10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period endedMarch 31, 2014

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: 1-12579

OGE ENERGY CORP.

(Exact name of registrant as specified in its charter)

Oklahoma	73-1481638
(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)

405-553-3000

(Registrant's telephone number, including area code)

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 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  þ	Accelerated filer  o
Non-accelerated filer    o (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

At March 31, 2014, there were 199,138,921 shares of common stock, par value $0.01 per share, outstanding.

OGE ENERGY CORP.

FORM 10-Q

FOR THE QUARTER ENDEDMARCH 31, 2014

TABLE OF CONTENTS

	Page
GLOSSARY OF TERMS	ii
FORWARD-LOOKING STATEMENTS	1
Part I - FINANCIAL INFORMATION
Item 1. Financial Statements (Unaudited)
Condensed Consolidated Statements of Income	2
Condensed Consolidated Statements of Comprehensive Income	3
Condensed Consolidated Statements of Cash Flows	4
Condensed Consolidated Balance Sheets	5
Condensed Consolidated Statements of Changes in Stockholders' Equity	7
Notes to Condensed Consolidated Financial Statements	8
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	24
Item 3. Quantitative and Qualitative Disclosures About Market Risk	39
Item 4. Controls and Procedures	39
Part II - OTHER INFORMATION
Item 1. Legal Proceedings	40
Item 1A. Risk Factors	40
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	40
Item 6. Exhibits	40
Signature	41

i

GLOSSARY OF TERMS

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

Abbreviation	Definition
2013 Form 10-K	Annual Report on Form 10-K for the year ended December 31, 2013
APSC	Arkansas Public Service Commission
ArcLight group	Bronco Midstream Holdings, LLC, Bronco Midstream Holdings II, LLC, collectively
BART	Best available retrofit technology
CenterPoint	CenterPoint Energy Resources Corp., wholly-owned subsidiary of CenterPoint Energy, Inc.
Company	OGE Energy, collectively with its subsidiaries
DOJ	U.S. Department of Justice
Dry Scrubbers	Dry flue gas desulfurization units with spray dryer absorber
Enable	Enable Midstream Partners, LP, partnership between OGE Energy, the ArcLight group and CenterPoint Energy, Inc. formed to own and operate the midstream businesses of OGE Energy and CenterPoint
Enogex Holdings	Enogex Holdings LLC, the parent company of Enogex LLC and a majority-owned subsidiary of OGE Holdings, LLC (prior to May 1, 2013)
Enogex LLC	Enogex LLC, collectively with its subsidiaries (effective July 30, 2013, the name was changed to Enable Oklahoma Intrastate Transmission, LLC)
EPA	U.S. Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
FIP	Federal implementation plan
GAAP	Accounting principles generally accepted in the United States
MATS	Mercury and Air Toxics Standards
NGLs	Natural gas liquids
NOX	Nitrogen oxide
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 Holdings	OGE Enogex Holdings, LLC, wholly-owned subsidiary of OGE Energy, parent company of Enogex Holdings (prior to May 1, 2013) and 28.5 percent owner of Enable Midstream Partners
Pension Plan	Qualified defined benefit retirement plan
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
TBtu/d	Trillion British thermal units per day

ii

FORWARD-LOOKING STATEMENTS

Except for the historical statements contained herein, the matters discussed in this Form 10-Q, including those matters discussed in "Item 2. 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 by the 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" in the Company's 2013Form 10-K and"Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" herein, factorsthat could cause actual 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 ofthe Company and its subsidiariesto access the capital markets and obtain financing on favorable terms as well as inflation rates and monetary fluctuations;

• prices and availability of electricity, coal, natural gasand NGLs;

• the timing and extent of changes in commodity prices, particularly natural gas and NGLs, the competitive effects of the available pipeline capacity in the regionsEnableserves, and the effects of geographic and seasonal commodity price differentials, including the effects of these circumstances on re-contracting available capacity onEnable's interstate pipelines;

• the timing and extent of changes in the supply of natural gas, particularly supplies available for gathering byEnable's gathering and processing business and transporting byEnable's interstate pipelines, including the impact of natural gas and NGLs prices on the level of drilling and production activities in the regionsEnableserves;

• business conditions in the energyand natural gas midstream industries;

• competitive factors including the extent and timing of the entry of additional competition in the markets served bythe Company;

• unusual weather;

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

• Federal or state legislation and regulatory decisions and initiatives that affect cost and investment recovery, have an impact on rate structures or affect the speed and degree to which competition entersthe Company'smarkets;

• environmental laws and regulations that may impactthe Company'soperations;

• 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;

• difficulty in making accurate assumptions and projections regarding future revenues and costs associated with the Company's equity investment inEnable that the Company does not control;and

• other risk factors listed in the reports filed bythe Companywith the Securities and Exchange Commission including those listed in"Item 1A.Risk Factors" andinExhibit 99.01 tothe Company's2013 Form 10-K.

The Company 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. FINANCIAL INFORMATION

Item 1.  Financial Statements.

OGE ENERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended
	March 31,
(In millions except per share data)	2014			2013
OPERATING REVENUES
Electric Utility	$	560.4		$	453.7
Natural Gas Midstream Operations (Note 1)	—			447.7
Total operating revenues	560.4			901.4
COST OF SALES
Electric Utility	293.4			201.1
Natural Gas Midstream Operations (Note 1)	—			351.9
Total cost of sales	293.4			553.0
OPERATING EXPENSES
Other operation and maintenance	112.4			148.0
Depreciation and amortization	67.2			91.9
Taxes other than income	25.6			33.1
Total operating expenses	205.2			273.0
OPERATING INCOME	61.8			75.4
OTHER INCOME (EXPENSE)
Equity in earnings of unconsolidated affiliates (Note 1)	47.9			—
Allowance for equity funds used during construction	1.1			1.2
Other income	1.4			14.7
Other expense	(3.3		)	(6.5		)
Net other income	47.1			9.4
INTEREST EXPENSE
Interest on long-term debt	35.1			39.7
Allowance for borrowed funds used during construction	(0.6		)	(0.7		)
Interest on short-term debt and other interest charges	1.4			2.2
Interest expense	35.9			41.2
INCOME BEFORE TAXES	73.0			43.6
INCOME TAX EXPENSE	23.7			15.6
NET INCOME	49.3			28.0
Less: Net income attributable to noncontrolling interests	—			4.9
NET INCOME ATTRIBUTABLE TO OGE ENERGY	$	49.3		$	23.1
BASIC AVERAGE COMMON SHARES OUTSTANDING	198.8			197.8
DILUTED AVERAGE COMMON SHARES OUTSTANDING	199.5			198.8
BASIC EARNINGS PER AVERAGE COMMON SHARE ATTRIBUTABLE TO OGE ENERGY COMMON SHAREHOLDERS	$	0.25		$	0.12
DILUTED EARNINGS PER AVERAGE COMMON SHARES ATTRIBUTABLE TO OGE ENERGY COMMON SHAREHOLDERS	$	0.25		$	0.12
DIVIDENDS DECLARED PER COMMON SHARE	$	0.22500		$	0.20875

The accompanying Notes to CondensedConsolidatedFinancial Statements are an integral part hereof.

2

OGE ENERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended
	March 31,
(In millions)	2014			2013
Net income	$	49.3		$	28.0
Other comprehensive income (loss), net of tax
Pension Plan and Restoration of Retirement Income Plan:
Amortization of deferred net loss, net of tax of $0.3 and $0.4, respectively	0.4			0.9
Postretirement Benefit Plans:
Amortization of deferred net loss, net of tax of $0.1 and $0.3, respectively	0.2			0.5
Amortization of prior service cost, net of tax of ($0.3) and ($0.3), respectively	(0.4		)	(0.5		)
Deferred commodity contracts hedging (gains) losses reclassified in net income, net of tax of $0.0 and ($0.1), respectively	—			(0.1		)
Amortization of deferred interest rate swap hedging losses, net of tax of $0.1 and $0.1, respectively	0.1			0.1
Other comprehensive income, net of tax	0.3			0.9
Comprehensive income	49.6			28.9
Less:  Comprehensive income attributable to noncontrolling interests	—			5.0
Total comprehensive income attributable to OGE Energy	$	49.6		$	23.9

The accompanying Notes to CondensedConsolidatedFinancial Statements are an integral part hereof.

3

OGE ENERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended
	March 31,
(In millions)	2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	49.3		$	28.0
Adjustments to reconcile net income to net cash provided from operating activities
Depreciation and amortization	67.2			92.9
Deferred income taxes and investment tax credits, net	22.0			15.4
Equity in earnings of unconsolidated affiliates	(47.9		)	—
Distributions from unconsolidated affiliates	32.5			—
Allowance for equity funds used during construction	(1.1		)	(1.2		)
Gain on disposition and abandonment of assets	(0.2		)	(8.7		)
Stock-based compensation	(8.6		)	(8.3		)
Regulatory assets	3.5			5.5
Regulatory liabilities	(1.9		)	(4.1		)
Other assets	(7.2		)	(0.1		)
Other liabilities	26.2			6.3
Change in certain current assets and liabilities
Accounts receivable, net	(12.5		)	8.4
Accounts receivable - unconsolidated affiliates	2.1			—
Accrued unbilled revenues	7.0			7.8
Fuel, materials and supplies inventories	(4.0		)	(7.7		)
Fuel clause under recoveries	(35.8		)	(0.4		)
Other current assets	3.7			(7.7		)
Accounts payable	(29.6		)	16.5
Fuel clause over recoveries	(0.4		)	(27.6		)
Other current liabilities	(41.1		)	(55.8		)
Net Cash Provided from Operating Activities	23.2			59.2
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(171.8		)	(325.1		)
Proceeds from sale of assets	0.4			35.6
Net Cash Used in Investing Activities	(171.4		)	(289.5		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	246.9			—
Issuance of common stock	3.4			3.2
Distributions to noncontrolling interest partners	—			(2.5		)
Dividends paid on common stock	(44.7		)	(41.2		)
(Decrease) increase in short-term debt	(61.8		)	276.1
Net Cash Provided from Financing Activities	143.8			235.6
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(4.4		)	5.3
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	6.8			1.8
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	2.4		$	7.1

The accompanying Notes to CondensedConsolidatedFinancial Statements are an integral part hereof.

4

OGE ENERGY CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In millions)	March 31, 2014		December 31, 2013
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$	2.4	$	6.8
Accounts receivable, less reserve of $1.1 and $1.9, respectively	191.9		179.4
Accounts receivable - unconsolidated affiliates	10.3		12.4
Accrued unbilled revenues	51.7		58.7
Income taxes receivable	5.6		5.6
Fuel inventories	82.4		74.4
Materials and supplies, at average cost	76.7		80.7
Deferred income taxes	188.6		215.8
Fuel clause under recoveries	62.0		26.2
Other	30.9		34.6
Total current assets	702.5		694.6
OTHER PROPERTY AND INVESTMENTS
Investment in unconsolidated affiliates	1,314.2		1,298.8
Other	63.1		61.0
Total other property and investments	1,377.3		1,359.8
PROPERTY, PLANT AND EQUIPMENT
In service	9,302.9		9,183.1
Construction work in progress	470.3		468.5
Total property, plant and equipment	9,773.2		9,651.6
Less accumulated depreciation	3,010.9		2,978.8
Net property, plant and equipment	6,762.3		6,672.8
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	374.4		379.1
Other	34.2		28.4
Total deferred charges and other assets	408.6		407.5
TOTAL ASSETS	$	9,250.7	$	9,134.7

The accompanying Notes to CondensedConsolidatedFinancial Statements are an integral part hereof.

5

OGE ENERGY CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS(Continued)

(In millions)	March 31, 2014			December 31, 2013
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Short-term debt	$	377.8		$	439.6
Accounts payable	209.6			251.0
Dividends payable	44.8			44.7
Customer deposits	71.4			70.9
Accrued taxes	26.0			39.9
Accrued interest	34.2			43.4
Accrued compensation	38.2			56.9
Long-term debt due within one year	100.0			100.0
Fuel clause over recoveries	—			0.4
Other	47.3			47.0
Total current liabilities	949.3			1,093.8
LONG-TERM DEBT	2,549.4			2,300.1
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	242.8			241.5
Deferred income taxes	2,119.8			2,125.3
Deferred investment tax credits	1.6			1.9
Regulatory liabilities	237.6			234.2
Other	112.4			100.8
Total deferred credits and other liabilities	2,714.2			2,703.7
Total liabilities	6,212.9			6,097.6
COMMITMENTS AND CONTINGENCIES (NOTE 13)
STOCKHOLDERS' EQUITY
Common stockholders' equity	1,069.6			1,073.6
Retained earnings	1,996.1			1,991.7
Accumulated other comprehensive loss, net of tax	(27.9		)	(28.2		)
Total stockholders' equity	3,037.8			3,037.1
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$	9,250.7		$	9,134.7

The accompanying Notes to CondensedConsolidatedFinancial Statements are an integral part hereof.

6

OGE ENERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY

(Unaudited)

(In millions)	Common Stock		Premium on Common Stock			Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interest			Treasury Stock			Total
Balance at December 31, 2013	$	2.0	$	1,071.6		$	1,991.7		$	(28.2	)	$	—		$	—		$	3,037.1
Net income	—		—			49.3			—			—			—			49.3
Other comprehensive income, net of tax	—		—			—			0.3			—			—			0.3
Dividends declared on common stock	—		—			(44.9		)	—			—			—			(44.9		)
Issuance of common stock	—		3.4			—			—			—			—			3.4
Stock-based compensation and other	—		(7.4		)	—			—			—			—			(7.4		)
Balance at March 31, 2014	$	2.0	$	1,067.6		$	1,996.1		$	(27.9	)	$	—		$	—		$	3,037.8
Balance at December 31, 2012	$	1.0	$	1,046.4		$	1,772.4		$	(49.1	)	$	305.2		$	(3.5	)	$	3,072.4
Net income	—		—			23.1			—			4.9			—			28.0
Other comprehensive income, net of tax	—		—			—			0.8			0.1			—			0.9
Dividends declared on common stock	—		—			(41.4		)	—			—			—			(41.4		)
Issuance of common stock	—		3.2			—			—			—			—			3.2
Stock-based compensation and other	—		(10.9		)	—			—			(0.9		)	3.5			(8.3		)
Distributions to noncontrolling interest partners	—		—			—			—			(2.5		)	—			(2.5		)
Balance at March 31, 2013	$	1.0	$	1,038.7		$	1,754.1		$	(48.3	)	$	306.8		$	—		$	3,052.3

The accompanying Notes to CondensedConsolidatedFinancial Statements are an integral part hereof.

7

OGE ENERGY CORP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Summary of Significant Accounting Policies

Organization

The Company is 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. The Company conducts these activities through two business segments:  (i) electric utility and (ii) natural gas midstream operations. For a discussion of change in business segments, see Note 12. For periods prior to May 1, 2013, the Company consolidated Enogex Holdings in its Condensed Consolidated Financial Statements. All significant intercompany transactions have been eliminated in consolidation.

Effective May 1, 2013,OGE Energy, the ArcLight group and CenterPoint Energy, Inc., formed Enable Midstream Partners, L.P. to own and operate the midstream businesses of OGE Energy and CenterPoint. In the formation transaction, OGE Energy and ArcLight contributed Enogex LLC to Enable andthe Company deconsolidated its previously held investment in Enogex Holdings and acquired an equity interest in Enable.The Company determined that its contribution of Enogex LLC to Enable met the requirements of being in substance real estate and was recorded at historical cost.The general partner of Enable is equally controlled by CenterPoint and OGE Energy, who each have50 percentof the management rights.Based on the 50/50 management ownership, with neither company having control,effective May 1, 2013, OGE Energybegan accounting for its interest in Enable using the equity method of accounting. At March 31, 2014, OGE Energy, through its wholly owned subsidiary OGE Holdings, held28.5 percentof the limited partner interests in Enable.OGE Energy also owns a60 percentinterest in any incentive distribution rights in Enable. Incentive distribution rights entitle the holder to increasing percentages, up to a maximum of50 percent, of the cash distributed by Enable in excess of the target quarterly distributions established in connection with Enable’s initial public offering as described below.On April 16, 2014, Enable completed an initial public offering of28,750,000common units resulting in Enable becoming a publicly traded Master Limited Partnership. The offering represented approximately6.9 percentof the limited partner interests and raised approximately$466 millionin net proceeds for Enable. As a result of the offering, OGE Holding's ownership was reduced from28.5 percent to 26.7 percent.

In connection with Enable’s initial public offering, approximately61.4 percentof OGE Holdings and CenterPoint’s common units were converted into subordinated units. As a result, following the initial public offering, OGE Holdings owned42,832,291common units and68,150,514subordinated units of Enable. Holders of subordinated units are not entitled to receive any distribution of available cash until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. The subordinated units will convert into common units when Enable has paid at least the minimum quarterly distribution for three years or paid at least 150 percent of the minimum quarterly distribution for one year.

Enable is expected to pay a minimum quarterly distribution of $0.2875 per unit on its outstanding units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to its general partner and its affiliates, within 45 days after the end of each quarter. Enable will adjust the amount of this distribution for the period from April 16, 2014, the completion of its initial public offering, through June 30, 2014 based on the actual length of the period.If cash distributions to Enable’s unitholders exceed $0.330625 per unit in any quarter, the general partner will receive increasing percentages, up to50 percent, of the cash Enable distributes in excess of that amount. As indicated above, OGE Holdings is entitled to60 percentof those “incentive distributions.” In certain circumstances, the general partner, will have the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable’s cash distributions at the time of the exercise of this reset election.

The electric utility segmentgenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas.  Its operations areconducted through OG&E and aresubject 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.

The natural gas midstream operations segment consists of the Company's investment in Enable. Enable is engaged in the business of gathering, processing, transporting and storing natural gas. Enable's natural gas gathering and processing assets are strategically located in four states and serve natural gas production from shale developments in the Anadarko, Arkoma and Ark-La-Tex basins. Enable also owns an emerging crude oil gathering business in the Bakken shale formation that commenced initial operations in November 2013. Enable is continuing to construct additional crude oil gathering capacity in this area. Enable's

8

natural gas transportation and storage assets extend from western Oklahoma and the Texas Panhandle to Alabama and from Louisiana to Illinois.

As discussed below, the Company completed a 2-for-1 stock split of the Company's common stock effective July 1, 2013. All share and per share amounts within this Form 10-Q reflect the effects of the stock split.

Basis of Presentation

The Condensed Consolidated Financial Statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations; however, the Company believes that the disclosures are adequate to prevent the information presented from being misleading.

In the opinion of management, all adjustments necessary to fairly present the consolidated financial position of the Company atMarch 31, 2014andDecember 31, 2013, the results of its operations for the threemonths endedMarch 31, 2014and2013and the results of its cash flows for thethreemonths endedMarch 31, 2014and2013, have been included and are of a normal recurring nature except as otherwise disclosed.

Due to seasonal fluctuations and other factors, the Company'soperating results for the threemonths endedMarch 31, 2014are not necessarily indicative of the results that may be expected for the year endingDecember 31, 2014or for any future period.The Condensed Consolidated Financial Statements and Notes thereto should be read in conjunction with the audited Consolidated Financial Statements and Notes thereto included in the Company's 2013Form 10-K.

