		(A)	$	25.89	23,952		(A)	$	26.73	3,824		$	29.71
Vested	(68,750	)		$	23.05	(22,914	)		$	20.81	(3,038	)	$	23.51
Forfeited	(7,940	)		$	25.23	(2,648	)		$	24.03	(884	)	$	28.31
Employee migration	(5,644	)	(B)	$	24.74	(1,884	)	(B)	$	23.23	—		$	—
Units/Shares Non-Vested at 12/31/13	138,076			$	25.90	46,024			$	25.25	5,948		$	27.91
Units/Shares Expected to Vest	126,390		(C)			42,130		(C)			5,948

(A) For performance units, this represents the target number of performance units granted.  Actual number of performance units earned, if any, is dependent upon performance and may range from0 percentto200 percentof the target.

(B) Due to certain employees transferring betweenOG&Eand its affiliates.

(C) The intrinsic value of the performance units based on total shareholder return and earnings per share is$5.6 million and $1.1 million, respectively.

Fair Value of Vested Performance Units and Restricted Stock [Table Text Block]

Fair Value of Vested Performance Units and Restricted Stock

A summary of OG&E's fair value for its vested performance units and restricted stock is shown in the following table.

Year ended December 31 (In millions)	2013		2012		2011
Performance units
Total shareholder return	$	1.6	$	1.4	$	1.2
Earnings per share	1.0		0.8		0.6
Restricted stock	0.1		0.1		0.3

Schedule of Unrecognized Compensation Cost, Nonvested Awards [Table Text Block]

Unrecognized Compensation Cost

A summary of OG&E's unrecognized compensation cost for its non-vested performance units and restricted stock and the weighted-average periods over which the compensation cost is expected to be recognized are shown in the following table.

December 31, 2013	Unrecognized Compensation Cost (in millions)		Weighted Average to be Recognized (in years)
Performance units
Total shareholder return	$	1.7	1.63
Earnings per share	0.3		1.52
Total performance units	2.0
Restricted stock	0.1		2.17
Total	$	2.1

Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]

A summary of the activity for OGE Energy's stock optionsapplicable to OG&E'S employeesatDecember 31, 2013and changes during2013are shown in the following table.

(dollars in millions)	Number of Options		Weighted-Average Exercise Price			Aggregate Intrinsic Value		Weighted-Average Remaining Contractual Term
Options Outstanding at 12/31/12	7,000		$	9.62
Exercised	(7,000	)	$	(9.62	)	$	0.2
Options Outstanding at 12/31/13	—		$	—		$	—	0.00	years
Options Fully Vested and Exercisable at 12/31/13	—		$	—		$	—	0.00	years

Exercised Stock Options [Table Text Block]

A summary of the activity for OG&E's exercised stock options in2013, 2012and2011are shown in the following table.

Year ended December 31 (In millions)	2013		2012		2011
Intrinsic value (A)	$	0.2	$	0.2	$	0.3

(A) The difference between the market value on the date of exercise and the option exercise price.

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Supplemental Cash Flow Information (Tables)

12 Months Ended

Dec. 31, 2013

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]

The following table discloses information about investing and financing activities that affected recognized assets and liabilities but which did not result in cash receipts or payments.  Also disclosed in the table iscash paid for interest, net of interest capitalized, and cash paid for income taxes, net of income tax refunds.

Year ended December 31 (In millions)	2013			2012			2011
NON-CASH INVESTING AND FINANCING ACTIVITIES
Installment payments for Tinker electric distribution system	$	—		$	10.6		$	—
Power plant long-term service agreement	9.7			—			1.7
SUPPLEMENTAL CASH FLOW INFORMATION
Cash Paid During the Period for
Interest (net of interest capitalized) (A)	$	127.5		$	122.1		$	108.2
Income taxes (net of income tax refunds)	(5.5		)	(1.2		)	4.5

(A) Net of interest capitalized of$3.4 million, $3.5 millionand$10.4 millionin2013, 2012and2011, respectively.

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STATEMENTS OF CAPITALIZATION (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Stockholder's Equity [Abstract]
Common stock, par value $2.50 per share; authorized 100.0 shares; and outstanding 40.4 and 40.4 shares, respectively	$ 100.9	$ 100.9
Premium on common stock	915.4	913.1
Retained earnings	1,813.0	1,690.4
Accumulated other comprehensive loss, net of tax	0	(1.3)
Total stockholder's equity	2,829.3	2,703.1
Total long-term debt	2,300.2	2,050.3
Total capitalization	5,129.5	4,753.4
OG&E [Member]
Stockholder's Equity [Abstract]
Unamortized discount	(5.5)	(5.8)
OG&E [Member] | Series Due January 15, 2016 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	110.0	110.0
OG&E [Member] | Series Due July 15, 2017 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	125.0	125.0
OG&E [Member] | Series Due September 1, 2018 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	250.0	250.0
OG&E [Member] | Series Due January 15, 2019 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	250.0	250.0
OG&E [Member] | Series Due July 15, 2027 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	125.0	125.0
OG&E [Member] | Series Due April 15, 2028 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	100.0	100.0
OG&E [Member] | Series Due August 1, 2034 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	140.0	140.0
OG&E [Member] | Series Due January 15, 2036 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	110.0	110.0
OG&E [Member] | Series Due February 1, 2038 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	200.0	200.0
OG&E [Member] | Series Due June 1, 2040 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	250.0	250.0
OG&E [Member] | Senior Notes due May 15, 2041 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	250.0	250.0
OG&E [Member] | Series due May 1, 2043 [Member] | Senior Notes [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	250.0	0
OG&E [Member] | Due August 31, 2062 [Member] | Long-term Debt [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	10.3	10.7
Debentures Subject to Mandatory Redemption [Member]
Stockholder's Equity [Abstract]
Total long-term debt	135.4
Debentures Subject to Mandatory Redemption [Member] | OG&E [Member] | Garfield Industrial Authority Bond, Due January 1, 2025 [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	47.0	47.0
Debentures Subject to Mandatory Redemption [Member] | OG&E [Member] | Muskogee Industrial Authority Bond, Due January 1, 2025 [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	32.4	32.4
Debentures Subject to Mandatory Redemption [Member] | OG&E [Member] | Muskogee Industrial Authority Bond, Due June 1, 2027 [Member]
Stockholder's Equity [Abstract]
Long term debt, gross	$ 56.0	$ 56.0

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2013

Income Taxes [Abstract]

Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]

The items comprising income tax expense are as follows:

Year ended December 31 (In millions)	2013			2012			2011
Provision (Benefit) for Current Income Taxes
Federal	$	(3.2	)	$	(9.0	)	$	23.4
State	0.6			0.3			(0.5		)
Total Provision (Benefit) for Current Income Taxes	(2.6		)	(8.7		)	22.9
Provision for Deferred Income Taxes, net
Federal	106.4			111.4			98.0
State	11.7			(5.9		)	0.3
Total Provision for Deferred Income Taxes, net	118.1			105.5			98.3
Deferred Federal Investment Tax Credits, net	(2.0		)	(2.2		)	(3.3		)
Total Income Tax Expense	$	113.5		$	94.6		$	117.9

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]

The following schedule reconciles the statutory Federal tax rate to the effective income tax rate:

Year ended December 31	2013		2012		2011
Statutory Federal tax rate	35.0	%	35.0	%	35.0	%
Amortization of net unfunded deferred taxes	0.8		1.0		0.9
Medicare Part D subsidy	—		—		0.4
Federal investment tax credits, net	(0.5	)	(0.6	)	(0.9	)
State income taxes, net of Federal income tax benefit	—		(0.7	)	0.1
Federal renewable energy credit (A)	(9.2	)	(9.4	)	(4.4	)
Uncertain tax positions	2.0		—		—
Other	(0.2	)	(0.1	)	(0.2	)
Effective income tax rate	27.9	%	25.2	%	30.9	%

(A) Represents credits associated with the production from OG&E's wind farms.

Schedule of Deferred Tax Assets and Liabilities [Table Text Block]

The deferred tax provisions are recognized as costs in the ratemaking process by the commissions having jurisdiction over the rates charged by OG&E.The components of Deferred Income Taxes atDecember 31, 2013and2012, respectively, were as follows:

December 31 (In millions)	2013			2012
Current Deferred Income Tax Assets
Net operating losses	$	168.7		$	113.8
Accrued liabilities	9.0			14.0
Federal tax credits	8.0			6.0
Accrued vacation	2.8			3.1
Uncollectible accounts	0.7			1.0
Derivative instruments	—			0.8
Total Current Deferred Income Tax Assets	$	189.2		$	138.7
Non-Current Deferred Income Tax Liabilities
Accelerated depreciation and other property related differences	$	1,747.0		$	1,648.5
OG&E pension plan	84.7			102.2
Regulatory asset	26.0			18.8
Income taxes refundable to customers, net	21.9			21.2
Bond redemption-unamortized costs	3.6			4.0
Total Non-Current Deferred Income Tax Liabilities	1,883.2			1,794.7
Non-Current Deferred Income Tax Assets
Federal tax credits	(101.9		)	(69.5		)
State tax credits	(86.1		)	(78.1		)
Regulatory liabilities	(61.3		)	(71.4		)
Postretirement medical and life insurance benefits	(45.2		)	(42.1		)
Asset retirement obligations	(20.8		)	—
Net operating losses	(17.6		)	(150.0		)
Deferred Federal investment tax credits	(0.7		)	(1.5		)
Other	(4.4		)	(4.3		)
Total Non-Current Deferred Income Tax Assets	(338.0		)	(416.9		)
Non-Current Deferred Income Tax Liabilities, net	$	1,545.2		$	1,377.8

Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block]

Following is a reconciliation of the OG&E’s total gross unrecognized tax benefits as of the years ended December 31, 2013, 2012, and 2011.

(Millions)	2013		2012		2011
Balance at January 1	$	—	$	—	$	—
Tax positions related to current year:
Additions	2.7		—		—
Tax positions related to prior years:
Additions	5.1		—		—
Balance at December 31	$	7.8	$	—	$	—

Summary of Tax Credit Carryforwards [Table Text Block]

Other

OG&E sustained Federal and state tax operating losses through2012caused primarily by bonus depreciation and other book verses tax temporary differences. As a result, OG&E had accrued Federal and state income tax benefits carrying into2013. As OG&E can no longer carry these losses back to prior periods, these losses are being carried forward for utilization in future years.In addition to the operating losses, OG&E was unable to utilize the various tax credits that were generating during these years.These tax losses and credits are being carried as deferred tax assets and will be utilized in future periods.Under current law, OG&E anticipates future taxable income will be sufficient to utilize all of the losses and credits before they begin to expire, accordingly no valuation allowance is considered necessary.The following table summarizes these carry forwards:

(In millions)	Carry Forward Amount		Deferred Tax Asset		Earliest Expiration Date
Net operating losses
State operating loss	$	656.3	$	24.2	2030
Federal operating loss	463.1		162.1		2030
Federal tax credits	109.9		109.9		2029
State tax credits
Oklahoma investment tax credits	96.3		62.6		N/A
Oklahoma capital investment board credits	7.3		7.3		N/A
Oklahoma zero emission tax credits	24.1		16.2		2020

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Summary of Significant Accounting Policies Allowance for Uncollectible Accounts Receviable (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Accounts receivable reserve	$ 1.9	$ 2.6

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Income Taxes (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Current Federal Tax Expense (Benefit)	$ (3.2)		$ (9.0)		$ 23.4
Current State and Local Tax Expense (Benefit)	0.6		0.3		(0.5)
Current Income Tax Expense (Benefit)	(2.6)		(8.7)		22.9
Deferred Federal Income Tax Expense (Benefit)	106.4		111.4		98.0
Deferred State and Local Income Tax Expense (Benefit)	11.7		(5.9)		0.3
Deferred Income Tax Expense (Benefit)	118.1		105.5		98.3
Investment Tax Credit	(2.0)		(2.2)		(3.3)
Income Tax Expense (Benefit)	113.5		94.6		117.9
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate	35.00%		35.00%		35.00%
Effective Income Tax Rate Reconciliation Amortization of Net Unfunded Deferred Taxes	0.80%		1.00%		0.90%
Effective Income Tax Rate Reconciliation, Deductions, Medicare Prescription Drug Benefit	0.00%		0.00%		0.40%
Effective Income Tax Rate Reconciliation, Tax Credits, Investment	(0.50%)		(0.60%)		(0.90%)
Effective Income Tax Rate Reconciliation, State and Local Income Taxes	0.00%		(0.70%)		0.10%
Effective Income Tax Rate Reconciliation, Tax Credits, Other	(9.20%)	[1]	(9.40%)	[1]	(4.40%)	[1]
Effective Income Tax Rate Reconciliation, Tax Contingency, Percent	2.00%		0.00%		0.00%
Effective Income Tax Rate Reconciliation, Other Adjustments	(0.20%)		(0.10%)		(0.20%)
Effective Income Tax Rate, Continuing Operations	27.90%		25.20%		30.90%
Deferred Tax Assets, Operating Loss Carryforwards	168.7		113.8
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Accrued Liabilities	9.0		14.0
Current Deferred Tax Assets, Federal Tax Credits	8.0		6.0
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Other	2.8		3.1
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Allowance for Doubtful Accounts	0.7		1.0
Deferred Tax Assets, Derivative Instruments	0		0.8
Deferred Tax Assets, Gross, Current	189.2		138.7
Deferred Tax Liabilities, Property, Plant and Equipment	1,747.0		1,648.5
Deferred Tax Liabilities, Prepaid Expenses	84.7		102.2
Deferred Tax Liabilities, Regulatory Assets	26.0		18.8
Deferred Tax Liabilities, Income Taxes Refundable to Customers, Net	21.9		21.2
Deferred Tax Liabilities, Unamortized Bond Redemption Costs	3.6		4.0
Deferred Tax Liabilities, Gross, Noncurrent	1,883.2		1,794.7
Deferred Tax Assets, Tax Credit Carryforwards	(101.9)		(69.5)
Non-Current Deferred Tax Assets, State Tax Credits	(86.1)		(78.1)
Non-Current Deferred Tax Assets, Regulatory Liabilities	(61.3)		(71.4)
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits	(45.2)		(42.1)
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Asset Retirement Obligations	(20.8)		0
Non-Current Deferred Tax Asset, Net Operating Losses	(17.6)		(150.0)
Non-Current Deferred Tax Assets, Deferred Federal Investment Tax Credits	(0.7)		(1.5)
Deferred Tax Assets, Other	(4.4)		(4.3)
Deferred Tax Assets, Gross, Noncurrent	(338.0)		(416.9)
Deferred Tax Liabilities, Net, Noncurrent	1,545.2		1,377.8
Unrecognized Tax Benefits	7.8		0		0		0
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions	2.7		0		0
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions	5.1		0		0
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	0
State operating loss [Member]
Tax Credit Carryforward, Amount	656.3
Tax Credit Carryforward, Deferred Tax Asset	24.2
Tax Credit Carryforward, Expiration Date	Dec. 31, 2030
Federal operating loss [Member]
Tax Credit Carryforward, Amount	463.1
Tax Credit Carryforward, Deferred Tax Asset	162.1
Tax Credit Carryforward, Expiration Date	Dec. 31, 2030
Federal tax credits [Member]
Tax Credit Carryforward, Amount	109.9
Tax Credit Carryforward, Deferred Tax Asset	109.9
Tax Credit Carryforward, Expiration Date	Dec. 31, 2029
Oklahoma investment tax credits [Member]
Tax Credit Carryforward, Amount	96.3
Tax Credit Carryforward, Deferred Tax Asset	62.6
Oklahoma capital investment board credits [Member]
Tax Credit Carryforward, Amount	7.3
Tax Credit Carryforward, Deferred Tax Asset	7.3
Oklahoma zero emission tax credits [Member]
Tax Credit Carryforward, Amount	24.1
Tax Credit Carryforward, Deferred Tax Asset	16.2
Tax Credit Carryforward, Expiration Date	Dec. 31, 2020
FIN 48 reserve, gross [Member]
Income Tax Reconciliation, Tax Contingencies, State and Local	7.8
FIN 48 reserve, net of tax [Member]
Income Tax Reconciliation, Tax Contingencies, State and Local	5.1
Additional FIN 48 Reserve [Member]
Income Tax Reconciliation, Tax Contingencies, State and Local	4.1
Additional FIN 48 reserve, net of tax [Member]
Income Tax Reconciliation, Tax Contingencies, State and Local	2.7
Federal operating loss [Member]
Deferred Tax Assets, Operating Loss Carryforwards	$ 168.7

[1] Represents credits associated with the production from OG&E's wind farms.

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STATEMENTS OF INCOME (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
OPERATING REVENUES	$ 2,262.2	$ 2,141.2	$ 2,211.5
COST OF SALES	965.9	879.1	1,013.5
OPERATING EXPENSES
Other operation and maintenance	438.8	446.3	436.0
Depreciation and amortization	248.4	248.7	216.1
Taxes other than income	83.8	77.7	73.6
Total operating expenses	771.0	772.7	725.7
OPERATING INCOME	525.3	489.4	472.3
OTHER INCOME (EXPENSE)
Allowance for borrowed funds used during construction	6.6	6.2	20.4
Other income	8.1	8.2	8.5
Other expense	(4.6)	(4.3)	(8.4)
Net other income (expense)	10.1	10.1	20.5
INTEREST EXPENSE
Interest on long-term debt	130.6	124.2	118.7
Allowance for borrowed funds used during construction	(3.4)	(3.5)	(10.4)
Interest on short-term debt and other interest charges	2.1	3.9	3.3
Interest expense	129.3	124.6	111.6
INCOME BEFORE TAXES	406.1	374.9	381.2
INCOME TAX EXPENSE	113.5	94.6	117.9
NET INCOME	$ 292.6	$ 280.3	$ 263.3

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Summary of Significant Accounting Policies Allowance for Funds Used During Construction (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Public Utilities, Allowance for Funds Used During Construction, Rate	8.33%	8.93%	8.71%

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BALANCE SHEETS (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
CURRENT ASSETS
Accounts receivable, less reserve of $1.9 and $2.6, respectively	$ 179.4	$ 161.5
Accrued unbilled revenues	58.7	57.4
Advances to parent	0	90.3
Fuel inventories	74.4	76.8
Materials and supplies, at average cost	79.4	74.7
Deferred income taxes	189.2	138.7
Fuel clause under recoveries	26.2	0
Other	31.9	34.6
Total current assets	639.2	634.0
OTHER PROPERTY AND INVESTMENTS	2.6	2.7
Public Utilities, Property, Plant and Equipment, Plant in Service	9,036.4	8,498.3
PROPERTY, PLANT AND EQUIPMENT
Construction work in progress	462.8	251.4
Total property, plant and equipment	9,499.2	8,749.7
Less accumulated depreciation	2,864.6	2,705.6
Net property, plant and equipment	6,634.6	6,044.1
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	379.1	510.6
Other	39.4	31.0
Total deferred charges and other assets	418.5	541.6
TOTAL ASSETS	7,694.9	7,222.4
CURRENT LIABILITIES
Accounts payable - affiliates	1.8	0.7
Accounts payable - other	237.2	186.7
Advances from parent	87.2	0
Customer deposits	70.9	68.5
Accrued taxes	38.0	35.0
Accrued interest	42.8	43.2
Accrued compensation	30.0	33.2
Fuel clause over recoveries	0.4	109.2
Other	46.8	56.0
Total current liabilities	555.1	532.5
LONG-TERM DEBT	2,300.2	2,050.3
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	149.0	240.9
Deferred income taxes	1,545.2	1,377.8
Deferred investment tax credits	1.9	3.9
Regulatory liabilities	234.2	245.1
Other	80.0	68.8
Total deferred credits and other liabilities	2,010.3	1,936.5
Total liabilities	4,865.6	4,519.3
COMMITMENTS AND CONTINGENCIES (NOTE 12)
STOCKHOLDER'S EQUITY
Common stockholder's equity	1,016.3	1,014.0
Retained earnings	1,813.0	1,690.4
Accumulated other comprehensive loss, net of tax	0	(1.3)
Total stockholder's equity	2,829.3	2,703.1
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY	$ 7,694.9	$ 7,222.4

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Commitments and Contingencies Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Loss Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	$ 726,500,000
Unrecorded Unconditional Purchase Obligation, Due within Two Years	657,100,000
Unrecorded Unconditional Purchase Obligation, Due within Three Years	588,400,000
Unrecorded Unconditional Purchase Obligation, Due within Four Years	609,600,000
Unrecorded Unconditional Purchase Obligation, Due within Five Years	243,000,000
Unrecorded Unconditional Purchase Obligation	2,824,600,000
Utilities Operating Expense, Purchased Power under Long-term Contracts	62,000,000	49,500,000	36,700,000
Operating Leases, Rent Expense, Net	5,700,000	5,800,000	4,200,000
Operating Leases, Future Minimum Payments Due, Next Twelve Months	5,900,000
Operating Leases, Future Minimum Payments, Due in Two Years	5,200,000
Operating Leases, Future Minimum Payments, Due in Three Years	29,400,000
Operating Leases, Future Minimum Payments, Due in Four Years	2,400,000
Operating Leases, Future Minimum Payments, Due in Five Years	2,400,000
Estimated Environmental Capital Costs	1,000,000,000
Operating Leases, Future Minimum Payments, Due Thereafter	48,800,000
Operating Leases, Future Minimum Payments Due	94,100,000
Potential Penalty Under the Federal Clean Air Act	37,500
OG&E Railcar Lease Agreement [Member]
Loss Contingencies [Line Items]
Loss Contingency, Range of Possible Loss, Maximum	22,800,000
Public Utility Regulatory Policy Act of 1978 [Member]
Loss Contingencies [Line Items]
Percentage of output purchased	100.00%
OG&E total cogeneration payments [Member]
Loss Contingencies [Line Items]
Long-term Purchase Commitment, Amount	134,800,000	135,100,000	140,700,000
OG&E capacity payments [Member]
Loss Contingencies [Line Items]
Long-term Purchase Commitment, Amount	74,400,000	77,100,000	78,000,000
CPV Keenan [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts	30,900,000	25,100,000	24,500,000
Edison Mission Energy [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts	20,600,000	20,200,000	8,500,000
FPL Energy [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts	3,300,000	3,400,000	3,700,000
OG&E cogeneration capacity and fixed operation and maintenance payments [Member]
Loss Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	85,100,000
Unrecorded Unconditional Purchase Obligation, Due within Two Years	82,700,000
Unrecorded Unconditional Purchase Obligation, Due within Three Years	81,900,000
Unrecorded Unconditional Purchase Obligation, Due within Four Years	79,600,000
Unrecorded Unconditional Purchase Obligation, Due within Five Years	77,000,000
Unrecorded Unconditional Purchase Obligation	406,300,000
OG&E expected cogeneration energy payments [Member]
Loss Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	61,100,000
Unrecorded Unconditional Purchase Obligation, Due within Two Years	60,900,000
Unrecorded Unconditional Purchase Obligation, Due within Three Years	75,700,000
Unrecorded Unconditional Purchase Obligation, Due within Four Years	81,500,000
Unrecorded Unconditional Purchase Obligation, Due within Five Years	87,400,000
Unrecorded Unconditional Purchase Obligation	366,600,000
OG&E minimum fuel purchase commitments [Member]
Loss Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	451,800,000
Unrecorded Unconditional Purchase Obligation, Due within Two Years	451,800,000
Unrecorded Unconditional Purchase Obligation, Due within Three Years	368,500,000
Unrecorded Unconditional Purchase Obligation, Due within Four Years	385,100,000
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0
Unrecorded Unconditional Purchase Obligation	1,657,200,000
Long-term Purchase Commitment, Amount	680,800,000	653,700,000	729,800,000
Percentage of OG&E's Projected 2014 Requirements	31.50%
OG&E expected wind purchase commitments [Member]
Loss Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	58,000,000
Unrecorded Unconditional Purchase Obligation, Due within Two Years	58,900,000
Unrecorded Unconditional Purchase Obligation, Due within Three Years	59,800,000
Unrecorded Unconditional Purchase Obligation, Due within Four Years	60,800,000
Unrecorded Unconditional Purchase Obligation, Due within Five Years	59,500,000
Unrecorded Unconditional Purchase Obligation	297,000,000
OG&E long-term service agreement commitments [Member]
Loss Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	70,500,000
Unrecorded Unconditional Purchase Obligation, Due within Two Years	2,800,000
Unrecorded Unconditional Purchase Obligation, Due within Three Years	2,500,000
Unrecorded Unconditional Purchase Obligation, Due within Four Years	2,600,000
Unrecorded Unconditional Purchase Obligation, Due within Five Years	19,100,000
Unrecorded Unconditional Purchase Obligation	97,500,000
NextEra Energy [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts	7,200,000	800,000	0
OG&E long-term service agreement commitments [Member] | McClain Plant [Member]
Loss Contingencies [Line Items]
Factored-Fired Hours	128,000
Factored-Fired Starts	3,600
OG&E long-term service agreement commitments [Member] | Redbud Plant [Member]
Loss Contingencies [Line Items]
Factored-Fired Hours	144,000
Additional Factored-Fired Hours	24,000
Factored-Fired Starts	4,500
OG&E Wind Energy Purchase Power Lawsuit [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual	4,300,000
OG&E Railcar Lease Agreement [Member]
Loss Contingencies [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	3,800,000
Operating Leases, Future Minimum Payments, Due in Two Years	3,100,000
Operating Leases, Future Minimum Payments, Due in Three Years	27,300,000
Operating Leases, Future Minimum Payments, Due in Four Years	0
Operating Leases, Future Minimum Payments, Due in Five Years	0
Operating Leases, Future Minimum Payments, Due Thereafter	0
Operating Leases, Future Minimum Payments Due	34,200,000
OG&E Wind Farm Land Lease Agreements [Member]
Loss Contingencies [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	2,100,000
Operating Leases, Future Minimum Payments, Due in Two Years	2,100,000
Operating Leases, Future Minimum Payments, Due in Three Years	2,100,000
Operating Leases, Future Minimum Payments, Due in Four Years	2,400,000
Operating Leases, Future Minimum Payments, Due in Five Years	2,400,000
Operating Leases, Future Minimum Payments, Due Thereafter	48,800,000
Operating Leases, Future Minimum Payments Due	$ 59,900,000

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Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2012

Commitments and Contingencies Disclosure [Abstract]

Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]

Operating Lease Obligations

OG&E has operating lease obligations expiring at various dates, primarily forrailcar leases and wind farm land leases. Future minimum payments for noncancellable operating leasesare as follows:

Year ended December 31 (In millions)	2014		2015		2016		2017		2018		After 2018		Total
Operating lease obligations
Railcars	$	3.8	$	3.1	$	27.3	$	—	$	—	$	—	$	34.2
Wind farm land leases	2.1		2.1		2.1		2.4		2.4		48.8		59.9
Total operating lease obligations	$	5.9	$	5.2	$	29.4	$	2.4	$	2.4	$	48.8	$	94.1

Unrecorded Unconditional Purchase Obligations Disclosure [Table Text Block]

Other Purchase Obligations and Commitments

OG&E's other future purchase obligations and commitments estimated for the next five years are as follows:

(In millions)	2014		2015		2016		2017		2018		Total
Other purchase obligations and commitments
Cogeneration capacity and fixed operation and maintenance payments	$	85.1	$	82.7	$	81.9	$	79.6	$	77.0	$	406.3
Expected cogeneration energy payments	61.1		60.9		75.7		81.5		87.4		366.6
Minimum fuel purchase commitments	451.8		451.8		368.5		385.1		—		1,657.2
Expected wind purchase commitments	58.0		58.9		59.8		60.8		59.5		297.0
Long-term service agreement commitments	70.5		2.8		2.5		2.6		19.1		97.5
Total other purchase obligations and commitments	$	726.5	$	657.1	$	588.4	$	609.6	$	243.0	$	2,824.6

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Commitments and Contingencies

12 Months Ended

Dec. 31, 2012

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Operating Lease Obligations

OG&E has operating lease obligations expiring at various dates, primarily forrailcar leases and wind farm land leases. Future minimum payments for noncancellable operating leasesare as follows:

Year ended December 31 (In millions)	2014		2015		2016		2017		2018		After 2018		Total
Operating lease obligations
Railcars	$	3.8	$	3.1	$	27.3	$	—	$	—	$	—	$	34.2
Wind farm land leases	2.1		2.1		2.1		2.4		2.4		48.8		59.9
Total operating lease obligations	$	5.9	$	5.2	$	29.4	$	2.4	$	2.4	$	48.8	$	94.1

Payments for operating lease obligations were$5.7 million, $5.8 millionand$4.2 millionfor the years endedDecember 31, 2013, 2012and2011, respectively.