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:

(In millions)	March 31, 2014		December 31, 2013
Regulatory Assets
Current
Fuel clause under recoveries	$	62.0	$	26.2
Oklahoma demand program rider under recovery (A)	8.8		10.6
Crossroads wind farm rider under recovery (A)	—		4.7
Other (A)	9.2		7.3
Total Current Regulatory Assets	$	80.0	$	48.8
Non-Current
Benefit obligations regulatory asset	$	224.8	$	227.4
Income taxes recoverable from customers, net	56.4		56.5
Smart Grid	44.1		44.2
Deferred storm expenses	21.5		21.6
Unamortized loss on reacquired debt	11.5		11.8
Pension tracker	—		1.4
Other	16.1		16.2
Total Non-Current Regulatory Assets	$	374.4	$	379.1
Regulatory Liabilities
Current
Smart Grid rider over recovery (B)	$	15.7	$	16.7
Fuel clause over recoveries	—		0.4
Other (B)	2.6		3.1
Total Current Regulatory Liabilities	$	18.3	$	20.2
Non-Current
Accrued removal obligations, net	$	230.8	$	227.7
Deferred pension credits	3.7		6.5
Pension tracker	3.1		—
Total Non-Current Regulatory Liabilities	$	237.6	$	234.2

(A) Included in Other Current Assets on theCondensed Consolidated Balance Sheets.

(B) Included in Other Current Liabilities on theCondensed Consolidated Balance Sheets.

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.If OG&E were 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.

Investment in Unconsolidated Affiliate

OGE Energy's investment in Enable is considered to be a variable interest entity because the owners of the equity at risk in this entity have disproportionate voting rights in relation to their obligations to absorb the entity's expected losses or to receive its expected residual returns. However, OGE Energy is not considered the primary beneficiary of Enable since it does not have the power to direct the activities of Enable that are considered most significant to the economic performance of Enable. As discussed above, OGE Energy accounts for the investment in Enable using the equity method of accounting. Under the equity method, the investment will be adjusted each period for contributions made, distributions received and the Company's share of the investee's comprehensive income. OGE Energy's maximum exposure to loss related to Enable is limited to OGE Energy's equity investment in Enable as presented on the Company's Condensed Consolidated Balance Sheet at March 31, 2014. The Company evaluates its equity method investment for impairment when events or changes in circumstances indicate there is a loss in value of the investment that is other than a temporary decline.

The Company considers distributions received from Enable which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment which are classified as operating activities in the Condensed Consolidated Statements of Cash Flows. The Company considers distributions received from Enable in excess of cumulative equity in earnings

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subsequent to the date of investment to be a return of investment which are classified as investing activities in the Condensed Consolidated Statements of Cash Flows.

Asset Retirement Obligation

The following table summarizes changes to the Company's asset retirement obligations during thethreemonths endedMarch 31, 2014and2013.

	Three Months Ended
	March 31,
(In millions)	2014		2013
Balance at January 1	$	55.2	$	54.0
Liabilities settled	—		(0.1		)
Accretion expense	0.6		0.6
Balance at March 31	$	55.8	$	54.5

Accumulated Other Comprehensive Income (Loss)

The following table summarizes changes in the components of accumulated other comprehensive loss attributable to OGE Energy during the threemonths endedMarch 31, 2014. All amounts below are presented net of tax and noncontrolling interest.

	Pension Plan and Restoration of Retirement Income Plan					Postretirement Benefit Plans
	Net loss			Prior service cost		Net loss			Prior service cost			Deferred interest rate swap hedging losses			Total
Balance at December 31, 2013	$	(27.4	)	$	0.1	$	(5.8	)	$	5.1		$	(0.2	)	$	(28.2	)
Amounts reclassified from accumulated other comprehensive income (loss)	0.4			—		0.2			(0.4		)	0.1			0.3
Net current period other comprehensive income (loss)	0.4			—		0.2			(0.4		)	0.1			0.3
Balance at March 31, 2014	$	(27.0	)	$	0.1	$	(5.6	)	$	4.7		$	(0.1	)	$	(27.9	)

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The following table summarizes significant amounts reclassified out of accumulated other comprehensive loss by the respective line items in net income during the threemonths endedMarch 31, 2014.

Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)			Affected Line Item in the Statement Where Net Income is Presented
	Three Months Ended
	March 31, 2014
Losses on cash flow hedges
Interest rate swap	$	(0.2	)	Interest expense
	(0.2		)	Total before tax
	(0.1		)	Tax benefit
	$	(0.1	)	Net of tax
Amortization of defined benefit pension items
Actuarial losses	$	(0.7	)	(A)
	(0.7		)	Total before tax
	(0.3		)	Tax benefit
	$	(0.4	)	Net of tax
Amortization of postretirement benefit plan items
Actuarial losses	$	(0.3	)	(A)
Prior service credit	0.7			(A)
	0.4			Total before tax
	0.2			Tax expense
	$	0.2		Net of tax
Total reclassifications for the period	$	(0.3	)	Net of tax

(A) These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost (see Note 11 for additional information).

Forward Stock Split

On May 16, 2013, the Company's Board of Directors approved a 2-for-1 forward stock split of the Company's common stock, effective July 1, 2013, which entitled each shareholder of record to receive two shares for every one share of Company stock owned by the shareholder.  In connection with the stock split, an amendment to the Company's Articles of Incorporation was approved on May 16, 2013 which increased the number of authorized shares of common stock from225 millionto450 million. All share and per share amounts within this Form 10-Q reflect the effects of the stock split.

Reclassifications

Prior to May 1, 2013, the Company reported the results of Enogex Holdings in two separate segments: the natural gas transportation and storage segment, and the natural gas gathering and processing segment. After the deconsolidation, these segments were combined into the natural gas midstream operations segment.The presentation of results for the three months ended March 31, 2013 have been revised to reflect this change.Effective May 1, 2013,the Company deconsolidated its previously held investment in Enogex Holdings and acquired an equity interest in Enable.

2. Accounting Pronouncement

There were no significant accounting pronouncements issued during the threemonths endedMarch 31, 2014 that had or will have a material impact on our consolidated results of operations, financial position or cash flows.

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3. Investment in Unconsolidated Affiliate and Related Party Transactions

On March 14, 2013, OGE Energy entered into a Master Formation Agreement with the ArcLight group and CenterPoint Energy, Inc., pursuant to which OGE Energy, the ArcLight Group and CenterPoint Energy, Inc., agreed to form Enable to own and operate the midstream businesses of OGE Energy and CenterPoint that was initially structured as a private limited partnership. This transaction closed on May 1, 2013.

Pursuant to the Master Formation Agreement, OGE Energy and the ArcLight group indirectly contributed100 percentof the equity interests inEnogex LLCto Enable. The Company determined that its contribution of Enogex LLC to Enable met the requirements of being in substance real estate and was recorded at historical cost. Immediately prior to closing, on May 1, 2013, the ArcLight group contributed $107.0 million and OGE Energy contributed $9.1 million to Enogex LLC in order to pay down short-term debt. At March 31, 2014, OGE Energy, through its wholly owned subsidiary OGE Holdings, held28.5 percentof the limited partner interests in Enable.

The general partner of Enable is equally controlled by CenterPoint and OGE Energy, who each have50 percentof the management rights. CenterPoint and OGE Energy also own a 40 percent and 60 percent interest, respectively, in any incentive distribution rights to be held by the general partner of Enable following the initial public offering of Enable on April 16, 2014 as described below. Based on the 50/50 management ownership, with neither company having control,effective May 1, 2013, OGE Energydeconsolidated its interest in Enogex Holdings LLC andbegan accounting for its interest in Enable using the equity method of accounting.

Pursuant to a Registration Rights Agreement dated as of May 1, 2013, OGE Energy and CenterPoint Energy, Inc. agreed to initiate the process for the sale of an equity interest in Enable in an initial public offering. On April 16, 2014, Enable completed an initial public offering of28,750,000common units resulting in Enable becoming a publicly traded Master Limited Partnership. The offering represented approximately6.9 percentof the limited partner interests and raised approximately$466 millionin net proceeds for Enable. As a result of the offering, OGE Holding's ownership was reduced from28.5 percent to 26.7 percent.

On May 1, 2013, OGE Energy, OGE Holdings and Enable entered into a Seconding Agreement. During the term of the Seconding Agreement, OGE Holdings' employees will continue to perform services for Enable and its subsidiaries.

Distributions received from Enable were $32.5 million during the three months ended March 31, 2014.

Related Party Transactions

OGE Energy charged operating costs to Enable of $6.0 millionduring thethreemonths endedMarch 31, 2014. OGE Energy charges operating costs to OG&E and Enable based on several factors. Operating costs directly related to OG&E and or Enable are assigned as such.  Operating costs incurred for the benefit of OG&E and Enable are allocated 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.

Related Party Transactions with Enable

	Three Months Ended
	March 31,
(In millions)	2014
Operating Revenues:
Electricity to power electric compression assets	$	2.9
Cost of Sales:
Natural gas transportation services	$	8.7
Natural gas storage services	3.3
Natural gas purchases	5.0

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Summarized Financial Information of Enable

Summarized unaudited financial information for 100 percent of Enable is presented below at March 31, 2014 and for the three months endedMarch 31, 2014.

Balance Sheet	March 31, 2014
	(In millions)
Current assets	$	500.6
Non-current assets	10,757.6
Current liabilities	1,038.9
Non-current liabilities	2,002.0

	Three Months Ended
Income Statement	March 31, 2014
	(In millions)
Operating revenues	$	1,001.6
Cost of sales	632.6
Operating income	161.9
Net income attributable to Enable	149.2

Enable concluded that the formation of Enable was considered a business combination, and CenterPoint Midstream was the acquirer of Enogex Holdings for accounting purposes.  Under this method, the fair value of the consideration paid by CenterPoint Midstream for Enogex Holdings is allocated to the assets acquired and liabilities assumed on May 1, 2013 based on their fair value.  Enogex Holdings' assets, liabilities and equity were accordingly adjusted to estimated fair value, resulting in an increase to equity of $2.2 billion. Due to the Company's determination that its contribution of Enogex LLC to Enable met the requirements of being in substance real estate and thus recording the initial investment at historical cost, the effects of the amortization and depreciation expense associated with the fair value adjustments on Enable's results of operations have been eliminated in the Company's recording of its equity in earnings of Enable.

OGE Energy recorded equity in earnings of unconsolidated affiliates of $47.9 million for the three months ended March 31, 2014. Equity in earnings of unconsolidated affiliates includes OGE Energy's28.5 percentshare of Enable earnings adjusted for the amortization of the basis difference of OGE Energy's original investment in Enogex and its underlying equity in net assets of Enable, based on historical cost as of May 1, 2013. The basis difference is being amortized over approximately 30 years, the average life of the assets to which the basis difference is attributed. Equity in earnings of unconsolidated affiliates is also adjusted for the elimination of the Enogex Holdings fair value adjustments as described above.

	Three Months Ended
Reconciliation of Equity in Earnings of Unconsolidated Affiliates	March 31, 2014
	(In millions)
OGE's 28.5% share of Enable Net Income	$	42.5
Amortization of basis difference	3.6
Elimination of Enogex Holdings fair value and other adjustments	1.8
OGE's Equity in earnings of unconsolidated affiliates	$	47.9

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4. Fair Value Measurements

The classification of the Company's fair value measurements requires judgment regarding the degree to which market data is observable or corroborated by observable market data. GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to quoted prices in active markets for identical unrestricted assets or liabilities (Level 1) and the lowest priority given to unobservable inputs (Level 3).  Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.  The three levels defined in the fair value hierarchy are as follows:

Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessible at the measurement date.

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.

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 the reporting entity's own assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk).

The Company had nofinancial instruments measured at fair value on a recurring basis atMarch 31, 2014.

The following table summarizes the fair value and carrying amount of the Company's financial instruments at March 31, 2014 and December 31, 2013.

	March 31, 2014				December 31, 2013
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-Term Debt
OG&E Senior Notes	$	2,403.8	$	2,728.0	$	2,154.5	$	2,405.0
OG&E Industrial Authority Bonds	135.4		135.4		135.4		135.4
OG&E Tinker Debt	10.3		9.2		10.3		9.1
OGE Energy Senior Notes	99.9		101.7		99.9		103.1

The Company's long-term debt is valued at the carrying amount.The fair value of the Company's long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturities and is classified as Level 2 in the fair value hierarchy except for the Tinker Debt which fair value was based on calculating the net present value of the monthly payments discounted by the Company's current borrowing rate and is classified as Level 3 in the fair value hierarchy.

5. Derivative Instruments and Hedging Activities

The Company is exposed to certain risks relating to its ongoing business operations, the most significant being interest rate risk, which the Company may manage through the use of derivative instruments. The Company is also exposed to credit risk in its business operations.

Interest Rate Risk

The Company's exposure to changes in interest rates primarily relates to short-term variable-rate debt and commercial paper.  The Company manages its interest rate exposure by monitoring and limiting the effects of market changes in interest rates.  The Company may utilize interest rate derivatives to alter interest rate exposure in an attempt to reduce the effects of these changes.  Interest rate derivatives are used solely to modify interest rate exposure and not to modify the overall leverage of the debt portfolio.

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Credit Risk

The Company is exposed to certain credit risks relating to its ongoing business operations. Credit risk includes the risk that counterparties that owe the Company money or energy will breach their obligations. If the counterparties to these arrangements fail to perform, the Company may be forced to enter into alternative arrangements. In that event, the Company's financial results could be adversely affected and the Company could incur losses.

Cash Flow Hedges

For derivatives that are designated and qualify as a cash flow hedge, the effective portion of the change in fair value of the derivative instrument is reported as a component of Accumulated Other Comprehensive Income (Loss) and recognized into earnings in the same period during which the hedged transaction affects earnings.  The ineffective portion of a derivative's change in fair value or hedge components excluded from the assessment of effectiveness is recognized currently in earnings. The Company measures the ineffectiveness of commodity cash flow hedges using the change in fair value method whereby the change in the expected future cash flows designated as the hedge transaction are compared to the change in fair value of the hedging instrument.  Forecasted transactions, which are designated as the hedged transaction in a cash flow hedge, are regularly evaluated to assess whether they continue to be probable of occurring.  If the forecasted transactions are no longer probable of occurring, hedge accounting will cease on a prospective basis and all future changes in the fair value of the derivative will be recognized directly in earnings.

The Company previously designated as cash flow hedges derivatives for OGE Holdings' NGLs volumes and corresponding keep-whole natural gas resulting from its natural gas processing contracts (processing hedges) and natural gas positions resulting from its natural gas gathering and processing operations and natural gas transportation and storage operations (operational gas hedges).  The Company also previously designated as cash flow hedges certain derivatives for certain natural gas storage inventory positions. Due to the deconsolidation of Enogex LLC effective May 1, 2013, the Company had no material instruments designated as cash flow hedges at March 31, 2014.

Income Statement Presentation Related to Derivative Instruments

The following tables present the effect of derivative instruments on the Company's Condensed Consolidated Statement of Income for thethreemonths endedMarch 31, 2013.

Derivatives in Cash Flow Hedging Relationships

(In millions)	Amount Recognized in Other Comprehensive Income		Amount Reclassified from Accumulated Other Comprehensive Income (Loss) into Income			Amount Recognized in Income
Natural Gas Financial Futures/Swaps	$	—	$	0.2		$	—
Interest Rate Swap	—		(0.2		)	—
Total	$	—	$	—		$	—

Derivatives Not Designated as Hedging Instruments

(In millions)	Amount Recognized in Income
Natural Gas Financial Futures/Swaps	(0.3		)
Total	$	(0.3	)

For derivatives designated as cash flow hedges in the tables above, amounts reclassified from Accumulated Other Comprehensive Income (Loss) into income (effective portion) and amounts recognized in income (ineffective portion) for the threemonths endedMarch 31, 2013, if any, are reported in Operating Revenues. For derivatives not designated as hedges in the tables above, amounts recognized in income for the threemonths endedMarch 31, 2013, if any, are reported in Operating Revenues.

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6. Stock-Based Compensation

The following table summarizes the Company's pre-tax compensation expense and related income tax benefit during thethreemonths endedMarch 31, 2014 and 2013related to the Company's performance units and restricted stock.

	Three Months Ended
	March 31,
(In millions)	2014		2013
Performance units
Total shareholder return	$	2.0	$	2.0
Earnings per share	1.7		0.6
Total performance units	3.7		2.6
Restricted stock	0.1		0.1
Total compensation expense	3.8		2.7
Less: Amount paid by unconsolidated affiliates	1.2		—
Net compensation expense	$	2.6	$	2.7
Income tax benefit	$	1.0	$	1.0

The Company has issued new shares to satisfy restricted stock grants and payouts of earned performance units. During thethreemonths endedMarch 31, 2014, there were495,185sharesof new common stock issued, respectively,pursuant to the Company's stock incentive plans related to restricted stock grants (net of forfeitures) and payouts of earned performance units.During thethreemonths endedMarch 31, 2014, there were1,411sharesof restricted stock, respectively, returned to the Company to satisfy tax liabilities.

The following table summarizes the activity of the Company's stock-based compensation during the three months ended March 31, 2014.

	Units/Shares	Fair Value
Grants
Performance units (Total shareholder return)	207,880	$	34.68
Performance units (Earnings per share)	69,295	$	34.69
Restricted stock	1,164	$	35.56
Conversions
Performance units (Total shareholder return) (A)	355,233	N/A
Performance units (Earnings per share) (A)	118,404	N/A

(A)Performance units were converted based on a payout ratio of 170 percent of the target number of performance units granted in February 2011 and are included in the 495,185 shares of common stock issued during the three months ended March 31, 2014 as discussed above.

7. Income Taxes

The Company files consolidated income tax returns in the U.S. Federal jurisdiction and various state jurisdictions.With few exceptions, the Company 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 taxes are generally 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 continues to amortize its Federal investment tax credits on a ratable basis throughout the year.  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 in electric generating facilities which further reduce the Company's effective tax rate.

As previously reported in the Company's 2013 Form 10-K, 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 2014, OG&E recorded an additional reserve for this item of$0.3 million ($0.2 millionafter the federal tax benefit) related to the same Oklahoma investment tax credits generated in the current year 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.

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8. Common Equity

Forward Stock Split

On May 16, 2013, the Company's Board of Directors approved a 2-for-1 forward stock split of the Company's common stock, effective July 1, 2013, which entitled each shareholder of record to receive two shares for every one share of Company stock owned by the shareholder.  In connection with the stock split, an amendment to the Company's Articles of Incorporation was approved on May 16, 2013 which increased the number of authorized shares of common stock from225 millionto450 million. All share and per share amounts within this Form 10-Q reflect the effects of the stock split.

Automatic Dividend Reinvestment and Stock Purchase Plan

The Company issued 98,476 shares of common stock under its Automatic Dividend Reinvestment and Stock Purchase Plan during the threemonths endedMarch 31, 2014 and received proceeds of $3.4 million.  The Company may, from time to time, issue additional shares under its Automatic Dividend Reinvestment and Stock Purchase Plan to fund capital requirements or working capital needs.  At March 31, 2014, there were 3,747,027 shares of unissued common stock reserved for issuance under the Company's Automatic Dividend Reinvestment and Stock Purchase Plan.

Earnings Per Share

Basic earnings per share is calculated by dividing net income attributable to OGE Energy by the weighted average number of the Company's common shares outstanding during the period. In the calculation of diluted earnings per share, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock. Potentially dilutive securities for the Company consist of performance units. Basic and diluted earnings per share for the Company were calculated as follows:

	Three Months Ended
	March 31,
(In millions except per share data)	2014		2013
Net Income Attributable to OGE Energy	$	49.3	$	23.1
Average Common Shares Outstanding
Basic average common shares outstanding	198.8		197.8
Effect of dilutive securities:
Contingently issuable shares (performance units)	0.7		1.0
Diluted average common shares outstanding	199.5		198.8
Basic Earnings Per Average Common Share Attributable to OGE Energy Common Shareholders	$	0.25	$	0.12
Diluted Earnings Per Average Common Share Attributable to OGE Energy Common Shareholders	$	0.25	$	0.12
Anti-dilutive shares excluded from earnings per share calculation	—		—

9. Long-Term Debt

AtMarch 31, 2014, the Company was in compliance with all of its debt agreements.

OG&E 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)
0.15%	-	0.18%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.08%	-	0.12%	Muskogee Industrial Authority, January 1, 2025	32.4
0.10%	-	0.10%	Muskogee Industrial Authority, June 1, 2027	56.0
Total (redeemable during next 12 months)				$	135.4

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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 the Company's Condensed Consolidated Financial Statements. OG&E believes that it has sufficient liquidity to meet these obligations.

Issuance of Long-Term Debt

On March 25, 2014, OG&E completed the issuance of$250 millionof4.55%senior notes dueMarch 15, 2044. The proceeds from the issuance were added to OG&E's general funds and were used to repay short-term debt, fund capital expenditures and general corporate expenses, and utilized 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.

10. Short-Term Debt and CreditFacilities

The Company borrows on a short-term basis, as necessary, by the issuance of commercial paper and by borrowings under its revolving credit agreements.The short-term debt balance was$377.8 millionand$439.6 millionatMarch 31, 2014 and December 31, 2013, respectively. The following table provides information regarding the Company's revolving credit agreements at March 31, 2014.

	Aggregate		Amount		Weighted-Average
Entity	Commitment		Outstanding (A)		Interest Rate			Maturity
	(In millions)
OGE Energy (B)	$	750.0	$	377.8	0.28	%	(D)	December 13, 2017
OG&E (C)	400.0		2.0		0.47	%	(D)	December 13, 2017
Total	$	1,150.0	$	379.8	0.28	%

(A) Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at March 31, 2014.

(B) This bank facility is available to back up OGE Energy's commercial paper borrowings and to provide revolving credit borrowings.  This bank facility can also be used as a letter of credit facility.  

(C) This bank facility 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.

(D) Represents the weighted-average interest rate for the outstanding borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit.

The Company's ability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions.Pricing grids associated with the Company's credit facilities could cause annual fees and borrowing rates to increase if an adverse ratings impact occurs. The impact of any future downgrade could include an increase in the costs of the Company's short-term borrowings, but a reduction in the Company's credit ratings would not result in any defaults or accelerations.Any future downgradecould also lead to higher long-term borrowing costs and, if below investment grade, would require the Company to post cash 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.

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11. Retirement Plans and Postretirement Benefit Plans

The details of net periodic benefit cost of the Company's Pension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans included in the Condensed Consolidated Financial Statements are as follows:

Net Periodic Benefit Cost

	Pension Plan						Restoration of Retirement Income Plan
	Three Months Ended						Three Months Ended
	March 31,						March 31,
(In millions)	2014 (B)			2013 (B)			2014 (B)		2013 (B)
Service cost	$	4.3		$	5.0		$	0.3	$	0.3
Interest cost	7.0			6.6			0.2		0.1
Expected return on plan assets	(12.5		)	(12.3		)	—		—
Amortization of net loss	3.5			6.2			—		0.1
Amortization of unrecognized prior service cost (A)	0.4			0.5			—		0.1
Total net periodic benefit cost	2.7			6.0			0.5		0.6
Less: Amount paid by unconsolidated affiliates	0.8			—			—		—
Net periodic benefit cost (net of unconsolidated affiliates)	$	1.9		$	6.0		$	0.5	$	0.6

(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$2.4 millionand$6.6 millionof net periodic benefit cost recognizedduring thethreemonths endedMarch 31, 2014and2013, respectively, OG&E recognized an increase in pension expense during thethreemonths endedMarch 31, 2014and2013of$3.3 millionand$1.9 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 liability (see Note 1).

	Postretirement Benefit Plans
	Three Months Ended
	March 31,
(In millions)	2014 (B)			2013 (B)
Service cost	$	0.9		$	1.2
Interest cost	2.8			2.6
Expected return on plan assets	(0.6		)	(0.6		)
Amortization of net loss	3.1			5.3
Amortization of unrecognized prior service cost (A)	(4.1		)	(4.1		)
Total net periodic benefit cost	2.1			4.4
Less: Amount paid by unconsolidated affiliates	0.3			—
Net periodic benefit cost (net of unconsolidated affiliates)	$	1.8		$	4.4

(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$1.8 millionand$4.4 millionof net periodic benefit cost recognizedduring thethreemonths endedMarch 31, 2014and2013, respectively, OG&E recognized an increase in postretirement medical expense duringthethreemonths endedMarch 31, 2014and2013of$1.2 millionand$0.1 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 liability (see Note 1).

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	Three Months Ended
	March 31,
(In millions)	2014		2013
Capitalized portion of net periodic pension cost	$	0.6	$	1.6
Capitalized portion of net periodic postretirement benefit cost	0.5		1.3

12. Report of Business Segments

The Company reports its operations in two business segments: (i) the electric utility segment, which is engaged in the generation, transmission, distribution and sale of electric energy, and (ii) natural gas midstream operations segment.

The natural gas midstream operations segment reflects the Company's equity interest in Enable since its formation on May 1, 2013. Prior to May 1, 2013, the Company reported the results of Enogex Holdings in two separate segments: the natural gas transportation and storage segment, and the natural gas gathering and processing segment. After the deconsolidation, these segments were combined into the natural gas midstream operations segment.The presentation of results for the three months ended March 31, 2013 have been revised to reflect this change. Equity in earnings of unconsolidated affiliates in the natural gas midstream operations segment includes OGE Energy's equity interest in Enable since May 1, 2013. Other than equity in earnings of unconsolidated affiliates, all amounts for the natural gas midstream operations segment represent the operation results of Enogex Holdings through April 30, 2013. Investment in unconsolidated affiliates in the natural gas midstream operations segment represents OGE Energy's investment in Enable at March 31, 2014.

Other Operations primarily includes the operations of the holding company. 

Intersegment revenues are recorded at prices comparable to those of unaffiliated customers and are affected by regulatory considerations.

In reviewing its segment operating results, the Company focuses on operating income and equity in earnings of unconsolidated affiliates as measures of segment profit and loss, and, therefore, has presented this information below.  The following tables summarize the results of the Company's business segments during the threemonths endedMarch 31, 2014 and 2013.

Three Months Ended March 31, 2014	Electric Utility		Natural Gas Midstream Operations		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	560.4	$	—	$	—		$	—		$	560.4
Cost of sales	293.4		—		—			—			293.4
Other operation and maintenance	117.1		—		(4.7		)	—			112.4
Depreciation and amortization	64.3		—		2.9			—			67.2
Taxes other than income	23.8		—		1.8			—			25.6
Operating income (loss)	$	61.8	$	—	$	—		$	—		$	61.8
Equity in earnings of unconsolidated affiliates	$	—	$	47.9	$	—		$	—		$	47.9
Investment in unconsolidated affiliates (at historical cost)	$	—	$	1,314.2	$	—		$	—		$	1,314.2
Total assets	$	7,826.8	$	1,367.4	$	127.9		$	(71.4	)	$	9,250.7

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Three Months Ended March 31, 2013	Electric Utility		Natural Gas Midstream Operations		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	455.5	$	464.3	$	—		$	(18.4	)	$	901.4
Cost of sales	213.0		359.2		—			(19.2		)	553.0
Other operation and maintenance	105.1		45.2		(2.3		)	—			148.0
Depreciation and amortization	61.3		27.6		3.0			—			91.9
Taxes other than income	23.2		8.0		1.9			—			33.1
Operating income (loss)	$	52.9	$	24.3	$	(2.6	)	$	0.8		$	75.4
Total assets	$	7,138.4	$	2,729.9	$	381.6		$	(268.1	)	$	9,981.8

13. Commitments and Contingencies

Except as set forth below, in Note 14 and under "Environmental Laws and Regulations" in Item 2 of Part I and in Item 1 of Part II of this Form 10-Q, the circumstances set forth in Notes 16 and 17 to the Company's Consolidated Financial Statements included in the Company's 2013Form 10-K appropriately represent, in all material respects, the current status of the Company's material commitments and contingent liabilities.

OG&E Minimum Fuel Purchase Commitments

OG&E has coal contracts for purchases through December 2016. Also, as previously reported, OG&E had entered into multiple-month term natural gas contracts for31.5 percentof its 2014 annual forecasted natural gas requirements. In March 2014, through a request for proposal, OG&E entered into various multiple-month term natural gas contracts for42.6 percentof its remaining forecasted 2014 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 mid-2014, along with monthly and daily purchases, all of which are expected to be made at market prices.

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. On March 17, 2014, OG&E entered into a new contract effective May 1, 2014 and expiring April 30, 2019.

Environmental Laws and Regulations

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.

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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. On March 4, 2014, the United States District Court for the Eastern District of Oklahoma dismissed the prevention of significant deterioration permit claim because it was filed after the statute of limitations expired, but the court allowed the opacity and particulate matter claims to proceed. 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,the Companyis 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,the Companyhas incurred a probable loss as set forth by GAAP, an estimate is made of the loss and the appropriate accounting entries are reflected in the Company's Condensed Consolidated Financial Statements.At the present time, based on currently available information, except as otherwise stated above, in Note 13 below, under "Environmental Laws and Regulations" in Item 2 of Part 1 and in Item 1 of Part II of this Form 10-Q, in Notes 15 and 16 of Notes to Consolidated Financial Statements and in Item 3 of Part I of the Company's 2013Form 10-K, the Company believes 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 on the Company's consolidated financial position, results of operations or cash flows.

14. Rate Matters and Regulation

Except as set forth below, the circumstances set forth in Note 16 to the Company's Consolidated Financial Statements included in the Company's 2013Form 10-K appropriately represent, in all material respects, the current status of the Company's regulatory matters.

Completed Regulatory Matters

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

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Marketplace. On February 28, 2014, FERC issued a letter order accepting OG&E’s market-based rate filing and tariff effective March 1, 2014. FERC found that OG&E passed the market power screens and satisfied requirements related to horizontal market power and vertical market power.

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.  OG&E and Arkansas Electric Cooperative Corporation agreed to terms of a settlement and filed the offer of settlement with FERC on February 24, 2014. On April 17, 2014, OG&E received a FERC order accepting the settlement agreement and terminating the Arkansas Electric Cooperative Corporation complaint docket. OG&E believes the reduction in revenue will be approximately$1.0 millionper year for the term of the agreement, which ends June 30, 2015.

Pending Regulatory Matters

Fuel Adjustment Clause Review for Calendar Year 2012

The OCC routinely reviews the costs recovered from customers through OG&E's fuel adjustment clause. 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. On April 24, 2014, the OCC administrative law judge at the hearing, on the merits, recommended that the OCC find for the calendar year 2012 OG&E's electric generation, purchased power and fuel procurement processes and costs were prudent.

Energy Efficiency Program Filing

On February 14, 2014, 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.

Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations.

Introduction

The Company is 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. The Company conducts these activities through two business segments:  (i) electric utility and (ii) natural gas midstream operations. For a discussion of change in business segments, see Note 12 of Notes to Condensed Consolidated Financial Statements. For periods prior to May 1, 2013, the Company consolidated Enogex Holdings in its Condensed Consolidated Financial Statements.

Effective May 1, 2013,OGE Energy, the ArcLight group and CenterPoint Energy, Inc., formed Enable Midstream Partners, L.P. to own and operate the midstream businesses of OGE Energy and CenterPoint. In the formation transaction, OGE Energy and ArcLight contributed Enogex LLC to Enable andthe Company deconsolidated its previously held investment in Enogex Holdings and acquired an equity interest in Enable.The Company determined that its contribution of Enogex LLC to Enable met the requirements of being in substance real estate and was recorded at historical cost.The general partner of Enable is equally controlled by CenterPoint and OGE Energy, who each have50 percentof the management rights.Based on the 50/50 management ownership, with neither company having control,effective May 1, 2013, OGE Energybegan accounting for its interest in Enable using the equity method of accounting. At March 31, 2014, OGE Energy, through its wholly owned subsidiary OGE Holdings, held28.5 percentof the limited partner interests in Enable.OGE Energy also owns a60 percentinterest in any incentive distribution rights in Enable. Incentive distribution rights entitle the holder to increasing percentages, up to a maximum of50 percent, of the cash distributed by Enable in excess of the target quarterly distributions established in connection with Enable’s initial public offering as described below.On April 16, 2014, Enable completed an initial public offering of28,750,000common units resulting in Enable becoming a publicly traded Master Limited Partnership. The offering represented approximately6.9 percentof the limited partner interests and raised approximately$466 millionin net proceeds for Enable. As a result of the offering, OGE Holding's ownership was reduced from28.5 percent to 26.7 percent.

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In connection with Enable’s initial public offering, approximately61.4 percentof OGE Holdings and CenterPoint’s common units were converted into subordinated units. As a result, following the initial public offering, OGE Holdings owned42,832,291common units and68,150,514subordinated units of Enable.

Enable is expected to pay a minimum quarterly distribution of $0.2875 per unit on its outstanding units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to its general partner and its affiliates, within 45 days after the end of each quarter. Enable will adjust the amount of this distribution for the period from April 16, 2014, the completion of its initial public offering, through June 30, 2014 based on the actual length of the period.If cash distributions to Enable’s unitholders exceed $0.330625 per unit in any quarter, the general partner will receive increasing percentages, up to50 percent, of the cash Enable distributes in excess of that amount. As indicated above, OGE Holdings is entitled to60 percentof those “incentive distributions.”

The electric utility segmentgenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas.  Its operations areconducted through OG&E and aresubject 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 began participating in the SPP Integrated Marketplace effective March 1, 2014.  The SPP Integrated Marketplace replaced the SPP Energy Imbalance Services market. As part of the Integrated Marketplace, the SPP assumed balancing authority responsibilities for its market participants.  The SPP Integrated Marketplace functions as a centralized dispatch, where market participants, including OG&E, submit offers to sell power to the SPP from their resources and bid to purchase power from the SPP for their customers.  The SPP Integrated Marketplace is intended to allow the SPP to optimize supply offers and demand bids based upon reliability and economic considerations, and determine which generating units will run at any given time for maximum cost-effectiveness.  As a result, OG&E's generating units may produce output that differs from OG&E's customer load requirements. Net fuel and purchased power costs will be recovered through fuel adjustment clauses.

The natural gas midstream operations segment consists of the Company's investment in Enable. Enable is engaged in the business of gathering, processing, transporting and storing natural gas. Enable's natural gas gathering and processing assets are strategically located in four states and serve natural gas production from shale developments in the Anadarko, Arkoma and Ark-La-Tex basins. Enable also owns an emerging crude oil gathering business in the Bakken shale formation that commenced initial operations in November 2013. Enable is continuing to construct additional crude oil gathering capacity in this area. Enable's natural gas transportation and storage assets extend from western Oklahoma and the Texas Panhandle to Alabama and from Louisiana to Illinois.

As discussed in Note 1 of Notes to Condensed Consolidated Financial Statements, the Company completed a 2-for-1 stock split of the Company's common stock effective July 1, 2013. All share and per share amounts within this Form 10-Q reflect the effects of the stock split.

Overview

Company Strategy

The Company'smission is to fulfill its critical role in the nation's electric utility and natural gas midstream pipeline infrastructure, through its equity interest in Enable, and meet individual customers' needs for energy and related services focusing on safety, efficiency, reliability, customer service and risk management.The Company'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, through its equity interest in Enable, 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.Additionally, the Company wants to achieve a premium valuation of its businesses relative to its peers, grow earnings per share with a stable earnings pattern, create a high performance culture and achieve desired outcomes with target stakeholders.The Company's financial objectives include a long-term annual earnings growth rate of five to seven percent on a weather-normalized basis, maintaining a strong credit rating as well as increasing the dividend to meet the Company's dividend payout objectives.  The Company's target payout ratio is to pay out dividends of approximately 60 percent of its normalized earnings on an annual basis.  The target payout ratio has been determined after consideration of numerous factors, including the largely retail composition of the Company's shareholder base, the Company's financial position, the Company's growth targets, the composition of the Company's assets and investment opportunities.  The Company believes it can accomplish these financial objectives by, among other things, pursuing multiple avenues to build its business, maintaining a diversified asset position, continuing to develop a wide range of skills to succeed with

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changes in its industries, providing products and services to customers efficiently, managing risks effectively and maintaining strong regulatory and legislative relationships.

Summary of Operating Results

ThreeMonths EndedMarch 31, 2014as Compared toThreeMonths EndedMarch 31, 2013

Net income attributable to OGE Energy was$49.3 million, or$0.25per diluted share, during thethreemonths endedMarch 31, 2014as compared to$23.1 million, or$0.12per diluted share, during the same period in2013. Theincreasein net income attributable to OGE Energy of$26.2 million, or$0.13 per diluted share, during thethreemonths endedMarch 31, 2014as compared to the same period in2013was primarily due to:

• an increasein net income at OG&E of$7.7 million, or59.2 percent, or $0.03 per diluted share of the Company's common stock, primarily due to an increase in gross margin as a result of higher transmission revenue along with higher sales due to colder weather, which was partially offset by higher expenses related to ongoing maintenance at the power plants;

• an increasein net income attributable to OGE Holdings of$17.1 million, or$0.09per diluted share of the Company's common stock,due to the accretive effect to OGE Holdings of Enable; and

• a decreasein net losses attributable to OGE Energy of$1.4 million, or$0.01per diluted shareof the Company's common stock, primarily due to transaction expenses related to the formation of Enable during 2013 and a decrease in deferred compensation expense.

2014 Outlook

The Company's2014consolidatedearnings guidance remained unchanged between approximately $388 million and $411 million of net income, or $1.94 to $2.06 per average diluted share and assumes approximately 200 million average share outstanding. This guidance assumes normal weather for the remainder of the year and includes the impact from the Company's equity interest in Enable. See the Company's 2013Form 10-K for other key factors and assumptions underlying its 2014 earnings guidance.

Results of Operations

The following discussion and analysis presents factors that affected the Company's consolidated results of operations for the threemonths endedMarch 31, 2014as compared to the same period in2013and the Company's consolidated financial position atMarch 31, 2014. Due to seasonal fluctuations and other factors, the Company'soperating results for the threemonths endedMarch 31, 2014are not necessarily indicative of the results that may be expected for the year endingDecember 31, 2014or for any future period.The following information should be read in conjunction with theCondensed Consolidated Financial Statements and Notes thereto. Known trends and contingencies of a material nature are discussed to the extent considered relevant.

	Three Months Ended
	March 31,
(In millions except per share data)	2014		2013
Operating income	$	61.8	$	75.4
Net income attributable to OGE Energy	$	49.3	$	23.1
Basic average common shares outstanding	198.8		197.8
Diluted average common shares outstanding	199.5		198.8
Basic earnings per average common share attributable to OGE Energy common shareholders	$	0.25	$	0.12
Diluted earnings per average common share attributable to OGE Energy common shareholders	$	0.25	$	0.12
Dividends declared per common share	$	0.22500	$	0.20875

In reviewing its consolidated operating results, the Company believes that it is appropriate to focus on operating income and equity in earnings of unconsolidated affiliates as reported in its Condensed Consolidated Statements of Income, as these measures indicate the ongoing profitability of the Company excluding the cost of capital and income taxes.

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Operating Results by Business Segment

	Three Months Ended
	March 31,
(In millions)	2014		2013
Operating income (loss)
OG&E (Electric Utility)	$	61.8	$	52.9
OGE Holdings (Natural Gas Midstream Operations) (A)	—		24.3
Other Operations (B)	—		(1.8		)
Consolidated operating income	$	61.8	$	75.4
Equity in earnings of unconsolidated affiliates
OGE Holdings (Natural Gas Midstream Operations) (A)	$	47.9	$	—

(A) Prior to May 1, 2013, the Company reported the results of Enogex Holdings in two separate segments: the natural gas transportation and storage segment, and the natural gas gathering and processing segment. After the deconsolidation, these segments were combined into the natural gas midstream operations segment.The presentation of results for the three months ended March 31, 2013 have been revised to reflect this change.