Railcar Lease Agreement

OG&E has a noncancellable operating lease with purchase options, covering 1,389 coal rotary gondola railcars to transport coal from Wyoming to OG&E's coal-fired generation units.  Rental payments are charged to Fuel Expense and are recovered through OG&E's tariffs and fuel adjustment clauses. On December 15, 2010, OG&E renewed the lease agreement effective February 1, 2011.  At the end of the new lease term, which is February 1, 2016, OG&E has the option to either purchase the railcars at a stipulated fair market value or renew the lease.  If OG&E chooses not to purchase the railcars or renew the lease agreement and the actual fair value of the railcars is less than the stipulated fair market value, OG&E would be responsible for the difference in those values up to a maximum of$22.8 million. OG&E is also required to maintain all of the railcars it has under the operating lease and has entered into an agreement with a non-affiliated company to furnish this maintenance.

On January 11, 2012, OG&E executed a five-year lease agreement for 135 railcars to replace railcars that have been taken out of service or destroyed. OG&E has a unilateral right to terminate this lease upon a 6-month notice effective April 2015 and April 2016.

Wind Farm Land Lease Agreements

OG&E has wind farm land operating leases for its Centennial, OU Spirit and Crossroads wind farms expiring at various dates. The Centennial lease has rent escalations which increase annually based on the Consumer Price Index. The OU Spirit and Crossroads leases have rent escalations which increase after five and 10 years. Although the leases are cancellable, OG&E is required to make annual lease payments as long as the wind turbines are located on the land. OG&E does not expect to terminate the leases until the wind turbines reach the end of their economic life.

Other Purchase Obligations and Commitments

OG&E's other future purchase obligations and commitments estimated for the next five years are as follows:

(In millions)	2014		2015		2016		2017		2018		Total
Other purchase obligations and commitments
Cogeneration capacity and fixed operation and maintenance payments	$	85.1	$	82.7	$	81.9	$	79.6	$	77.0	$	406.3
Expected cogeneration energy payments	61.1		60.9		75.7		81.5		87.4		366.6
Minimum fuel purchase commitments	451.8		451.8		368.5		385.1		—		1,657.2
Expected wind purchase commitments	58.0		58.9		59.8		60.8		59.5		297.0
Long-term service agreement commitments	70.5		2.8		2.5		2.6		19.1		97.5
Total other purchase obligations and commitments	$	726.5	$	657.1	$	588.4	$	609.6	$	243.0	$	2,824.6

Public Utility Regulatory Policy Act of 1978

AtDecember 31, 2013, OG&E has QF contracts having terms of15to32years.  These contracts were entered into pursuant to the Public Utility Regulatory Policy Act of 1978.  Stated generally, the Public Utility Regulatory Policy Act of 1978 and the regulations thereunder promulgated by the FERC require OG&E to purchase power generated in a manufacturing process from a QF.  The rate for such power to be paid by OG&E was approved by the OCC.  The rate generally consists of two components: one is a rate for actual electricity purchased from the QF by OG&E; the other is a capacity charge, which OG&E must pay the QF for having the capacity available.  However, if no electrical power is made available to OG&E for a period of time (generally three months), OG&E's obligation to pay the capacity charge is suspended.  The total cost of cogeneration payments is recoverable in rates from customers.  For the320MW AES-Shady Point, Inc. QF contract and the120MW PowerSmith Cogeneration Project, L.P. QF contract, OG&E purchases100 percentof the electricity generated by the QFs.

For the years endedDecember 31, 2013, 2012and2011, OG&E made total payments to cogenerators of$134.8 million, $135.1 millionand$140.7 million, respectively, of which$74.4 million, $77.1 millionand$78.0 million, respectively, represented capacity payments.  All payments for purchased power, including cogeneration, are included in theStatements of Income as Cost of Sales.

Minimum Fuel Purchase Commitments

OG&E purchased necessary fuel supplies of coal and natural gas for its generating units of$680.8 million, $653.7 millionand$729.8 millionfor the years endedDecember 31, 2013, 2012and2011, respectively.OG&E has coal contracts for purchases from through December 2016.OG&E has entered into multiple month term natural gas contracts for31.5 percentof its 2014 annual forecasted natural gas requirements. Additional gas supplies to fulfill OG&E's remaining 2014 natural gas requirements will be acquired through additional requests for proposal in early to mid-2014, along with monthly and daily purchases, all of which are expected to be made at market prices.

Wind Purchase Commitments

OG&E's current wind power portfolio includes: (i) the120MW Centennial wind farm, (ii) the101MW OU Spirit wind farm, (iii) the227.5MW Crossroads wind farm, (iv) access to up to50MWs of electricity generated at a wind farm near Woodward, Oklahoma from a 15-year contract OG&E entered into with FPL Energy that expires in 2018, (v) access to up to150MWs of electricity generated at a wind farm in Woodward County, Oklahoma from a 20-year contract OG&E entered into with CPV Keenan that expires in 2030, (vi) access to up to130MWs of electricity generated at a wind farm in Dewey County, Oklahoma from a 20-year contract OG&E entered into with Edison Mission Energy that expires in 2030 and (vii) access to up to60MWs of electricity generated at a wind farm near Blackwell, Oklahoma from a 20-year contract OG&E entered into with NextEra Energy that expires in 2032.

The following table summarizes OG&E's wind power purchases for the years endedDecember 31, 2013, 2012and2011. 

Year ended December 31 (In millions)	2013		2012		2011
CPV Keenan	$	30.9	$	25.1	$	24.5
Edison Mission Energy	20.6		20.2		8.5
FPL Energy	3.3		3.4		3.7
NextEra Energy	7.2		0.8		—
Total wind power purchased	$	62.0	$	49.5	$	36.7

Long-Term Service Agreement Commitments

OG&E has a long-term parts and service maintenance contract for the upkeep of the McClain Plant.  The existing contract will expire on January 1, 2015. In May 2013, a new contract was signed that is expected to run for the earlier of128,000factored-fired hours or3,600factored-fired starts. Based on historical usage and current expectations for future usage, this contract is expected to run until 2030. The contract requires payments based on both a fixed and variable cost component, depending on how much the McClain Plant is used.

OG&E has a long-term parts and service maintenance contract for the upkeep of the Redbud Plant. In March 2013, the contract was amended to extend the contract coverage for an additional24,000factored-fired hours resulting in a maximum of the earlier of144,000factored-fired hours or4,500factored-fired starts. Based on historical usage and current expectations for future usage, this contract is expected to run until 2031. The contract requires payments based on both a fixed and variable cost component, depending on how much the Redbud Plant is used.

Wind Energy Purchased Power Lawsuit

In 2009, OG&E entered into a wind energy purchase power agreement with CPV Keenan for the purchase of all the energy output from its150MW wind farm in Woodward County, Oklahoma. In August of 2013, CPV Keenan filed suit against OG&E for the non-payment of curtailment charges.In December 2013, OG&E settled its current case with CPV Keenan and recorded additional purchased power expense of$4.3 million, which will be recovered through the fuel adjustment clause.

Enable Gas Transportation and Storage Agreement

OG&E contracts with Enable for gas transportation and storage services. The stated term of this contract expired April 30, 2009, but remained in effect from year-to-year thereafter. On January 31, 2014, in anticipation of entering into a new, five-year contract, OG&E provided written notice of termination of the contract, effective April 30, 2014. Negotiations regarding the new contract are ongoing, and there can be no assurance that the new contract will be agreed upon, or if agreed upon, that the terms of the new contract will be as favorable to us as the expiring contract.

Environmental Laws and Regulations

The activities ofOG&Eare subject to stringent and complex Federal, state and local laws and regulations governing environmental protection relating to air quality, water quality, waste management, wildlife conservation and natural resources. These laws and regulations can restrict or impact business activities in many ways, such as restricting the way it can handle or dispose of its wastes, requiring remedial action to mitigate environmental issues that may be caused by its operations or that are attributable to former operators, requiring changes in operations and requiring the installation and operation of pollution control equipment. Failure to comply with these laws and regulations could result in the assessment of administrative, civil and criminal penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations.

Environmental regulation can increase the cost of planning, design, initial installation and operation of OG&E's facilities. Historically, OG&E's total expenditures for environmental control facilities and for remediation have not been significant in relation to itsfinancial position or results of operations.OG&Ebelieves, however, that it is reasonably likely that the trend in environmental legislation and regulations will continue towards more restrictive standards.  Compliance with these standards is expected to increase the cost of conducting business. Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

OG&E is managing several significant uncertainties about the scope and timing for the acquisition, installation and operation of additional pollution control equipment and compliance costs for a variety of the EPA rules that are being challenged in court.OG&E is unable to predict the financial impact of these matters with certainty at this time.See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Environmental Laws and Regulations" for a discussion of OG&E's environmental matters.

Federal Clean Air Act New Source Review Litigation

As previously reported, in July 2008, OG&E received a request for information from the EPA regarding Federal Clean Air Act compliance at OG&E's Muskogee and Sooner generating plants. In recent years, the EPA has issued similar requests to numerous other electric utilities seeking to determine whether various maintenance, repair and replacement projects should have required permits under the Federal Clean Air Act's new source review process. In January 2012, OG&E received a supplemental request for an update of the previously provided information and for some additional information not previously requested. On May 1, 2012, OG&E responded to the EPA's supplemental request for information. On April 26, 2011, the EPA issued a notice of violation alleging that 13 projects occurred at OG&E's Muskogee and Sooner generating plants between 1993 and 2006 without the required new source review permits. The notice of violation also alleges that OG&E's visible emissions at its Muskogee and Sooner generating plants are not in accordance with applicable new source performance standards.

In March 2013, the DOJ informed OG&E that it was prepared to initiate enforcement litigation concerning the matters identified in the notice of violation. OG&E subsequently met with EPA and DOJ representatives regarding the notice of violation and proposals for resolving the matter without litigation. On July 8, 2013, the United States, at the request of the EPA, filed a complaint for declaratory relief against OG&E in United States District Court for the Western District of Oklahoma (Case No. CIV-13-690-D) alleging that OG&E did not follow the Federal Clean Air Act procedures for projecting emission increases attributable to eight projects that occurred between 2003 and 2006. This complaint seeks to have OG&E submit a new assessment of whether the projects were likely to result in a significant emissions increase. The Sierra Club has intervened in this proceeding and has asserted claims for declaratory relief that are similar to those requested by the United States. OG&E expects to vigorously defend against these claims, but OG&E cannot predict the outcome of such litigation. On August 12, 2013, the Sierra Club filed a complaint against OG&E in the United States District Court for the Eastern District of Oklahoma (Case No. 13-CV-00356) alleging that OG&E modifications made at Unit 6 of the Muskogee generating plant in 2008 were made without obtaining a prevention of significant deterioration permit and that the plant has exceeded emissions limits for opacity and particulate matter. The Sierra Club seeks a permanent injunction preventing OG&E from operating the Muskogee generating plant. At this time, OG&E continues to believe that it has acted in compliance with the Federal Clean Air Act.

If OG&E does not prevail in these proceedings and if a new assessment of the projects were to conclude that they caused a significant emissions increase, the EPA and the Sierra Club could seek to require OG&E to install additional pollution control equipment, including scrubbers, baghouses and selective catalytic reduction systems with capital costs in excess of$1.0 billionand pay fines and significant penalties as a result of the allegations in the notice of violation. Section 113 of the Federal Clean Air Act (along with the Federal Civil Penalties Inflation Adjustment Act of 1996) provides for civil penalties as much as$37,500per day for each violation. The cost of any required pollution control equipment could also be significant. OG&E cannot predict at this time whether it will be legally required to incur any of these costs.

Other

In the normal course of business,OG&Eis confronted with issues or events that may result in a contingent liability.These generally relate to lawsuits or claims made by third parties, including governmental agencies.When appropriate, management consults with legal counsel and other appropriate experts to assess the claim.If, in management's opinion,OG&Ehas incurred a probable loss as set forth by GAAP, an estimate is made of the loss and the appropriate accounting entries are reflected inOG&E'sFinancial Statements.At the present time, based on currently available information, except as otherwise stated above, in Note 13 below, in Item 3 of Part I and under "Environmental Laws and Regulations" in Item 7 of Part IIof this Form 10-K, OG&Ebelieves that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect onOG&E'sfinancial position, results of operations or cash flows.

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Quarterly Financial Data (Tables)

12 Months Ended

Dec. 31, 2012

Quarterly Financial Data [Abstract]

Schedule of Quarterly Financial Information [Table Text Block]

Due to the seasonal fluctuations and other factors of OG&E's business, the operating results for interim periods are not necessarily indicative of the results that may be expected for the year.In OG&E's opinion, the following quarterly financial data includes all adjustments, consisting of normal recurring adjustments, necessary to fairly present such amounts.Summarizedquarterly unaudited financial data is as follows:

Quarter ended (In millions)		March 31		June 30		September 30		December 31		Total
Operating revenues	2013	$	455.5	$	574.6	$	723.2	$	508.9	$	2,262.2
	2012	$	426.7	$	528.0	$	721.0	$	465.5	$	2,141.2
Operating income	2013	$	52.9	$	138.1	$	261.0	$	73.3	$	525.3
	2012	$	39.8	$	127.8	$	258.0	$	63.8	$	489.4
Net income	2013	$	13.0	$	79.0	$	171.5	$	29.1	$	292.6
	2012	$	12.1	$	73.4	$	167.2	$	27.6	$	280.3

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Quarterly Financial Data

12 Months Ended

Dec. 31, 2012

Quarterly Financial Data [Abstract]

Quarterly Financial Information [Text Block]

Quarterly Financial Data (Unaudited)

Due to the seasonal fluctuations and other factors of OG&E's business, the operating results for interim periods are not necessarily indicative of the results that may be expected for the year.In OG&E's opinion, the following quarterly financial data includes all adjustments, consisting of normal recurring adjustments, necessary to fairly present such amounts.Summarizedquarterly unaudited financial data is as follows:

Quarter ended (In millions)		March 31		June 30		September 30		December 31		Total
Operating revenues	2013	$	455.5	$	574.6	$	723.2	$	508.9	$	2,262.2
	2012	$	426.7	$	528.0	$	721.0	$	465.5	$	2,141.2
Operating income	2013	$	52.9	$	138.1	$	261.0	$	73.3	$	525.3
	2012	$	39.8	$	127.8	$	258.0	$	63.8	$	489.4
Net income	2013	$	13.0	$	79.0	$	171.5	$	29.1	$	292.6
	2012	$	12.1	$	73.4	$	167.2	$	27.6	$	280.3

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BALANCE SHEETS Parenthetical (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Accounts receivable reserve	$ 1.9	$ 2.6

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STATEMENTS OF COMPREHENSIVE INCOME (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net income	$ 292.6	$ 280.3	$ 263.3
Other comprehensive income (loss), net of tax
Deferred commodity contracts hedging (gains) losses reclassified in net income, net of tax of $0.8, $0.7 and ($0.1), respectively	1.3	1.2	(0.4)
Comprehensive income (loss)	293.9	281.5	262.9
Retained Earnings [Member]
Net income	$ 292.6	$ 280.3	$ 263.3

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Income Taxes

12 Months Ended

Dec. 31, 2013

Income Tax Disclosure [Abstract]

Income Tax Disclosure Text Block

Income Taxes

The items comprising income tax expense are as follows:

Year ended December 31 (In millions)	2013			2012			2011
Provision (Benefit) for Current Income Taxes
Federal	$	(3.2	)	$	(9.0	)	$	23.4
State	0.6			0.3			(0.5		)
Total Provision (Benefit) for Current Income Taxes	(2.6		)	(8.7		)	22.9
Provision for Deferred Income Taxes, net
Federal	106.4			111.4			98.0
State	11.7			(5.9		)	0.3
Total Provision for Deferred Income Taxes, net	118.1			105.5			98.3
Deferred Federal Investment Tax Credits, net	(2.0		)	(2.2		)	(3.3		)
Total Income Tax Expense	$	113.5		$	94.6		$	117.9

OG&E isa member of an affiliated group thatfilesconsolidated income tax returns in the U.S. Federal jurisdiction and various state jurisdictions. With few exceptions, OG&E is no longer subject to U.S. Federal tax examinations by tax authorities for years prior to2010or state and local tax examinations by tax authorities for years prior to2009.  Income taxesaregenerally allocated to each company in the affiliated group based on its stand-alone taxable income or loss.Federal investment tax credits previously claimed on electric utility property have been deferred and are being amortized to income over the life of the related property.OG&E earns both Federal and Oklahoma state tax credits associated with production from its wind farms and earns Oklahoma state tax credits associated with its investments inelectric generatingfacilities which further reduce OG&E's effective tax rate.The following schedule reconciles the statutory Federal tax rate to the effective income tax rate:

Year ended December 31	2013		2012		2011
Statutory Federal tax rate	35.0	%	35.0	%	35.0	%
Amortization of net unfunded deferred taxes	0.8		1.0		0.9
Medicare Part D subsidy	—		—		0.4
Federal investment tax credits, net	(0.5	)	(0.6	)	(0.9	)
State income taxes, net of Federal income tax benefit	—		(0.7	)	0.1
Federal renewable energy credit (A)	(9.2	)	(9.4	)	(4.4	)
Uncertain tax positions	2.0		—		—
Other	(0.2	)	(0.1	)	(0.2	)
Effective income tax rate	27.9	%	25.2	%	30.9	%

(A) Represents credits associated with the production from OG&E's wind farms.

The deferred tax provisions are recognized as costs in the ratemaking process by the commissions having jurisdiction over the rates charged by OG&E.The components of Deferred Income Taxes atDecember 31, 2013and2012, respectively, were as follows:

December 31 (In millions)	2013			2012
Current Deferred Income Tax Assets
Net operating losses	$	168.7		$	113.8
Accrued liabilities	9.0			14.0
Federal tax credits	8.0			6.0
Accrued vacation	2.8			3.1
Uncollectible accounts	0.7			1.0
Derivative instruments	—			0.8
Total Current Deferred Income Tax Assets	$	189.2		$	138.7
Non-Current Deferred Income Tax Liabilities
Accelerated depreciation and other property related differences	$	1,747.0		$	1,648.5
OG&E pension plan	84.7			102.2
Regulatory asset	26.0			18.8
Income taxes refundable to customers, net	21.9			21.2
Bond redemption-unamortized costs	3.6			4.0
Total Non-Current Deferred Income Tax Liabilities	1,883.2			1,794.7
Non-Current Deferred Income Tax Assets
Federal tax credits	(101.9		)	(69.5		)
State tax credits	(86.1		)	(78.1		)
Regulatory liabilities	(61.3		)	(71.4		)
Postretirement medical and life insurance benefits	(45.2		)	(42.1		)
Asset retirement obligations	(20.8		)	—
Net operating losses	(17.6		)	(150.0		)
Deferred Federal investment tax credits	(0.7		)	(1.5		)
Other	(4.4		)	(4.3		)
Total Non-Current Deferred Income Tax Assets	(338.0		)	(416.9		)
Non-Current Deferred Income Tax Liabilities, net	$	1,545.2		$	1,377.8

As of December 31, 2013, OG&E has classified $7.8 million of unrecognized tax benefits as a reduction of deferred tax assets recorded. Management is currently unaware of any issues under review that could result in significant additional payments, accruals, or other material deviation from this amount.

Following is a reconciliation of the OG&E’s total gross unrecognized tax benefits as of the years ended December 31, 2013, 2012, and 2011.

(Millions)	2013		2012		2011
Balance at January 1	$	—	$	—	$	—
Tax positions related to current year:
Additions	2.7		—		—
Tax positions related to prior years:
Additions	5.1		—		—
Balance at December 31	$	7.8	$	—	$	—

Where applicable, OG&E classifies income tax-related interest and penalties as interest expense and selling general and administrative expense, respectively. During the year ended December 31, 2013, there were no income tax-related interest or penalties recorded with regard to uncertain tax positions. The total amount of unrecognized tax benefits that would impact the effective tax rate, if recognized, was $7.8 million as of December 31, 2013.

As previously reported, in January 2013, OG&E determined that a portion of certain Oklahoma investment tax credits previously recognized but not yet utilized may not be available for utilization in future years. During the first quarter of 2013, OG&E recorded a reserve of$7.8 million ($5.1 millionafter tax) related to a portion of the Oklahoma investment tax credits generated in years prior to 2013 but not yet utilized due to management's determination that it is more likely than not that it will be unable to utilize these credits. An additional reserve of$4.1 million ($2.7 millionafter tax) was established with regard to these credits generated in the current year.

Prior to2013 , OG&E had a Federal tax operating loss primarily caused by the accelerated tax "bonus" depreciation provision contained within the Tax Relief, Unemployment Insurance Reauthorization and Job Creation Act of 2010 which allowed OG&E to record a current income tax deduction for100 percentof the cost of certain property placed into service in 2011 and50 percentfor certain property placed into service in 2012. During 2013, OG&E began to utilize these net operating losses

On January 2, 2013, the American Taxpayer Relief Act of 2012 was signed into law. Among other things, the law included an extension of bonus depreciation for one year for property generally placed in service before January 1, 2014. The impact of the new law was reflected in OG&E's 2013Financial Statements as an increase in Deferred Tax Liabilities with a corresponding increase in Deferred Tax Assets related to the net operating loss.

In June 2010, new legislation was passed in Oklahoma that created a moratorium, from July 1, 2010 through June 30, 2012, on 30 income tax credits. For income tax purposes, credits affected by the moratorium could not be claimed for any event, transaction, investment, expenditure or other act for which the credits would otherwise be allowable. During this two-year period, affected credits generated by OG&E were deferred and will be utilized at a future date. For financial accounting purposes, OG&E is receiving the benefits as most of these credits did not expire if they were not utilized in the period they were generated.

Other

OG&E sustained Federal and state tax operating losses through2012caused primarily by bonus depreciation and other book verses tax temporary differences. As a result, OG&E had accrued Federal and state income tax benefits carrying into2013. As OG&E can no longer carry these losses back to prior periods, these losses are being carried forward for utilization in future years.In addition to the operating losses, OG&E was unable to utilize the various tax credits that were generating during these years.These tax losses and credits are being carried as deferred tax assets and will be utilized in future periods.Under current law, OG&E anticipates future taxable income will be sufficient to utilize all of the losses and credits before they begin to expire, accordingly no valuation allowance is considered necessary.The following table summarizes these carry forwards:

(In millions)	Carry Forward Amount		Deferred Tax Asset		Earliest Expiration Date
Net operating losses
State operating loss	$	656.3	$	24.2	2030
Federal operating loss	463.1		162.1		2030
Federal tax credits	109.9		109.9		2029
State tax credits
Oklahoma investment tax credits	96.3		62.6		N/A
Oklahoma capital investment board credits	7.3		7.3		N/A
Oklahoma zero emission tax credits	24.1		16.2		2020

OG&E projects full utilization of all Federal operating losses in 2014 as well as partial utilization of State operating loss carryforwards. Accordingly, a current deferred tax asset of $168.7 million has been reflected on the balance sheet.

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Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jan. 31, 2014	Jun. 28, 2013
Document Information [Line Items]
Entity Registrant Name	OKLAHOMA GAS & ELECTRIC CO
Entity Central Index Key	0000074145
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		40,378,745
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0

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Common Stock and Cumulative Preferred Stock

12 Months Ended

Dec. 31, 2013

Common Stock and Cumulative Preferred Stock [Abstract]

Common Stock and Cumulative Preferred Stock [Text Block]

Common Stock and Cumulative Preferred Stock

There were no new shares of common stock issued in 2013, 2012 or 2011.  

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STATEMENTS OF COMPREHENSIVE INCOME Parenthetical (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other comprehensive income (loss), net of tax
Deferred commodity contracts hedging losses reclassified in net income	$ 0.8	$ 0.7	$ (0.1)

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Accounting Pronouncement

12 Months Ended

Dec. 31, 2013

Accounting Pronouncement [Abstract]

New Accounting Pronouncements and Changes in Accounting Principles [Text Block]

2. Accounting Pronouncements

In July 2013, the Emerging Issues Task Force issued "Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward or Tax Credit Carryforward Exists." The new standard requires entities to present an unrecognized tax benefit, or a portion of an unrecognized tax benefit, in the statement of financial position as a reduction to a deferred tax asset for a net operating loss carryforward or a tax credit carryforward, except as follows: to the extent that a net operating loss carryforward or tax credit carryforward at the reporting date is not available under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position, the unrecognized tax benefit would be presented in the statement of financial position as a liability. The new standard is applicable for all entities that have unrecognized tax benefits when a net operating loss carryforward or a tax credit carryforward exists. The new standard is effective for interim and annual reporting periods beginning after December 15, 2013 and does not require any new financial statement disclosures. This new standard may be applied retrospectively or prospectively with early adoption permitted. OG&E retrospectively adopted this new standard effective January 1, 2013.

In February 2013, the Financial Accounting Standards Board issued "Comprehensive Income: Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income." The new standard requires an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, the new standard requires an entity to present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items in net income but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. The new standard is applicable for all entities that issue financial statements that are presented in conformity with U.S. GAAP and that report items of other comprehensive income. The new standard is effective forinterim andannual reporting periods for fiscal years beginning afterDecember 15, 2012and is required to be applied prospectively. OG&E adoptedthis new standard effectiveJanuary 1, 2013.

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Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2013

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]

Summary of Significant Accounting Policies

Organization

OG&Egenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. Its operationsare subject to regulation by the OCC, the APSC and the FERC.OG&E was incorporated in 1902 under the laws of the Oklahoma Territory. OG&E is the largest electric utility in Oklahoma and its franchised service territory includes the Fort Smith, Arkansas area. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.OG&E is a wholly-owned subsidiary of OGE Energy, an energy and energy services provider offering physical delivery and related services for both electricity and natural gas primarily in the south central United States.

Basis of Presentation

In the opinion of management, all adjustments necessary to fairly present thefinancial position of OG&E atDecember 31, 2013and2012and the results of its operations and cash flows for the years endedDecember 31, 2013, 2012and2011, have been included and are of a normal recurring nature except as otherwise disclosed.

Accounting Records

The accounting records of OG&E are maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the OCC and the APSC.  Additionally,OG&E, as a regulated utility, is subject to accounting principles for certain types of rate-regulated activities, which provide that certain actual or anticipated costs that would otherwise be charged to expense can be deferred as regulatory assets, based on the expected recovery from customers in future rates.  Likewise, certain actual or anticipated credits that would otherwise reduce expense can be deferred as regulatory liabilities, based on the expected flowback to customers in future rates.  Management's expected recovery of deferred costs and flowback of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment.

OG&E records certain actual or anticipated costs and obligations as regulatory assets or liabilities if it is probable, based on regulatory orders or other available evidence, that the cost or obligation will be included in amounts allowable for recovery or refund in future rates.

The following table is a summary of OG&E's regulatory assets and liabilities at:

December 31 (In millions)	2013		2012
Regulatory Assets
Current
Fuel clause under recoveries	$	26.2	$	—
Oklahoma demand program rider under recovery (A)	10.6		9.2
Crossroads wind farm rider under recovery (A)	4.7		14.9
Other (A)	7.3		2.9
Total Current Regulatory Assets	$	48.8	$	27.0
Non-Current
Benefit obligations regulatory asset	$	227.4	$	370.6
Income taxes recoverable from customers, net	56.5		54.7
Smart Grid	44.2		42.8
Deferred storm expenses	21.6		12.7
Unamortized loss on reacquired debt	11.8		13.0
Pension tracker	1.4		—
Other	16.2		16.8
Total Non-Current Regulatory Assets	$	379.1	$	510.6
Regulatory Liabilities
Current
Smart Grid rider over recovery (B)	$	16.7	$	24.1
Fuel clause over recoveries	0.4		109.2
Other (B)	3.1		7.8
Total Current Regulatory Liabilities	$	20.2	$	141.1
Non-Current
Accrued removal obligations, net	$	227.7	$	218.2
Deferred pension credits	6.5		17.7
Pension tracker	—		9.2
Total Non-Current Regulatory Liabilities	$	234.2	$	245.1

(A) Included in Other Current Assets on theBalance Sheets.

(B) Included in Other Current Liabilities on theBalance Sheets.

OG&E recovers a return on the capital expenditures along with operation and maintenance expense and depreciation expense related to the Crossroads wind farm through riders established by the OCC and APSC. OG&E began recovery in the fourth quarter of 2011 in Oklahoma and June of 2013 in Arkansas, and believes the rider will continue until new rates are implemented in OG&E's next general rate case in each jurisdiction.

OG&E recovers program costs related to the Demand and Energy Efficiency Program. An extension of the demand program rider was approved in December 2012, which allows for the recovery of demand program costs, lost revenues associated with certain achieved energy, demand savings and performance based incentives and the recovery of costs associated with research and development investments through December 2015.

Fuel clause under recoveries are generated from under recoveries from OG&E's customers when OG&E's cost of fuel exceeds the amount billed to its customers.  Fuel clause over recoveries are generated from over recoveries from OG&E's customers when the amount billed to its customers exceeds OG&E's cost of fuel.OG&E's fuel recovery clauses are designed to smooth the impact of fuel price volatility on customers' bills.As a result, OG&E under recovers fuel costs in periods of rising fuel prices above the baseline charge for fuel and over recovers fuel costs when prices decline below the baseline charge for fuel. Provisions in the fuel clauses are intended to allow OG&E to amortize under and over recovery balances.

The benefit obligations regulatory asset is comprised of expenses recorded which are probable of future recovery and that have not yet been recognized as components of net periodic benefit cost, including net loss, prior service cost and net transition obligation.These expenses are recorded as a regulatory asset as OG&E had historically recovered and currently recovers pension and postretirement benefit plan expense in its electric rates. If, in the future, the regulatory bodies indicate a change in policy related to the recovery of pension and postretirement benefit plan expenses, this could cause the benefit obligations regulatory asset balance to be reclassified to Accumulated other comprehensive income.

The following table is a summary of the components of the benefit obligations regulatory asset at:

December 31 (In millions)	2013			2012
Pension Plan and Restoration of Retirement Income Plan
Net loss	$	178.4		$	278.6
Prior service cost	2.5			4.5
Postretirement Benefit Plans
Net loss	79.9			134.6
Prior service cost	(33.4		)	(47.1		)
Total	$	227.4		$	370.6

The following amounts in the benefit obligations regulatory asset atDecember 31, 2013are expected to be recognized as components of net periodic benefit cost in2014: 

(In millions)
Pension Plan and Restoration of Retirement Income Plan
Net loss	$	11.4
Prior service cost	2.0
Postretirement Benefit Plans
Net loss	11.0
Prior service cost	(13.7		)
Total	$	10.7

Income taxes recoverable from customers, which represents income tax benefits previously used to reduce OG&E's revenues, are treated as regulatory assets and liabilities and are being amortized over the estimated remaining life of the assets to which they relate.  These amounts are being recovered in rates as the temporary differences that generated the income tax benefit turn around.  The income tax related regulatory assets and liabilities are netted in Income taxes recoverable from customers, net in the regulatory assets and liabilities table above.

OG&E recovers the cost of system-wide deployment of smart grid technology and implementing the smart grid pilot program, the incremental costs for web portal access, education and providing home energy reports and stranded costs associated with OG&E's existing meters.The costs recoverable from Oklahoma customers for system-wide deployment of smart grid technology and implementing the smart grid pilot program were capped at$366.4 million(inclusive of the U.S. Department of Energy grant award of$130.0 million) subject to an offset for any recovery of those costs from Arkansas customers. These amounts are currently being recovered through a rider which will remain in effect until the smart grid project costs are included in base rates in OG&E's next general rate case. Costs not included in the rider arethe incremental costs for web portal access, education and home energy reports, which are capped at$6.9 million, and the stranded costs associated with OG&E's existing meters, which have been replaced by smart meters, which were accumulated during the smart grid deployment and have been included in the Smart Grid asset in the table above. These costs are expected to be recovered in base rates in OG&E's next general rate case.

OG&E defers annual Oklahoma storm-related operation and maintenance expenses in excess of$2.7 millionand expenses any Oklahoma storm-related operation and maintenance expenses up to$2.7 million. OG&E will recover the deferred amounts over afive-year period ending in August 2017.

Unamortized loss on reacquired debt is comprised of unamortized debt issuance costs related to the early retirement of OG&E's long-term debt.  These amounts are recorded in interest expenses and are being amortized over the term of the long-term debt which replaced the previous long-term debt.  The unamortized loss on reacquired debt is not included in OG&E's rate base and does not otherwise earn a rate of return.

OG&E recovers specific amounts of pension and postretirement medical costs in rates approved in its Oklahoma rate cases. In accordance with approved orders, OG&E defers the difference between actual pension and postretirement medical expenses and the amount approved in its last Oklahoma rate case as a regulatory asset or regulatory liability. These amounts have been recorded in the Pension tracker in the regulatory assets and liabilities table above.

In September 2011, OG&E was allowed to include postretirement medical expenses in its pension tracker. In August 2012, OG&E was allowed to recover pension and postretirement medical expenses over a two-year period ending July 2014 which is included in Deferred pension credits in the regulatory assets and liabilities table above.

Accrued removal obligations represent asset retirement costs previously recovered from ratepayers for other than legal obligations.

Management continuously monitors the future recoverability of regulatory assets.When in management's judgment future recovery becomes impaired, the amount of the regulatory asset is adjusted, as appropriate.IfOG&Ewere required to discontinue the application of accounting principles for certain types of rate-regulated activities for some or all of its operations, it could result in writing off the related regulatory assets, which could have significant financial effects.

Use of Estimates

In preparing theFinancial Statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and contingent liabilities at the date of theFinancial Statements and the reported amounts of revenues and expenses during the reporting period.  Changes to these assumptions and estimates could have a material effect onOG&E'sFinancial Statements.  However,OG&Ebelieves it has taken reasonable positions where assumptions and estimates are used in order to minimize the negative financial impact toOG&Ethat could result if actual results vary from the assumptions and estimates.  In management's opinion, the areas ofOG&Ewhere the most significant judgment is exercisedincludes the determination of Pension Plan assumptions,impairment estimates of long-lived assets (including intangible assets), income taxes,contingency reserves, asset retirement obligations, assets and depreciable lives of property, plant and equipment, the existence of regulatory assets and liabilities and unbilled revenues.

Cash and Cash Equivalents

For purposes of theFinancial Statements, OG&E considers all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents.  These investments are carried at cost, which approximates fair value.

Allowance for Uncollectible Accounts Receivable

Customer balances are generally written off if not collected within six months after the final billing date. The allowance for uncollectible accounts receivable for OG&E is calculated by multiplying the last six months of electric revenue by the provision rate.  The provision rate is based on a 12-month historical average of actual balances written off.  To the extent the historical collection rates are not representative of future collections, there could be an effect on the amount of uncollectible expense recognized.  Also, a portion of the uncollectible provision related to fuel within the Oklahoma jurisdiction is being recovered through the fuel adjustment clause.The allowance for uncollectible accounts receivable was$1.9 millionand$2.6 millionatDecember 31, 2013 and 2012, respectively.

New business customers are required to provide a security deposit in the form of cash, bond or irrevocable letter of credit that is refunded when the account is closed.  New residential customers, whose outside credit scores indicate an elevated risk, are required to provide a security deposit that is refunded based on customer protection rules defined by the OCC and the APSC.  The payment behavior of all existing customers is continuously monitored and, if the payment behavior indicates sufficient risk within the meaning of the applicable utility regulation, customers will be required to provide a security deposit.

Fuel Inventories

Fuel inventories for the generation of electricity consist of coal, natural gas and oil.  OG&E uses the weighted-average cost method of accounting for inventory that is physically added to or withdrawn from storage or stockpiles.  The amount of fuel inventory was$74.4 millionand$76.8 millionatDecember 31, 2013and2012, respectively.

Gas Imbalances

Gas imbalances occur when the actual amounts of natural gas delivered from or received byOG&Ediffer from the amounts scheduled to be delivered or received.OG&Evalues all imbalances at an average of current market indices applicable toOG&E's operations, not to exceed net realizable value.

Property, Plant and Equipment

All property, plant and equipment is recorded at cost.  Newly constructed plant is added to plant balances at cost which includes contracted services, direct labor, materials, overhead, transportation costs and the allowance for funds used during construction.  Replacements of units of property are capitalized as plant.  For assets that belong to a common plant account, the replaced plant is removed from plant balances and the cost of such property is charged to Accumulated Depreciation.  For assets that do not belong to a common plant account, the replaced plant is removed from plant balances with the related accumulated depreciation and the remaining balance net of any salvage proceeds is recorded as a loss in theStatements of Income as Other Expense.  Repair and replacement of minor items of property are included in theStatements of Income as Other Operation and Maintenance Expense.

The table below presents OG&E's ownership interest in the jointly-owned McClain Plant and the jointly-owned Redbud Plant, and, as disclosed below, only OG&E's ownership interest is reflected in the property, plant and equipment and accumulated depreciation balances in these tables.  The owners of the remaining interests in the McClain Plant and the Redbud Plant are responsible for providing their own financing of capital expenditures.  Also, only OG&E's proportionate interests of any direct expenses of the McClain Plant and the Redbud Plant such as fuel, maintenance expense and other operating expenses are included in the applicable financial statement captions in theStatement of Income.

December 31, 2013 (In millions)	Percentage Ownership		Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)	77	%	$	180.8	$	62.1	$	118.7
Redbud Plant (A)(B)	51	%	$	498.9	$	89.7	$	409.2

(A) Construction work in progress was$0.1 millionand$39.5 millionfor the McClain and Redbud Plants, respectively.

(B) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$28.8 million.

December 31, 2012 (In millions)	Percentage Ownership		Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)	77	%	$	182.1	$	56.3	$	125.8
Redbud Plant (A)(B)	51	%	$	458.5	$	69.5	$	389.0

(A) Construction work in progress was$0.1 millionand$0.3 millionfor the McClain and Redbud Plants, respectively.

(B) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$23.3 million.

OG&E's property, plant and equipment and related accumulated depreciation are divided into the following major classes at:

December 31, 2013 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
Distribution assets	$	3,403.8	$	1,028.2	$	2,375.6
Electric generation assets (A)	3,551.0		1,306.1		2,244.9
Transmission assets (B)	2,163.7		385.0		1,778.7
Intangible plant	50.5		27.1		23.4
Other property and equipment	330.2		118.2		212.0
Total property, plant and equipment	$	9,499.2	$	2,864.6	$	6,634.6

(A) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$28.8 million.

(B) This amount includes a plant acquisition adjustment of$3.3 millionand accumulated amortization of$0.3 million.

December 31, 2012 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
Distribution assets	$	3,222.7	$	969.6	$	2,253.1
Electric generation assets (A)	3,446.6		1,242.4		2,204.2
Transmission assets (B)	1,712.6		359.8		1,352.8
Intangible plant	50.2		25.0		25.2
Other property and equipment	317.6		108.8		208.8
Total property, plant and equipment	$	8,749.7	$	2,705.6	$	6,044.1

(A) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$23.3 million.

(B) This amount includes a plant acquisition adjustment of$3.3 millionand accumulated amortization of$0.3 million.

The unamortized computer software costs were$16.8 millionand$17.6 millionatDecember 31, 2013and2012, respectively. In2013, 2012and2011, amortization expense for computer software costs was$4.0 million, $4.2 millionand$1.8 million, respectively.

Depreciation and Amortization

The provision for depreciation, which was2.8 percentand3.0 percent, respectively, of the average depreciable utility plant for2013and2012, is provided on a straight-line method over the estimated service life of the utility assets.  Depreciation is provided at the unit level for production plant and at the account or sub-account level for all other plant, and is based on the average life group method. In2014, the provision for depreciation is projected to be2.8 percentof the average depreciable utility plant. Amortization of intangible assets is computed using the straight-line method. Of the remaining amortizable intangible plant balance atDecember 31, 2013, 93.5 percentwill be amortized over9.30years with6.5 percentof the remaining amortizable intangible plant balance atDecember 31, 2013being amortized over25.6years.Amortization of plant acquisition adjustments is provided on a straight-line basis over the estimated remaining service life of the acquired asset.  Plant acquisition adjustments include$148.3 millionfor the Redbud Plant, which are being amortized over a27-yearlife and$3.3 millionfor certain substation facilities in OG&E's service territory, which are being amortized over a26to59-yearperiod.

Asset Retirement Obligations

OG&Ehas previously recorded asset retirement obligations that are being amortized over their respective lives ranging from20to74years.

The following table summarizes changes to OG&E's asset retirement obligations during theyears endedDecember 31, 2013and2012.

(In millions)	2013			2012
Balance at January 1	$	53.6		$	24.8
Accretion expense	2.3			1.9
Revisions in estimated cash flows (A)	(0.7		)	26.9
Balance at December 31	$	55.2		$	53.6

(A) Due to changes to OG&E's asset retirement obligations related to its wind farms as a result of changes in the assumption related to the timing of removal used in the valuation of the asset retirement obligations.

Allowance for Funds Used During Construction

For OG&E, allowance for funds used during construction is calculated according to the FERC pronouncements for the imputed cost of equity and borrowed funds.  Allowance for funds used during construction, a non-cash item, is reflected as an increase to net other income and a reduction to interest expense in theStatements of Income and as an increase to Construction Work in Progress in theBalance Sheets.Allowance for funds used during construction rates, compounded semi-annually, were8.33 percent, 8.93 percentand8.71 percentfor the years endedDecember 31, 2013, 2012and2011, respectively.Thedecreasein the allowance for funds used during construction rates in 2013 was primarily due to two factors. First, a decrease in the common equity cost rate caused the equity portion of allowance for equity funds used during construction to decrease. Second, an increase in the average daily balance of short term debt allowed the fixed commercial paper fees to be lower per dollar of short term debt, resulting in a lower short term debt rate, which caused the debt portion of allowance for funds used during construction to decrease.

Collection of Sales Tax

In the normal course of its operations, OG&E collects sales tax from its customers.  OG&E records a current liability for sales taxes when it bills its customers and eliminates this liability when the taxes are remitted to the appropriate governmental authorities.  OG&E excludes the sales tax collected from its operating revenues.

Revenue Recognition

General

OG&E reads its customers' meters and sends bills to its customers throughout each month.  As a result, there is a significant amount of customers' electricity consumption that has not been billed at the end of each month.  Unbilled revenue is presented in Accrued Unbilled Revenues on theBalance Sheets and in Operating Revenues on theStatements of Income based on estimates of usage and prices during the period.The estimates that management uses in this calculation could vary from the actual amounts to be paid by customers.

SPP Purchases and Sales

OG&E participates in the SPP energy imbalance service market in a dual role as a load serving entity and as a generation owner.  The energy imbalance service market requires cash settlements for over or under schedules of generation and load. Market participants, including OG&E, are required to submit resource plans and can submit offer curves for each resource available for dispatch.  A function of interchange accounting is to match participants' MWH entitlements (generation plus scheduled bilateral purchases) against their MWH obligations (load plus scheduled bilateral sales) during every hour of every day. If the net result during any given hour is an entitlement, the participant is credited with a spot-market sale to the SPP at the respective market price for that hour; if the net result is an obligation, the participant is charged with a spot-market purchase from the SPP at the respective market price for that hour. The SPP purchases and sales are not allocated to individual customers.  OG&E records the hourly sales to the SPP at market rates in Operating Revenues and the hourly purchases from the SPP at market rates in Cost of Sales in itsFinancial Statements.

Fuel Adjustment Clauses

Variances in the actual cost of fuel used in electric generation and certain purchased power costs, as compared to the fuel component included in the cost-of-service for ratemaking, are passed through to OG&E's customers through fuel adjustment clauses. The fuel adjustment clauses are subject to periodic review by the OCC, the APSC and the FERC. The OCC, the APSC and the FERC have authority to review the appropriateness of gas transportation charges or other fees OG&E pays to its affiliate, Enable.

Income Taxes

OG&E isa member of an affiliated group thatfilesconsolidated income tax returns in the U.S. Federal jurisdiction and various state jurisdictions. Income taxesaregenerally allocated to each company in the affiliated group based on its stand-alone taxable income or loss.Federal investment tax credits previously claimed on electric utility property have been deferred and are being amortized to income over the life of the related property.  OG&E uses the asset and liability method of accounting for income taxes. Under this method, a deferred tax asset or liability is recognized for the estimated future tax effects attributable to temporary differences between the financial statement basis and the tax basis of assets and liabilities as well as tax credit carry forwards and net operating loss carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period of the change. OG&E recognizes interest related to unrecognized tax benefits in interest expense and recognizes penalties in other expense.

Accrued Vacation

OG&E accrues vacation pay monthly by establishing a liability for vacation earned. Vacation may be taken as earned and is charged against the liability. At the end of each year, the liability represents the amount of vacation earned, but not taken. OGE employees can carryover no more than 80 hours to be used in future years.

Accumulated Other Comprehensive Loss

The balance of Accumulated Other Comprehensive Loss was $1.3 million at December 31,2012 related to deferred commodity contracts hedging activity. There was no balance in Accumulated Other Comprehensive Loss at December 31, 2013.

Environmental Costs

Accruals for environmental costs are recognized when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated.  Costs are charged to expenseor deferred as a regulatory asset based on expected recovery from customers in future rates,if they relate to the remediation of conditions caused by past operations or if they are not expected to mitigate or prevent contamination from future operations.  Where environmental expenditures relate to facilities currently in use, such as pollution control equipment, the costs may be capitalized and depreciated over the future service periods.  Estimated remediation costs are recorded at undiscounted amounts, independent of any insuranceor raterecovery, based on prior experience, assessments and current technology.  Accrued obligations are regularly adjusted as environmental assessments and estimates are revised, and remediation efforts proceed.For sites whereOG&E has been designated as one of several potentially responsible parties, the amount accrued representsOG&E'sestimated share of the cost.  OG&E had$6.2 millionand$5.8 millioninaccrued environmental liabilities atDecember 31, 2013and2012, respectively, which are included in the summary of asset retirement obligations above.

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Rate Matters and Regulation

12 Months Ended

Dec. 31, 2012

Regulated Operations [Abstract]

Rate Matters and Regulation

Rate Matters and Regulation

Regulation and Rates

OG&E's retail electric tariffs are regulated by the OCC in Oklahoma and by the APSC in Arkansas.  The issuance of certain securities by OG&E is also regulated by the OCC and the APSC.  OG&E's wholesale electric tariffs, transmission activities, short-term borrowing authorization and accounting practices are subject to the jurisdiction of the FERC.  The Secretary of the U.S. Department of Energy has jurisdiction over some of OG&E's facilities and operations.In2013, 85 percentof OG&E's electric revenue was subject to the jurisdiction of the OCC,eight percentto the APSC andseven percentto the FERC.

The OCC issued an order in 1996 authorizing OG&E to reorganize into a subsidiary of OGE Energy.  The order required that, among other things, (i) OGE Energy permit the OCC access to the books and records of OGE Energy and its affiliates relating to transactions with OG&E, (ii) OGE Energy employ accounting and other procedures and controls to protect against subsidization of non-utility activities by OG&E's customers and (iii) OGE Energy refrain from pledging OG&E assets or income for affiliate transactions.  In addition, the Energy Policy Act of 2005 enacted the Public Utility Holding Company Act of 2005, which in turn granted to the FERC access to the books and records of OGE Energy and its affiliates as the FERC deems relevant to costs incurred by OG&E or necessary or appropriate for the protection of utility customers with respect to the FERC jurisdictional rates.

Completed Regulatory Matters

Crossroads Wind Farm

As previously reported, OG&E signed memoranda of understanding in February 2010 for approximately 197.8 megawatts of wind turbine generators and certain related balance of plant engineering, procurement and construction services associated with the Crossroads wind farm. Also as part of this project, on June 16, 2011, OG&E entered into an interconnection agreement with the SPP for the Crossroads wind farm which allowed the Crossroads wind farm to interconnect at 227.5 megawatts. On August 31, 2012, OG&E filed an application with the APSC requesting approval to recover the Arkansas portion of the costs of the Crossroads wind farm through a rider until such costs are included in OG&E's base rates as part of its next general rate proceeding. On April 15, 2013, the APSC issued an order authorizing OG&E to recover the Arkansas portion of the cost to construct the Crossroads wind farm, effective retroactively to August 1, 2012. The costs are being recovered through the Energy Cost Recovery Rider.