(B) Other Operations primarily includes the operations of the holding company and consolidating eliminations.

The following operating income analysis by business segment includes intercompany transactions that are eliminated in the Condensed Consolidated Financial Statements. 

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OG&E (Electric Utility)

	Three Months Ended
	March 31,
(Dollars in millions)	2014			2013
Operating revenues	$	560.4		$	455.5
Cost of sales	293.4			213.0
Other operation and maintenance	117.1			105.1
Depreciation and amortization	64.3			61.3
Taxes other than income	23.8			23.2
Operating income	61.8			52.9
Allowance for equity funds used during construction	1.1			1.2
Other income (loss)	(0.3		)	2.7
Other expense	0.4			0.5
Interest expense	33.9			31.4
Income tax expense	7.6			11.9
Net income	$	20.7		$	13.0
Operating revenues by classification
Residential	$	220.5		$	183.4
Commercial	123.7			105.6
Industrial	50.8			46.1
Oilfield	44.3			36.8
Public authorities and street light	47.9			41.6
Sales for resale	16.6			14.5
System sales revenues	503.8			428.0
Off-system sales revenues	19.0			2.1
Other	37.6			25.4
Total operating revenues	$	560.4		$	455.5
Reconciliation of gross margin to revenue:
Operating revenues	$	560.4		$	455.5
Cost of sales	293.4			213.0
Gross Margin	$	267.0		$	242.5
Megawatt-hour sales by classification (In millions)
Residential	2.5			2.2
Commercial	1.6			1.5
Industrial	0.9			0.9
Oilfield	0.8			0.8
Public authorities and street light	0.7			0.7
Sales for resale	0.3			0.3
System sales	6.8			6.4
Off-system sales	0.4			0.1
Total sales	7.2			6.5
Number of customers	809,602			801,194
Weighted-average cost of energy per kilowatt-hour - cents
Natural gas	5.518			3.409
Coal	2.146			2.286
Total fuel	3.490			2.827
Total fuel and purchased power	3.792			3.037
Degree days (A)
Heating - Actual	2,065			1,800
Heating - Normal	1,798			1,798
Cooling - Actual	9			4
Cooling - Normal	13			13

(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

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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.

ThreeMonths EndedMarch 31, 2014as Compared toThreeMonths EndedMarch 31, 2013

OG&E's operating incomeincreased$8.9 million, or16.8 percent, during thethreemonths endedMarch 31, 2014as compared to the same period in2013primarily due to higher gross margin partially offset by higher other operation and maintenance expense and higher depreciation and amortization.

Gross Margin

Gross Margin is defined by OG&E as operating revenues less fuel, purchased power and certain 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 and purchased power 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$560.4 millionduring thethreemonths endedMarch 31, 2014as compared to$455.5 millionduring the same period in2013, an increaseof$104.9 million, or23.0 percent. Cost of sales were$293.4 millionduring thethreemonths endedMarch 31, 2014as compared to$213.0 millionduring the same period in2013, an increaseof$80.4 million, or37.7 percent. Gross margin was$267.0 millionduring thethreemonths endedMarch 31, 2014as compared to$242.5 millionduring the same period in2013, an increaseof$24.5 million, or10.1 percent. The below factors contributed to the change in gross margin:

	$ Change
	(In millions)
Wholesale transmission revenue (A)	$	11.7
Quantity variance (primarily weather)	10.0
New customer growth	2.2
Non-residential demand and related revenues	1.1
Other	0.5
Price variance (B)	(1.0		)
Change in gross margin	$	24.5

(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$195.1 millionduring thethreemonths endedMarch 31, 2014as compared to$146.4 millionduring the same period in2013, an increaseof$48.7 million, or33.3 percent, primarily due to higher natural gas prices. Purchased power costs were$89.8 millionduring thethreemonths endedMarch 31, 2014as compared to$60.1 millionduring the same period in2013, an increaseof$29.7 million, or49.4 percent, primarily due to an increase in purchases from the SPP, reflecting the impact of OG&E's participation in the SPP Integrated Market, which began on March 1, 2014. Transmission expense is charged to OG&E by the SPP for the utilization of transmission systems owned by other SPP members and is recovered from retail customers through the SPP Cost Tracker in Oklahoma and through the Transmission Cost Rider in Arkansas. Transmission charges were$8.5 millionduring thethreemonths endedMarch 31, 2014as compared to$6.5 millionduring the same period in2013, an increaseof$2.0 million, or30.8 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 expense was$117.1 millionduring thethreemonths endedMarch 31, 2014as compared to$105.1 millionduring the same period in2013, an increaseof$12.0 million, or11.4 percent. The below factors contributed to the change in other operation and maintenance expense:

	$ Change
	(In millions)
Ongoing maintenance at power plants (A)	$	7.4
Corporate overhead and allocations	2.5
Contract professional services (primarily marketing services)	1.6
Capitalized labor	1.6
Other	0.8
Vegetation management	(1.9		)
Change in other operation and maintenance expense	$	12.0

(A) Increased as a result of routine maintenance typically performed in the first quarter that was delayed until the fourth quarter of 2013.

Depreciation and amortization expense was$64.3 millionduring thethreemonths endedMarch 31, 2014as compared to$61.3 millionduring the same period in2013, an increaseof$3.0 million, or4.9 percent, primarily due to additional assets being placed in service throughout 2013. This was partially offset by a decrease in the amortization of the pension regulatory asset which was fully amortized in July 2013.

Additional Information

Other Income.Other income was a net loss of$0.3 millionduring thethreemonths endedMarch 31, 2014as compared toa net gain of$2.7 millionduring the same period in2013, a decreaseof$3.0 million, primarily due toa decreasedmargin of$2.7 millionrecognized in the guaranteed flat bill program during 2014 as a result of higher usage due to cooler weather.

Interest Expense.Interest expense was$33.9 millionduring thethreemonths endedMarch 31, 2014as compared to $31.4 millionduring the same period in2013, an increaseof$2.5 million, or8.0 percent, primarily due to a$2.6 millionincreasein interest on long term debt related to a $250 million debt issuance that occurred in May 2013 and a $250 million debt issuance that occurred in March 2014.

Income Tax Expense.Income tax expense was$7.6 millionduring thethreemonths endedMarch 31, 2014as compared to$11.9 millionduring the same period in2013, a decreaseof$4.3 millionor36.1 percent, primarily due to a reduced tax expense provided for an uncertain tax position partially offset by an increase in tax fromhigherpre-tax income during thethreemonths endedMarch 31, 2014as compared to the same period in2013.

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OGE Holdings (Natural Gas Midstream Operations)

	Three Months Ended
	March 31,
(In millions)	2014		2013
Operating revenues	$	—	$	464.3
Cost of sales	—		359.2
Other operation and maintenance	—		45.2
Depreciation and amortization	—		27.6
Taxes other than income	—		8.0
Operating income	—		24.3
Equity in earnings of unconsolidated affiliates	47.9		—
Other income	—		10.2
Other expense	—		1.2
Interest expense	—		8.1
Income tax expense	18.5		7.7
Net income	29.4		17.5
Less: Net income attributable to noncontrolling interests	—		5.2
Net income attributable to OGE Holdings	$	29.4	$	12.3

Effective May 1, 2013, the Company deconsolidated its previously held investment in Enogex Holdings and acquired a 28.5 percent equity interest in Enable which is being accounted for using the equity method of accounting. Prior to May 1, 2013, the Company reported the results of Enogex Holdings in two separate segments: the natural gas transportation and storage segment, and the natural gas gathering and processing segment. After the deconsolidation, these segments were combined into the natural gas midstream operations segment.The presentation of results for the three months ended March 31, 2013 have been revised to reflect this change.

ThreeMonths EndedMarch 31, 2014as Compared toThreeMonths EndedMarch 31, 2013

	Enable Midstream Partners (Equity Method - Three Months Ended March 31, 2014)		Natural Gas Midstream Operations (Consolidated - Three Months Ended March 31, 2013)
(In millions)
Operating revenues	$	—	$	464.3
Cost of sales	—		359.2
Operating expenses	—		80.8
Operating income	—		24.3
Equity in earnings of unconsolidated affiliates	47.9		—
Income tax expense	18.5		7.7
Net income	29.4		12.3

The increase in results for the three months ended March 31, 2014 reflect the accretive effect of the Enable transaction, as well asincreases in Enable's transportation and storage business primarily driven by higher natural gas prices and higher natural gas liquids sales.

Income Tax Expense.Income tax expense was$18.5 millionduring thethreemonths endedMarch 31, 2014as compared to$7.7 millionduring the same period in2013, an increaseof$10.8 million primarily due to higher pre-tax income during the threemonths endedMarch 31, 2014as compared to the same period in2013.

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Enable Midstream Partners Results of Operations during the ThreeMonths EndedMarch 31, 2014

	Three Months Ended
	March 31, 2014
	(In millions)
Operating revenues	$	1,001.6
Cost of sales	632.6
Operating income	161.9
Net income attributable to Enable	149.2

Equity in earnings of unconsolidated affiliates includes OGE Energy's28.5 percentshare of Enable earnings adjusted for the amortization of the basis difference of OGE Energy's original investment in Enogex and its underlying equity in net assets of Enable, based on historical cost as of May 1, 2013. The basis difference is being amortized over approximately 30 years, the average life of the assets to which the basis difference is attributed. Equity in earnings of unconsolidated affiliates is also adjusted for the elimination of the Enogex Holdings fair value adjustments.

Reconciliation of Equity in Earnings of Unconsolidated Affiliates

	Three Months Ended
	March 31, 2014
	(In millions)
OGE's 28.5% share of Enable Net Income	$	42.5
Amortization of basis difference	3.6
Elimination of Enogex Holdings fair value and other adjustments	1.8
OGE's Equity in earnings of unconsolidated affiliates	$	47.9

Enable Midstream Partners Operating Data during the ThreeMonths EndedMarch 31, 2014

	Three Months Ended
	March 31, 2014
Gathered volumes - TBtu/d (A)	3.31
Transportation volumes - TBtu/d	5.55
Natural gas processed - TBtu/d	1.44
NGLs sold - million gallons/d	66.16

(A) Excludes volumes billed under throughput agreements.

Off-Balance Sheet Arrangement

There have been no significant changes in the Company's off-balance sheet arrangement from that discussed in the Company's 2013Form 10-K. The Company has no off-balance sheet arrangements with equity method investments that would affect its liquidity.

Liquidity and Capital Resources

Working Capital

Working capital is defined as the amount by which current assets exceed current liabilities. The Company'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 and Accrued Unbilled Revenues was$253.9 millionand$250.5 millionatMarch 31, 2014andDecember 31, 2013, respectively,an increaseof$3.4 million, or1.4 percent, primarily due toincreases in billings to

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partners of jointly-owned power plants and transmission revenue partially offset by a decrease in billings to OG&E's retail customers reflecting milder weather in March 2014 as compared to December 2013.

The balance of Accounts Payable was$209.6 millionand$251.0 millionatMarch 31, 2014andDecember 31, 2013, respectively,a decreaseof$41.4 million, or16.5 percent, primarily due toa decrease in accruals.

Cash Flows

	Three Months Ended
	March 31,						2014 vs. 2013
(In millions)	2014			2013			$ Change			% Change
Net cash provided from operating activities	$	23.2		$	59.2		$	(36.0	)	(60.8	)%
Net cash used in investing activities	(171.4		)	(289.5		)	118.1			40.8	%
Net cash provided from financing activities	143.8			235.6			(91.8		)	39.0	%

Operating Activities

Thedecrease of $36.0 million, or 60.8 percent, in net cash provided from operating activities during thethreemonths endedMarch 31, 2014as compared to the same period in2013was primarily due to:

• increased vendor payments, including payments for ongoing maintenance at the power plants; and

• the deconsolidation of Enogex Holdings on May 1, 2013.

Investing Activities

Thedecrease of $118.1 million, or 40.8 percent, in net cashused ininvesting activities during thethreemonths endedMarch 31, 2014as compared to the same period in2013was primarily due to lower levels of capital expenditures due to the deconsolidation of Enogex Holdings and a decreased level of transmission projects at OG&E.

Financing Activities

Thedecrease of $91.8 million, or 39.0 percent, in net cash provided from financing activitiesduring thethreemonths endedMarch 31, 2014as compared to the same period in2013was primarily due to a decrease in short-term debt and the deconsolidation of Enogex Holdings partially offset by proceeds received from OG&E's issuance of long-term debt in March 2014.

Future Capital Requirements and Financing Activities

The Company's primary needs for capital are related to acquiring or constructing new facilities and replacing or expanding existing facilities at OG&E. 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. The Company generally meets its cash needs through a combination of cash generated from operations, short-term borrowings (through a combination of bank borrowings and commercial paper) and permanent financings.

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Capital Expenditures

The Company's consolidated estimates of capital expenditures for the years 2014 through 2018 are shown in the following table.These capital expenditures represent the base maintenance capital expenditures (i.e., capital expenditures to maintain and operate the Company's business) plus capital expenditures for known and committed projects. The Company believes that Enable has, or will have access to, adequate liquidity and, therefore, no contributions are expected to be necessary to fund the capital expenditures of Enable from the general partners. Accordingly, capital expenditures for Enable are not included in the table below.

(In millions)	2014		2015		2016		2017		2018
OG&E Base Transmission	$	30	$	30	$	30	$	30	$	30
OG&E Base Distribution	175		175		175		175		175
OG&E Base Generation	140		75		75		75		75
OG&E Other	15		15		15		15		15
Total OG&E Base Transmission, Distribution, Generation and Other	360		295		295		295		295
OG&E Known and Committed Projects:
Transmission Projects:
Regionally Allocated Base Projects (A)	55		20		20		20		20
Balanced Portfolio 3E Projects (B)	15		—		—		—		—
SPP Priority Projects (B)(C)	75		—		—		—		—
SPP Integrated Transmission Projects (B) (C)	10		25		30		25		10
Total Transmission Projects	155		45		50		45		30
Other Projects:
Smart Grid Program	25		10		10		—		—
Environmental - low NOX burners	25		25		20		10		—
Environmental - activated carbon injection	5		10		5		—		—
Total Other Projects	55		45		35		10		—
Total OG&E Known and Committed Projects	210		90		85		55		30
Total OG&E (D)	570		385		380		350		325
OGE Energy	15		10		10		10		10
Total capital expenditures	$	585	$	395	$	390	$	360	$	335

(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
	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 SO₂emissions under the regional haze requirements due to the uncertainty regarding the approach and timing for such pollution control equipment.The SO₂emissions 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 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.

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• 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 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 millionover 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 achieving the Company's financial objectives.

Security Ratings

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 with the Company's credit facilities could cause annual fees and borrowing rates to increase if an adverse ratings impact occurs. The impact of any future downgrade could include an increase in the costs of the Company's short-term borrowings, but a reduction in the Company's credit ratings would not result in any defaults or accelerations.Any future downgradecould also lead to higher long-term borrowing costs and, if below investment grade, would require the Company to post cash collateral or letters of credit.

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 Sources of Financing

Management expects that cash generated from operations, proceeds from the issuance of long and short-term debt, distributions from equity method investments and proceeds from the sales ofcommon stock to the public through the Company's Automatic Dividend Reinvestment and Stock Purchase Plan or other offerings and distributions from Enable will be adequate over the next three years to meet anticipated cash needs and to fund future growth opportunities. The Company utilizes short-term borrowings (through a combination of bank borrowings and commercial paper)to satisfy temporary working capital needs and as an interim source of financing capital expenditures until permanent financing is arranged.

Short-Term Debt and CreditFacilities

Short-term borrowings generally are used to meet working capital requirements. The Company borrows on a short-term basis, as necessary, by the issuance of commercial paper and by borrowings under its revolving credit agreements. At March 31, 2014, the Company has revolving credit facilities totaling in the aggregate 1,150.0 million. These bank facilities can also be used asletter of credit facilities. The short-term debt balance was$377.8 millionand$439.6 millionatMarch 31, 2014 and December 31, 2013, respectively. The weighted-average interest rate on short-term debt at March 31, 2014 was 0.28 percent.  The average balance of short-term debt during the three months ended March 31, 2014 was $507.6 million at a weighted-average interest rate of 0.29 percent. The maximum month-end balance of short-term debt during the three months ended March 31, 2014 was $570.7 million. AtMarch 31, 2014, there was$2.0 millionsupporting letters of credit at a weighted-average interest rate of0.47 percent. At March 31, 2014, the Company had $770.2 millionof net available liquidity under its revolving credit agreements.  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.  At March 31, 2014, the Company had $2.4 million in cash and cash equivalents.  See Note 10 of Notes to Condensed Consolidated Financial Statements for a discussion of the Company's short-term debt activity.

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Issuance of Long-Term Debt

On March 25, 2014, OG&E completed the issuance of$250 millionof4.55%senior notes dueMarch 15, 2044. The proceeds from the issuance were added to OG&E's general funds and were used to repay short-term debt, fund capital expenditures and general corporate expenses, and utilized 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.

Quarterly Distributions by Enable Midstream Partners

Pursuant to the Enable Midstream Partners Agreement, during the first quarter Enable Midstream Partners made distributions of approximately $32.5 million to the Company.

Critical Accounting Policies and Estimates

The Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements contain information that is pertinent to Management's Discussion and Analysis.In preparing the Condensed Consolidated Financial 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 the Condensed Consolidated Financial Statements and the reported amounts of revenues and expenses during the reporting period.  Changes to these assumptions and estimates could have a material effect on the Company's Condensed Consolidated Financial Statements.  However, the Company believes it has taken reasonable, but conservative, positions where assumptions and estimates are used in order to minimize the negative financial impact to the Company that could result if actual results vary from the assumptions and estimates.

In management's opinion, the areas of the Company where the most significant judgment is exercised for all Company segments includes the determination of Pension Plan assumptions,impairment estimates of long-lived assets (including intangible assets), and income taxes. For the electric utility segment, significant judgment is also exercised in contingency reserves, asset retirement obligations, the allowance for uncollectible accounts and the valuation of regulatory assets and liabilities and unbilled revenues. The selection, application and disclosure of the Company's critical accounting estimates have been discussed with the Company's Audit Committee and are discussed in detail in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations in the Company's 2013Form 10-K.

Commitments and Contingencies

In the normal course of business,the Companyis 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,the Companyhas incurred a probable loss as set forth by GAAP, an estimate is made of the loss and the appropriate accounting entries are reflected in the Company's Condensed Consolidated Financial Statements.At the present time, based on currently available information, except as otherwise stated in Notes 13 and 14 of Notes to Condensed Consolidated Financial Statements, under "Environmental Laws and Regulations" below and in Item 1 of Part II of this Form 10-Q, in Notes 15 and 16 of Notes to Consolidated Financial Statements and in Item 3 of Part I of the Company's 2013Form 10-K, the Company believes 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 on the Company's consolidated financial position, results of operations or cash flows.

Environmental Laws and Regulations

The activities of OG&E are subject to numerous, stringent and complex Federal, state and local laws and regulations governing environmental protection. These laws and regulations can change, restrict or otherwise impact OG&E's business activities in many ways including the handling or disposal of waste material, future construction activities to avoid or mitigate harm to threatened or endangered species and requiring the installation and operation of emissions 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. OG&E believes that its operations are in substantial compliance with current Federal, state and local environmental standards. These environmental laws and regulations are discussed in detail in Management's Discussion and Analysis of Financial Condition and Results of Operations in the Company's 2013Form 10-K. Except as set forth below, there have been no material changes to such items.