Fuel Adjustment Clause Review for Calendar Year 2011

The OCC routinely reviews the costs recovered from customers through OG&E’s fuel adjustment clause. On July 31, 2012, the OCC Staff filed an application for a public hearing to review and monitor OG&E's application of the 2011 fuel adjustment clause and for a prudence review of OG&E's electric generation, purchased power and fuel procurement processes and costs in calendar year 2011.  OG&E filed information and documents in response to the OCC's application on October 1, 2012.  On December 19, 2012, witnesses for the OCC Staff filed responsive testimony recommending that the OCC approve OG&E's fuel adjustment clause costs and recoveries for the calendar year 2011 and recommending that the OCC find that OG&E's electric generation, purchased power, fuel procurement and other fuel related practices, policies and decisions during calendar year 2011 were fair, just and reasonable and prudent. On April 9, 2013, the OCC administrative law judge recommended that the OCC find that for the calendar year 2011 OG&E's electric generation, purchased power and fuel procurement processes and costs were prudent. On June 18, 2013, the OCC issued an order approving the administrative law judge’s recommendation.

Pending Regulatory Matters

FERC Order No. 1000, Final Rule on Transmission Planning and Cost Allocation

On July 21, 2011, the FERC issued Order No. 1000, which revised the FERC's existing regulations governing the process for planning enhancements and expansions of the electric transmission grid in a particular region, along with the corresponding process for allocating the costs of such expansions. Order No. 1000 leaves to individual regions to determine whether a previously-approved project is subject to reevaluation and is therefore governed by the new rule.

Order No. 1000 requires, among other things, public utility transmission providers, such as the SPP, to participate in a process that produces a regional transmission plan satisfying certain standards, and requires that each such regional process consider transmission needs driven by public policy requirements (such as state or Federal policies favoring increased use of renewable energy resources). Order No. 1000 also directs public utility transmission providers to coordinate with neighboring transmission planning regions. In addition, Order No. 1000 establishes specific regional cost allocation principles and directs public utility transmission providers to participate in regional and interregional transmission planning processes that satisfy these principles.

On the issue of determining how entities are to be selected to develop and construct the specific transmission projects, Order No. 1000 directs public utility transmission providers to remove from the FERC-jurisdictional tariffs and agreements provisions that establish any Federal "right of first refusal" for the incumbent transmission owner (such as OG&E) regarding transmission facilities selected in a regional transmission planning process, subject to certain limitations. However, Order No. 1000 is not intended to affect the right of an incumbent transmission owner (such as OG&E) to build, own and recover costs for upgrades to its own transmission facilities, and Order No. 1000 does not alter an incumbent transmission owner's use and control of existing rights of way. Order No. 1000 also clarifies that incumbent transmission owners may rely on regional transmission facilities to meet their reliability needs or service obligations. The SPP currently has a "right of first refusal" for incumbent transmission owners and this provision has played a role in OG&E being selected by the SPP to build various transmission projects in Oklahoma. These changes to the "right of first refusal" apply only to "new transmission facilities," which are described as those subject to evaluation or reevaluation (under the applicable local or regional transmission planning process) subsequent to the effective date of the regulatory compliance filings required by the rule, which were filed on November 13, 2012. On May 29, 2013, the Governor signed House Bill 1932 into law which establishes a right of first refusal for Oklahoma incumbent transmission owners, including OG&E, to build new transmission projects with voltages under 300 kilovolts that interconnect to those incumbent entities' existing facilities. OG&E believes this law is consistent with the language of Order No. 1000.

On July 18, 2013, the FERC issued an order on the SPP's Order No. 1000 compliance filing.  This order accepted in part and rejected in part the SPP's plan for complying with Order No. 1000.  The FERC rejected the SPP's plan to retain the right of first refusal for projects that would operate between 100 kilovolts and 300 kilovolts.  However, the FERC clarified that a right of first refusal was appropriate in certain circumstances.  It is not clear how the FERC's order will relate to the recently enacted Oklahoma law addressing a right of first refusal for lower voltages.  On November 15, 2013, SPP made its FERC compliance filing, as required by the July 18, 2013 order. The SPP changes to its tariff and Membership Agreement included provisions that (i) clarify that facilities between 100 kilovolts and 300 kilovolts would be subject to the competitive selection process, (ii) only allow certain evidence, such as state laws (like House Bill 1932) and the holders of existing rights of way, to be considered during the competitive selection process and not earlier in the process; (iii) apply a right of first refusal to transmission projects needed for reliability within three years in certain situations; and (iv) revise the tariff’s competitive selection process, including changes to the criteria for identifying qualifying transmission owners, the requirements for submission of information by transmission owners seeking to participate in competitive selections, and the procedures that govern the competitive selection process.

OGE Energy cannot, at this time, determine the precise impact of Order No. 1000 on OG&E. OG&E has filed a petition for review in the D.C. Circuit relating to the same matter. Nevertheless, at the present time, OGE Energy has no reason to believe that the implementation of Order No. 1000 will impact OG&E's transmission projects currently under development and construction for which OG&E has received a notice to proceed from the SPP.

Fuel Adjustment Clause Review for Calendar Year 2012

On July 31, 2013, the OCC Staff filed an application to review OG&E's fuel adjustment clause for calendar year 2012, including the prudence of OG&E's electric generation, purchased power and fuel procurement costs. OG&E filed the necessary information and documents needed to satisfy the OCC's minimum filing requirement rules on October 9, 2013. A hearing on this matter is scheduled for April 24, 2014.

Request for Modification to Previous Orders

On August 2, 2013, OG&E filed an application at the OCC seeking to make minor modifications to three previous OCC orders. The purpose of the application was to address the timing of certain requirements contained in those orders. OG&E's application proposed to address these issues in OG&E's next general rate case thus avoiding the cost associated with a rate case filing now and benefiting customers by deferring the recovery of certain costs identified in the previous orders. On September 3, 2013, the PUD Staff filed a motion to dismiss OG&E's application. PUD Staff requested that the OCC dismiss OG&E's application and issue an order requiring OG&E to file a rate case for the 2012 test year.

On September 11, 2013, the PUD Staff withdrew their motion to dismiss OG&E's application and on September 12, 2013, filed an application requesting a public hearing, review and possible adjustment of the rates and charges of OG&E based on the 2012 test year. To date, no procedural schedule has been established for either the OG&E application or the PUD Staff application.

Energy Efficiency Program Filing

On October 9, 2013 OG&E filed an application with the APSC requesting approval of interim modifications to approved Energy Efficiency Programs, new tariff revisions and the waiver of certain provisions of the Commission’s Rules for Conservation and Energy Efficiency Programs.

Market-Based Rate Authority

On June 29, 2012, OG&E filed its triennial market power update with the FERC to retain its market-based rate authorization in the SPP's energy imbalance service market but to surrender its market-based rate authorization for any market-based rates sales outside of the SPP's energy imbalance service market. On May 2, 2013, the FERC issued an order accepting OG&E's June 2012 triennial market power update.

On December 30, 2013, OG&E submitted to the FERC a market-based rate change in status filing and a revised market-based rate tariff.  The revised tariff will authorize OG&E to (i) sell electric energy and capacity at market-based rates without geographic restriction, and (ii) sell ancillary services in the SPP and Midcontinent Independent System Operator, Inc. markets.  The primary goal of this filing was to implement the market-based rate authority OG&E needs to fully participate in SPP’s Integrated Marketplace.  OG&E requested that FERC issue an order on or before February 28, 2014 that accepts the revised market-based rate tariff to be effective on the date SPP’s Integrated Marketplace goes into operation, which is expected to be March 1, 2014.

Section 206 Complaint

On November 26, 2013, Arkansas Electric Cooperative Corporation filed a complaint at the FERC against OG&E, arguing that the wholesale formula rate contract between OG&E and Arkansas Electric Cooperative Corporation (formerly between OG&E and Arkansas Valley Electric Cooperative) is unjust and unreasonable with respect to several items.  After engaging in settlement discussions, OG&E and Arkansas Electric Cooperative Corporation have tentatively agreed to terms of a settlement and are jointly preparing an offer of settlement to be filed with FERC. OG&E believes the reduction in revenue will be less than$1.0 millionper year.

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Long-Term Debt

12 Months Ended

Dec. 31, 2013

Long-term Debt, Unclassified [Abstract]

Long-Term Debt

Long-Term Debt

A summary of OG&E's long-term debt is included in theStatements of Capitalization.AtDecember 31, 2013, OG&E was in compliance with all of its debt agreements.

Industrial Authority Bonds

OG&E has tax-exempt pollution control bonds with optional redemption provisions that allow the holders to request repayment of the bonds on any business day.  The bonds, which can be tendered at the option of the holder during the next 12 months, are as follows:

SERIES			DATE DUE	AMOUNT
				(In millions)
0.18%	-	0.34%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.10%	-	0.39%	Muskogee Industrial Authority, January 1, 2025	32.4
0.10%	-	0.30%	Muskogee Industrial Authority, June 1, 2027	56.0
Total (redeemable during next 12 months)				$	135.4

All of these bonds are subject to an optional tender at the request of the holders, at100 percentof the principal amount, together with accrued and unpaid interest to the date of purchase.  The bond holders, on any business day, can request repayment of the bond by delivering an irrevocable notice to the tender agent stating the principal amount of the bond, payment instructions for the purchase price and the business day the bond is to be purchased.  The repayment option may only be exercised by the holder of a bond for the principal amount.  When a tender notice has been received by the trustee, a third party remarketing agent for the bonds will attempt to remarket any bonds tendered for purchase.  This process occurs once per week.  Since the original issuance of these series of bonds in 1995 and 1997, the remarketing agent has successfully remarketed all tendered bonds.  If the remarketing agent is unable to remarket any such bonds, OG&E is obligated to repurchase such unremarketed bonds.  As OG&E has both the intent and ability to refinance the bonds on a long-term basis and such ability is supported by an ability to consummate the refinancing, the bonds are classified as long-term debt in OG&E's Financial Statements. OG&E believes that it has sufficient liquidity to meet these obligations.

Issuance of Long-Term Debt

On May 8, 2013, OG&E issued$250 millionof3.9%senior notes dueMay 1, 2043. The proceeds from the issuance were added to OG&E's general funds and were used to repay short-term debt, fund capital expenditures, general corporate expenses and for working capital purposes. OG&E expects to issue additional long-term debt from time to time when market conditions are favorable and when the need arises.

Long-Term Debt Maturities

Maturities of OG&E's long-term debt during the next five years consist of$0.2 million, $0.2 million, $110.2 million, $125.1 millionand$250.1 millionin years2014, 2015, 2016, 2017and2018, respectively.

OG&E has previously incurred costs related to debt refinancings.Unamortized loss on reacquired debt is classified asa Non-Current Regulatory Asset,unamortized debt expense is classified asDeferred Charges and Other Assets and the unamortized premium and discount on long-term debt is classified as Long-Term Debt, respectively, in theBalance Sheets and are being amortized over the life of the respective debt.

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Stock-Based Compensation

12 Months Ended

Dec. 31, 2013

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Disclosure of Compensation Related Costs, Share-based Payments [Text Block]

5. Stock-Based Compensation

In 2013,OGE Energyadopted, and its shareowners approved, the 2013 Stock Incentive Plan. The 2013 Plan replaced the 2008 Plan and no further awards will be granted under the 2008 Plan.Under the 2013 Stock Incentive Plan, restricted stock, restricted stock units, stock options,stock appreciation rightsand performance units may be granted to officers, directors and other key employeesof OGE Energy and its subsidiaries. OGE Energy has authorized the issuance of up to7,400,000shares under the 2013 Stock Incentive Plan.

The following table summarizes OG&E's pre-tax compensation expense and related income tax benefit for the years endedDecember 31, 2013, 2012and2011related toperformance units and restricted stockfor OG&E employees.

Year ended December 31 (In millions)	2013		2012		2011
Performance units
Total shareholder return	$	1.7	$	1.7	$	1.6
Earnings per share	0.5		0.9		1.1
Total performance units	2.2		2.6		2.7
Restricted stock	0.1		0.1		0.2
Net compensation expense	$	2.3	$	2.7	$	2.9
Income tax benefit	$	0.9	$	1.2	$	1.2

OGE Energyhas issued new shares to satisfy stock option exercises, restricted stock grants and payouts of earned performance units.In2013, 2012and2011, there were139,706shares, 205,838sharesand113,602shares, respectively, of new common stock issuedto OG&E's employees pursuant to OGE Energy'sstock incentive plans related to exercised stock options, restricted stock grants (net of forfeitures) and payouts of earned performance units. In2013, there were692shares of restricted stockreturned toOGE Energyto satisfy tax liabilities.

Performance Units

Under the 2008 Stock Incentive Plan,OGE Energyhas issued performance units which represent the value of one share ofOGE Energy'scommon stock.  The performance units provide for accelerated vesting if there is a change in control (as defined in the 2008 Stock Incentive Plan).  Each performance unit is subject to forfeiture if the recipient terminates employment withOGE Energyor a subsidiary prior to the end of the three-year award cycle for any reason other than death, disability or retirement.  In the event of death, disability or retirement, a participant will receive a prorated payment based on such participant's number of full months of service during the award cycle, further adjusted based on the achievement of the performance goals during the award cycle.

The performance units granted based on total shareholder return are contingently awarded and will be payable in shares ofOGE Energy'scommon stock subject to the condition that the number of performance units, if any, earned by the employees upon the expiration of a three-year award cycle (i.e., three-year cliff vesting period) is dependent onOGE Energy'stotal shareholder return ranking relative to a peer group of companies.  The performance units granted based on earnings per share are contingently awarded and will be payable in shares ofOGE Energy'scommon stock based onOGE Energy'searnings per share growth over a three-year award cycle (i.e., three-year cliff vesting period) compared to a target set at the time of the grant by the Compensation Committee ofOGE Energy'sBoard of Directors. All of theseperformance units are classified as equity inOGE Energy'sConsolidated Balance Sheet.  If there is no or only a partial payout for the performance units at the end of the award cycle, the unearned performance units are cancelled. Payout requires approval of the Compensation Committee ofOGE Energy'sBoard of Directors. Payouts, if any, are all made in common stock and are considered made when the payout is approved by the Compensation Committee.

Performance Units – Total Shareholder Return

The fair value of the performance units based on total shareholder return was estimated on the grant date using a lattice-based valuation model that factors in information, including the expected dividend yield, expected price volatility, risk-free interest rate and the probable outcome of the market condition, over the expected life of the performance units.  Compensation expense for the performance units is a fixed amount determined at the grant date fair value and is recognized over the three-year award cycle regardless of whether performance units are awarded at the end of the award cycle.  Dividends are not accrued or paid during the performance period and, therefore, are not included in the fair value calculation.  Expected price volatility is based on the historical volatility ofOGE Energy'scommon stock for the past three years and was simulated using the Geometric Brownian Motion process.  The risk-free interest rate for the performance unit grants is based on the three-year U.S. Treasury yield curve in effect at the time of the grant.  The expected life of the units is based on the non-vested period since inception of the award cycle.  There are no post-vesting restrictions related toOGE Energy'sperformance units based on total shareholder return.The number of performance units granted based on total shareholder return and the assumptions used to calculate the grant date fair value of the performance units based on total shareholder return are shown in the following table.

	2013			2012			2011
Number of units granted to OG&E employees	71,850			81,122			86,604
Fair value of units granted	$	25.89		$	25.91		$	23.05
Expected dividend yield	2.8		%	3.0		%	3.2		%
Expected price volatility	20.0		%	22.0		%	33.0		%
Risk-free interest rate	0.37		%	0.38		%	1.40		%
Expected life of units (in years)	2.84			2.87			2.87

Performance Units – Earnings Per Share

The fair value of the performance units based on earnings per share is based on grant date fair value which is equivalent to the price of one share ofOGE Energy'scommon stock on the date of grant.  The fair value of performance units based on earnings per share varies as the number of performance units that will vest is based on the grant date fair value of the units and the probable outcome of the performance condition.OGE Energyreassesses at each reporting date whether achievement of the performance condition is probable and accrues compensation expense if and when achievement of the performance condition is probable.  As a result, the compensation expense recognized for these performance units can vary from period to period.  There are no post-vesting restrictions related toOGE Energy'sperformance units based on earnings per share.The number of performance units granted based on earnings per share and the grant date fair value are shown in the following table.

	2013		2012		2011
Number of units granted to OG&E employees	23,952		27,038		28,862
Fair value of units granted	$	26.73	$	23.82	$	20.81

Restricted Stock

Under the 2008 Stock Incentive Plan and beginning in 2008, OGE Energyissued restricted stock to certain existing non-officer employees as well as other executives upon hire to attract and retain individuals to be competitive in the marketplace. The restricted stock vests in one-third annual increments.  Prior to vesting, each share of restricted stock is subject to forfeiture if the recipient ceases to render substantial services toOGE Energyor a subsidiary for any reason other than death, disability or retirement. These shares may not be sold, assigned, transferred or pledged and are subject to a risk of forfeiture.

The fair value of the restricted stock was based on the closing market price ofOGE Energy'scommon stock on the grant date. Compensation expense for the restricted stock is a fixed amount determined at the grant date fair value and is recognized as services are rendered by employees over a three-year vesting period. Also, OG&E treats its restricted stock as multiple separate awards by recording compensation expense separately for each tranche whereby a substantial portion of the expense is recognized in the earlier years in the requisite service period. Dividends are accrued and paid during the vesting period and, therefore, are included in the fair value calculation. The expected life of the restricted stock is based on the non-vested period since inception of the three-year award cycle.  There are no post-vesting restrictions related toOGE Energy'srestricted stock.The number of shares of restricted stock grantedrelated to OG&E employeesand the grant date fair value are shown in the following table.

	2013		2012		2011
Shares of restricted stock granted to OG&E employees	3,824		2,216		4,468
Fair value of restricted stock granted	$	29.71	$	26.93	$	23.61

A summary of the activity forOGE Energy'sperformance units and restricted stockapplicable to OG&E'S employeesatDecember 31, 2013and changes in2013are shown in the following table.

	Performance Units
	Total Shareholder Return					Earnings Per Share					Restricted Stock
(dollars in millions)	Number of Units			Aggregate Intrinsic Value		Number of Units			Aggregate Intrinsic Value		Number of Shares		Aggregate Intrinsic Value
Units/Shares Outstanding at 12/31/12	224,012					74,670					6,046
Granted	71,850		(A)			23,952		(A)			3,824
Converted	(75,452	)	(B)	$	4.4	(25,152	)	(B)	$	1.5	N/A
Vested	N/A					N/A					(3,038	)	$	0.1
Forfeited	(7,940	)				(2,648	)				(884	)
Employee migration	(5,644	)	(C)			(1,884	)	(C)			—
Units/Shares Outstanding at 12/31/13	206,826			$	9.9	68,938			$	2.7	5,948		$	0.2
Units/Shares Fully Vested at 12/31/13	68,750			$	3.7	22,914			$	1.6

(A) For performance units, this represents the target number of performance units granted.  Actual number of performance units earned, if any, is dependent upon performance and may range from0 percentto200 percentof the target.

(B) These amounts represent performance units that vested atDecember 31, 2012which were settled in February 2013.

(C) Due to certain employees transferring betweenOG&Eand its affiliates.

A summary of the activity forOGE Energy'snon-vested performance units and restricted stockapplicable to OG&E'S employeesatDecember 31, 2013and changes in2013are shown in the following table.

	Performance Units
	Total Shareholder Return					Earnings Per Share					Restricted Stock
	Number of Units			Weighted-Average Grant Date Fair Value		Number of Units			Weighted-Average Grant Date Fair Value		Number of Shares		Weighted-Average Grant Date Fair Value
Units/Shares Non-Vested at 12/31/12	148,560			$	24.51	49,518			$	22.34	6,046		$	24.62
Granted	71,850		(A)	$	25.89	23,952		(A)	$	26.73	3,824		$	29.71
Vested	(68,750	)		$	23.05	(22,914	)		$	20.81	(3,038	)	$	23.51
Forfeited	(7,940	)		$	25.23	(2,648	)		$	24.03	(884	)	$	28.31
Employee migration	(5,644	)	(B)	$	24.74	(1,884	)	(B)	$	23.23	—		$	—
Units/Shares Non-Vested at 12/31/13	138,076			$	25.90	46,024			$	25.25	5,948		$	27.91
Units/Shares Expected to Vest	126,390		(C)			42,130		(C)			5,948

(A) For performance units, this represents the target number of performance units granted.  Actual number of performance units earned, if any, is dependent upon performance and may range from0 percentto200 percentof the target.

(B) Due to certain employees transferring betweenOG&Eand its affiliates.

(C) The intrinsic value of the performance units based on total shareholder return and earnings per share is$5.6 million and $1.1 million, respectively.

Fair Value of Vested Performance Units and Restricted Stock

A summary of OG&E's fair value for its vested performance units and restricted stock is shown in the following table.

Year ended December 31 (In millions)	2013		2012		2011
Performance units
Total shareholder return	$	1.6	$	1.4	$	1.2
Earnings per share	1.0		0.8		0.6
Restricted stock	0.1		0.1		0.3

Unrecognized Compensation Cost

A summary of OG&E's unrecognized compensation cost for its non-vested performance units and restricted stock and the weighted-average periods over which the compensation cost is expected to be recognized are shown in the following table.

December 31, 2013	Unrecognized Compensation Cost (in millions)		Weighted Average to be Recognized (in years)
Performance units
Total shareholder return	$	1.7	1.63
Earnings per share	0.3		1.52
Total performance units	2.0
Restricted stock	0.1		2.17
Total	$	2.1

Stock Options

OGE Energy last issued stock options in2004and as ofDecember 31, 2006, all stock options were fully vested and expensed. All stock options have a contractual life of10years.A summary of the activity for OGE Energy's stock optionsapplicable to OG&E'S employeesatDecember 31, 2013and changes during2013are shown in the following table.

(dollars in millions)	Number of Options		Weighted-Average Exercise Price			Aggregate Intrinsic Value		Weighted-Average Remaining Contractual Term
Options Outstanding at 12/31/12	7,000		$	9.62
Exercised	(7,000	)	$	(9.62	)	$	0.2
Options Outstanding at 12/31/13	—		$	—		$	—	0.00	years
Options Fully Vested and Exercisable at 12/31/13	—		$	—		$	—	0.00	years

A summary of the activity for OG&E's exercised stock options in2013, 2012and2011are shown in the following table.

Year ended December 31 (In millions)	2013		2012		2011
Intrinsic value (A)	$	0.2	$	0.2	$	0.3

(A) The difference between the market value on the date of exercise and the option exercise price.

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Rate Matters and Regulation (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Oklahoma Corporation Commission [Member]
OG&E's Jurisdictional Revenues	85.00%
Arkansas Public Service Commission [Member]
OG&E's Jurisdictional Revenues	8.00%
Federal Energy Regulatory Commission [Member]
OG&E's Jurisdictional Revenues	7.00%
Section 206 Complaint [Member]
Reduction of Revenue	$ 1.0

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Related-Party Transactions (Notes)

12 Months Ended

Dec. 31, 2013

Related Party Transaction [Line Items]

Related Party Transactions Disclosure [Text Block]

Related Party Transactions

OGE Energy charged operating costs to OG&E of$120.1 million, $118.4 millionand$129.7 millionin2013, 2012and2011, respectively.OGE Energy charges operating costs to its subsidiaries and unconsolidated affiliate based on several factors. Operating costs directly related to specific subsidiaries or unconsolidated affiliate are assigned to those subsidiaries or unconsolidated affiliate.Where more than one subsidiary or unconsolidated affiliate benefits from certain expenditures, the costs are shared between those subsidiaries and unconsolidated affiliate receiving the benefits.  Operating costs incurred for the benefit of all subsidiaries and unconsolidated affiliate are allocated among the subsidiaries and unconsolidated affiliate, either as overhead based primarily on labor costs or using the "Distrigas" method.  The Distrigas method is a three-factor formula that uses an equal weighting of payroll, net operating revenues and gross property, plant and equipment.  OGE Energy adopted the Distrigas method in January 1996 as a result of a recommendation by the OCC Staff.  OGE Energy believes this method provides a reasonable basis for allocating common expenses.

The following table summarizes related party transactions between OG&E and its affiliate, Enable, during 2013, 2012 and 2011.

	December 31,
(In millions)	2013		2012		2011
Operating Revenues:
Electricity to power electric compression assets	$	10.2	$	12.4	$	8.1
Cost of Sales:
Natural gas transportation services	$	34.8	$	34.8	$	34.8
Natural gas storage services	12.9		12.9		12.7
Natural gas purchases	22.4		20.4		34.7

In2013and2012, OG&E declared dividends to OGE Energy of$170.0 millionand$75.0 million, respectively. In2011, OG&E declarednodividends to OGE Energy.

In June 2011, OGE Energy made a capital contribution to OG&E for$50.0 million.

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Fair Value Measurements

12 Months Ended

Dec. 31, 2013

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

OG&E had nofinancial instruments measured at fair value on a recurring basis atDecember 31, 2013 and December 31, 2012.

The following table summarizes the fair value and carrying amount of OG&E's financial instruments atDecember 31, 2013 and December 31, 2012.

	2013				2012
December 31 (In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-Term Debt
Senior Notes	$	2,154.5	$	2,405.0	$	1,904.2	$	2,401.6
Industrial Authority Bonds	135.4		135.4		135.4		135.4
Tinker Debt	10.3		9.1		10.7		10.0

The carrying value of the financial instruments included in theBalance Sheets approximates fair value except for long-term debt which is valued at the carrying amount.The fair value of OG&E's long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturitiesand is classified as Level 2 in the fair value hierarchy.

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Supplemental Cash Flow Information

12 Months Ended

Dec. 31, 2013

Supplemental Cash Flow Information [Abstract]

Cash Flow, Supplemental Disclosures [Text Block]

Supplemental Cash Flow Information

The following table discloses information about investing and financing activities that affected recognized assets and liabilities but which did not result in cash receipts or payments.  Also disclosed in the table iscash paid for interest, net of interest capitalized, and cash paid for income taxes, net of income tax refunds.

Year ended December 31 (In millions)	2013			2012			2011
NON-CASH INVESTING AND FINANCING ACTIVITIES
Installment payments for Tinker electric distribution system	$	—		$	10.6		$	—
Power plant long-term service agreement	9.7			—			1.7
SUPPLEMENTAL CASH FLOW INFORMATION
Cash Paid During the Period for
Interest (net of interest capitalized) (A)	$	127.5		$	122.1		$	108.2
Income taxes (net of income tax refunds)	(5.5		)	(1.2		)	4.5

(A) Net of interest capitalized of$3.4 million, $3.5 millionand$10.4 millionin2013, 2012and2011, respectively.

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Retirement Plans and Postretirement Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2013

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

Schedule of Net Funded Status [Table Text Block]

The following table presents the status ofOG&E's portion of OGE Energy'sPension Plan and Restoration of Retirement Income Plan atDecember 31, 2013and2012. These amounts have been recorded in Accrued Benefit Obligations with the offsetrecorded as a regulatory asset in OG&E's Balance Sheet as discussed in Note 1. Theregulatory assetrepresents a net periodic benefit cost to be recognized in theStatements of Income in future periods.

	Pension Plan						Restoration of Retirement Income Plan
December 31 (In millions)	2013			2012			2013			2012
Benefit obligations	$	(503.6	)	$	(574.6	)	$	(2.1	)	$	(2.2	)
Fair value of plan assets	516.5			519.0			—			—
Funded status at end of year	$	12.9		$	(55.6	)	$	(2.1	)	$	(2.2	)

The following table presents the status ofOG&E's portion of OGE Energy'spostretirement benefit plans atDecember 31, 2013and2012. These amounts have been recorded in Accrued Benefit Obligations with the offsetrecorded as a regulatory asset in OG&E's Balance Sheet as discussed in Note 1. Theregulatory assetrepresents a net periodic benefit cost to be recognized in theStatements of Income in future periods.

December 31 (In millions)	2013			2012
Benefit obligations	$	(202.4	)	$	(236.4	)
Fair value of plan assets	56.7			55.5
Funded status at end of year	$	(145.7	)	$	(180.9	)

Schedule of Expected Benefit Payments [Table Text Block]

The Medicare Prescription Drug, Improvement and Modernization Act of 2003 expanded coverage for prescription drugs.  The following table summarizes the gross benefit payments OG&E expects to pay related to its postretirement benefit plans, including prescription drug benefits.

(In millions)	Gross Projected Postretirement Benefit Payments
2014	$	13.1
2015	13.5
2016	13.8
2017	14.0
2018	14.3
After 2018	71.6

The following table summarizes the benefit payments OG&E expects to pay related to its Pension Plan and Restoration of Retirement Income Plan.These expected benefits are based on the same assumptions used to measure OGE Energy's benefit obligation at the end of the year and include benefits attributable to estimated future employee service.

(In millions)	Projected Benefit Payments
2014	$	75.4
2015	65.1
2016	59.9
2017	53.1
2018	49.1
After 2018	183.3

Projected Benefit Obligation Funded Status Thresholds [Table Text Block]

The Pension Plan assets are held in a trust which follows an investment policy and strategy designed to reduce the funded status volatility of the Plan by utilizing liability driven investing. The purpose of liability driven investing is to structure the asset portfolio to more closely resemble the pension liability and thereby more effectively hedge against changes in the liability. The investment policy follows a glide path approach that shifts a higher portfolio weighting to fixed income as the Plan's funded status increases. The table below sets forth the targeted fixed income and equity allocations at different funded status levels.

Projected Benefit Obligation Funded Status Thresholds	<90%	95%	100%	105%	110%	115%	120%
Fixed income	50%	58%	65%	73%	80%	85%	90%
Equity	50%	42%	35%	27%	20%	15%	10%
Total	100%	100%	100%	100%	100%	100%	100%

Pension Plan Equity Asset Allocation Table [Table Text Block]

Within the portfolio's overall allocation to equities, the funds are allocated according to the guidelines in the table below.

Asset Class	Target Allocation	Minimum	Maximum
Domestic All-Cap/Large Cap Equity	50%	50%	60%
Domestic Mid-Cap Equity	15%	5%	25%
Domestic Small-Cap Equity	15%	5%	25%
International Equity	20%	10%	30%

Schedule of Allocation of Plan Assets [Table Text Block]

The following tables summarizeOG&E's portion of OGE Energy'spostretirement benefit plans investments that are measured at fair value on a recurring basis atDecember 31, 2013and2012.  There werenoLevel 2 investments held by the postretirement benefit plans atDecember 31, 2013and2012.

(In millions)	December 31, 2013			Level 1		Level 3
Group retiree medical insurance contract (A)	$	53.1		$	—	$	53.1
Mutual funds investment
U.S. equity investments	7.9			7.9		—
Money market funds investment	0.4			0.4		—
Total Plan investments	$	61.4		$	8.3	$	53.1
Plan investments attributable to affiliates	(4.7		)
Total Plan assets	$	56.7

(In millions)	December 31, 2012			Level 1		Level 3
Group retiree medical insurance contract (A)	$	53.3		$	—	$	53.3
Mutual funds investment
U.S. equity investments	6.0			6.0		—
Money market funds investment	0.3			0.3		—
Total Plan investments	$	59.6		$	6.3	$	53.3
Plan investments attributable to affiliates	(4.1		)
Total Plan assets	$	55.5

(A) This category represents a group retiree medical insurance contract which invests in a pool of common stocks, bonds and money market accounts, of which a significant portion is comprised of mortgage-backed securities.

The following tables summarizeOG&E's portion of OGE Energy'sPension Plan's investments that are measured at fair value on a recurring basis atDecember 31, 2013and2012.  There werenoLevel 3 investments held by the Pension Plan atDecember 31, 2013and2012. 

(In millions)	December 31, 2013			Level 1		Level 2
Common stocks
U.S. common stocks	$	236.8		$	236.8	$	—
Foreign common stocks	39.3			39.3		—
U.S. Government obligations
U.S. treasury notes and bonds (A)	159.8			159.8		—
Mortgage-backed securities	50.3			—		50.3
Bonds, debentures and notes (B)
Corporate fixed income and other securities	110.6			—		110.6
Mortgage-backed securities	22.3			—		22.3
Commingled fund (C)	29.2			—		29.2
Common/collective trust (D)	26.0			—		26.0
Foreign government bonds	4.0			—		4.0
U.S. municipal bonds	2.0			—		2.0
Interest-bearing cash	0.1			0.1		—
Forward contracts
Receivable (foreign currency)	1.1			—		1.1
Payable (foreign currency)	(1.1		)	—		(1.1		)
Total Plan investments	$	680.4		$	436.0	$	244.4
Receivable from broker for securities sold	11.5
Interest and dividends receivable	3.2
Payable to broker for securities purchased	(40.2		)
Plan investments attributable to affiliates	(138.4		)
Total Plan assets	$	516.5

(In millions)	December 31, 2012			Level 1		Level 2
Common stocks
U.S. common stocks	$	232.2		$	232.2	$	—
Foreign common stocks	39.9			39.9		—
U.S. Government obligations
U.S. treasury notes and bonds (A)	138.6			138.6		—
Mortgage-backed securities	55.8			—		55.8
Bonds, debentures and notes (B)
Corporate fixed income and other securities	98.4			—		98.4
Mortgage-backed securities	13.5			—		13.5
Commingled fund (C)	34.9			—		34.9
Common/collective trust (D)	25.6			—		25.6
Foreign government bonds	3.9			—		3.9
U.S. municipal bonds	0.8			—		0.8
Interest-bearing cash	0.2			0.2		—
Forward contracts
Receivable (foreign currency)	0.4			—		0.4
Payable (foreign currency)	(0.4		)	—		(0.4		)
Total Plan investments	$	643.8		$	410.9	$	232.9
Receivable from broker for securities sold	0.8
Interest and dividends receivable	2.8
Payable to broker for securities purchased	(21.4		)
Plan investments attributable to affiliates	(107.0		)
Total Plan assets	$	519.0

(A) This category represents U.S. treasury notes and bonds with a Moody's Investors Services rating of Aaa and Government Agency Bonds with a Moody's Investors Services rating of A1 or higher.

(B) This category primarily represents U.S. corporate bonds with an investment grade rating at or above Baa3 or BBB- by Moody's Investors Services, Standard & Poor's Ratings Services or Fitch Ratings.

(C) This category represents units of participation in a commingled fund that primarily invested in stocks of international companies and emerging markets.

(D) This category represents units of participation in an investment pool which primarily invests in foreign or domestic bonds, debentures, mortgages, equipment or other trust certificates, notes, obligations issued or guaranteed by the U.S. Government or its agencies, bank certificates of deposit, bankers' acceptances and repurchase agreements, high grade commercial paper and other instruments with money market characteristics with a fixed or variable interest rate. There are no restrictions on redemptions in the common/collective trust.

Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block]

The following table summarizes the postretirement benefit plans investments that are measured at fair value on a recurring basis using significant unobservable inputs (Level 3).

Year ended December 31 (In millions)	2013
Group retiree medical insurance contract
Beginning balance	$	53.3
Net unrealized gains related to instruments held at the reporting date	(0.5		)
Interest income	1.1
Dividend income	0.6
Realized gains	0.4
Administrative expenses and charges	(0.1		)
Claims paid	(1.7		)
Ending balance	$	53.1

Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates [Table Text Block]

A one-percentage point change in the assumed health care cost trend rate would have the following effects:

ONE-PERCENTAGE POINT INCREASE
Year ended December 31 (In millions)	2013		2012		2011
Effect on aggregate of the service and interest cost components	$	—	$	—	$	—
Effect on accumulated postretirement benefit obligations	0.1		0.1		0.1

ONE-PERCENTAGE POINT DECREASE
Year ended December 31 (In millions)	2013		2012		2011
Effect on aggregate of the service and interest cost components	$	—	$	0.1	$	0.1
Effect on accumulated postretirement benefit obligations	0.4		0.7		0.4

Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets [Table Text Block]

The following table presents the status ofOG&E's portion of OGE Energy'sPension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans for2013and2012. OG&E's portion of the benefit obligation for OGE Energy'sPension Plan and the Restoration of Retirement Income Plan represents the projected benefit obligation, while the benefit obligation for the postretirement benefit plans represents the accumulated postretirement benefit obligation. The accumulated postretirement benefit obligation forOGE Energy'sPension Plan and Restoration of Retirement Income Plan differs from the projected benefit obligation in that the former includes no assumption about future compensation levels. The accumulated postretirement benefit obligation for the Pension Plan and the Restoration of Retirement Income Plan atDecember 31, 2013was$483.0 millionand$1.9 million, respectively. The accumulated postretirement benefit obligation for the Pension Plan and the Restoration of Retirement Income Plan atDecember 31, 2012was$549.3 millionand$2.1 million, respectively. The details of the funded status of the Pension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans and the amounts included in theBalance Sheets are as follows:

	Pension Plan						Restoration of Retirement Income Plan						Postretirement Benefit Plans
December 31 (In millions)	2013			2012			2013			2012			2013			2012
Change in Benefit Obligation
Beginning obligations	$	(574.6	)	$	(546.9	)	$	(2.2	)	$	(2.2	)	$	(236.4	)	$	(223.1	)
Service cost	(11.6		)	(10.9		)	(0.1		)	(0.1		)	(2.9		)	(2.7		)
Interest cost	(20.4		)	(23.5		)	(0.1		)	(0.1		)	(8.1		)	(9.4		)
Participants' contributions	49.9			—			—			—			(2.5		)	(2.5		)
Medicare subsidies received	—			—			—			—			—			(0.5		)
Actuarial gains (losses)	39.8			(43.7		)	0.2			(0.4		)	35.4			(9.4		)
Benefits paid	13.3			50.4			0.1			0.6			12.1			11.2
Ending obligations	$	(503.6	)	$	(574.6	)	$	(2.1	)	$	(2.2	)	$	(202.4	)	$	(236.4	)
Change in Plans' Assets
Beginning fair value	$	519.0		$	485.9		$	—		$	—		$	55.5		$	57.2
Actual return on plans' assets	60.7			50.5			—			—			3.4			4.3
Employer contributions	—			33.0			0.1			0.6			7.4			2.2
Participants' contributions	(49.9		)	—			—			—			2.5			2.5
Medicare subsidies received	—			—			—			—			—			0.5
Benefits paid	(13.3		)	(50.4		)	(0.1		)	(0.6		)	(12.1		)	(11.2		)
Ending fair value	$	516.5		$	519.0		$	—		$	—		$	56.7		$	55.5
Funded status at end of year	$	12.9		$	(55.6	)	$	(2.1	)	$	(2.2	)	$	(145.7	)	$	(180.9	)

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

Net Periodic Benefit Cost

	Pension Plan									Restoration of Retirement Income Plan						Postretirement Benefit Plans
Year ended December 31 (In millions)	2013			2012			2011			2013		2012		2011		2013			2012			2011
Service cost	$	11.6		$	10.9		$	10.8		$	0.1	$	0.1	$	0.1	$	2.9		$	2.7		$	2.4
Interest cost	20.4			23.5			26.2			0.1		0.1		0.1		8.1			9.4			10.0
Expected return on plan assets	(38.9		)	(38.2		)	(37.3		)	—		—		—		(2.4		)	(2.8		)	(4.9		)
Amortization of transition obligation	—			—			—			—		—		—		—			2.5			2.6
Amortization of net loss	20.7			19.3			15.6			—		0.1		0.1		18.2			17.4			15.5
Amortization of unrecognized prior service cost (A)	1.9			2.2			2.5			0.1		0.2		0.2		(13.7		)	(13.6		)	(13.7		)
Settlement	17.6			—			—			—		0.3		—		—			—			—
Net periodic benefit cost (B)	$	33.3		$	17.7		$	17.8		$	0.3	$	0.8	$	0.5	$	13.1		$	15.6		$	11.9

(A) Unamortized prior service cost is amortized on a straight-line basis over the average remaining service period to the first eligibility age of participants who are expected to receive a benefit and are active at the date of the plan amendment.

(B) In addition to the$46.7 million, $34.1 millionand$30.2 millionof net periodic benefit cost recognized in2013, 2012and2011, respectively, OG&E recognized the following:

• an increase in pension expense in2013, 2012 and 2011 of $5.8 million, $8.3 millionand$10.8 million, respectively,to maintain the allowable amount to be recovered for pension expense in the Oklahoma jurisdiction, which are included in the Pension tracker regulatory asset or liability (see Note 1); and

• an increase in postretirement medical expense in2013and2012of$0.6 millionand$0.8 millionrespectively, to maintain the allowable amount to be recovered for postretirement medical expense in the Oklahoma jurisdiction which are included in the Pension tracker regulatory asset or liability (see Note 1);

• a deferral of pension expense in 2013 of$17.0 million which includes a portion of OGE Energy's pension settlement charge, related to the pension settlement charge of$17.6 million which is included in the Pension tracker regulatory account (see Note 1).

Schedule of Assumptions Used [Table Text Block]

Rate Assumptions

	Pension Plan and Restoration of Retirement Income Plan						Postretirement Benefit Plans
Year ended December 31	2013		2012		2011		2013		2012		2011
Discount rate	4.60	%	3.70	%	4.50	%	4.60	%	3.60	%	4.50	%
Rate of return on plans' assets	8.00	%	8.00	%	8.00	%	4.00	%	4.00	%	6.50	%
Compensation increases	4.20	%	4.20	%	4.40	%	N/A		N/A		N/A
Assumed health care cost trend:
Initial trend	N/A		N/A		N/A		8.35	%	8.55	%	8.75	%
Ultimate trend rate	N/A		N/A		N/A		4.48	%	4.48	%	4.48	%
Ultimate trend year	N/A		N/A		N/A		2028		2028		2028

N/A - not applicable

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Stock-Based Compensation (Details) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Shares Authorized	7,400,000
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Minimum payout range	0.00%
Maximum payout range	200.00%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Total Compensation Cost Not yet Recognized	$ 2.1
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Options, Outstanding, Beginning Balance	7,000
Options, Exercises in Period	(7,000)
Options, Outstanding, Ending Balance	0		7,000
Options, Exercisable	0
Options, Outstanding, Weighted Average Exercise Price	$ 0.00		$ 9.62
Options, Exercises in Period, Weighted Average Exercise Price	$ (9.62)
Options, Exercisable, Weighted Average Exercise Price	$ 0.00
Options, Exercises in Period, Total Intrinsic Value	0.2	[1]	0.2	[1]	0.3	[1]
Options, Exercisable, Intrinsic Value	0
Options, Outstanding, Intrinsic Value	0
Options, Outstanding, Weighted Average Remaining Contractual Term	0 days
Options, Exercisable, Weighted Average Remaining Contractual Term	0 days
Tax Benefit from Compensation Expense	0.9		1.2		1.2
Performance Units Related to Earnings Per Share [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	23,952	[2]	27,038		28,862
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	68,938		74,670
Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 26.73		$ 23.82		$ 20.81
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Equity Instruments Other than Options, Converted in Period	(25,152)	[3]
Equity Instruments Other than Options, Vested in Period	(22,914)
Equity Other Than Options, Employee Migration	(1,884)	[4]
Awards Other than Options, Fully Vested, Outstanding	22,914
Equity Instruments Other than Options, Converted, Aggregrate Intrinsic Value	1.5	[3]
Equity Instruments Other than Options, Fully Vested, Aggregrate Intrinsic Value	1.6
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Equity Instruments Other than Options, Nonvested, Beginning Balance	49,518
Equity Instruments Other than Options, Vested in Period	(22,914)
Equity Other Than Options, Employee Migration	(1,884)	[4]
Equity Instruments Other than Options, Nonvested, Ending Balance	46,024		49,518
Awards Other than Options, Vested and Expected to Vest	42,130	[5]
Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 25.25		$ 22.34
Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 20.81
Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$ 24.03
Equity Other Than Options, Employee Migration, Weighted Average Grant Date Fair Value	$ 23.23
Equity Instruments Other than Options, Expected to Vest, Intrinsic Value	1.1
Fair Value of Vested Performance Units and Restricted Stock	1.0		0.8		0.6
Total Compensation Cost Not yet Recognized	0.3
Total Compensation Cost Not yet Recognized, Period for Recognition	1 year 6 months 7 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(2,648)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Outstanding	2.7
Total Shareholder Return [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	71,850	[2]	81,122		86,604
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	206,826		224,012
Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 25.89		$ 25.91		$ 23.05
Expected Dividend Rate	2.80%		3.00%		3.20%
Expected Volatility Rate	20.00%		22.00%		33.00%
Risk Free Interest Rate	0.37%		0.38%		1.40%
Expected Term	2 years 10 months 2 days		2 years 10 months 13 days		2 years 10 months 13 days
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Equity Instruments Other than Options, Converted in Period	(75,452)	[3]
Equity Instruments Other than Options, Vested in Period	(68,750)
Equity Other Than Options, Employee Migration	(5,644)	[4]
Awards Other than Options, Fully Vested, Outstanding	68,750
Equity Instruments Other than Options, Converted, Aggregrate Intrinsic Value	4.4	[3]
Equity Instruments Other than Options, Fully Vested, Aggregrate Intrinsic Value	3.7
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Equity Instruments Other than Options, Nonvested, Beginning Balance	148,560
Equity Instruments Other than Options, Vested in Period	(68,750)
Equity Other Than Options, Employee Migration	(5,644)	[4]
Equity Instruments Other than Options, Nonvested, Ending Balance	138,076		148,560
Awards Other than Options, Vested and Expected to Vest	126,390	[5]
Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 25.90		$ 24.51
Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 23.05
Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$ 25.23
Equity Other Than Options, Employee Migration, Weighted Average Grant Date Fair Value	$ 24.74
Equity Instruments Other than Options, Expected to Vest, Intrinsic Value	5.6
Fair Value of Vested Performance Units and Restricted Stock	1.6		1.4		1.2
Total Compensation Cost Not yet Recognized	1.7
Total Compensation Cost Not yet Recognized, Period for Recognition	1 year 7 months 17 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(7,940)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Outstanding	9.9
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	2.2		2.6		2.7
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Total Compensation Cost Not yet Recognized	2.0
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	3,824		2,216		4,468
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	5,948		6,046
Compensation expense	0.1		0.1		0.2
Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 29.71
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Equity Instruments Other than Options, Vested in Period	(3,038)
Equity Other Than Options, Employee Migration	0	[4]
Equity Instruments Other than Options, Vested in Period, Aggregate Intrinsic Value	0.1
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Equity Instruments Other than Options, Nonvested, Beginning Balance	6,046
Equity Instruments Other than Options, Vested in Period	(3,038)
Equity Other Than Options, Employee Migration	0	[4]
Equity Instruments Other than Options, Nonvested, Ending Balance	5,948		6,046
Awards Other than Options, Vested and Expected to Vest	5,948	[5]
Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 27.91		$ 24.62
Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 29.71		$ 26.93		$ 23.61
Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 23.51
Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$ 28.31
Equity Other Than Options, Employee Migration, Weighted Average Grant Date Fair Value	$ 0.00
Fair Value of Vested Performance Units and Restricted Stock	0.1		0.1		0.3
Total Compensation Cost Not yet Recognized	0.1
Total Compensation Cost Not yet Recognized, Period for Recognition	2 years 2 months 1 day
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(884)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Outstanding	0.2
Stock Compensation Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	2.3		2.7		2.9
Performance Units Related to Earnings Per Share [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	0.5		0.9		1.1
Total Shareholder Return [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 1.7		$ 1.7		$ 1.6
Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares Issued in Period	139,706		205,838		113,602
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares Paid for Tax Withholding	692

[1] The difference between the market value on the date of exercise and the option exercise price.

[2] For performance units, this represents the target number of performance units granted. Actual number of performance units earned, if any, is dependent upon performance and may range from 0 percent to 200 percent of the target.

[3] These amounts represent performance units that vested at December 31, 2012 which were settled in February 2013.

[4] Due to certain employees transferring between OG&E and its affiliates.

[5] The intrinsic value of the performance units based on total shareholder return and earnings per share is $5.6 million and $1.1 million, respectively.

XML

Retirement Plans and Postretirement Benefit Plans

12 Months Ended

Dec. 31, 2013

Retirement Plans and Postretirement Benefit Plans [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

Retirement Plans and Postretirement Benefit Plans

Pension Plan and Restoration of Retirement Income Plan

OG&E's employees participate inOGE Energy'sPension Plan and Restoration of Retirement Income Plan.

Employees hired or rehired on or after December 1, 2009 do not participate in the Pension Plan but are eligible to participate in the 401(k) Plan where, for each pay period,OGE Energycontributes to the 401(k) Plan, on behalf of each participant,200 percentof the participant's contributions up tofive percentof compensation.

It isOGE Energy'spolicyto fund the Pension Plan on a current basis based on the net periodic pension expense as determined byOGE Energy'sactuarial consultants.During both2013and2012, OGE Energy made contributions to its Pension Plan of$35 millionof whichnonein 2013 and$33 millionin 2012 was OG&E's portion,to help ensure that the Pension Plan maintains an adequate funded status.Such contributions are intended to provide not only for benefits attributed to service to date, but also for those expected to be earned in the future.During2014, OGE Energy expects to contribute up to$26 millionto its Pension Plan, of which$1 millionis expected to be OG&E's portion.The expected contribution to the Pension Plan during 2014 would be a discretionary contribution, anticipated to be in the form of cash, and is not required to satisfy the minimum regulatory funding requirement specified by the Employee Retirement Income Security Act of 1974, as amended.OGE Energy could be required to make additional contributions if the value of its pension trust and postretirement benefit plan trust assets are adversely impacted by a major market disruption in the future.

In accordance with ASC Topic 715, "Compensation - Retirement Benefits," a one-time settlement charge is required to be recorded by an organization when lump sum payments or other settlements that relieve the organization from the responsibility for the pension benefit obligation during a plan year exceed the service cost and interest cost components of the organization’s net periodic pension cost. During 2013, OG&E experienced an increase in both the number of employees electing to retire and the amount of lump sum payments to be paid to such employees upon retirement. As a result, and based in part on OG&E's historical experience regarding eligible employees who elect to retire in the last quarter of a particular year, OG&E recorded pension settlement charges of$17.6 millionin the fourth quarter of 2013, of which$17.0 millionrelated to OG&E’s Oklahoma jurisdiction and has been included in the pension tracker. The pension settlement charge did not require a cash outlay by OG&E and did not increase OG&E’s total pension expense over time, as the charges were an acceleration of costs that otherwise would be recognized as pension expense in future periods.

OGE Energy provides a Restoration of Retirement Income Plan to those participants inOGE Energy'sPension Plan whose benefits are subject to certain limitations of the Code.  Participants in the Restoration of Retirement Income Planreceive the same benefits that they would have received underOGE Energy'sPension Plan in the absence of limitations imposed by the Federal tax laws.The Restoration of Retirement Income Plan is intended to be an unfunded plan.

The following table presents the status ofOG&E's portion of OGE Energy'sPension Plan and Restoration of Retirement Income Plan atDecember 31, 2013and2012. These amounts have been recorded in Accrued Benefit Obligations with the offsetrecorded as a regulatory asset in OG&E's Balance Sheet as discussed in Note 1. Theregulatory assetrepresents a net periodic benefit cost to be recognized in theStatements of Income in future periods.

	Pension Plan						Restoration of Retirement Income Plan
December 31 (In millions)	2013			2012			2013			2012
Benefit obligations	$	(503.6	)	$	(574.6	)	$	(2.1	)	$	(2.2	)
Fair value of plan assets	516.5			519.0			—			—
Funded status at end of year	$	12.9		$	(55.6	)	$	(2.1	)	$	(2.2	)

The following table summarizes the benefit payments OG&E expects to pay related to its Pension Plan and Restoration of Retirement Income Plan.These expected benefits are based on the same assumptions used to measure OGE Energy's benefit obligation at the end of the year and include benefits attributable to estimated future employee service.