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OG&E expects that environmental expenditures necessary to comply with the environmental laws and regulations discussed below will qualify as part of a pre-approval 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.

Air

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. The regional haze rule is intended to protect visibility in certain national parks and wilderness areas throughout the United States. In Oklahoma, the Wichita Mountains are the only area covered under the rule. However, Oklahoma's impact on parks in other states must also be evaluated.

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. Certain of OG&E’s units at the Horseshoe Lake, Seminole, Muskogee and Sooner generating stations were evaluated for BART. 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 NO_X and SO₂from 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 NO_Xemissions at all of the subject units should be the installation of low NO_Xburners with overfire air (flue gas recirculation was also required on two of the units) and set forth associated NO_Xemission rates and limits. OG&E preliminarily estimates that the total capital cost of installing and operating these NO_Xcontrols 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 SO₂control 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 SO₂control 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 NO_Xin the final rule, it rejected Oklahoma's SO₂BART 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 SO₂emission rate of0.06pounds per million British thermal unit 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 request to stay the FIP 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 require 27states 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 make sixadditional states, including Oklahoma, subject to the Cross-State Air Pollution Rule for NO_Xemissions during the ozone-season from May 1 through September 30. Under the rule, OG&E would have been required to reduce ozone-season NO_Xemissions 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

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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 April 29, 2014, the U.S. Supreme Court reversed the decision by the U.S. Court of Appeals. It is anticipated that further proceedings will occur in the U.S. Court of Appeals and at EPA to establish new compliance deadlines. The Company's appeal of the supplemental rule, which applies to Oklahoma remains pending in the U.S. Court of Appeals and was not directly affected by the U.S. Supreme Court decision.

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. On March 4, 2014, the United States District Court for the Eastern District of Oklahoma dismissed the prevention of significant deterioration permit claim because it was filed after the statute of limitations expired, but the court allowed the opacity and particulate matter claims to proceed. 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.

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 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 Arkansas are 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 the Company's facilities, this could result in significant additional compliance costs that would affect the Company’s future financial position, results of operations and cash flows if such costs are not recovered through regulated rates.

38

In January 2014, the EPA published reproposed 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, and consistent with a 2010 settlement agreement, 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.

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

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 the Company conducts operations, or if additional species in those areas become subject to protection, the Company’s operations and development projects, particularly transmission, wind or pipeline projects, could be restricted or delayed, or the Company 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. The decision applies to a 5-state area including parts of Oklahoma where OG&E has undertaken the development of certain large transmission projects. On March 10, 2014, the Company enrolled in the Western Association of Fish and Wildlife Agencies’ Range-Wide Conservation Plan for the lesser prairie chicken. This Range-Wide Conservation Plan consists of industry-specific conservation practices that apply to projects and activities in the impacted area. The Range-Wide Conservation Plan has been approved by the U.S. Fish and Wildlife Service and incorporated as part of the agency’s final decision on March 27th to list the lesser prairie chicken as a threatened species. More than 32 companies have enrolled in the Range-Wide Conservation Plan.

Item 3.  Quantitative and Qualitative Disclosures About Market Risk.

There have been no significant changes in the market risks affecting the Company from those discussed in the Company's 2013 Form 10-K.

Item 4.  Controls and Procedures.

The Company maintains a set of disclosure controls and procedures designed to ensure that information required to be disclosed by the Company 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. The Company has an investment in an unconsolidated affiliate (see Note 3 of Notes to Condensed Consolidated Financial Statements). As the Company does not control this affiliate, its disclosure controls and procedures with respect to such affiliate is more limited than those the Company maintains with respect to its consolidated subsidiaries. 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 the Company's management, including the chief executive officer and chief financial officer, of the effectiveness of the Company'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 the Company's disclosure controls and procedures are effective.

No change in the Company's internal control over financial reporting has occurred during the Company's most recently completed fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Company'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).

39

PART II. OTHER INFORMATION

Item 1.  Legal Proceedings.

Reference is made to Item 3 of Part I of the Company's 2013Form 10-K for a description of certain legal proceedings presently pending. Except as described above under Item 2. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Environmental Laws and Regulations," there are no new significant cases to report against the Company or its subsidiaries and there have been no material changes in the previously reported proceedings.

Item 1A.  Risk Factors.

There have been no significant changes in the Company's risk factors from those discussed in the Company's 2013Form 10-K, which are incorporated herein by reference.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

The following table contains information about the Company's purchases of its common stock during the first quarter of 2014.

Period	Total Number of Shares Purchased		Average Price Paid Per Share		Total Number of Shares Purchased as Part of Publicly Announced Plan	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plan
1/1/14 - 1/31/14	—		$	—	N/A	N/A
2/1/14 - 2/28/14	1,411	(A)	$	35.13	N/A	N/A
3/1/14 - 3/31/14	—		$	—	N/A	N/A

(A) These shares of restricted stock were returned to the Company to satisfy tax liabilities.

Item 6.  Exhibits.

Exhibit No.	Description
4.01	Supplemental Indenture No. 14 dated as of March 15, 2014 between OG&E and UMB Bank, N.A., as trustee. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed March 25, 2014 (File No. 1-1097) and incorporated by reference herein).
10.01	Second Amended and Restated Limited Liability Company Agreement of Enable GP, LLC as amended as of April 16, 2014. (Filed as Exhibit 10.01 to OGE Energy's Form 8-K filed April 22, 2014 (File No. 1-12579) and incorporated by reference herein).
10.02	Second Amended and Restated Agreement of Limited Partnership of Enable Midstream Partners, LP dated April 16, 2014 (Filed as Exhibit 3.1 of Form 8-K Report of Enable Midstream Partners, LP (File No. 001-36413) and incorporated by reference herein).
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.
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.

40

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	OGE ENERGY CORP.
	(Registrant)
By:	/s/ Scott Forbes
	Scott Forbes
	Controller and Chief Accounting Officer
	(On behalf of the Registrant and in his capacity as Chief Accounting Officer)

May 1, 2014

41

EX-31.01

Exhibit 31.01

CERTIFICATIONS

I, Peter B. Delaney, certify that:

1. I have reviewed this quarterly report on Form 10-Q ofOGE Energy Corp.;

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: May 1, 2014

  /s/ Peter B. Delaney

       Peter B. Delaney

Chairman of the Board, President and Chief Executive Officer

Exhibit 31.01

CERTIFICATIONS

I, Sean Trauschke, certify that:

1. I have reviewed this quarterly report on Form 10-Q ofOGE Energy Corp.;

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: May 1, 2014

  /s/ Sean Trauschke

       Sean Trauschke

Chief Financial Officer

EX-31.02

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 Quarterly Report of the Company on Form 10-Q for the period endedMarch 31, 2014, 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.

May 1, 2014

          /s/ Peter B. Delaney

               Peter B. Delaney

Chairman of the Board, President and Chief Executive Officer

          /s/ Sean Trauschke

               Sean Trauschke

Chief Financial Officer

XML

Summary of Significant Accounting Policies Asset Retirement Obligation (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance at January 1	$ 55.2	$ 54.0
Liabilities settled	0	(0.1)
Accretion expense	0.6	0.6
Balance at March 31	$ 55.8	$ 54.5

XML

Common Equity Forward Stock Split (Details) In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Common Stock, Shares Authorized	450	225

XML

Fair Value Measurements, Fair Value Hierarchy (Details) (Fair Value, Measurements, Recurring [Member], USD $) In Millions, unless otherwise specified	Mar. 31, 2014
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

XML

Common Equity Automatic Dividend Reinvestment and Stock Purchase Plan (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Proceeds From Issuance of Shares Under Dividend Reinvestment Plan And Stock Purchase Plan	$ 3.4	$ 3.2
Automatic Dividend Reinvestment and Stock Purchase Plan [Member]
Stock Issued During Period, Shares, Dividend Reinvestment Plan and Stock Purchase Plan	98,476
Proceeds From Issuance of Shares Under Dividend Reinvestment Plan And Stock Purchase Plan	$ 3.4
Shares Held in Reserve Related to Dividend Reinvestment Plan and Stock Purchase Plan	3,747,027

XML

Investment in Unconsolidated Affiliates Summarized Income Statement of Equity Method Investment (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014
Summarized Income Statement of Equity Method Investment [Abstract]
Operating revenues	$ 1,001.6
Cost of sales	632.6
Operating income	161.9
Net income attributable to Enable	$ 149.2

XML

Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2014

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)
0.15%	-	0.18%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.08%	-	0.12%	Muskogee Industrial Authority, January 1, 2025	32.4
0.10%	-	0.10%	Muskogee Industrial Authority, June 1, 2027	56.0
Total (redeemable during next 12 months)				$	135.4

XML

Long-Term Debt (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014
Debt Instrument [Line Items]
Percent of Principal Amount Subject to Optional Tender	100.00%
Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Date Due	Jan. 01, 2025
Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Date Due	Jan. 01, 2025
Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Date Due	Jun. 01, 2027
Redeemable during the next 12 months
Debt Instrument [Line Items]
Long-term debt	$ 135.4
Redeemable during the next 12 months | Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Series Minimum	0.15%
Series Maximum	0.18%
Redeemable during the next 12 months | Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Series Minimum	0.08%
Series Maximum	0.12%
Redeemable during the next 12 months | Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Series Minimum	0.10%
Series Maximum	0.10%
OG&E [Member] | Redeemable during the next 12 months | Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Long term debt, gross	47.0
OG&E [Member] | Redeemable during the next 12 months | Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Long term debt, gross	32.4
OG&E [Member] | Redeemable during the next 12 months | Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Long term debt, gross	56.0
Senior Notes [Member] | OG&E [Member] | Series due May 1, 2043 [Member]
Debt Instrument [Line Items]
Long term debt, gross	$ 250.0
Debt Instrument, Interest Rate, Stated Percentage	4.55%
Date Due	Mar. 15, 2044

XML

Investment in Unconsolidated Affiliates (Tables)

3 Months Ended

Mar. 31, 2014

Related Party Transactions [Abstract]

Schedule of Related Party Transactions [Table Text Block]

Related Party Transactions with Enable

	Three Months Ended
	March 31,
(In millions)	2014
Operating Revenues:
Electricity to power electric compression assets	$	2.9
Cost of Sales:
Natural gas transportation services	$	8.7
Natural gas storage services	3.3
Natural gas purchases	5.0

XML

Derivative Instruments and Hedging Activities, Quantitative Disclosures Related to Derivative Instruments (Details) (Cash Flow Hedging [Member], USD $) In Millions, unless otherwise specified	Mar. 31, 2014
Cash Flow Hedging [Member]
Derivative [Line Items]
Cash Flow Hedges Derivative Instruments at Fair Value, Net	$ 0

XML

Summary of Significant Accounting Policies Forward Stock Split (Details) In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Class of Stock [Line Items]
Common Stock, Shares Authorized	450	225

XML

Summary of Significant Accounting Policies Equity Ownership (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended
	Jun. 30, 2014	Mar. 31, 2014
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		6.90%
OGE Energy [Member]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	26.70%	28.50%
Percent of Subordinated Limited Partner Units		61.40%
Percent of Incentive Distribution Rights		60.00%
Percentage Share of Management Rights		50.00%
OGE Holdings [Member]
Units Held by Limited Partners of the LLC or LP.		42,832,291
Subordinated Units Held by Limited Partners of the LLC or LP.		68,150,514
CenterPoint [Member]
Percent of Subordinated Limited Partner Units		61.40%
Percent of Incentive Distribution Rights		40.00%
Percentage Share of Management Rights		50.00%
Enable Midstream Partners [Member]
Partners' Capital Account, Units, Sold in Public Offering		28,750,000
Proceeds from Issuance Initial Public Offering		$ 466.0

XML

Stock-Based Compensation (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit	$ 1.0		$ 1.0
Stock-Based Compensation Activity
Maximum payout range	170.00%
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	3.7		2.6
Total Shareholder Return [Member]
Stock-Based Compensation Activity
Number of shares granted	207,880
Fair value of shares granted	$ 34.68
Equity Instruments Other than Options, Converted in Period	355,233	[1]
Performance Units Related to Earnings Per Share [Member]
Stock-Based Compensation Activity
Number of shares granted	69,295
Fair value of shares granted	$ 34.69
Equity Instruments Other than Options, Converted in Period	118,404	[1]
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	0.1		0.1
Stock-Based Compensation Activity
Number of shares granted	1,164
Fair value of shares granted	$ 35.56
Stock Compensation Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	3.8		2.7
Less: Amount paid by unconsolidated affiliates	1.2		0
Net compensation expense	2.6		2.7
Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures	495,185
Restricted Stock [Member]
Stock-Based Compensation Activity
Shares Paid for Tax Withholding for Share Based Compensation	1,411
Total Shareholder Return [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	2.0		2.0
Performance Units Related to Earnings Per Share [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 1.7		$ 0.6

[1] Performance units were converted based on a payout ratio of 170 percent of the target number of performance units granted in February 2011 and are included in the 495,185 shares of common stock issued during the three months ended March 31, 2014 as discussed above.

XML

Commitments and Contingencies (Details) (USD $)			3 Months Ended	7 Months Ended
	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014 OG&E minimum fuel purchase commitments [Member]	Oct. 31, 2014 OG&E minimum fuel purchase commitments [Member]
Long-term Purchase Commitment [Line Items]
Percentage of OG&E's Projected 2014 Requirements			31.50%	42.60%
Commitments and Contingencies
Estimated Environmental Capital Costs	1,000,000,000
Potential Penalty Under the Federal Clean Air Act	$ 37,500

XML

Investment in Unconsolidated Affiliates Reconciliation of Equity in Earnings of Unconsolidated Affiliates (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]
OGE's 28.5% share of Enable Net Income	$ 42.5
Amortization of basis difference	3.6
Elimination of Enogex Holdings fair value and other adjustments	1.8
Equity in earnings of unconsolidated affiliates	$ 47.9	$ 0

XML

Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2014

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Organization

The Company is 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. The Company conducts these activities through two business segments:  (i) electric utility and (ii) natural gas midstream operations. For a discussion of change in business segments, see Note 12. For periods prior to May 1, 2013, the Company consolidated Enogex Holdings in its Condensed Consolidated Financial Statements. All significant intercompany transactions have been eliminated in consolidation.

Effective May 1, 2013,OGE Energy, the ArcLight group and CenterPoint Energy, Inc., formed Enable Midstream Partners, L.P. to own and operate the midstream businesses of OGE Energy and CenterPoint. In the formation transaction, OGE Energy and ArcLight contributed Enogex LLC to Enable andthe Company deconsolidated its previously held investment in Enogex Holdings and acquired an equity interest in Enable.The Company determined that its contribution of Enogex LLC to Enable met the requirements of being in substance real estate and was recorded at historical cost.The general partner of Enable is equally controlled by CenterPoint and OGE Energy, who each have50 percentof the management rights.Based on the 50/50 management ownership, with neither company having control,effective May 1, 2013, OGE Energybegan accounting for its interest in Enable using the equity method of accounting. At March 31, 2014, OGE Energy, through its wholly owned subsidiary OGE Holdings, held28.5 percentof the limited partner interests in Enable.OGE Energy also owns a60 percentinterest in any incentive distribution rights in Enable. Incentive distribution rights entitle the holder to increasing percentages, up to a maximum of50 percent, of the cash distributed by Enable in excess of the target quarterly distributions established in connection with Enable’s initial public offering as described below.On April 16, 2014, Enable completed an initial public offering of28,750,000common units resulting in Enable becoming a publicly traded Master Limited Partnership. The offering represented approximately6.9 percentof the limited partner interests and raised approximately$466 millionin net proceeds for Enable. As a result of the offering, OGE Holding's ownership was reduced from28.5 percent to 26.7 percent.

In connection with Enable’s initial public offering, approximately61.4 percentof OGE Holdings and CenterPoint’s common units were converted into subordinated units. As a result, following the initial public offering, OGE Holdings owned42,832,291common units and68,150,514subordinated units of Enable. Holders of subordinated units are not entitled to receive any distribution of available cash until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. The subordinated units will convert into common units when Enable has paid at least the minimum quarterly distribution for three years or paid at least 150 percent of the minimum quarterly distribution for one year.

Enable is expected to pay a minimum quarterly distribution of $0.2875 per unit on its outstanding units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to its general partner and its affiliates, within 45 days after the end of each quarter. Enable will adjust the amount of this distribution for the period from April 16, 2014, the completion of its initial public offering, through June 30, 2014 based on the actual length of the period.If cash distributions to Enable’s unitholders exceed $0.330625 per unit in any quarter, the general partner will receive increasing percentages, up to50 percent, of the cash Enable distributes in excess of that amount. As indicated above, OGE Holdings is entitled to60 percentof those “incentive distributions.” In certain circumstances, the general partner, will have the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable’s cash distributions at the time of the exercise of this reset election.

The electric utility segmentgenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas.  Its operations areconducted through OG&E and aresubject 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.

The natural gas midstream operations segment consists of the Company's investment in Enable. Enable is engaged in the business of gathering, processing, transporting and storing natural gas. Enable's natural gas gathering and processing assets are strategically located in four states and serve natural gas production from shale developments in the Anadarko, Arkoma and Ark-La-Tex basins. Enable also owns an emerging crude oil gathering business in the Bakken shale formation that commenced initial operations in November 2013. Enable is continuing to construct additional crude oil gathering capacity in this area. Enable's natural gas transportation and storage assets extend from western Oklahoma and the Texas Panhandle to Alabama and from Louisiana to Illinois.

As discussed below, the Company completed a 2-for-1 stock split of the Company's common stock effective July 1, 2013. All share and per share amounts within this Form 10-Q reflect the effects of the stock split.

Basis of Presentation

The Condensed Consolidated Financial Statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations; however, the Company believes that the disclosures are adequate to prevent the information presented from being misleading.

In the opinion of management, all adjustments necessary to fairly present the consolidated financial position of the Company atMarch 31, 2014andDecember 31, 2013, the results of its operations for the threemonths endedMarch 31, 2014and2013and the results of its cash flows for thethreemonths endedMarch 31, 2014and2013, have been included and are of a normal recurring nature except as otherwise disclosed.

Due to seasonal fluctuations and other factors, the Company'soperating results for the threemonths endedMarch 31, 2014are not necessarily indicative of the results that may be expected for the year endingDecember 31, 2014or for any future period.The Condensed Consolidated Financial Statements and Notes thereto should be read in conjunction with the audited Consolidated Financial Statements and Notes thereto included in the Company's 2013Form 10-K.

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:

(In millions)	March 31, 2014		December 31, 2013
Regulatory Assets
Current
Fuel clause under recoveries	$	62.0	$	26.2
Oklahoma demand program rider under recovery (A)	8.8		10.6
Crossroads wind farm rider under recovery (A)	—		4.7
Other (A)	9.2		7.3
Total Current Regulatory Assets	$	80.0	$	48.8
Non-Current
Benefit obligations regulatory asset	$	224.8	$	227.4
Income taxes recoverable from customers, net	56.4		56.5
Smart Grid	44.1		44.2
Deferred storm expenses	21.5		21.6
Unamortized loss on reacquired debt	11.5		11.8
Pension tracker	—		1.4
Other	16.1		16.2
Total Non-Current Regulatory Assets	$	374.4	$	379.1
Regulatory Liabilities
Current
Smart Grid rider over recovery (B)	$	15.7	$	16.7
Fuel clause over recoveries	—		0.4
Other (B)	2.6		3.1
Total Current Regulatory Liabilities	$	18.3	$	20.2
Non-Current
Accrued removal obligations, net	$	230.8	$	227.7
Deferred pension credits	3.7		6.5
Pension tracker	3.1		—
Total Non-Current Regulatory Liabilities	$	237.6	$	234.2

(A) Included in Other Current Assets on theCondensed Consolidated Balance Sheets.