(In millions)	Projected Benefit Payments
2014	$	75.4
2015	65.1
2016	59.9
2017	53.1
2018	49.1
After 2018	183.3

Plan Investments, Policies and Strategies

The Pension Plan assets are held in a trust which follows an investment policy and strategy designed to reduce the funded status volatility of the Plan by utilizing liability driven investing. The purpose of liability driven investing is to structure the asset portfolio to more closely resemble the pension liability and thereby more effectively hedge against changes in the liability. The investment policy follows a glide path approach that shifts a higher portfolio weighting to fixed income as the Plan's funded status increases. The table below sets forth the targeted fixed income and equity allocations at different funded status levels.

Projected Benefit Obligation Funded Status Thresholds	<90%	95%	100%	105%	110%	115%	120%
Fixed income	50%	58%	65%	73%	80%	85%	90%
Equity	50%	42%	35%	27%	20%	15%	10%
Total	100%	100%	100%	100%	100%	100%	100%

Within the portfolio's overall allocation to equities, the funds are allocated according to the guidelines in the table below.

Asset Class	Target Allocation	Minimum	Maximum
Domestic All-Cap/Large Cap Equity	50%	50%	60%
Domestic Mid-Cap Equity	15%	5%	25%
Domestic Small-Cap Equity	15%	5%	25%
International Equity	20%	10%	30%

OGE Energy has retained an investment consultant responsible for the general investment oversight, analysis, monitoring investment guideline compliance and providing quarterly reports to certain of OG&E's members and OGE Energy's Investment Committee.The various investment managers used by the trust operate within the general operating objectives as established in the investment policy and within the specific guidelines established for each investment manager's respective portfolio.

The portfolio is rebalanced on an annual basis to bring the asset allocations of various managers in line with the target asset allocation listed above.  More frequent rebalancing may occur if there are dramatic price movements in the financial markets which may cause the trust's exposure to any asset class to exceed or fall below the established allowable guidelines.

To evaluate the progress of the portfolio, investment performance is reviewed quarterly.It is, however, expected that performance goals will be met over a full market cycle, normally defined as athreetofiveyear period.Analysis of performance is within the context of the prevailing investment environment and the advisors' investment style.The goal of the trust is to provide a rate of return consistently fromthree percenttofive percentover the rate of inflation (as measured by the national Consumer Price Index) on a fee adjusted basis over a typical market cycle of no less thanthreeyears and no more thanfiveyears.Each investment manager is expected to outperform its respective benchmark.  Below is a list of each asset class utilized with appropriate comparative benchmark(s) each manager is evaluated against:

Asset Class	Comparative Benchmark(s)
Core Fixed Income	Barclays Capital Aggregate Index
Interest Rate Sensitive Fixed Income	Barclays Capital Aggregate Index
Long Duration Fixed Income	Barclays Long Government/Credit
Equity Index	Standard & Poor's 500 Index
All-Cap Equity	Russell 3000 Index
	Russell 3000 Value Index
Mid-Cap Equity	Russell Midcap Index
	Russell Midcap Value Index
Small-Cap Equity	Russell 2000 Index
	Russell 2000 Value Index
International Equity	Morgan Stanley Capital Investment ACWI ex-US

The fixed income manager is expected to use discretion over the asset mix of the trust assets in its efforts to maximize risk-adjusted performance.  Exposure to any single issuer, other than the U.S. government, its agencies, or its instrumentalities (which have no limits) is limited tofive percentof the fixed income portfolio as measured by market value.  At least75 percentof the invested assets must possess an investment grade rating at or above Baa3 or BBB- by Moody's Investors Services, Standard & Poor's Ratings Services or Fitch Ratings.  The portfolio may invest up to10 percentof the portfolio's market value in convertible bonds as long as the securities purchased meet the quality guidelines.The purchase of any of OGE Energy's equity, debt or other securities is prohibited.

The domestic value equity managers focus on stocks that the manager believes are undervalued in price and earn an average or less than average return on assets, and often pays out higher than average dividend payments. The domestic growth equity manager will invest primarily in growth companies which consistently experience above average growth in earnings and sales, earn a high return on assets, and reinvest cash flow into existing business.  The domestic mid-cap equity portfolio manager focuses on companies with market capitalizations lower than the average company traded on the public exchanges with the following characteristics: price/earnings ratio at or near the Russell Midcap Index, small dividend yield, return on equity at or near the Russell Midcap Index and an earnings per share growth rate at or near the Russell Midcap Index.  The domestic small-cap equity manager will purchase shares of companies with market capitalizations lower than the average company traded on the public exchanges with the following characteristics: price/earnings ratio at or near the Russell 2000, small dividend yield, return on equity at or near the Russell 2000 and an earnings per share growth rate at or near the Russell 2000.  The international global equity manager invests primarily in non-dollar denominated equity securities. Investing internationally diversifies the overall trust across the global equity markets.  The manager is required to operate under certain restrictions including: regional constraints, diversification requirements and percentage of U.S. securities. The Morgan Stanley Capital International All Country World ex-US Index is the benchmark for comparative performance purposes. The Morgan Stanley Capital International All Country World ex-US Index is a market value weighted index designed to measure the combined equity market performance of developed and emerging markets countries, excluding the United States. All of the equities which are purchased for the international portfolio are thoroughly researched.  Only companies with a market capitalization in excess of$100 millionare allowable.  No more thanfive percentof the portfolio can be invested in any one stock at the time of purchase. All securities are freely traded on a recognized stock exchange and there are no 144-A securities and no over-the-counter derivatives.  The following investment categories are excluded: options (other than traded currency options), commodities, futures (other than currency futures or currency hedging), short sales/margin purchases, private placements, unlisted securities and real estate (but not real estate shares).

For all domestic equity investment managers, no more thaneight percent (five percentfor mid-cap and small-cap equity managers) can be invested in any one stock at the time of purchase and no more than16 percent (10 percentfor mid-cap and small-cap equity managers) after accounting for price appreciation. Options or financial futures may not be purchased unless prior approval of OGE Energy's Investment Committee is received.  The purchase of securities on margin is prohibited as is securities lending.  Private placement or venture capital may not be purchased.  All interest and dividend payments must be swept on a daily basis into a short-term money market fund for re-deployment.  The purchase of any of OGE Energy's equity, debt or other securities is prohibited.  The purchase of equity or debt issues of the portfolio manager's organization is also prohibited.  The aggregate positions in any company may not exceedone percentof the fair market value of its outstanding stock.

Plan Investments

The following tables summarizeOG&E's portion of OGE Energy'sPension Plan's investments that are measured at fair value on a recurring basis atDecember 31, 2013and2012.  There werenoLevel 3 investments held by the Pension Plan atDecember 31, 2013and2012. 

(In millions)	December 31, 2013			Level 1		Level 2
Common stocks
U.S. common stocks	$	236.8		$	236.8	$	—
Foreign common stocks	39.3			39.3		—
U.S. Government obligations
U.S. treasury notes and bonds (A)	159.8			159.8		—
Mortgage-backed securities	50.3			—		50.3
Bonds, debentures and notes (B)
Corporate fixed income and other securities	110.6			—		110.6
Mortgage-backed securities	22.3			—		22.3
Commingled fund (C)	29.2			—		29.2
Common/collective trust (D)	26.0			—		26.0
Foreign government bonds	4.0			—		4.0
U.S. municipal bonds	2.0			—		2.0
Interest-bearing cash	0.1			0.1		—
Forward contracts
Receivable (foreign currency)	1.1			—		1.1
Payable (foreign currency)	(1.1		)	—		(1.1		)
Total Plan investments	$	680.4		$	436.0	$	244.4
Receivable from broker for securities sold	11.5
Interest and dividends receivable	3.2
Payable to broker for securities purchased	(40.2		)
Plan investments attributable to affiliates	(138.4		)
Total Plan assets	$	516.5

(In millions)	December 31, 2012			Level 1		Level 2
Common stocks
U.S. common stocks	$	232.2		$	232.2	$	—
Foreign common stocks	39.9			39.9		—
U.S. Government obligations
U.S. treasury notes and bonds (A)	138.6			138.6		—
Mortgage-backed securities	55.8			—		55.8
Bonds, debentures and notes (B)
Corporate fixed income and other securities	98.4			—		98.4
Mortgage-backed securities	13.5			—		13.5
Commingled fund (C)	34.9			—		34.9
Common/collective trust (D)	25.6			—		25.6
Foreign government bonds	3.9			—		3.9
U.S. municipal bonds	0.8			—		0.8
Interest-bearing cash	0.2			0.2		—
Forward contracts
Receivable (foreign currency)	0.4			—		0.4
Payable (foreign currency)	(0.4		)	—		(0.4		)
Total Plan investments	$	643.8		$	410.9	$	232.9
Receivable from broker for securities sold	0.8
Interest and dividends receivable	2.8
Payable to broker for securities purchased	(21.4		)
Plan investments attributable to affiliates	(107.0		)
Total Plan assets	$	519.0

(A) This category represents U.S. treasury notes and bonds with a Moody's Investors Services rating of Aaa and Government Agency Bonds with a Moody's Investors Services rating of A1 or higher.

(B) This category primarily represents U.S. corporate bonds with an investment grade rating at or above Baa3 or BBB- by Moody's Investors Services, Standard & Poor's Ratings Services or Fitch Ratings.

(C) This category represents units of participation in a commingled fund that primarily invested in stocks of international companies and emerging markets.

(D) This category represents units of participation in an investment pool which primarily invests in foreign or domestic bonds, debentures, mortgages, equipment or other trust certificates, notes, obligations issued or guaranteed by the U.S. Government or its agencies, bank certificates of deposit, bankers' acceptances and repurchase agreements, high grade commercial paper and other instruments with money market characteristics with a fixed or variable interest rate. There are no restrictions on redemptions in the common/collective trust.

The three levels defined in the fair value hierarchy and examples of each are as follows:

Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessibleby the Pension Planat the measurement date.Instruments classified as Level 1 include investments in common and preferred stocks, U.S. treasury notes and bonds, mutual funds and interest-bearing cash.

Level 2 inputs are inputs other than quoted prices in active markets included within Level 1 that are either directly or indirectly observable at the reporting date for the asset or liability for substantially the full term of the asset or liability.  Level 2 inputs include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.Instruments classified as Level 2 include corporate fixed income and other securities, mortgage-backed securities, other U.S. Government obligations, commingled fund, a common/collective trust, U.S. municipal bonds, foreign government bonds, a repurchase agreement, money market fund and forward contracts.

Level 3 inputs are prices or valuation techniques for the asset or liability that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity).Unobservable inputs reflect thePlan'sown assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk).

Postretirement Benefit Plans

In addition to providing pension benefits,OGE Energyprovides certain medical and life insurance benefits for eligible retired members.  Regular, full-time, active employees hired prior to February 1, 2000 whose age and years of credited service total or exceed 80 or have attained at least age 55 with 10 or more years of service at the time of retirement are entitled to postretirement medical benefits while employees hired on or after February 1, 2000 are not entitled to postretirement medical benefits.Eligible retirees must contribute such amount asOGE Energyspecifies from time to time toward the cost of coverage for postretirement benefits.  The benefits are subject to deductibles, co-payment provisions and other limitations.OG&Echarges to expense the postretirement benefit costsand includes an annual amount as a component of the cost-of-service in future ratemaking proceedings.

OGE Energy'scontribution to the medical costs for pre-65 aged eligible retirees are fixed at the 2011 level andOGE Energycovers future annual medical inflationary cost increases up tofive percent. Increases in excess offive percentannually are covered by the pre-65 aged retiree in the form of premium increases.OGE Energyprovides Medicare-eligible retirees and their Medicare-eligible spouses an annual fixed contribution toOGE Energy'ssponsoredhealth reimbursement arrangement.OGE Energy'sMedicare-eligible retirees are able to purchase individual insurance policies supplemental to Medicare through a third-party administrator and use their health reimbursement arrangement funds for reimbursement of medical premiums and other eligible medical expenses.

Plan Investments

The following tables summarizeOG&E's portion of OGE Energy'spostretirement benefit plans investments that are measured at fair value on a recurring basis atDecember 31, 2013and2012.  There werenoLevel 2 investments held by the postretirement benefit plans atDecember 31, 2013and2012.

(In millions)	December 31, 2013			Level 1		Level 3
Group retiree medical insurance contract (A)	$	53.1		$	—	$	53.1
Mutual funds investment
U.S. equity investments	7.9			7.9		—
Money market funds investment	0.4			0.4		—
Total Plan investments	$	61.4		$	8.3	$	53.1
Plan investments attributable to affiliates	(4.7		)
Total Plan assets	$	56.7

(In millions)	December 31, 2012			Level 1		Level 3
Group retiree medical insurance contract (A)	$	53.3		$	—	$	53.3
Mutual funds investment
U.S. equity investments	6.0			6.0		—
Money market funds investment	0.3			0.3		—
Total Plan investments	$	59.6		$	6.3	$	53.3
Plan investments attributable to affiliates	(4.1		)
Total Plan assets	$	55.5

(A) This category represents a group retiree medical insurance contract which invests in a pool of common stocks, bonds and money market accounts, of which a significant portion is comprised of mortgage-backed securities.

The postretirement benefit plans Level 3 investment includes an investment in a group retiree medical insurance contract. The unobservable input included in the valuation of the contract includes the approach for determining the allocation of the postretirement benefit plans pro-rata share of the total assets in the contract.

The following table summarizes the postretirement benefit plans investments that are measured at fair value on a recurring basis using significant unobservable inputs (Level 3).

Year ended December 31 (In millions)	2013
Group retiree medical insurance contract
Beginning balance	$	53.3
Net unrealized gains related to instruments held at the reporting date	(0.5		)
Interest income	1.1
Dividend income	0.6
Realized gains	0.4
Administrative expenses and charges	(0.1		)
Claims paid	(1.7		)
Ending balance	$	53.1

The following table presents the status ofOG&E's portion of OGE Energy'spostretirement benefit plans atDecember 31, 2013and2012. These amounts have been recorded in Accrued Benefit Obligations with the offsetrecorded as a regulatory asset in OG&E's Balance Sheet as discussed in Note 1. Theregulatory assetrepresents a net periodic benefit cost to be recognized in theStatements of Income in future periods.

December 31 (In millions)	2013			2012
Benefit obligations	$	(202.4	)	$	(236.4	)
Fair value of plan assets	56.7			55.5
Funded status at end of year	$	(145.7	)	$	(180.9	)

The assumed health care cost trend rates have a significant effect on the amounts reported for postretirement medical benefit plans.  Future health care cost trend rates are assumed to be8.35 percentin2014with the rates trending downward to4.48 percentby2028.  A one-percentage point change in the assumed health care cost trend rate would have the following effects:

ONE-PERCENTAGE POINT INCREASE
Year ended December 31 (In millions)	2013		2012		2011
Effect on aggregate of the service and interest cost components	$	—	$	—	$	—
Effect on accumulated postretirement benefit obligations	0.1		0.1		0.1

ONE-PERCENTAGE POINT DECREASE
Year ended December 31 (In millions)	2013		2012		2011
Effect on aggregate of the service and interest cost components	$	—	$	0.1	$	0.1
Effect on accumulated postretirement benefit obligations	0.4		0.7		0.4

Medicare Prescription Drug, Improvement and Modernization Act of 2003

The Medicare Prescription Drug, Improvement and Modernization Act of 2003 expanded coverage for prescription drugs.  The following table summarizes the gross benefit payments OG&E expects to pay related to its postretirement benefit plans, including prescription drug benefits.

(In millions)	Gross Projected Postretirement Benefit Payments
2014	$	13.1
2015	13.5
2016	13.8
2017	14.0
2018	14.3
After 2018	71.6

Obligations and Funded Status

The following table presents the status ofOG&E's portion of OGE Energy'sPension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans for2013and2012. OG&E's portion of the benefit obligation for OGE Energy'sPension Plan and the Restoration of Retirement Income Plan represents the projected benefit obligation, while the benefit obligation for the postretirement benefit plans represents the accumulated postretirement benefit obligation. The accumulated postretirement benefit obligation forOGE Energy'sPension Plan and Restoration of Retirement Income Plan differs from the projected benefit obligation in that the former includes no assumption about future compensation levels. The accumulated postretirement benefit obligation for the Pension Plan and the Restoration of Retirement Income Plan atDecember 31, 2013was$483.0 millionand$1.9 million, respectively. The accumulated postretirement benefit obligation for the Pension Plan and the Restoration of Retirement Income Plan atDecember 31, 2012was$549.3 millionand$2.1 million, respectively. The details of the funded status of the Pension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans and the amounts included in theBalance Sheets are as follows:

	Pension Plan						Restoration of Retirement Income Plan						Postretirement Benefit Plans
December 31 (In millions)	2013			2012			2013			2012			2013			2012
Change in Benefit Obligation
Beginning obligations	$	(574.6	)	$	(546.9	)	$	(2.2	)	$	(2.2	)	$	(236.4	)	$	(223.1	)
Service cost	(11.6		)	(10.9		)	(0.1		)	(0.1		)	(2.9		)	(2.7		)
Interest cost	(20.4		)	(23.5		)	(0.1		)	(0.1		)	(8.1		)	(9.4		)
Participants' contributions	49.9			—			—			—			(2.5		)	(2.5		)
Medicare subsidies received	—			—			—			—			—			(0.5		)
Actuarial gains (losses)	39.8			(43.7		)	0.2			(0.4		)	35.4			(9.4		)
Benefits paid	13.3			50.4			0.1			0.6			12.1			11.2
Ending obligations	$	(503.6	)	$	(574.6	)	$	(2.1	)	$	(2.2	)	$	(202.4	)	$	(236.4	)
Change in Plans' Assets
Beginning fair value	$	519.0		$	485.9		$	—		$	—		$	55.5		$	57.2
Actual return on plans' assets	60.7			50.5			—			—			3.4			4.3
Employer contributions	—			33.0			0.1			0.6			7.4			2.2
Participants' contributions	(49.9		)	—			—			—			2.5			2.5
Medicare subsidies received	—			—			—			—			—			0.5
Benefits paid	(13.3		)	(50.4		)	(0.1		)	(0.6		)	(12.1		)	(11.2		)
Ending fair value	$	516.5		$	519.0		$	—		$	—		$	56.7		$	55.5
Funded status at end of year	$	12.9		$	(55.6	)	$	(2.1	)	$	(2.2	)	$	(145.7	)	$	(180.9	)

Net Periodic Benefit Cost

	Pension Plan									Restoration of Retirement Income Plan						Postretirement Benefit Plans
Year ended December 31 (In millions)	2013			2012			2011			2013		2012		2011		2013			2012			2011
Service cost	$	11.6		$	10.9		$	10.8		$	0.1	$	0.1	$	0.1	$	2.9		$	2.7		$	2.4
Interest cost	20.4			23.5			26.2			0.1		0.1		0.1		8.1			9.4			10.0
Expected return on plan assets	(38.9		)	(38.2		)	(37.3		)	—		—		—		(2.4		)	(2.8		)	(4.9		)
Amortization of transition obligation	—			—			—			—		—		—		—			2.5			2.6
Amortization of net loss	20.7			19.3			15.6			—		0.1		0.1		18.2			17.4			15.5
Amortization of unrecognized prior service cost (A)	1.9			2.2			2.5			0.1		0.2		0.2		(13.7		)	(13.6		)	(13.7		)
Settlement	17.6			—			—			—		0.3		—		—			—			—
Net periodic benefit cost (B)	$	33.3		$	17.7		$	17.8		$	0.3	$	0.8	$	0.5	$	13.1		$	15.6		$	11.9

(A) Unamortized prior service cost is amortized on a straight-line basis over the average remaining service period to the first eligibility age of participants who are expected to receive a benefit and are active at the date of the plan amendment.

(B) In addition to the$46.7 million, $34.1 millionand$30.2 millionof net periodic benefit cost recognized in2013, 2012and2011, respectively, OG&E recognized the following:

• an increase in pension expense in2013, 2012 and 2011 of $5.8 million, $8.3 millionand$10.8 million, respectively,to maintain the allowable amount to be recovered for pension expense in the Oklahoma jurisdiction, which are included in the Pension tracker regulatory asset or liability (see Note 1); and

• an increase in postretirement medical expense in2013and2012of$0.6 millionand$0.8 millionrespectively, to maintain the allowable amount to be recovered for postretirement medical expense in the Oklahoma jurisdiction which are included in the Pension tracker regulatory asset or liability (see Note 1);

• a deferral of pension expense in 2013 of$17.0 million which includes a portion of OGE Energy's pension settlement charge, related to the pension settlement charge of$17.6 million which is included in the Pension tracker regulatory account (see Note 1).

The capitalized portion of the net periodic pension benefit cost was$4.2 million, $5.5 millionand$5.3 millionatDecember 31, 2013, 2012and2011, respectively.  The capitalized portion of the net periodic postretirement benefit cost was$3.4 million, $4.7 millionand$3.3 millionatDecember 31, 2013, 2012and2011, respectively.

Rate Assumptions

	Pension Plan and Restoration of Retirement Income Plan						Postretirement Benefit Plans
Year ended December 31	2013		2012		2011		2013		2012		2011
Discount rate	4.60	%	3.70	%	4.50	%	4.60	%	3.60	%	4.50	%
Rate of return on plans' assets	8.00	%	8.00	%	8.00	%	4.00	%	4.00	%	6.50	%
Compensation increases	4.20	%	4.20	%	4.40	%	N/A		N/A		N/A
Assumed health care cost trend:
Initial trend	N/A		N/A		N/A		8.35	%	8.55	%	8.75	%
Ultimate trend rate	N/A		N/A		N/A		4.48	%	4.48	%	4.48	%
Ultimate trend year	N/A		N/A		N/A		2028		2028		2028

N/A - not applicable

The overall expected rate of return on plan assets assumption remained at8.00 percentin2012and2013in determining net periodic benefit cost due to recent returns onOGE Energy'slong-term investment portfolio. The rate of return on plan assets assumption is the average long-term rate of earnings expected on the funds currently invested and to be invested for the purpose of providing benefits specified by the Pension Plan or postretirement benefit plans.  This assumption is reexamined at least annually and updated as necessary.  The rate of return on plan assets assumption reflects a combination of historical return analysis, forward-looking return expectations and the plans' current and expected asset allocation.

Post-Employment Benefit Plan

Disabled employees receiving benefits fromOGE Energy'sGroup Long-Term Disability Plan are entitled to continue participating inOGE Energy'sMedical Plan along with their dependents.  The post-employment benefit obligation represents the actuarial present value of estimated future medical benefits that are attributed to employee service rendered prior to the date as of which such information is presented.  The obligation also includes future medical benefits expected to be paid to current employees participating inOGE Energy'sGroup Long-Term Disability Plan and their dependents, as defined inOGE Energy'sMedical Plan.

The post-employment benefit obligation is determined by an actuary on a basis similar to the accumulated postretirement benefit obligation.  The estimated future medical benefits are projected to grow with expected future medical cost trend rates and are discounted for interest at the discount rate and for the probability that the participant will discontinue receiving benefits fromOGE Energy'sGroup Long-Term Disability Plan due to death, recovery from disability, or eligibility for retiree medical benefits.  OG&E's post-employment benefit obligation was$1.4 millionand$2.2 millionatDecember 31, 2013and2012, respectively.

401(k) Plan

OGE Energyprovides a 401(k) Plan.  Each regular full-time employee ofOGE Energyor a participating affiliate is eligible to participate in the 401(k) Plan immediately.  All other employees ofOGE Energyor a participating affiliate are eligible to become participants in the 401(k) Plan after completing one year of service as defined in the 401(k) Plan.Participants may contribute each pay period any whole percentage betweentwo percentand19 percentof their compensation, as defined in the 401(k) Plan, for that pay period.Participants who have attained age 50 before the close of a year are allowed to make additional contributions referred to as "Catch-Up Contributions," subject to certain limitations of the Code.Participants may designate, at their discretion, all or any portion of their contributions as: (i) a before-tax contribution under Section 401(k) of the Code subject to the limitations thereof; or (ii) a contribution made on an after-tax basis.The 401(k) Plan also includes an eligible automatic contribution arrangement and provides for a qualified default investment alternative consistent with the U.S. Department of Labor regulations. Participants may elect, in accordance with the 401(k) Plan procedures, to have his or her future salary deferral rate to be automatically increased annually on a date and in an amount as specified by the participant in such election.

NoOGE Energycontributions are made with respect to a participant's Catch-Up Contributions, rollover contributions, or with respect to a participant's contributions based on overtime payments, pay-in-lieu of overtime for exempt personnel, special lump-sum recognition awards and lump-sum merit awards included in compensation for determining the amount of participant contributions.Once made,OGE Energy'scontribution may be directed to any available investment option in the 401(k) Plan.OGE Energymatch contributions vest over athree-year period.Aftertwoyears of service, participants become20 percentvested in theirOGE Energycontribution account and become fully vested on completingthreeyears of service. In addition, participants fully vest when they are eligible for normal or early retirement under the Pension Plan, in the event of their termination due to death or permanent disability or upon attainment of age 65 while employed byOGE Energyor its affiliates.  OG&E contributed$7.8 million, $7.6 millionand$7.0 millionin2013, 2012and2011, respectively, to the 401(k) Plan.

Deferred Compensation Plan

OGE Energyprovides a nonqualified deferred compensation plan which is intended to be an unfunded plan.  The plan's primary purpose is to provide a tax-deferred capital accumulation vehicle for a select group of management, highly compensated employees and non-employee members of the Board of Directors ofOGE Energyand to supplement such employees' 401(k) Plan contributions as well as offering this plan to be competitive in the marketplace.