(B) Included in Other Current Liabilities on theCondensed Consolidated Balance Sheets.

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.If OG&E were 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.

Investment in Unconsolidated Affiliate

OGE Energy's investment in Enable is considered to be a variable interest entity because the owners of the equity at risk in this entity have disproportionate voting rights in relation to their obligations to absorb the entity's expected losses or to receive its expected residual returns. However, OGE Energy is not considered the primary beneficiary of Enable since it does not have the power to direct the activities of Enable that are considered most significant to the economic performance of Enable. As discussed above, OGE Energy accounts for the investment in Enable using the equity method of accounting. Under the equity method, the investment will be adjusted each period for contributions made, distributions received and the Company's share of the investee's comprehensive income. OGE Energy's maximum exposure to loss related to Enable is limited to OGE Energy's equity investment in Enable as presented on the Company's Condensed Consolidated Balance Sheet at March 31, 2014. The Company evaluates its equity method investment for impairment when events or changes in circumstances indicate there is a loss in value of the investment that is other than a temporary decline.

The Company considers distributions received from Enable which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment which are classified as operating activities in the Condensed Consolidated Statements of Cash Flows. The Company considers distributions received from Enable in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment which are classified as investing activities in the Condensed Consolidated Statements of Cash Flows.

Asset Retirement Obligation

The following table summarizes changes to the Company's asset retirement obligations during thethreemonths endedMarch 31, 2014and2013.

	Three Months Ended
	March 31,
(In millions)	2014		2013
Balance at January 1	$	55.2	$	54.0
Liabilities settled	—		(0.1		)
Accretion expense	0.6		0.6
Balance at March 31	$	55.8	$	54.5

Accumulated Other Comprehensive Income (Loss)

The following table summarizes changes in the components of accumulated other comprehensive loss attributable to OGE Energy during the threemonths endedMarch 31, 2014. All amounts below are presented net of tax and noncontrolling interest.

	Pension Plan and Restoration of Retirement Income Plan					Postretirement Benefit Plans
	Net loss			Prior service cost		Net loss			Prior service cost			Deferred interest rate swap hedging losses			Total
Balance at December 31, 2013	$	(27.4	)	$	0.1	$	(5.8	)	$	5.1		$	(0.2	)	$	(28.2	)
Amounts reclassified from accumulated other comprehensive income (loss)	0.4			—		0.2			(0.4		)	0.1			0.3
Net current period other comprehensive income (loss)	0.4			—		0.2			(0.4		)	0.1			0.3
Balance at March 31, 2014	$	(27.0	)	$	0.1	$	(5.6	)	$	4.7		$	(0.1	)	$	(27.9	)

The following table summarizes significant amounts reclassified out of accumulated other comprehensive loss by the respective line items in net income during the threemonths endedMarch 31, 2014.

Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)			Affected Line Item in the Statement Where Net Income is Presented
	Three Months Ended
	March 31, 2014
Losses on cash flow hedges
Interest rate swap	$	(0.2	)	Interest expense
	(0.2		)	Total before tax
	(0.1		)	Tax benefit
	$	(0.1	)	Net of tax
Amortization of defined benefit pension items
Actuarial losses	$	(0.7	)	(A)
	(0.7		)	Total before tax
	(0.3		)	Tax benefit
	$	(0.4	)	Net of tax
Amortization of postretirement benefit plan items
Actuarial losses	$	(0.3	)	(A)
Prior service credit	0.7			(A)
	0.4			Total before tax
	0.2			Tax expense
	$	0.2		Net of tax
Total reclassifications for the period	$	(0.3	)	Net of tax

(A) These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost (see Note 11 for additional information).

Forward Stock Split

On May 16, 2013, the Company's Board of Directors approved a 2-for-1 forward stock split of the Company's common stock, effective July 1, 2013, which entitled each shareholder of record to receive two shares for every one share of Company stock owned by the shareholder.  In connection with the stock split, an amendment to the Company's Articles of Incorporation was approved on May 16, 2013 which increased the number of authorized shares of common stock from225 millionto450 million. All share and per share amounts within this Form 10-Q reflect the effects of the stock split.

Reclassifications

Prior to May 1, 2013, the Company reported the results of Enogex Holdings in two separate segments: the natural gas transportation and storage segment, and the natural gas gathering and processing segment. After the deconsolidation, these segments were combined into the natural gas midstream operations segment.The presentation of results for the three months ended March 31, 2013 have been revised to reflect this change.Effective May 1, 2013,the Company deconsolidated its previously held investment in Enogex Holdings and acquired an equity interest in Enable.

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Rate Matters and Regulation Rate Matters and Regulation (Details) (Section 206 Complaint [Member], USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014
Section 206 Complaint [Member]
Reduction of Revenue	$ 1.0

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Investment in Unconsolidated Affiliates (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended
	Jun. 30, 2014	Mar. 31, 2014
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		6.90%
Enogex LLC [Member]
Percentage of Enogex LLC Contributed		100.00%
ArcLight group [Member]
Contributions to Pay Down Short-Term Debt		$ 107.0
OGE Holdings [Member]
Contributions to Pay Down Short-Term Debt		9.1
Units Held by Limited Partners of the LLC or LP.		42,832,291
OGE Energy [Member]
Percentage Share of Management Rights		50.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	26.70%	28.50%
Percent of Incentive Distribution Rights		60.00%
CenterPoint [Member]
Percentage Share of Management Rights		50.00%
Percent of Incentive Distribution Rights		40.00%
Enable Midstream Partners [Member]
Partners' Capital Account, Units, Sold in Public Offering		28,750,000
Proceeds from Issuance Initial Public Offering		466.0
Distributions from unconsolidated affiliates		$ 32.5

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2014

Fair Value Disclosures [Abstract]

Schedule of Fair Value and Carrying Amount of PRM Financial Instruments [Table Text Block]

The following table summarizes the fair value and carrying amount of the Company's financial instruments at March 31, 2014 and December 31, 2013.

	March 31, 2014				December 31, 2013
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-Term Debt
OG&E Senior Notes	$	2,403.8	$	2,728.0	$	2,154.5	$	2,405.0
OG&E Industrial Authority Bonds	135.4		135.4		135.4		135.4
OG&E Tinker Debt	10.3		9.2		10.3		9.1
OGE Energy Senior Notes	99.9		101.7		99.9		103.1

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Investment in Unconsolidated Affiliates Reconciliation of Equity in Earnings of Unconsolidated Affiliates (Tables)

3 Months Ended

Mar. 31, 2014

Reconciliation of Equity in Earnings of Unconsolidated Affiliates [Line Items]

Reconciliation of Equity in Earnings of Unconsolidated Affiliates [Table Text Block]

	Three Months Ended
Reconciliation of Equity in Earnings of Unconsolidated Affiliates	March 31, 2014
	(In millions)
OGE's 28.5% share of Enable Net Income	$	42.5
Amortization of basis difference	3.6
Elimination of Enogex Holdings fair value and other adjustments	1.8
OGE's Equity in earnings of unconsolidated affiliates	$	47.9

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Common Equity Earnings Per Share (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Equity [Abstract]
Net Income Attributable to OGE Energy	$ 49.3	$ 23.1
Basic average common shares outstanding	198.8	197.8
Contingently issuable shares (performance units)	0.7	1.0
Diluted average common shares outstanding	199.5	198.8
Earnings Per Share, Basic and Diluted [Abstract]
Basic Earnings Per Average Common Share Attributable to OGE Energy Common Shareholders	$ 0.25	$ 0.12
Diluted Earnings Per Average Common Share Attributable to OGE Energy Common Shareholders	$ 0.25	$ 0.12
Anti-dilutive shares excluded from earnings per share calculation	0	0

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Investment in Unconsolidated Affiliates Related Party Transactions (Details) (Enable Midstream Partners [Member], Og and E [Member], USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014
Related Party Transaction [Line Items]
Electricity to power electric compression assets	$ 2.9
Operating Costs Charged [Member]
Related Party Transaction [Line Items]
Operating expenses	6.0
Natural Gas Transportation [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	8.7
Natural Gas Storage [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	3.3
Natural Gas Purchases [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	$ 5.0

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Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]

Income Statement Presentation Related to Derivative Instruments

The following tables present the effect of derivative instruments on the Company's Condensed Consolidated Statement of Income for thethreemonths endedMarch 31, 2013.

Derivatives in Cash Flow Hedging Relationships

(In millions)	Amount Recognized in Other Comprehensive Income		Amount Reclassified from Accumulated Other Comprehensive Income (Loss) into Income			Amount Recognized in Income
Natural Gas Financial Futures/Swaps	$	—	$	0.2		$	—
Interest Rate Swap	—		(0.2		)	—
Total	$	—	$	—		$	—

Derivatives Not Designated as Hedging Instruments

(In millions)	Amount Recognized in Income
Natural Gas Financial Futures/Swaps	(0.3		)
Total	$	(0.3	)

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Stock-Based Compensation (Tables)

3 Months Ended

Mar. 31, 2014

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

Schedule of Compensation Cost for Share-based Payment Arrangements, Allocation of Share-based Compensation Costs by Plan [Table Text Block]

The following table summarizes the Company's pre-tax compensation expense and related income tax benefit during thethreemonths endedMarch 31, 2014 and 2013related to the Company's performance units and restricted stock.

	Three Months Ended
	March 31,
(In millions)	2014		2013
Performance units
Total shareholder return	$	2.0	$	2.0
Earnings per share	1.7		0.6
Total performance units	3.7		2.6
Restricted stock	0.1		0.1
Total compensation expense	3.8		2.7
Less: Amount paid by unconsolidated affiliates	1.2		—
Net compensation expense	$	2.6	$	2.7
Income tax benefit	$	1.0	$	1.0

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

The following table summarizes the activity of the Company's stock-based compensation during the three months ended March 31, 2014.

	Units/Shares	Fair Value
Grants
Performance units (Total shareholder return)	207,880	$	34.68
Performance units (Earnings per share)	69,295	$	34.69
Restricted stock	1,164	$	35.56
Conversions
Performance units (Total shareholder return) (A)	355,233	N/A
Performance units (Earnings per share) (A)	118,404	N/A

(A)Performance units were converted based on a payout ratio of 170 percent of the target number of performance units granted in February 2011 and are included in the 495,185 shares of common stock issued during the three months ended March 31, 2014 as discussed above.

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CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Unaudited) (USD $) In Millions, unless otherwise specified	Total	Common Stock	Premium on Common Stock	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interest	Treasury Stock
Balance at Dec. 31, 2012	$ 3,072.4	$ 1.0	$ 1,046.4	$ 1,772.4	$ (49.1)	$ 305.2	$ (3.5)
Changes in Stockholders' Equity
Net income	28.0	0	0	23.1	0	4.9	0
Other comprehensive income, net of tax	0.9	0	0	0	0.8	0.1	0
Dividends declared on common stock	(41.4)	0	0	(41.4)	0	0	0
Issuance of common stock	3.2	0	3.2	0	0	0	0
Stock-based compensation and other	(8.3)	0	(10.9)	0	0	(0.9)	3.5
Distributions to noncontrolling interest partners	(2.5)	0	0	0	0	(2.5)	0
Balance at Mar. 31, 2013	3,052.3	1.0	1,038.7	1,754.1	(48.3)	306.8	0
Balance at Dec. 31, 2013	3,037.1	2.0	1,071.6	1,991.7	(28.2)	0	0
Changes in Stockholders' Equity
Net income	49.3	0	0	49.3	0	0	0
Other comprehensive income, net of tax	0.3	0	0	0	0.3	0	0
Dividends declared on common stock	(44.9)	0	0	(44.9)	0	0	0
Issuance of common stock	3.4	0	3.4	0	0	0	0
Stock-based compensation and other	(7.4)	0	(7.4)	0	0	0	0
Distributions to noncontrolling interest partners	0
Balance at Mar. 31, 2014	$ 3,037.8	$ 2.0	$ 1,067.6	$ 1,996.1	$ (27.9)	$ 0	$ 0

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Common Equity (Tables)

3 Months Ended

Mar. 31, 2014

Equity [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

Basic and diluted earnings per share for the Company were calculated as follows:

	Three Months Ended
	March 31,
(In millions except per share data)	2014		2013
Net Income Attributable to OGE Energy	$	49.3	$	23.1
Average Common Shares Outstanding
Basic average common shares outstanding	198.8		197.8
Effect of dilutive securities:
Contingently issuable shares (performance units)	0.7		1.0
Diluted average common shares outstanding	199.5		198.8
Basic Earnings Per Average Common Share Attributable to OGE Energy Common Shareholders	$	0.25	$	0.12
Diluted Earnings Per Average Common Share Attributable to OGE Energy Common Shareholders	$	0.25	$	0.12
Anti-dilutive shares excluded from earnings per share calculation	—		—

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Summary of Significant Accounting Policies Accumulated Other Comprehensive Income (Loss) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (27.9)		$ (28.2)
Amounts reclassified from accumulated other comprehensive income (loss)	(0.4)	(0.9)
Amounts reclassified from accumulated other comprehensive income (loss)	(0.3)
Amounts reclassified from accumulated other comprehensive income (loss)	0.3
Net current period other comprehensive income (loss)	0.3
Interest Rate Swap [Member]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	(0.1)		(0.2)
Amounts reclassified from accumulated other comprehensive income (loss)	0.1
Net current period other comprehensive income (loss)	0.1
Pension Plans, Defined Benefit [Member] | Defined Benefit Plan Income Loss [Member]
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(27.0)		(27.4)
Amounts reclassified from accumulated other comprehensive income (loss)	0.4
Net current period other comprehensive income (loss)	0.4
Pension Plans, Defined Benefit [Member] | Defined Benefit Plan Prior Service Cost [Member]
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	0.1		0.1
Amounts reclassified from accumulated other comprehensive income (loss)	0
Net current period other comprehensive income (loss)	0
Other Postretirement Benefit Plans, Defined Benefit [Member] | Defined Benefit Plan Income Loss [Member]
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(5.6)		(5.8)
Amounts reclassified from accumulated other comprehensive income (loss)	0.2
Net current period other comprehensive income (loss)	0.2
Other Postretirement Benefit Plans, Defined Benefit [Member] | Defined Benefit Plan Prior Service Cost [Member]
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	4.7		5.1
Amounts reclassified from accumulated other comprehensive income (loss)	(0.4)
Net current period other comprehensive income (loss)	$ (0.4)

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Income Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2013
FIN 48 [Member]
Income Tax Reconciliation, Tax Contingencies, State and Local	$ 0.3
FIN 48 reserve, net of tax [Member]
Income Tax Reconciliation, Tax Contingencies, State and Local	$ 0.2

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CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
OPERATING REVENUES
Electric Utility	$ 560.4	$ 453.7
Natural Gas Midstream Operations (Note 1)	0	447.7
Total operating revenues	560.4	901.4
COST OF SALES
Electric Utility	293.4	201.1
Natural Gas Midstream Operations (Note 1)	0	351.9
Total cost of sales	293.4	553.0
OPERATING EXPENSES
Other operation and maintenance	112.4	148.0
Depreciation and amortization	67.2	91.9
Taxes other than income	25.6	33.1
Total operating expenses	205.2	273.0
OPERATING INCOME	61.8	75.4
OTHER INCOME (EXPENSE)
Equity in earnings of unconsolidated affiliates (Note 1)	47.9	0
Allowance for equity funds used during construction	1.1	1.2
Other income	1.4	14.7
Other expense	(3.3)	(6.5)
Net other income	47.1	9.4
INTEREST EXPENSE
Interest on long-term debt	35.1	39.7
Allowance for borrowed funds used during construction	(0.6)	(0.7)
Interest on short-term debt and other interest charges	1.4	2.2
Interest expense	35.9	41.2
INCOME BEFORE TAXES	73.0	43.6
INCOME TAX EXPENSE	23.7	15.6
NET INCOME	49.3	28.0
Less: Net income attributable to noncontrolling interests	0	4.9
NET INCOME ATTRIBUTABLE TO OGE ENERGY	$ 49.3	$ 23.1
BASIC AVERAGE COMMON SHARES OUTSTANDING	198.8	197.8
DILUTED AVERAGE COMMON SHARES OUTSTANDING	199.5	198.8
BASIC EARNINGS PER AVERAGE COMMON SHARE ATTRIBUTABLE TO OGE ENERGY COMMON SHAREHOLDERS	$ 0.25	$ 0.12
DILUTED EARNINGS PER AVERAGE COMMON SHARES ATTRIBUTABLE TO OGE ENERGY COMMON SHAREHOLDERS	$ 0.25	$ 0.12
DIVIDENDS DECLARED PER COMMON SHARE	$ 0.22500	$ 0.20875

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Investment in Unconsolidated Affiliates Summarized Balance Sheet Information of Equity Method Investment (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2014
Summarized Balance Sheet Information of Equity Method Investment [Abstract]
Current assets	$ 500.6
Non-current assets	10,757.6
Current liabilities	1,038.9
Non-current liabilities	$ 2,002.0

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $) In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
CURRENT ASSETS
Cash and cash equivalents	$ 2.4	$ 6.8
Accounts receivable, less reserve of $1.1 and $1.9, respectively	191.9	179.4
Accounts receivable - unconsolidated affiliates	10.3	12.4
Accrued unbilled revenues	51.7	58.7
Income taxes receivable	5.6	5.6
Fuel inventories	82.4	74.4
Materials and supplies, at average cost	76.7	80.7
Deferred income taxes	188.6	215.8
Fuel clause under recoveries	62.0	26.2
Other	30.9	34.6
Total current assets	702.5	694.6
OTHER PROPERTY AND INVESTMENTS
Investment in unconsolidated affiliates	1,314.2	1,298.8
Other	63.1	61.0
Total other property and investments	1,377.3	1,359.8
PROPERTY, PLANT AND EQUIPMENT
In service	9,302.9	9,183.1
Construction work in progress	470.3	468.5
Total property, plant and equipment	9,773.2	9,651.6
Less accumulated depreciation	3,010.9	2,978.8
Net property, plant and equipment	6,762.3	6,672.8
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	374.4	379.1
Other	34.2	28.4
Total deferred charges and other assets	408.6	407.5
TOTAL ASSETS	9,250.7	9,134.7
CURRENT LIABILITIES
Short-term debt	377.8	439.6
Accounts payable	209.6	251.0
Dividends payable	44.8	44.7
Customer deposits	71.4	70.9
Accrued taxes	26.0	39.9
Accrued interest	34.2	43.4
Accrued compensation	38.2	56.9
Long-term debt due within one year	100.0	100.0
Fuel clause over recoveries	0	0.4
Other	47.3	47.0
Total current liabilities	949.3	1,093.8
LONG-TERM DEBT	2,549.4	2,300.1
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	242.8	241.5
Deferred income taxes	2,119.8	2,125.3
Deferred investment tax credits	1.6	1.9
Regulatory liabilities	237.6	234.2
Other	112.4	100.8
Total deferred credits and other liabilities	2,714.2	2,703.7
Total liabilities	6,212.9	6,097.6
COMMITMENTS AND CONTINGENCIES (NOTE 13)
STOCKHOLDERS' EQUITY
Common stockholders' equity	1,069.6	1,073.6
Retained earnings	1,996.1	1,991.7
Accumulated other comprehensive loss, net of tax	(27.9)	(28.2)
Total stockholders' equity	3,037.8	3,037.1
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$ 9,250.7	$ 9,134.7

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Retirement Plans and Postretirement Benefit Plans (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Net periodic benefit cost (net of unconsolidated affiliates)	$ 2.4		$ 6.6
Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	4.3		5.0
Interest cost	7.0		6.6
Expected return on plan assets	(12.5)		(12.3)
Amortization of net loss	3.5		6.2
Amortization of unrecognized prior service cost	0.4	[1]	0.5	[1]
Total net periodic benefit cost	2.7		6.0
Less: Amount paid by unconsolidated affiliates	0.8		0
Net periodic benefit cost (net of unconsolidated affiliates)	1.9	[2]	6.0	[2]
Capitalized Portion of Net Periodic Benefit Cost	0.6		1.6
Restoration of Retirement Income Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0.3		0.3
Interest cost	0.2		0.1
Expected return on plan assets	0		0
Amortization of net loss	0		0.1
Amortization of unrecognized prior service cost	0	[1]	0.1	[1]
Total net periodic benefit cost	0.5		0.6
Less: Amount paid by unconsolidated affiliates	0		0
Net periodic benefit cost (net of unconsolidated affiliates)	0.5	[2]	0.6	[2]
Postretirement Benefit Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0.9		1.2
Interest cost	2.8		2.6
Expected return on plan assets	(0.6)		(0.6)
Amortization of net loss	3.1		5.3
Amortization of unrecognized prior service cost	(4.1)	[1]	(4.1)	[1]
Total net periodic benefit cost	2.1		4.4
Less: Amount paid by unconsolidated affiliates	0.3		0
Net periodic benefit cost (net of unconsolidated affiliates)	1.8	[3]	4.4	[3]
Capitalized Portion of Net Periodic Benefit Cost	0.5		1.3
OKLAHOMA | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Additional Pension Expense to Meet State Requirements	3.3		1.9
OKLAHOMA | Postretirement Benefit Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Additional Pension Expense to Meet State Requirements	$ 1.2		$ 0.1

[1] 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.