Eligible employees who enroll in the plan have the following deferral options: (i) eligible employees may elect to defer up to a maximum of70 percentof base salary and100 percentof annual bonus awards or (ii) eligible employees may elect a deferral percentage of base salary and bonus awards based on the deferral percentage elected for a year under the 401(k) Plan with such deferrals to start when maximum deferrals to the qualified 401(k) Plan have been made because of limitations in that plan. Eligible directors who enroll in the plan may elect to defer up to a maximum of100 percentof directors' meeting fees and annual retainers.OGE Energymatches employee (but not non-employee director) deferrals to make up for any match lost in the 401(k) Plan because of deferrals to the deferred compensation plan, and to allow for a match that would have been made under the 401(k) Plan on that portion of either the firstsix percentof total compensation or the firstfive percentof total compensation, depending on the option the participant elected under the choice provided to eligible employees in the qualified 401(k) Plan discussed above, deferred that exceeds the limits allowed in the 401(k) Plan. Matching credits vest based on years of service, with full vesting afterthreeyears or, if earlier, on retirement, disability, death, a change in control ofOGE Energyor termination of the plan.Deferrals, plus anyOGE Energymatch, are credited to a recordkeeping account in the participant's name. Earnings on the deferrals are indexed to the assumed investment funds selected by the participant.In2013, those investment optionsincludedan OGE EnergyCommon Stock fund, whose value was determined based on the stock price ofOGE Energy'sCommon Stock.

Supplemental Executive Retirement Plan

OGE Energy provides a supplemental executive retirement plan in order to attract and retain lateral hires or other executives designated by the Compensation Committee ofOGE Energy'sBoard of Directors who may not otherwise qualify for a sufficient level of benefits underOGE Energy'sPension Plan and Restoration of Retirement Income Plan.The supplemental executive retirement plan is intended to be an unfunded plan and not subject to the benefit limitations of the Code.

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Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2013

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Accounting, Policy [Policy Text Block]

Basis of Presentation

In the opinion of management, all adjustments necessary to fairly present thefinancial position of OG&E atDecember 31, 2013and2012and the results of its operations and cash flows for the years endedDecember 31, 2013, 2012and2011, have been included and are of a normal recurring nature except as otherwise disclosed.

Public Utilities, Policy [Policy Text Block]

Accounting Records

The accounting records of OG&E are maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the OCC and the APSC.  Additionally,OG&E, as a regulated utility, is subject to accounting principles for certain types of rate-regulated activities, which provide that certain actual or anticipated costs that would otherwise be charged to expense can be deferred as regulatory assets, based on the expected recovery from customers in future rates.  Likewise, certain actual or anticipated credits that would otherwise reduce expense can be deferred as regulatory liabilities, based on the expected flowback to customers in future rates.  Management's expected recovery of deferred costs and flowback of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment.

OG&E records certain actual or anticipated costs and obligations as regulatory assets or liabilities if it is probable, based on regulatory orders or other available evidence, that the cost or obligation will be included in amounts allowable for recovery or refund in future rates.

Management continuously monitors the future recoverability of regulatory assets.When in management's judgment future recovery becomes impaired, the amount of the regulatory asset is adjusted, as appropriate.IfOG&Ewere required to discontinue the application of accounting principles for certain types of rate-regulated activities for some or all of its operations, it could result in writing off the related regulatory assets, which could have significant financial effects.

Use of Estimates, Policy [Policy Text Block]

Use of Estimates

In preparing theFinancial Statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and contingent liabilities at the date of theFinancial Statements and the reported amounts of revenues and expenses during the reporting period.  Changes to these assumptions and estimates could have a material effect onOG&E'sFinancial Statements.  However,OG&Ebelieves it has taken reasonable positions where assumptions and estimates are used in order to minimize the negative financial impact toOG&Ethat could result if actual results vary from the assumptions and estimates.  In management's opinion, the areas ofOG&Ewhere the most significant judgment is exercisedincludes the determination of Pension Plan assumptions,impairment estimates of long-lived assets (including intangible assets), income taxes,contingency reserves, asset retirement obligations, assets and depreciable lives of property, plant and equipment, the existence of regulatory assets and liabilities and unbilled revenues.

Cash and Cash Equivalents, Policy [Policy Text Block]

Cash and Cash Equivalents

For purposes of theFinancial Statements, OG&E considers all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents.  These investments are carried at cost, which approximates fair value.

Allowance for Doubtful Accounts, Policy [Policy Text Block]

Allowance for Uncollectible Accounts Receivable

Customer balances are generally written off if not collected within six months after the final billing date. The allowance for uncollectible accounts receivable for OG&E is calculated by multiplying the last six months of electric revenue by the provision rate.  The provision rate is based on a 12-month historical average of actual balances written off.  To the extent the historical collection rates are not representative of future collections, there could be an effect on the amount of uncollectible expense recognized.  Also, a portion of the uncollectible provision related to fuel within the Oklahoma jurisdiction is being recovered through the fuel adjustment clause.The allowance for uncollectible accounts receivable was$1.9 millionand$2.6 millionatDecember 31, 2013 and 2012, respectively.

New business customers are required to provide a security deposit in the form of cash, bond or irrevocable letter of credit that is refunded when the account is closed.  New residential customers, whose outside credit scores indicate an elevated risk, are required to provide a security deposit that is refunded based on customer protection rules defined by the OCC and the APSC.  The payment behavior of all existing customers is continuously monitored and, if the payment behavior indicates sufficient risk within the meaning of the applicable utility regulation, customers will be required to provide a security deposit.

Inventory, Policy [Policy Text Block]

Fuel Inventories

Fuel inventories for the generation of electricity consist of coal, natural gas and oil.  OG&E uses the weighted-average cost method of accounting for inventory that is physically added to or withdrawn from storage or stockpiles.  The amount of fuel inventory was$74.4 millionand$76.8 millionatDecember 31, 2013and2012, respectively.

Gas Imbalances, Policy [Policy Text Block]

Gas Imbalances

Gas imbalances occur when the actual amounts of natural gas delivered from or received byOG&Ediffer from the amounts scheduled to be delivered or received.OG&Evalues all imbalances at an average of current market indices applicable toOG&E's operations, not to exceed net realizable value.

Property, Plant and Equipment, Policy [Policy Text Block]

Property, Plant and Equipment

All property, plant and equipment is recorded at cost.  Newly constructed plant is added to plant balances at cost which includes contracted services, direct labor, materials, overhead, transportation costs and the allowance for funds used during construction.  Replacements of units of property are capitalized as plant.  For assets that belong to a common plant account, the replaced plant is removed from plant balances and the cost of such property is charged to Accumulated Depreciation.  For assets that do not belong to a common plant account, the replaced plant is removed from plant balances with the related accumulated depreciation and the remaining balance net of any salvage proceeds is recorded as a loss in theStatements of Income as Other Expense.  Repair and replacement of minor items of property are included in theStatements of Income as Other Operation and Maintenance Expense.

Depreciation and Amortization, Policy [Policy Text Block]

Depreciation and Amortization

The provision for depreciation, which was2.8 percentand3.0 percent, respectively, of the average depreciable utility plant for2013and2012, is provided on a straight-line method over the estimated service life of the utility assets.  Depreciation is provided at the unit level for production plant and at the account or sub-account level for all other plant, and is based on the average life group method. In2014, the provision for depreciation is projected to be2.8 percentof the average depreciable utility plant. Amortization of intangible assets is computed using the straight-line method. Of the remaining amortizable intangible plant balance atDecember 31, 2013, 93.5 percentwill be amortized over9.30years with6.5 percentof the remaining amortizable intangible plant balance atDecember 31, 2013being amortized over25.6years.Amortization of plant acquisition adjustments is provided on a straight-line basis over the estimated remaining service life of the acquired asset.  Plant acquisition adjustments include$148.3 millionfor the Redbud Plant, which are being amortized over a27-yearlife and$3.3 millionfor certain substation facilities in OG&E's service territory, which are being amortized over a26to59-yearperiod.

Asset Retirement Obligations, Policy [Policy Text Block]

Asset Retirement Obligations

OG&Ehas previously recorded asset retirement obligations that are being amortized over their respective lives ranging from20to74years.

Allowance for Funds Used During Construction, Policy [Policy Text Block]

Allowance for Funds Used During Construction

For OG&E, allowance for funds used during construction is calculated according to the FERC pronouncements for the imputed cost of equity and borrowed funds.  Allowance for funds used during construction, a non-cash item, is reflected as an increase to net other income and a reduction to interest expense in theStatements of Income and as an increase to Construction Work in Progress in theBalance Sheets.Allowance for funds used during construction rates, compounded semi-annually, were8.33 percent, 8.93 percentand8.71 percentfor the years endedDecember 31, 2013, 2012and2011, respectively.Thedecreasein the allowance for funds used during construction rates in 2013 was primarily due to two factors. First, a decrease in the common equity cost rate caused the equity portion of allowance for equity funds used during construction to decrease. Second, an increase in the average daily balance of short term debt allowed the fixed commercial paper fees to be lower per dollar of short term debt, resulting in a lower short term debt rate, which caused the debt portion of allowance for funds used during construction to decrease.

Collection of Sales Tax, Policy [Policy Text Block]

Collection of Sales Tax

In the normal course of its operations, OG&E collects sales tax from its customers.  OG&E records a current liability for sales taxes when it bills its customers and eliminates this liability when the taxes are remitted to the appropriate governmental authorities.  OG&E excludes the sales tax collected from its operating revenues.

Revenue Recognition, Policy [Policy Text Block]

General

OG&E reads its customers' meters and sends bills to its customers throughout each month.  As a result, there is a significant amount of customers' electricity consumption that has not been billed at the end of each month.  Unbilled revenue is presented in Accrued Unbilled Revenues on theBalance Sheets and in Operating Revenues on theStatements of Income based on estimates of usage and prices during the period.The estimates that management uses in this calculation could vary from the actual amounts to be paid by customers.

SPP Purchases and Sales

OG&E participates in the SPP energy imbalance service market in a dual role as a load serving entity and as a generation owner.  The energy imbalance service market requires cash settlements for over or under schedules of generation and load. Market participants, including OG&E, are required to submit resource plans and can submit offer curves for each resource available for dispatch.  A function of interchange accounting is to match participants' MWH entitlements (generation plus scheduled bilateral purchases) against their MWH obligations (load plus scheduled bilateral sales) during every hour of every day. If the net result during any given hour is an entitlement, the participant is credited with a spot-market sale to the SPP at the respective market price for that hour; if the net result is an obligation, the participant is charged with a spot-market purchase from the SPP at the respective market price for that hour. The SPP purchases and sales are not allocated to individual customers.  OG&E records the hourly sales to the SPP at market rates in Operating Revenues and the hourly purchases from the SPP at market rates in Cost of Sales in itsFinancial Statements.

Fuel Adjustment Clauses, Policy [Policy Text Block]

Fuel Adjustment Clauses

Variances in the actual cost of fuel used in electric generation and certain purchased power costs, as compared to the fuel component included in the cost-of-service for ratemaking, are passed through to OG&E's customers through fuel adjustment clauses. The fuel adjustment clauses are subject to periodic review by the OCC, the APSC and the FERC. The OCC, the APSC and the FERC have authority to review the appropriateness of gas transportation charges or other fees OG&E pays to its affiliate, Enable.

Income Taxes, Policy [Policy Text Block]

Income Taxes

OG&E isa member of an affiliated group thatfilesconsolidated income tax returns in the U.S. Federal jurisdiction and various state jurisdictions. Income taxesaregenerally allocated to each company in the affiliated group based on its stand-alone taxable income or loss.Federal investment tax credits previously claimed on electric utility property have been deferred and are being amortized to income over the life of the related property.  OG&E uses the asset and liability method of accounting for income taxes. Under this method, a deferred tax asset or liability is recognized for the estimated future tax effects attributable to temporary differences between the financial statement basis and the tax basis of assets and liabilities as well as tax credit carry forwards and net operating loss carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period of the change. OG&E recognizes interest related to unrecognized tax benefits in interest expense and recognizes penalties in other expense.

Accrued Vacation, Policy [Policy Text Block]

Accrued Vacation

OG&E accrues vacation pay monthly by establishing a liability for vacation earned. Vacation may be taken as earned and is charged against the liability. At the end of each year, the liability represents the amount of vacation earned, but not taken. OGE employees can carryover no more than 80 hours to be used in future years.

Environmental Costs, Policy [Policy Text Block]

Environmental Costs

Accruals for environmental costs are recognized when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated.  Costs are charged to expenseor deferred as a regulatory asset based on expected recovery from customers in future rates,if they relate to the remediation of conditions caused by past operations or if they are not expected to mitigate or prevent contamination from future operations.  Where environmental expenditures relate to facilities currently in use, such as pollution control equipment, the costs may be capitalized and depreciated over the future service periods.  Estimated remediation costs are recorded at undiscounted amounts, independent of any insuranceor raterecovery, based on prior experience, assessments and current technology.  Accrued obligations are regularly adjusted as environmental assessments and estimates are revised, and remediation efforts proceed.For sites whereOG&E has been designated as one of several potentially responsible parties, the amount accrued representsOG&E'sestimated share of the cost.  OG&E had$6.2 millionand$5.8 millioninaccrued environmental liabilities atDecember 31, 2013and2012, respectively, which are included in the summary of asset retirement obligations above.

Related Party Transactions [Policy Text Block]

OGE Energy charges operating costs to its subsidiaries and unconsolidated affiliate based on several factors. Operating costs directly related to specific subsidiaries or unconsolidated affiliate are assigned to those subsidiaries or unconsolidated affiliate.Where more than one subsidiary or unconsolidated affiliate benefits from certain expenditures, the costs are shared between those subsidiaries and unconsolidated affiliate receiving the benefits.  Operating costs incurred for the benefit of all subsidiaries and unconsolidated affiliate are allocated among the subsidiaries and unconsolidated affiliate, either as overhead based primarily on labor costs or using the "Distrigas" method.  The Distrigas method is a three-factor formula that uses an equal weighting of payroll, net operating revenues and gross property, plant and equipment.  OGE Energy adopted the Distrigas method in January 1996 as a result of a recommendation by the OCC Staff.  OGE Energy believes this method provides a reasonable basis for allocating common expenses.

Fair Value of Financial Instruments, Policy [Policy Text Block]

The carrying value of the financial instruments included in theBalance Sheets approximates fair value except for long-term debt which is valued at the carrying amount.The fair value of OG&E's long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturitiesand is classified as Level 2 in the fair value hierarchy.

Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]

Performance Units – Earnings Per Share

The fair value of the performance units based on earnings per share is based on grant date fair value which is equivalent to the price of one share ofOGE Energy'scommon stock on the date of grant.  The fair value of performance units based on earnings per share varies as the number of performance units that will vest is based on the grant date fair value of the units and the probable outcome of the performance condition.OGE Energyreassesses at each reporting date whether achievement of the performance condition is probable and accrues compensation expense if and when achievement of the performance condition is probable.  As a result, the compensation expense recognized for these performance units can vary from period to period.  There are no post-vesting restrictions related toOGE Energy'sperformance units based on earnings per share.

Restricted Stock

Under the 2008 Stock Incentive Plan and beginning in 2008, OGE Energyissued restricted stock to certain existing non-officer employees as well as other executives upon hire to attract and retain individuals to be competitive in the marketplace. The restricted stock vests in one-third annual increments.  Prior to vesting, each share of restricted stock is subject to forfeiture if the recipient ceases to render substantial services toOGE Energyor a subsidiary for any reason other than death, disability or retirement. These shares may not be sold, assigned, transferred or pledged and are subject to a risk of forfeiture.

The fair value of the restricted stock was based on the closing market price ofOGE Energy'scommon stock on the grant date. Compensation expense for the restricted stock is a fixed amount determined at the grant date fair value and is recognized as services are rendered by employees over a three-year vesting period. Also, OG&E treats its restricted stock as multiple separate awards by recording compensation expense separately for each tranche whereby a substantial portion of the expense is recognized in the earlier years in the requisite service period. Dividends are accrued and paid during the vesting period and, therefore, are included in the fair value calculation. The expected life of the restricted stock is based on the non-vested period since inception of the three-year award cycle.  There are no post-vesting restrictions related toOGE Energy'srestricted stock.

Performance Units

Under the 2008 Stock Incentive Plan,OGE Energyhas issued performance units which represent the value of one share ofOGE Energy'scommon stock.  The performance units provide for accelerated vesting if there is a change in control (as defined in the 2008 Stock Incentive Plan).  Each performance unit is subject to forfeiture if the recipient terminates employment withOGE Energyor a subsidiary prior to the end of the three-year award cycle for any reason other than death, disability or retirement.  In the event of death, disability or retirement, a participant will receive a prorated payment based on such participant's number of full months of service during the award cycle, further adjusted based on the achievement of the performance goals during the award cycle.

The performance units granted based on total shareholder return are contingently awarded and will be payable in shares ofOGE Energy'scommon stock subject to the condition that the number of performance units, if any, earned by the employees upon the expiration of a three-year award cycle (i.e., three-year cliff vesting period) is dependent onOGE Energy'stotal shareholder return ranking relative to a peer group of companies.  The performance units granted based on earnings per share are contingently awarded and will be payable in shares ofOGE Energy'scommon stock based onOGE Energy'searnings per share growth over a three-year award cycle (i.e., three-year cliff vesting period) compared to a target set at the time of the grant by the Compensation Committee ofOGE Energy'sBoard of Directors. All of theseperformance units are classified as equity inOGE Energy'sConsolidated Balance Sheet.  If there is no or only a partial payout for the performance units at the end of the award cycle, the unearned performance units are cancelled. Payout requires approval of the Compensation Committee ofOGE Energy'sBoard of Directors. Payouts, if any, are all made in common stock and are considered made when the payout is approved by the Compensation Committee.

Stock Options

OGE Energy last issued stock options in2004and as ofDecember 31, 2006, all stock options were fully vested and expensed. All stock options have a contractual life of10years.

Performance Units – Total Shareholder Return

The fair value of the performance units based on total shareholder return was estimated on the grant date using a lattice-based valuation model that factors in information, including the expected dividend yield, expected price volatility, risk-free interest rate and the probable outcome of the market condition, over the expected life of the performance units.  Compensation expense for the performance units is a fixed amount determined at the grant date fair value and is recognized over the three-year award cycle regardless of whether performance units are awarded at the end of the award cycle.  Dividends are not accrued or paid during the performance period and, therefore, are not included in the fair value calculation.  Expected price volatility is based on the historical volatility ofOGE Energy'scommon stock for the past three years and was simulated using the Geometric Brownian Motion process.  The risk-free interest rate for the performance unit grants is based on the three-year U.S. Treasury yield curve in effect at the time of the grant.  The expected life of the units is based on the non-vested period since inception of the award cycle.  There are no post-vesting restrictions related toOGE Energy'sperformance units based on total shareholder return.

Pension and Other Postretirement Plans, Policy [Policy Text Block]

respectively.

Rate Assumptions

	Pension Plan and Restoration of Retirement Income Plan						Postretirement Benefit Plans
Year ended December 31	2013		2012		2011		2013		2012		2011
Discount rate	4.60	%	3.70	%	4.50	%	4.60	%	3.60	%	4.50	%
Rate of return on plans' assets	8.00	%	8.00	%	8.00	%	4.00	%	4.00	%	6.50	%
Compensation increases	4.20	%	4.20	%	4.40	%	N/A		N/A		N/A
Assumed health care cost trend:
Initial trend	N/A		N/A		N/A		8.35	%	8.55	%	8.75	%
Ultimate trend rate	N/A		N/A		N/A		4.48	%	4.48	%	4.48	%
Ultimate trend year	N/A		N/A		N/A		2028		2028		2028

N/A - not applicable

The overall expected rate of return on plan assets assumption remained at8.00 percentin2012and2013in determining net periodic benefit cost due to recent returns onOGE Energy'slong-term investment portfolio. The rate of return on plan assets assumption is the average long-term rate of earnings expected on the funds currently invested and to be invested for the purpose of providing benefits specified by the Pension Plan or postretirement benefit plans.  This assumption is reexamined at least annually and updated as necessary.  The rate of return on plan assets assumption reflects a combination of historical return analysis, forward-looking return expectations and the plans' current and expected asset allocation.

Post-Employment Benefit Plan

The three levels defined in the fair value hierarchy and examples of each are as follows:

Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessibleby the Pension Planat the measurement date.Instruments classified as Level 1 include investments in common and preferred stocks, U.S. treasury notes and bonds, mutual funds and interest-bearing cash.

Level 2 inputs are inputs other than quoted prices in active markets included within Level 1 that are either directly or indirectly observable at the reporting date for the asset or liability for substantially the full term of the asset or liability.  Level 2 inputs include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.Instruments classified as Level 2 include corporate fixed income and other securities, mortgage-backed securities, other U.S. Government obligations, commingled fund, a common/collective trust, U.S. municipal bonds, foreign government bonds, a repurchase agreement, money market fund and forward contracts.

Level 3 inputs are prices or valuation techniques for the asset or liability that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity).Unobservable inputs reflect thePlan'sown assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk).

OGE Energy provides a Restoration of Retirement Income Plan to those participants inOGE Energy'sPension Plan whose benefits are subject to certain limitations of the Code.  Participants in the Restoration of Retirement Income Planreceive the same benefits that they would have received underOGE Energy'sPension Plan in the absence of limitations imposed by the Federal tax laws.The Restoration of Retirement Income Plan is intended to be an unfunded plan.

Pension Plan and Restoration of Retirement Income Plan

OG&E's employees participate inOGE Energy'sPension Plan and Restoration of Retirement Income Plan.

Employees hired or rehired on or after December 1, 2009 do not participate in the Pension Plan but are eligible to participate in the 401(k) Plan where, for each pay period,OGE Energycontributes to the 401(k) Plan, on behalf of each participant,200 percentof the participant's contributions up tofive percentof compensation.

It isOGE Energy'spolicyto fund the Pension Plan on a current basis based on the net periodic pension expense as determined byOGE Energy'sactuarial consultants.During both2013and2012, OGE Energy made contributions to its Pension Plan of$35 millionof whichnonein 2013 and$33 millionin 2012 was OG&E's portion,to help ensure that the Pension Plan maintains an adequate funded status.Such contributions are intended to provide not only for benefits attributed to service to date, but also for those expected to be earned in the future.During2014, OGE Energy expects to contribute up to$26 millionto its Pension Plan, of which$1 millionis expected to be OG&E's portion.The expected contribution to the Pension Plan during 2014 would be a discretionary contribution, anticipated to be in the form of cash, and is not required to satisfy the minimum regulatory funding requirement specified by the Employee Retirement Income Security Act of 1974, as amended.OGE Energy could be required to make additional contributions if the value of its pension trust and postretirement benefit plan trust assets are adversely impacted by a major market disruption in the future.

In accordance with ASC Topic 715, "Compensation - Retirement Benefits," a one-time settlement charge is required to be recorded by an organization when lump sum payments or other settlements that relieve the organization from the responsibility for the pension benefit obligation during a plan year exceed the service cost and interest cost components of the organization’s net periodic pension cost. During 2013, OG&E experienced an increase in both the number of employees electing to retire and the amount of lump sum payments to be paid to such employees upon retirement. As a result, and based in part on OG&E's historical experience regarding eligible employees who elect to retire in the last quarter of a particular year, OG&E recorded pension settlement charges of$17.6 millionin the fourth quarter of 2013, of which$17.0 millionrelated to OG&E’s Oklahoma jurisdiction and has been included in the pension tracker. The pension settlement charge did not require a cash outlay by OG&E and did not increase OG&E’s total pension expense over time, as the charges were an acceleration of costs that otherwise would be recognized as pension expense in future periods.

Postretirement Benefit Plans

In addition to providing pension benefits,OGE Energyprovides certain medical and life insurance benefits for eligible retired members.  Regular, full-time, active employees hired prior to February 1, 2000 whose age and years of credited service total or exceed 80 or have attained at least age 55 with 10 or more years of service at the time of retirement are entitled to postretirement medical benefits while employees hired on or after February 1, 2000 are not entitled to postretirement medical benefits.Eligible retirees must contribute such amount asOGE Energyspecifies from time to time toward the cost of coverage for postretirement benefits.  The benefits are subject to deductibles, co-payment provisions and other limitations.OG&Echarges to expense the postretirement benefit costsand includes an annual amount as a component of the cost-of-service in future ratemaking proceedings.

Plan Investments, Policies and Strategies, Policy [Policy Text Block]

Plan Investments, Policies and Strategies

The Pension Plan assets are held in a trust which follows an investment policy and strategy designed to reduce the funded status volatility of the Plan by utilizing liability driven investing. The purpose of liability driven investing is to structure the asset portfolio to more closely resemble the pension liability and thereby more effectively hedge against changes in the liability. The investment policy follows a glide path approach that shifts a higher portfolio weighting to fixed income as the Plan's funded status increases. The table below sets forth the targeted fixed income and equity allocations at different funded status levels.

Projected Benefit Obligation Funded Status Thresholds	<90%	95%	100%	105%	110%	115%	120%
Fixed income	50%	58%	65%	73%	80%	85%	90%
Equity	50%	42%	35%	27%	20%	15%	10%
Total	100%	100%	100%	100%	100%	100%	100%

Within the portfolio's overall allocation to equities, the funds are allocated according to the guidelines in the table below.

Asset Class	Target Allocation	Minimum	Maximum
Domestic All-Cap/Large Cap Equity	50%	50%	60%
Domestic Mid-Cap Equity	15%	5%	25%
Domestic Small-Cap Equity	15%	5%	25%
International Equity	20%	10%	30%

OGE Energy has retained an investment consultant responsible for the general investment oversight, analysis, monitoring investment guideline compliance and providing quarterly reports to certain of OG&E's members and OGE Energy's Investment Committee.The various investment managers used by the trust operate within the general operating objectives as established in the investment policy and within the specific guidelines established for each investment manager's respective portfolio.

The portfolio is rebalanced on an annual basis to bring the asset allocations of various managers in line with the target asset allocation listed above.  More frequent rebalancing may occur if there are dramatic price movements in the financial markets which may cause the trust's exposure to any asset class to exceed or fall below the established allowable guidelines.

To evaluate the progress of the portfolio, investment performance is reviewed quarterly.It is, however, expected that performance goals will be met over a full market cycle, normally defined as athreetofiveyear period.Analysis of performance is within the context of the prevailing investment environment and the advisors' investment style.The goal of the trust is to provide a rate of return consistently fromthree percenttofive percentover the rate of inflation (as measured by the national Consumer Price Index) on a fee adjusted basis over a typical market cycle of no less thanthreeyears and no more thanfiveyears.Each investment manager is expected to outperform its respective benchmark.  Below is a list of each asset class utilized with appropriate comparative benchmark(s) each manager is evaluated against:

Asset Class	Comparative Benchmark(s)
Core Fixed Income	Barclays Capital Aggregate Index
Interest Rate Sensitive Fixed Income	Barclays Capital Aggregate Index
Long Duration Fixed Income	Barclays Long Government/Credit
Equity Index	Standard & Poor's 500 Index
All-Cap Equity	Russell 3000 Index
	Russell 3000 Value Index
Mid-Cap Equity	Russell Midcap Index
	Russell Midcap Value Index
Small-Cap Equity	Russell 2000 Index
	Russell 2000 Value Index
International Equity	Morgan Stanley Capital Investment ACWI ex-US

The fixed income manager is expected to use discretion over the asset mix of the trust assets in its efforts to maximize risk-adjusted performance.  Exposure to any single issuer, other than the U.S. government, its agencies, or its instrumentalities (which have no limits) is limited tofive percentof the fixed income portfolio as measured by market value.  At least75 percentof the invested assets must possess an investment grade rating at or above Baa3 or BBB- by Moody's Investors Services, Standard & Poor's Ratings Services or Fitch Ratings.  The portfolio may invest up to10 percentof the portfolio's market value in convertible bonds as long as the securities purchased meet the quality guidelines.The purchase of any of OGE Energy's equity, debt or other securities is prohibited.

The domestic value equity managers focus on stocks that the manager believes are undervalued in price and earn an average or less than average return on assets, and often pays out higher than average dividend payments. The domestic growth equity manager will invest primarily in growth companies which consistently experience above average growth in earnings and sales, earn a high return on assets, and reinvest cash flow into existing business.  The domestic mid-cap equity portfolio manager focuses on companies with market capitalizations lower than the average company traded on the public exchanges with the following characteristics: price/earnings ratio at or near the Russell Midcap Index, small dividend yield, return on equity at or near the Russell Midcap Index and an earnings per share growth rate at or near the Russell Midcap Index.  The domestic small-cap equity manager will purchase shares of companies with market capitalizations lower than the average company traded on the public exchanges with the following characteristics: price/earnings ratio at or near the Russell 2000, small dividend yield, return on equity at or near the Russell 2000 and an earnings per share growth rate at or near the Russell 2000.  The international global equity manager invests primarily in non-dollar denominated equity securities. Investing internationally diversifies the overall trust across the global equity markets.  The manager is required to operate under certain restrictions including: regional constraints, diversification requirements and percentage of U.S. securities. The Morgan Stanley Capital International All Country World ex-US Index is the benchmark for comparative performance purposes. The Morgan Stanley Capital International All Country World ex-US Index is a market value weighted index designed to measure the combined equity market performance of developed and emerging markets countries, excluding the United States. All of the equities which are purchased for the international portfolio are thoroughly researched.  Only companies with a market capitalization in excess of$100 millionare allowable.  No more thanfive percentof the portfolio can be invested in any one stock at the time of purchase. All securities are freely traded on a recognized stock exchange and there are no 144-A securities and no over-the-counter derivatives.  The following investment categories are excluded: options (other than traded currency options), commodities, futures (other than currency futures or currency hedging), short sales/margin purchases, private placements, unlisted securities and real estate (but not real estate shares).

For all domestic equity investment managers, no more thaneight percent (five percentfor mid-cap and small-cap equity managers) can be invested in any one stock at the time of purchase and no more than16 percent (10 percentfor mid-cap and small-cap equity managers) after accounting for price appreciation. Options or financial futures may not be purchased unless prior approval of OGE Energy's Investment Committee is received.  The purchase of securities on margin is prohibited as is securities lending.  Private placement or venture capital may not be purchased.  All interest and dividend payments must be swept on a daily basis into a short-term money market fund for re-deployment.  The purchase of any of OGE Energy's equity, debt or other securities is prohibited.  The purchase of equity or debt issues of the portfolio manager's organization is also prohibited.  The aggregate positions in any company may not exceedone percentof the fair market value of its outstanding stock.

Plan Investments

Postemployment Benefit Plans, Policy [Policy Text Block]

Post-Employment Benefit Plan

Disabled employees receiving benefits fromOGE Energy'sGroup Long-Term Disability Plan are entitled to continue participating inOGE Energy'sMedical Plan along with their dependents.  The post-employment benefit obligation represents the actuarial present value of estimated future medical benefits that are attributed to employee service rendered prior to the date as of which such information is presented.  The obligation also includes future medical benefits expected to be paid to current employees participating inOGE Energy'sGroup Long-Term Disability Plan and their dependents, as defined inOGE Energy'sMedical Plan.

The post-employment benefit obligation is determined by an actuary on a basis similar to the accumulated postretirement benefit obligation.  The estimated future medical benefits are projected to grow with expected future medical cost trend rates and are discounted for interest at the discount rate and for the probability that the participant will discontinue receiving benefits fromOGE Energy'sGroup Long-Term Disability Plan due to death, recovery from disability, or eligibility for retiree medical benefits.  OG&E's post-employment benefit obligation was$1.4 millionand$2.2 millionatDecember 31, 2013and2012, respectively.

Pension and Other Postretirement Plans, Nonpension Benefits, Policy [Policy Text Block]

401(k) Plan

OGE Energyprovides a 401(k) Plan.  Each regular full-time employee ofOGE Energyor a participating affiliate is eligible to participate in the 401(k) Plan immediately.  All other employees ofOGE Energyor a participating affiliate are eligible to become participants in the 401(k) Plan after completing one year of service as defined in the 401(k) Plan.Participants may contribute each pay period any whole percentage betweentwo percentand19 percentof their compensation, as defined in the 401(k) Plan, for that pay period.Participants who have attained age 50 before the close of a year are allowed to make additional contributions referred to as "Catch-Up Contributions," subject to certain limitations of the Code.Participants may designate, at their discretion, all or any portion of their contributions as: (i) a before-tax contribution under Section 401(k) of the Code subject to the limitations thereof; or (ii) a contribution made on an after-tax basis.The 401(k) Plan also includes an eligible automatic contribution arrangement and provides for a qualified default investment alternative consistent with the U.S. Department of Labor regulations. Participants may elect, in accordance with the 401(k) Plan procedures, to have his or her future salary deferral rate to be automatically increased annually on a date and in an amount as specified by the participant in such election.

NoOGE Energycontributions are made with respect to a participant's Catch-Up Contributions, rollover contributions, or with respect to a participant's contributions based on overtime payments, pay-in-lieu of overtime for exempt personnel, special lump-sum recognition awards and lump-sum merit awards included in compensation for determining the amount of participant contributions.Once made,OGE Energy'scontribution may be directed to any available investment option in the 401(k) Plan.OGE Energymatch contributions vest over athree-year period.Aftertwoyears of service, participants become20 percentvested in theirOGE Energycontribution account and become fully vested on completingthreeyears of service. In addition, participants fully vest when they are eligible for normal or early retirement under the Pension Plan, in the event of their termination due to death or permanent disability or upon attainment of age 65 while employed byOGE Energyor its affiliates.  OG&E contributed$7.8 million, $7.6 millionand$7.0 millionin2013, 2012and2011, respectively, to the 401(k) Plan.

Deferred Compensation Plan

OGE Energyprovides a nonqualified deferred compensation plan which is intended to be an unfunded plan.  The plan's primary purpose is to provide a tax-deferred capital accumulation vehicle for a select group of management, highly compensated employees and non-employee members of the Board of Directors ofOGE Energyand to supplement such employees' 401(k) Plan contributions as well as offering this plan to be competitive in the marketplace.

Eligible employees who enroll in the plan have the following deferral options: (i) eligible employees may elect to defer up to a maximum of70 percentof base salary and100 percentof annual bonus awards or (ii) eligible employees may elect a deferral percentage of base salary and bonus awards based on the deferral percentage elected for a year under the 401(k) Plan with such deferrals to start when maximum deferrals to the qualified 401(k) Plan have been made because of limitations in that plan. Eligible directors who enroll in the plan may elect to defer up to a maximum of100 percentof directors' meeting fees and annual retainers.OGE Energymatches employee (but not non-employee director) deferrals to make up for any match lost in the 401(k) Plan because of deferrals to the deferred compensation plan, and to allow for a match that would have been made under the 401(k) Plan on that portion of either the firstsix percentof total compensation or the firstfive percentof total compensation, depending on the option the participant elected under the choice provided to eligible employees in the qualified 401(k) Plan discussed above, deferred that exceeds the limits allowed in the 401(k) Plan. Matching credits vest based on years of service, with full vesting afterthreeyears or, if earlier, on retirement, disability, death, a change in control ofOGE Energyor termination of the plan.Deferrals, plus anyOGE Energymatch, are credited to a recordkeeping account in the participant's name. Earnings on the deferrals are indexed to the assumed investment funds selected by the participant.In2013, those investment optionsincludedan OGE EnergyCommon Stock fund, whose value was determined based on the stock price ofOGE Energy'sCommon Stock.

Supplemental Executive Retirement Plan

OGE Energy provides a supplemental executive retirement plan in order to attract and retain lateral hires or other executives designated by the Compensation Committee ofOGE Energy'sBoard of Directors who may not otherwise qualify for a sufficient level of benefits underOGE Energy'sPension Plan and Restoration of Retirement Income Plan.The supplemental executive retirement plan is intended to be an unfunded plan and not subject to the benefit limitations of the Code.

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Fair Value Measurements Recurring (Details) (Fair Value, Measurements, Recurring [Member], USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ 0

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Summary of Significant Accounting Policies Fuel Inventories (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fuel inventories	$ 74.4	$ 76.8
Public Utilities, Inventory, Fuel [Member]
Fuel inventories	$ 74.4	$ 76.8

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STATEMENTS OF CASH FLOWS (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 292.6	$ 280.3	$ 263.3
Adjustments to reconcile net income to net cash provided from operating activities
Depreciation and amortization	248.4	248.7	216.1
Deferred Income Taxes and Tax Credits	116.1	103.3	95.0
Allowance for equity funds used during construction	(6.6)	(6.2)	(20.4)
Stock-based compensation expense	2.3	2.6	3.0
Regulatory assets	26.8	20.3	14.0
Regulatory liabilities	(32.5)	(14.8)	(1.9)
Other assets	10.0	(4.5)	2.0
Other liabilities	(6.2)	(28.7)	(62.9)
Change in certain current assets and liabilities
Accounts receivable, net	(17.9)	20.9	(40.1)
Accrued unbilled revenues	(1.3)	1.9	(2.5)
Fuel, materials and supplies inventories	(2.3)	6.5	54.0
Fuel clause under recoveries	(26.2)	1.8	(0.8)
Other current assets	2.7	(6.6)	(7.5)
Accounts payable	49.4	9.7	13.4
Accounts payable - affiliates	1.1	(0.6)	(3.1)
Income taxes payable - parent	2.9	(7.1)	23.0
Fuel clause over recoveries	(108.8)	101.5	(22.2)
Other current liabilities	(5.4)	8.4	26.9
Net Cash Provided from Operating Activities	545.1	737.4	549.3
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(797.6)	(704.4)	(844.5)
Reimbursement of capital expenditures	0	27.5	49.6
Proceeds from sale of assets	0.8	0.6	0.6
Net Cash Used in Investing Activities	(796.8)	(676.3)	(794.3)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	247.4	0	246.3
Changes in advances with parent	124.4	14.0	(51.3)
Capital contribution from OGE Energy	0	0	50.0
Payment of long-term debt	(0.1)	(0.1)	0
Dividends paid on common stock	(120.0)	(75.0)	0
Net Cash Provided from (Used in) Financing Activities	251.7	(61.1)	245.0
NET CHANGE IN CASH AND CASH EQUIVALENTS	0	0	0
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	0	0	0
CASH AND CASH EQUIVALENTS AT END OF PERIOD	0	0	0
Retained Earnings [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	292.6	280.3	263.3
CASH FLOWS FROM FINANCING ACTIVITIES
Capital contribution from OGE Energy			$ 0

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STATEMENTS OF CHANGES IN STOCKHOLDER'S EQUITY (USD $) In Millions, unless otherwise specified	Total	Common Stock	Premium on Common Stock	Retained Earnings	Accumulated Other Comprehensive Income (Loss)
Balance at Dec. 31, 2010	$ 2,178.1	$ 100.9	$ 857.5	$ 1,221.8	$ (2.1)
Comprehensive income (loss)
Net income	263.3	0	0	263.3	0
Other comprehensive income (loss), net of tax	(0.4)	0	0	0	(0.4)
Stock-based compensation	3.0	0	3.0	0	0
Capital contribution from OGE Energy	50.0	0	50.0	0	0
Balance at Dec. 31, 2011	2,494.0	100.9	910.5	1,485.1	(2.5)
Comprehensive income (loss)
Net income	280.3	0	0	280.3	0
Other comprehensive income (loss), net of tax	1.2	0	0	0	1.2
Dividends declared on common stock	(75.0)	0	0	75.0	0
Stock-based compensation	2.6	0	2.6	0	0
Capital contribution from OGE Energy	0
Balance at Dec. 31, 2012	2,703.1	100.9	913.1	1,690.4	(1.3)
Comprehensive income (loss)
Net income	292.6	0	0	292.6	0
Other comprehensive income (loss), net of tax	1.3	0	0	0	1.3
Dividends declared on common stock	(170.0)	0	0	170.0	0
Stock-based compensation	2.3	0	2.3	0	0
Capital contribution from OGE Energy	0
Balance at Dec. 31, 2013	$ 2,829.3	$ 100.9	$ 915.4	$ 1,813.0	$ 0

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Retirement Plans and Postretirement Benefit Plans Postretirement Benefit Plans (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	$ 61.4		$ 59.6
Plan investments attributable to affiliates	(4.7)		(4.1)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Level 3 Asset Value, Beginning of Period	53.3
Unrealized Gains	(0.5)
Interest Income	1.1
Dividend Income	0.6
Realized Gains	0.4
Administrative Expenses and Charges	(0.1)
Claims Paid	(1.7)
Level 3 Asset Value, End of Period	53.1
Postretirement Plan, Expected Future Benefit Payments in Year One	13.1
Postretirement Plan, Expected Future Benefit Payments in Year Two	13.5
Postretirement Plan, Expected Future Benefit Payments in Year Three	13.8
Postretirement Plan, Expected Future Benefit Payments in Year Four	14.0
Postretirement Plan, Expected Future Benefit Payments in Year Five	14.3
Postretirement Plan, Expected Future Benefit Payments Thereafter	71.6
Postemployment Benefits Liability	1.4		2.2
Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	8.3		6.3
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	53.1		53.3
OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	56.7		55.5
Group Retiree Medical Insurance Contract [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	53.1	[1]	53.3	[1]
Group Retiree Medical Insurance Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0	[1]	0	[1]
Group Retiree Medical Insurance Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	53.1	[1]	53.3	[1]
U.S. Equity Mutual Funds Investment [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	7.9		6.0
U.S. Equity Mutual Funds Investment [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	7.9		6.0
U.S. Equity Mutual Funds Investment [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Money Market Funds [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0.4		0.3
Money Market Funds [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0.4		0.3
Money Market Funds [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0		0
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Benefit Obligation	(202.4)		(236.4)
Fair Value of Plan Assets	56.7		55.5
Funded Status of Plan	(145.7)		(180.9)
Postretirement Benefit Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Benefit Obligation	(202.4)		(236.4)		(223.1)
Fair Value of Plan Assets	56.7		55.5		57.2
Funded Status of Plan	(145.7)		(180.9)
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	8.35%		8.55%		8.75%
Postretirement Benefit Plan [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	$ 0		$ 0

[1] This category represents a group retiree medical insurance contract which invests in a pool of common stocks, bonds and money market accounts, of which a significant portion is comprised of mortgage-backed securities.

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Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2013

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Regulatory Assets and Liabilities [Table Text Block]

The following table is a summary of OG&E's regulatory assets and liabilities at:

December 31 (In millions)	2013		2012
Regulatory Assets
Current
Fuel clause under recoveries	$	26.2	$	—
Oklahoma demand program rider under recovery (A)	10.6		9.2
Crossroads wind farm rider under recovery (A)	4.7		14.9
Other (A)	7.3		2.9
Total Current Regulatory Assets	$	48.8	$	27.0
Non-Current
Benefit obligations regulatory asset	$	227.4	$	370.6
Income taxes recoverable from customers, net	56.5		54.7
Smart Grid	44.2		42.8
Deferred storm expenses	21.6		12.7
Unamortized loss on reacquired debt	11.8		13.0
Pension tracker	1.4		—
Other	16.2		16.8
Total Non-Current Regulatory Assets	$	379.1	$	510.6
Regulatory Liabilities
Current
Smart Grid rider over recovery (B)	$	16.7	$	24.1
Fuel clause over recoveries	0.4		109.2
Other (B)	3.1		7.8
Total Current Regulatory Liabilities	$	20.2	$	141.1
Non-Current
Accrued removal obligations, net	$	227.7	$	218.2
Deferred pension credits	6.5		17.7
Pension tracker	—		9.2
Total Non-Current Regulatory Liabilities	$	234.2	$	245.1

(A) Included in Other Current Assets on theBalance Sheets.

(B) Included in Other Current Liabilities on theBalance Sheets.

Components of Benefit Obligation Regulatory Asset [Table Text Block]

The following table is a summary of the components of the benefit obligations regulatory asset at:

December 31 (In millions)	2013			2012
Pension Plan and Restoration of Retirement Income Plan
Net loss	$	178.4		$	278.6
Prior service cost	2.5			4.5
Postretirement Benefit Plans
Net loss	79.9			134.6
Prior service cost	(33.4		)	(47.1		)
Total	$	227.4		$	370.6

Schedule of Net Periodic Benefit Cost Not yet Recognized [Table Text Block]

The following amounts in the benefit obligations regulatory asset atDecember 31, 2013are expected to be recognized as components of net periodic benefit cost in2014: 

(In millions)
Pension Plan and Restoration of Retirement Income Plan
Net loss	$	11.4
Prior service cost	2.0
Postretirement Benefit Plans
Net loss	11.0
Prior service cost	(13.7		)
Total	$	10.7

Schedule of Jointly Owned Utility Plants [Table Text Block]

The table below presents OG&E's ownership interest in the jointly-owned McClain Plant and the jointly-owned Redbud Plant, and, as disclosed below, only OG&E's ownership interest is reflected in the property, plant and equipment and accumulated depreciation balances in these tables.  The owners of the remaining interests in the McClain Plant and the Redbud Plant are responsible for providing their own financing of capital expenditures.  Also, only OG&E's proportionate interests of any direct expenses of the McClain Plant and the Redbud Plant such as fuel, maintenance expense and other operating expenses are included in the applicable financial statement captions in theStatement of Income.

December 31, 2013 (In millions)	Percentage Ownership		Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)	77	%	$	180.8	$	62.1	$	118.7
Redbud Plant (A)(B)	51	%	$	498.9	$	89.7	$	409.2

(A) Construction work in progress was$0.1 millionand$39.5 millionfor the McClain and Redbud Plants, respectively.

(B) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$28.8 million.

December 31, 2012 (In millions)	Percentage Ownership		Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)	77	%	$	182.1	$	56.3	$	125.8
Redbud Plant (A)(B)	51	%	$	458.5	$	69.5	$	389.0

(A) Construction work in progress was$0.1 millionand$0.3 millionfor the McClain and Redbud Plants, respectively.

(B) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$23.3 million.

Property, Plant and Equipment [Table Text Block]

OG&E's property, plant and equipment and related accumulated depreciation are divided into the following major classes at:

December 31, 2013 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
Distribution assets	$	3,403.8	$	1,028.2	$	2,375.6
Electric generation assets (A)	3,551.0		1,306.1		2,244.9
Transmission assets (B)	2,163.7		385.0		1,778.7
Intangible plant	50.5		27.1		23.4
Other property and equipment	330.2		118.2		212.0
Total property, plant and equipment	$	9,499.2	$	2,864.6	$	6,634.6

(A) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$28.8 million.

(B) This amount includes a plant acquisition adjustment of$3.3 millionand accumulated amortization of$0.3 million.

December 31, 2012 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
Distribution assets	$	3,222.7	$	969.6	$	2,253.1
Electric generation assets (A)	3,446.6		1,242.4		2,204.2
Transmission assets (B)	1,712.6		359.8		1,352.8
Intangible plant	50.2		25.0		25.2
Other property and equipment	317.6		108.8		208.8
Total property, plant and equipment	$	8,749.7	$	2,705.6	$	6,044.1

(A) This amount includes a plant acquisition adjustment of$148.3 millionand accumulated amortization of$23.3 million.

(B) This amount includes a plant acquisition adjustment of$3.3 millionand accumulated amortization of$0.3 million.

Schedule of Change in Asset Retirement Obligation [Table Text Block]

The following table summarizes changes to OG&E's asset retirement obligations during theyears endedDecember 31, 2013and2012.

(In millions)	2013			2012
Balance at January 1	$	53.6		$	24.8
Accretion expense	2.3			1.9
Revisions in estimated cash flows (A)	(0.7		)	26.9
Balance at December 31	$	55.2		$	53.6

(A) Due to changes to OG&E's asset retirement obligations related to its wind farms as a result of changes in the assumption related to the timing of removal used in the valuation of the asset retirement obligations.

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Summary of Significant Accounting Policies Regulated Operations (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Schedule of Regulatory Assets and Liabilities [Line Items]
Fuel clause under recoveries	$ 26.2		$ 0
Regulatory Assets, Current	48.8		27.0
Regulatory Assets, Noncurrent	379.1		510.6
Fuel clause over recoveries	0.4		109.2
Regulatory Liability, Current	20.2		141.1
Regulatory Liability, Noncurrent	234.2		245.1
Smart Grid rider over recovery [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	16.7	[1]	24.1	[1]
Other Regulatory Liabilities [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	3.1	[1]	7.8	[1]
Accrued removal obligations [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Noncurrent	227.7		218.2
Deferred Pension Credits [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Noncurrent	6.5		17.7
Pension tracker [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Noncurrent	0		9.2
Crossroads wind farm rider under recovery [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	4.7	[2]	14.9	[2]
Oklahoma demand program rider under recovery [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	10.6	[2]	9.2	[2]
Other Regulatory Assets [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	7.3	[2]	2.9	[2]
Regulatory Assets, Noncurrent	16.2		16.8
Benefit Obligations [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	227.4		370.6
Income taxes recoverable from customers, net [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	56.5		54.7
Smart Grid [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	44.2		42.8
Deferred storm expenses [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	21.6		12.7
Unamortized loss on reacquired debt [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	11.8		13.0
Pension tracker [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Noncurrent	$ 1.4		$ 0

[1] Included in Other Current Liabilities on the Balance Sheets.

[2] Included in Other Current Assets on the Balance Sheets.

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Short-Term Debt and Credit Facility

12 Months Ended

Dec. 31, 2012

Short-term Debt [Abstract]

Short-Term Debt and Credit Facility

Short-Term Debt and Credit Facility

At December 31, 2013, there were$87.2 millionin net outstanding advances from OGE Energy as compared to$90.3 million in net outstanding advances to OGE Energy at December 31, 2012. OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $400 million of OGE Energy's revolving credit amount.  Effective July 29, 2013, OG&E extended the termination date of this agreement to December 13, 2017.   At December 31, 2013, there were no intercompany borrowings under this agreement.  OG&E has a $400 million unsecured five-year revolving credit facility which is available to back up OG&E's commercial paper borrowings and to provide revolving credit borrowings.  This bank facility can also be used as a letter of credit facility. At December 31, 2013, there was $2.1 million supporting letters of credit at a weighted-average interest rate of0.53 percent.  There were no outstanding borrowings under this revolving credit agreement and no outstanding commercial paper borrowings at December 31, 2013.  At December 31, 2013, OG&E had less than $0.1 million in cash and cash equivalents.

In December 2011,OG&E entered into an unsecured five-year revolving credit agreement for $400.0 million. This credit facility containan option, which may be exercised up to two times, to extend the term for an additional year, subject to consent of a specified percentage of the lenders. Effective July 29, 2013,OG&E utilized one of these one-year extensions, and received consent from all of the lenders, to extend the maturity of its credit agreementsto December 13, 2017.

OGE Energy's and OG&E'sability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions.Pricing grids associated withOGE Energy's and OG&E'screditfacilitiescould cause annual fees and borrowing rates to increase if an adverse rating impact occurs. The impact of any future downgrade could include an increase in the costs ofOGE Energy's and OG&E'sshort-term borrowings, but a reduction inOGE Energy's and OG&E'scredit ratings would not result in any defaults or accelerations. Any future downgradeof OGE Energy or OG&Ecould also lead to higher long-term borrowing costs and, if below investment grade, would requireOG&Eto post collateral or letters of credit.

OG&E must obtain regulatory approval from the FERC in order to borrow on a short-term basis.OG&E has the necessary regulatory approvals to incur up to$800 millionin short-term borrowings at any one time for a two-year period beginning January 1, 2013 and ending December 31, 2014.