[2] In addition to the $2.4 million and $6.6 million of net periodic benefit cost recognized during the three months ended March 31, 2014 and 2013, respectively, OG&E recognized an increase in pension expense during the three months ended March 31, 2014 and 2013 of $3.3 million and $1.9 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 liability (see Note 1).

[3] In addition to the $1.8 million and $4.4 million of net periodic benefit cost recognized during the three months ended March 31, 2014 and 2013, respectively, OG&E recognized an increase in postretirement medical expense during the three months ended March 31, 2014 and 2013 of $1.2 million and $0.1 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 liability (see Note 1).

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Retirement Plans and Postretirement Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2014

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

The details of net periodic benefit cost of the Company's Pension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans included in the Condensed Consolidated Financial Statements are as follows:

Net Periodic Benefit Cost

	Pension Plan						Restoration of Retirement Income Plan
	Three Months Ended						Three Months Ended
	March 31,						March 31,
(In millions)	2014 (B)			2013 (B)			2014 (B)		2013 (B)
Service cost	$	4.3		$	5.0		$	0.3	$	0.3
Interest cost	7.0			6.6			0.2		0.1
Expected return on plan assets	(12.5		)	(12.3		)	—		—
Amortization of net loss	3.5			6.2			—		0.1
Amortization of unrecognized prior service cost (A)	0.4			0.5			—		0.1
Total net periodic benefit cost	2.7			6.0			0.5		0.6
Less: Amount paid by unconsolidated affiliates	0.8			—			—		—
Net periodic benefit cost (net of unconsolidated affiliates)	$	1.9		$	6.0		$	0.5	$	0.6

(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$2.4 millionand$6.6 millionof net periodic benefit cost recognizedduring thethreemonths endedMarch 31, 2014and2013, respectively, OG&E recognized an increase in pension expense during thethreemonths endedMarch 31, 2014and2013of$3.3 millionand$1.9 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 liability (see Note 1).

	Postretirement Benefit Plans
	Three Months Ended
	March 31,
(In millions)	2014 (B)			2013 (B)
Service cost	$	0.9		$	1.2
Interest cost	2.8			2.6
Expected return on plan assets	(0.6		)	(0.6		)
Amortization of net loss	3.1			5.3
Amortization of unrecognized prior service cost (A)	(4.1		)	(4.1		)
Total net periodic benefit cost	2.1			4.4
Less: Amount paid by unconsolidated affiliates	0.3			—
Net periodic benefit cost (net of unconsolidated affiliates)	$	1.8		$	4.4

(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$1.8 millionand$4.4 millionof net periodic benefit cost recognizedduring thethreemonths endedMarch 31, 2014and2013, respectively, OG&E recognized an increase in postretirement medical expense duringthethreemonths endedMarch 31, 2014and2013of$1.2 millionand$0.1 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 liability (see Note 1).

Schedule of Capitalized Pension and Postretirement Cost [Table Text Block]

	Three Months Ended
	March 31,
(In millions)	2014		2013
Capitalized portion of net periodic pension cost	$	0.6	$	1.6
Capitalized portion of net periodic postretirement benefit cost	0.5		1.3

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Rate Matters and Regulation

3 Months Ended

Mar. 31, 2014

Regulated Operations [Abstract]

Rate Matters and Regulation

Rate Matters and Regulation

Except as set forth below, the circumstances set forth in Note 16 to the Company's Consolidated Financial Statements included in the Company's 2013Form 10-K appropriately represent, in all material respects, the current status of the Company's regulatory matters.

Completed Regulatory Matters

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. On February 28, 2014, FERC issued a letter order accepting OG&E’s market-based rate filing and tariff effective March 1, 2014. FERC found that OG&E passed the market power screens and satisfied requirements related to horizontal market power and vertical market power.

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.  OG&E and Arkansas Electric Cooperative Corporation agreed to terms of a settlement and filed the offer of settlement with FERC on February 24, 2014. On April 17, 2014, OG&E received a FERC order accepting the settlement agreement and terminating the Arkansas Electric Cooperative Corporation complaint docket. OG&E believes the reduction in revenue will be approximately$1.0 millionper year for the term of the agreement, which ends June 30, 2015.

Pending Regulatory Matters

Fuel Adjustment Clause Review for Calendar Year 2012

The OCC routinely reviews the costs recovered from customers through OG&E's fuel adjustment clause. 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. On April 24, 2014, the OCC administrative law judge at the hearing, on the merits, recommended that the OCC find for the calendar year 2012 OG&E's electric generation, purchased power and fuel procurement processes and costs were prudent.

Energy Efficiency Program Filing

On February 14, 2014, 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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Report of Business Segments (Tables)

3 Months Ended

Mar. 31, 2014

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment [Table Text Block]

The following tables summarize the results of the Company's business segments during the threemonths endedMarch 31, 2014 and 2013.

Three Months Ended March 31, 2014	Electric Utility		Natural Gas Midstream Operations		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	560.4	$	—	$	—		$	—		$	560.4
Cost of sales	293.4		—		—			—			293.4
Other operation and maintenance	117.1		—		(4.7		)	—			112.4
Depreciation and amortization	64.3		—		2.9			—			67.2
Taxes other than income	23.8		—		1.8			—			25.6
Operating income (loss)	$	61.8	$	—	$	—		$	—		$	61.8
Equity in earnings of unconsolidated affiliates	$	—	$	47.9	$	—		$	—		$	47.9
Investment in unconsolidated affiliates (at historical cost)	$	—	$	1,314.2	$	—		$	—		$	1,314.2
Total assets	$	7,826.8	$	1,367.4	$	127.9		$	(71.4	)	$	9,250.7

Three Months Ended March 31, 2013	Electric Utility		Natural Gas Midstream Operations		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	455.5	$	464.3	$	—		$	(18.4	)	$	901.4
Cost of sales	213.0		359.2		—			(19.2		)	553.0
Other operation and maintenance	105.1		45.2		(2.3		)	—			148.0
Depreciation and amortization	61.3		27.6		3.0			—			91.9
Taxes other than income	23.2		8.0		1.9			—			33.1
Operating income (loss)	$	52.9	$	24.3	$	(2.6	)	$	0.8		$	75.4
Total assets	$	7,138.4	$	2,729.9	$	381.6		$	(268.1	)	$	9,981.8

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2014

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:

(In millions)	March 31, 2014		December 31, 2013
Regulatory Assets
Current
Fuel clause under recoveries	$	62.0	$	26.2
Oklahoma demand program rider under recovery (A)	8.8		10.6
Crossroads wind farm rider under recovery (A)	—		4.7
Other (A)	9.2		7.3
Total Current Regulatory Assets	$	80.0	$	48.8
Non-Current
Benefit obligations regulatory asset	$	224.8	$	227.4
Income taxes recoverable from customers, net	56.4		56.5
Smart Grid	44.1		44.2
Deferred storm expenses	21.5		21.6
Unamortized loss on reacquired debt	11.5		11.8
Pension tracker	—		1.4
Other	16.1		16.2
Total Non-Current Regulatory Assets	$	374.4	$	379.1
Regulatory Liabilities
Current
Smart Grid rider over recovery (B)	$	15.7	$	16.7
Fuel clause over recoveries	—		0.4
Other (B)	2.6		3.1
Total Current Regulatory Liabilities	$	18.3	$	20.2
Non-Current
Accrued removal obligations, net	$	230.8	$	227.7
Deferred pension credits	3.7		6.5
Pension tracker	3.1		—
Total Non-Current Regulatory Liabilities	$	237.6	$	234.2

(A) Included in Other Current Assets on theCondensed Consolidated Balance Sheets.

(B) Included in Other Current Liabilities on theCondensed Consolidated Balance Sheets.

Schedule of Change in Asset Retirement Obligation [Table Text Block]

The following table summarizes changes to the Company's asset retirement obligations during thethreemonths endedMarch 31, 2014and2013.

	Three Months Ended
	March 31,
(In millions)	2014		2013
Balance at January 1	$	55.2	$	54.0
Liabilities settled	—		(0.1		)
Accretion expense	0.6		0.6
Balance at March 31	$	55.8	$	54.5

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

The following table summarizes changes in the components of accumulated other comprehensive loss attributable to OGE Energy during the threemonths endedMarch 31, 2014. All amounts below are presented net of tax and noncontrolling interest.

	Pension Plan and Restoration of Retirement Income Plan					Postretirement Benefit Plans
	Net loss			Prior service cost		Net loss			Prior service cost			Deferred interest rate swap hedging losses			Total
Balance at December 31, 2013	$	(27.4	)	$	0.1	$	(5.8	)	$	5.1		$	(0.2	)	$	(28.2	)
Amounts reclassified from accumulated other comprehensive income (loss)	0.4			—		0.2			(0.4		)	0.1			0.3
Net current period other comprehensive income (loss)	0.4			—		0.2			(0.4		)	0.1			0.3
Balance at March 31, 2014	$	(27.0	)	$	0.1	$	(5.6	)	$	4.7		$	(0.1	)	$	(27.9	)

Schedule of Amounts Reclassified out of Accumulated Other Comprehensive Income [Table Text Block]

The following table summarizes significant amounts reclassified out of accumulated other comprehensive loss by the respective line items in net income during the threemonths endedMarch 31, 2014.

Details about Accumulated Other Comprehensive Loss Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)			Affected Line Item in the Statement Where Net Income is Presented
	Three Months Ended
	March 31, 2014
Losses on cash flow hedges
Interest rate swap	$	(0.2	)	Interest expense
	(0.2		)	Total before tax
	(0.1		)	Tax benefit
	$	(0.1	)	Net of tax
Amortization of defined benefit pension items
Actuarial losses	$	(0.7	)	(A)
	(0.7		)	Total before tax
	(0.3		)	Tax benefit
	$	(0.4	)	Net of tax
Amortization of postretirement benefit plan items
Actuarial losses	$	(0.3	)	(A)
Prior service credit	0.7			(A)
	0.4			Total before tax
	0.2			Tax expense
	$	0.2		Net of tax
Total reclassifications for the period	$	(0.3	)	Net of tax

(A) These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost (see Note 11 for additional information).

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) Parenthetical (USD $) In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Allowance for Doubtful Accounts Receivable	$ 1.1	$ 1.9

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Net income	$ 49.3	$ 28.0
Pension Plan and Restoration of Retirement Income Plan:
Amortization of deferred net loss, net of tax of $0.3 and $0.4, respectively	0.4	0.9
Postretirement Benefit Plans:
Amortization of deferred net loss, net of tax of $0.1 and $0.3, respectively	0.2	0.5
Amortization of prior service cost, net of tax of ($0.3) and ($0.3), respectively	(0.4)	(0.5)
Deferred commodity contracts hedging (gains) losses reclassified in net income, net of tax of $0.0 and ($0.1), respectively	0	(0.1)
Amortization of deferred interest rate swap hedging losses, net of tax of $0.1 and $0.1, respectively	0.1	0.1
Other comprehensive income, net of tax	0.3	0.9
Comprehensive income	49.6	28.9
Less: Comprehensive income attributable to noncontrolling interests	0	5.0
Total comprehensive income attributable to OGE Energy	$ 49.6	$ 23.9

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Long-Term Debt

3 Months Ended

Mar. 31, 2014

Long-term Debt, Unclassified [Abstract]

Long-Term Debt

Long-Term Debt

AtMarch 31, 2014, the Company was in compliance with all of its debt agreements.

OG&E 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)
0.15%	-	0.18%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.08%	-	0.12%	Muskogee Industrial Authority, January 1, 2025	32.4
0.10%	-	0.10%	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 the Company's Condensed Consolidated Financial Statements. OG&E believes that it has sufficient liquidity to meet these obligations.

Issuance of Long-Term Debt

On March 25, 2014, OG&E completed the issuance of$250 millionof4.55%senior notes dueMarch 15, 2044. The proceeds from the issuance were added to OG&E's general funds and were used to repay short-term debt, fund capital expenditures and general corporate expenses, and utilized 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.

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Document and Entity Information Document	3 Months Ended
	Mar. 31, 2014
Document Information [Line Items]
Entity Registrant Name	OGE ENERGY CORP.
Entity Central Index Key	0001021635
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Mar. 31, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding	199,138,921

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Short-Term Debt and Credit Facilities

3 Months Ended

Mar. 31, 2014

Short-term Debt [Abstract]

Short-Term Debt and Credit Facilities

Short-Term Debt and CreditFacilities

The Company borrows on a short-term basis, as necessary, by the issuance of commercial paper and by borrowings under its revolving credit agreements.The short-term debt balance was$377.8 millionand$439.6 millionatMarch 31, 2014 and December 31, 2013, respectively. The following table provides information regarding the Company's revolving credit agreements at March 31, 2014.

	Aggregate		Amount		Weighted-Average
Entity	Commitment		Outstanding (A)		Interest Rate			Maturity
	(In millions)
OGE Energy (B)	$	750.0	$	377.8	0.28	%	(D)	December 13, 2017
OG&E (C)	400.0		2.0		0.47	%	(D)	December 13, 2017
Total	$	1,150.0	$	379.8	0.28	%

(A) Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at March 31, 2014.

(B) This bank facility is available to back up OGE Energy's commercial paper borrowings and to provide revolving credit borrowings.  This bank facility can also be used as a letter of credit facility.  

(C) This bank facility 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.

(D) Represents the weighted-average interest rate for the outstanding borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit.

The Company's ability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions.Pricing grids associated with the Company's credit facilities could cause annual fees and borrowing rates to increase if an adverse ratings impact occurs. The impact of any future downgrade could include an increase in the costs of the Company's short-term borrowings, but a reduction in the Company's credit ratings would not result in any defaults or accelerations.Any future downgradecould also lead to higher long-term borrowing costs and, if below investment grade, would require the Company to post cash 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.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) Parenthetical (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Pension Plan and Restoration of Retirement Income Plan:
Amortization of deferred net loss	$ 0.3	$ 0.4
Postretirement Benefit Plans:
Amortization of deferred net loss	0.1	0.3
Amortization of prior service cost	(0.3)	(0.3)
Deferred commodity contracts hedging gains reclassified in net income	0	(0.1)
Amortization of deferred interest rate swap hedging losses	$ 0.1	$ 0.1

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Fair Value Measurements

3 Months Ended

Mar. 31, 2014

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

The classification of the Company's fair value measurements requires judgment regarding the degree to which market data is observable or corroborated by observable market data. GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to quoted prices in active markets for identical unrestricted assets or liabilities (Level 1) and the lowest priority given to unobservable inputs (Level 3).  Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.  The three levels defined in the fair value hierarchy are as follows:

Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessible at the measurement date.

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.

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 the reporting entity's own assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk).

The Company had nofinancial instruments measured at fair value on a recurring basis atMarch 31, 2014.

The following table summarizes the fair value and carrying amount of the Company's financial instruments at March 31, 2014 and December 31, 2013.

	March 31, 2014				December 31, 2013
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-Term Debt
OG&E Senior Notes	$	2,403.8	$	2,728.0	$	2,154.5	$	2,405.0
OG&E Industrial Authority Bonds	135.4		135.4		135.4		135.4
OG&E Tinker Debt	10.3		9.2		10.3		9.1
OGE Energy Senior Notes	99.9		101.7		99.9		103.1

The Company's long-term debt is valued at the carrying amount.The fair value of the Company's long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturities and is classified as Level 2 in the fair value hierarchy except for the Tinker Debt which fair value was based on calculating the net present value of the monthly payments discounted by the Company's current borrowing rate and is classified as Level 3 in the fair value hierarchy.

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Investment in Unconsolidated Affiliates

3 Months Ended

Mar. 31, 2014

OGE Energy Midstream Partnership with CenterPoint Energy Inc. [Abstract]

Equity Method Investments and Joint Ventures Disclosure [Text Block]

Investment in Unconsolidated Affiliate and Related Party Transactions

On March 14, 2013, OGE Energy entered into a Master Formation Agreement with the ArcLight group and CenterPoint Energy, Inc., pursuant to which OGE Energy, the ArcLight Group and CenterPoint Energy, Inc., agreed to form Enable to own and operate the midstream businesses of OGE Energy and CenterPoint that was initially structured as a private limited partnership. This transaction closed on May 1, 2013.

Pursuant to the Master Formation Agreement, OGE Energy and the ArcLight group indirectly contributed100 percentof the equity interests inEnogex LLCto Enable. The Company determined that its contribution of Enogex LLC to Enable met the requirements of being in substance real estate and was recorded at historical cost. Immediately prior to closing, on May 1, 2013, the ArcLight group contributed $107.0 million and OGE Energy contributed $9.1 million to Enogex LLC in order to pay down short-term debt. At March 31, 2014, OGE Energy, through its wholly owned subsidiary OGE Holdings, held28.5 percentof the limited partner interests in Enable.

The general partner of Enable is equally controlled by CenterPoint and OGE Energy, who each have50 percentof the management rights. CenterPoint and OGE Energy also own a 40 percent and 60 percent interest, respectively, in any incentive distribution rights to be held by the general partner of Enable following the initial public offering of Enable on April 16, 2014 as described below. Based on the 50/50 management ownership, with neither company having control,effective May 1, 2013, OGE Energydeconsolidated its interest in Enogex Holdings LLC andbegan accounting for its interest in Enable using the equity method of accounting.

Pursuant to a Registration Rights Agreement dated as of May 1, 2013, OGE Energy and CenterPoint Energy, Inc. agreed to initiate the process for the sale of an equity interest in Enable in an initial public offering. On April 16, 2014, Enable completed an initial public offering of28,750,000common units resulting in Enable becoming a publicly traded Master Limited Partnership. The offering represented approximately6.9 percentof the limited partner interests and raised approximately$466 millionin net proceeds for Enable. As a result of the offering, OGE Holding's ownership was reduced from28.5 percent to 26.7 percent.

On May 1, 2013, OGE Energy, OGE Holdings and Enable entered into a Seconding Agreement. During the term of the Seconding Agreement, OGE Holdings' employees will continue to perform services for Enable and its subsidiaries.

Distributions received from Enable were $32.5 million during the three months ended March 31, 2014.

Related Party Transactions

OGE Energy charged operating costs to Enable of $6.0 millionduring thethreemonths endedMarch 31, 2014. OGE Energy charges operating costs to OG&E and Enable based on several factors. Operating costs directly related to OG&E and or Enable are assigned as such.  Operating costs incurred for the benefit of OG&E and Enable are allocated 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.

Related Party Transactions with Enable

	Three Months Ended
	March 31,
(In millions)	2014
Operating Revenues:
Electricity to power electric compression assets	$	2.9
Cost of Sales:
Natural gas transportation services	$	8.7
Natural gas storage services	3.3
Natural gas purchases	5.0

Summarized Financial Information of Enable

Summarized unaudited financial information for 100 percent of Enable is presented below at March 31, 2014 and for the three months endedMarch 31, 2014.

Balance Sheet	March 31, 2014
	(In millions)
Current assets	$	500.6
Non-current assets	10,757.6
Current liabilities	1,038.9
Non-current liabilities	2,002.0

	Three Months Ended
Income Statement	March 31, 2014
	(In millions)
Operating revenues	$	1,001.6
Cost of sales	632.6
Operating income	161.9
Net income attributable to Enable	149.2

Enable concluded that the formation of Enable was considered a business combination, and CenterPoint Midstream was the acquirer of Enogex Holdings for accounting purposes.  Under this method, the fair value of the consideration paid by CenterPoint Midstream for Enogex Holdings is allocated to the assets acquired and liabilities assumed on May 1, 2013 based on their fair value.  Enogex Holdings' assets, liabilities and equity were accordingly adjusted to estimated fair value, resulting in an increase to equity of $2.2 billion. Due to the Company's determination that its contribution of Enogex LLC to Enable met the requirements of being in substance real estate and thus recording the initial investment at historical cost, the effects of the amortization and depreciation expense associated with the fair value adjustments on Enable's results of operations have been eliminated in the Company's recording of its equity in earnings of Enable.

OGE Energy recorded equity in earnings of unconsolidated affiliates of $47.9 million for the three months ended March 31, 2014. Equity in earnings of unconsolidated affiliates includes OGE Energy's28.5 percentshare of Enable earnings adjusted for the amortization of the basis difference of OGE Energy's original investment in Enogex and its underlying equity in net assets of Enable, based on historical cost as of May 1, 2013. The basis difference is being amortized over approximately 30 years, the average life of the assets to which the basis difference is attributed. Equity in earnings of unconsolidated affiliates is also adjusted for the elimination of the Enogex Holdings fair value adjustments as described above.

	Three Months Ended
Reconciliation of Equity in Earnings of Unconsolidated Affiliates	March 31, 2014
	(In millions)
OGE's 28.5% share of Enable Net Income	$	42.5
Amortization of basis difference	3.6
Elimination of Enogex Holdings fair value and other adjustments	1.8
OGE's Equity in earnings of unconsolidated affiliates	$	47.9

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2014

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Consolidation, Policy [Policy Text Block]

Organization

The Company is 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. The Company conducts these activities through two business segments:  (i) electric utility and (ii) natural gas midstream operations. For a discussion of change in business segments, see Note 12. For periods prior to May 1, 2013, the Company consolidated Enogex Holdings in its Condensed Consolidated Financial Statements. All significant intercompany transactions have been eliminated in consolidation.

Effective May 1, 2013,OGE Energy, the ArcLight group and CenterPoint Energy, Inc., formed Enable Midstream Partners, L.P. to own and operate the midstream businesses of OGE Energy and CenterPoint. In the formation transaction, OGE Energy and ArcLight contributed Enogex LLC to Enable andthe Company deconsolidated its previously held investment in Enogex Holdings and acquired an equity interest in Enable.The Company determined that its contribution of Enogex LLC to Enable met the requirements of being in substance real estate and was recorded at historical cost.The general partner of Enable is equally controlled by CenterPoint and OGE Energy, who each have50 percentof the management rights.Based on the 50/50 management ownership, with neither company having control,effective May 1, 2013, OGE Energybegan accounting for its interest in Enable using the equity method of accounting. At March 31, 2014, OGE Energy, through its wholly owned subsidiary OGE Holdings, held28.5 percentof the limited partner interests in Enable.OGE Energy also owns a60 percentinterest in any incentive distribution rights in Enable. Incentive distribution rights entitle the holder to increasing percentages, up to a maximum of50 percent, of the cash distributed by Enable in excess of the target quarterly distributions established in connection with Enable’s initial public offering as described below.On April 16, 2014, Enable completed an initial public offering of28,750,000common units resulting in Enable becoming a publicly traded Master Limited Partnership. The offering represented approximately6.9 percentof the limited partner interests and raised approximately$466 millionin net proceeds for Enable. As a result of the offering, OGE Holding's ownership was reduced from28.5 percent to 26.7 percent.

In connection with Enable’s initial public offering, approximately61.4 percentof OGE Holdings and CenterPoint’s common units were converted into subordinated units. As a result, following the initial public offering, OGE Holdings owned42,832,291common units and68,150,514subordinated units of Enable. Holders of subordinated units are not entitled to receive any distribution of available cash until the common units have received the minimum quarterly distribution plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. The subordinated units will convert into common units when Enable has paid at least the minimum quarterly distribution for three years or paid at least 150 percent of the minimum quarterly distribution for one year.

Enable is expected to pay a minimum quarterly distribution of $0.2875 per unit on its outstanding units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to its general partner and its affiliates, within 45 days after the end of each quarter. Enable will adjust the amount of this distribution for the period from April 16, 2014, the completion of its initial public offering, through June 30, 2014 based on the actual length of the period.If cash distributions to Enable’s unitholders exceed $0.330625 per unit in any quarter, the general partner will receive increasing percentages, up to50 percent, of the cash Enable distributes in excess of that amount. As indicated above, OGE Holdings is entitled to60 percentof those “incentive distributions.” In certain circumstances, the general partner, will have the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable’s cash distributions at the time of the exercise of this reset election.

The electric utility segmentgenerates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas.  Its operations areconducted through OG&E and aresubject 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.

The natural gas midstream operations segment consists of the Company's investment in Enable. Enable is engaged in the business of gathering, processing, transporting and storing natural gas. Enable's natural gas gathering and processing assets are strategically located in four states and serve natural gas production from shale developments in the Anadarko, Arkoma and Ark-La-Tex basins. Enable also owns an emerging crude oil gathering business in the Bakken shale formation that commenced initial operations in November 2013. Enable is continuing to construct additional crude oil gathering capacity in this area. Enable's natural gas transportation and storage assets extend from western Oklahoma and the Texas Panhandle to Alabama and from Louisiana to Illinois.

As discussed below, the Company completed a 2-for-1 stock split of the Company's common stock effective July 1, 2013. All share and per share amounts within this Form 10-Q reflect the effects of the stock split.

Basis of Accounting [Text Block]

Basis of Presentation

The Condensed Consolidated Financial Statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations; however, the Company believes that the disclosures are adequate to prevent the information presented from being misleading.

In the opinion of management, all adjustments necessary to fairly present the consolidated financial position of the Company atMarch 31, 2014andDecember 31, 2013, the results of its operations for the threemonths endedMarch 31, 2014and2013and the results of its cash flows for thethreemonths endedMarch 31, 2014and2013, have been included and are of a normal recurring nature except as otherwise disclosed.

Due to seasonal fluctuations and other factors, the Company'soperating results for the threemonths endedMarch 31, 2014are not necessarily indicative of the results that may be expected for the year endingDecember 31, 2014or for any future period.The Condensed Consolidated Financial Statements and Notes thereto should be read in conjunction with the audited Consolidated Financial Statements and Notes thereto included in the Company's 2013Form 10-K.

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.If OG&E were 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.

Equity Method Investments, Policy [Policy Text Block]

Based on the 50/50 management ownership, with neither company having control,effective May 1, 2013, OGE Energybegan accounting for its interest in Enable using the equity method of accounting.

Investment in Unconsolidated Affiliate

OGE Energy's investment in Enable is considered to be a variable interest entity because the owners of the equity at risk in this entity have disproportionate voting rights in relation to their obligations to absorb the entity's expected losses or to receive its expected residual returns. However, OGE Energy is not considered the primary beneficiary of Enable since it does not have the power to direct the activities of Enable that are considered most significant to the economic performance of Enable. As discussed above, OGE Energy accounts for the investment in Enable using the equity method of accounting. Under the equity method, the investment will be adjusted each period for contributions made, distributions received and the Company's share of the investee's comprehensive income. OGE Energy's maximum exposure to loss related to Enable is limited to OGE Energy's equity investment in Enable as presented on the Company's Condensed Consolidated Balance Sheet at March 31, 2014. The Company evaluates its equity method investment for impairment when events or changes in circumstances indicate there is a loss in value of the investment that is other than a temporary decline.

The Company considers distributions received from Enable which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment which are classified as operating activities in the Condensed Consolidated Statements of Cash Flows. The Company considers distributions received from Enable in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment which are classified as investing activities in the Condensed Consolidated Statements of Cash Flows.

Fair Value of Financial Instruments, Policy [Policy Text Block]

The classification of the Company's fair value measurements requires judgment regarding the degree to which market data is observable or corroborated by observable market data. GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to quoted prices in active markets for identical unrestricted assets or liabilities (Level 1) and the lowest priority given to unobservable inputs (Level 3).  Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.  The three levels defined in the fair value hierarchy are as follows:

Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessible at the measurement date.

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.

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 the reporting entity's own assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk).

The Company's long-term debt is valued at the carrying amount.The fair value of the Company's long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturities and is classified as Level 2 in the fair value hierarchy except for the Tinker Debt which fair value was based on calculating the net present value of the monthly payments discounted by the Company's current borrowing rate and is classified as Level 3 in the fair value hierarchy.

Derivatives, Policy [Policy Text Block]

Cash Flow Hedges

For derivatives that are designated and qualify as a cash flow hedge, the effective portion of the change in fair value of the derivative instrument is reported as a component of Accumulated Other Comprehensive Income (Loss) and recognized into earnings in the same period during which the hedged transaction affects earnings.  The ineffective portion of a derivative's change in fair value or hedge components excluded from the assessment of effectiveness is recognized currently in earnings. The Company measures the ineffectiveness of commodity cash flow hedges using the change in fair value method whereby the change in the expected future cash flows designated as the hedge transaction are compared to the change in fair value of the hedging instrument.  Forecasted transactions, which are designated as the hedged transaction in a cash flow hedge, are regularly evaluated to assess whether they continue to be probable of occurring.  If the forecasted transactions are no longer probable of occurring, hedge accounting will cease on a prospective basis and all future changes in the fair value of the derivative will be recognized directly in earnings.

The Company previously designated as cash flow hedges derivatives for OGE Holdings' NGLs volumes and corresponding keep-whole natural gas resulting from its natural gas processing contracts (processing hedges) and natural gas positions resulting from its natural gas gathering and processing operations and natural gas transportation and storage operations (operational gas hedges).  The Company also previously designated as cash flow hedges certain derivatives for certain natural gas storage inventory positions. Due to the deconsolidation of Enogex LLC effective May 1, 2013, the Company had no material instruments designated as cash flow hedges at March 31, 2014.

Income Tax, Policy [Policy Text Block]

Income taxes are generally 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.

The Company files consolidated income tax returns in the U.S. Federal jurisdiction and various state jurisdictions.

Earnings Per Share, Policy [Policy Text Block]

Earnings Per Share

Basic earnings per share is calculated by dividing net income attributable to OGE Energy by the weighted average number of the Company's common shares outstanding during the period. In the calculation of diluted earnings per share, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock. Potentially dilutive securities for the Company consist of performance units.

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Retirement Plans and Postretirement Benefit Plans

3 Months Ended

Mar. 31, 2014

Retirement Plans and Postretirement Benefit Plans [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

Retirement Plans and Postretirement Benefit Plans

The details of net periodic benefit cost of the Company's Pension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans included in the Condensed Consolidated Financial Statements are as follows:

Net Periodic Benefit Cost

	Pension Plan						Restoration of Retirement Income Plan
	Three Months Ended						Three Months Ended
	March 31,						March 31,
(In millions)	2014 (B)			2013 (B)			2014 (B)		2013 (B)
Service cost	$	4.3		$	5.0		$	0.3	$	0.3
Interest cost	7.0			6.6			0.2		0.1
Expected return on plan assets	(12.5		)	(12.3		)	—		—
Amortization of net loss	3.5			6.2			—		0.1
Amortization of unrecognized prior service cost (A)	0.4			0.5			—		0.1
Total net periodic benefit cost	2.7			6.0			0.5		0.6
Less: Amount paid by unconsolidated affiliates	0.8			—			—		—
Net periodic benefit cost (net of unconsolidated affiliates)	$	1.9		$	6.0		$	0.5	$	0.6

(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$2.4 millionand$6.6 millionof net periodic benefit cost recognizedduring thethreemonths endedMarch 31, 2014and2013, respectively, OG&E recognized an increase in pension expense during thethreemonths endedMarch 31, 2014and2013of$3.3 millionand$1.9 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 liability (see Note 1).

	Postretirement Benefit Plans
	Three Months Ended
	March 31,
(In millions)	2014 (B)			2013 (B)
Service cost	$	0.9		$	1.2
Interest cost	2.8			2.6
Expected return on plan assets	(0.6		)	(0.6		)
Amortization of net loss	3.1			5.3
Amortization of unrecognized prior service cost (A)	(4.1		)	(4.1		)
Total net periodic benefit cost	2.1			4.4
Less: Amount paid by unconsolidated affiliates	0.3			—
Net periodic benefit cost (net of unconsolidated affiliates)	$	1.8		$	4.4

(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$1.8 millionand$4.4 millionof net periodic benefit cost recognizedduring thethreemonths endedMarch 31, 2014and2013, respectively, OG&E recognized an increase in postretirement medical expense duringthethreemonths endedMarch 31, 2014and2013of$1.2 millionand$0.1 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 liability (see Note 1).

	Three Months Ended
	March 31,
(In millions)	2014		2013
Capitalized portion of net periodic pension cost	$	0.6	$	1.6
Capitalized portion of net periodic postretirement benefit cost	0.5		1.3

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Income Taxes

3 Months Ended

Mar. 31, 2014

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

The Company files consolidated income tax returns in the U.S. Federal jurisdiction and various state jurisdictions.With few exceptions, the Company 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 taxes are generally 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 continues to amortize its Federal investment tax credits on a ratable basis throughout the year.  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 in electric generating facilities which further reduce the Company's effective tax rate.

As previously reported in the Company's 2013 Form 10-K, 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 2014, OG&E recorded an additional reserve for this item of$0.3 million ($0.2 millionafter the federal tax benefit) related to the same Oklahoma investment tax credits generated in the current year 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.

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Report of Business Segments (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Segment Reporting Information [Line Items]
Operating revenues	$ 560.4	$ 901.4
Cost of sales	293.4	553.0
Other operation and maintenance	112.4	148.0
Depreciation and amortization	67.2	91.9
Taxes other than income	25.6	33.1
Operating income (loss)	61.8	75.4
Equity in earnings of unconsolidated affiliates	47.9	0
Investment in unconsolidated affiliates	1,314.2		1,298.8
Total assets	9,250.7	9,981.8	9,134.7
Electric Utility [Member]
Segment Reporting Information [Line Items]
Operating revenues	560.4	455.5
Cost of sales	293.4	213.0
Other operation and maintenance	117.1	105.1
Depreciation and amortization	64.3	61.3
Taxes other than income	23.8	23.2
Operating income (loss)	61.8	52.9
Equity in earnings of unconsolidated affiliates	0
Investment in unconsolidated affiliates	0
Total assets	7,826.8	7,138.4
Natural Gas Midstream Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	464.3
Cost of sales	0	359.2
Other operation and maintenance	0	45.2
Depreciation and amortization	0	27.6
Taxes other than income	0	8.0
Operating income (loss)	0	24.3
Equity in earnings of unconsolidated affiliates	47.9
Investment in unconsolidated affiliates	1,314.2
Total assets	1,367.4	2,729.9
Other Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0
Cost of sales	0	0
Other operation and maintenance	(4.7)	(2.3)
Depreciation and amortization	2.9	3.0
Taxes other than income	1.8	1.9
Operating income (loss)	0	(2.6)
Equity in earnings of unconsolidated affiliates	0
Investment in unconsolidated affiliates	0
Total assets	127.9	381.6
Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	(18.4)
Cost of sales	0	(19.2)
Other operation and maintenance	0	0
Depreciation and amortization	0	0
Taxes other than income	0	0
Operating income (loss)	0	0.8
Equity in earnings of unconsolidated affiliates	0
Investment in unconsolidated affiliates	0
Total assets	$ (71.4)	$ (268.1)

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Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

The Company is exposed to certain risks relating to its ongoing business operations, the most significant being interest rate risk, which the Company may manage through the use of derivative instruments. The Company is also exposed to credit risk in its business operations.

Interest Rate Risk

The Company's exposure to changes in interest rates primarily relates to short-term variable-rate debt and commercial paper.  The Company manages its interest rate exposure by monitoring and limiting the effects of market changes in interest rates.  The Company may utilize interest rate derivatives to alter interest rate exposure in an attempt to reduce the effects of these changes.  Interest rate derivatives are used solely to modify interest rate exposure and not to modify the overall leverage of the debt portfolio.

Credit Risk

The Company is exposed to certain credit risks relating to its ongoing business operations. Credit risk includes the risk that counterparties that owe the Company money or energy will breach their obligations. If the counterparties to these arrangements fail to perform, the Company may be forced to enter into alternative arrangements. In that event, the Company's financial results could be adversely affected and the Company could incur losses.

Cash Flow Hedges

For derivatives that are designated and qualify as a cash flow hedge, the effective portion of the change in fair value of the derivative instrument is reported as a component of Accumulated Other Comprehensive Income (Loss) and recognized into earnings in the same period during which the hedged transaction affects earnings.  The ineffective portion of a derivative's change in fair value or hedge components excluded from the assessment of effectiveness is recognized currently in earnings. The Company measures the ineffectiveness of commodity cash flow hedges using the change in fair value method whereby the change in the expected future cash flows designated as the hedge transaction are compared to the change in fair value of the hedging instrument.  Forecasted transactions, which are designated as the hedged transaction in a cash flow hedge, are regularly evaluated to assess whether they continue to be probable of occurring.  If the forecasted transactions are no longer probable of occurring, hedge accounting will cease on a prospective basis and all future changes in the fair value of the derivative will be recognized directly in earnings.

The Company previously designated as cash flow hedges derivatives for OGE Holdings' NGLs volumes and corresponding keep-whole natural gas resulting from its natural gas processing contracts (processing hedges) and natural gas positions resulting from its natural gas gathering and processing operations and natural gas transportation and storage operations (operational gas hedges).  The Company also previously designated as cash flow hedges certain derivatives for certain natural gas storage inventory positions. Due to the deconsolidation of Enogex LLC effective May 1, 2013, the Company had no material instruments designated as cash flow hedges at March 31, 2014.

Income Statement Presentation Related to Derivative Instruments

The following tables present the effect of derivative instruments on the Company's Condensed Consolidated Statement of Income for thethreemonths endedMarch 31, 2013.

Derivatives in Cash Flow Hedging Relationships

(In millions)	Amount Recognized in Other Comprehensive Income		Amount Reclassified from Accumulated Other Comprehensive Income (Loss) into Income			Amount Recognized in Income
Natural Gas Financial Futures/Swaps	$	—	$	0.2		$	—
Interest Rate Swap	—		(0.2		)	—
Total	$	—	$	—		$	—

Derivatives Not Designated as Hedging Instruments

(In millions)	Amount Recognized in Income
Natural Gas Financial Futures/Swaps	(0.3		)
Total	$	(0.3	)

For derivatives designated as cash flow hedges in the tables above, amounts reclassified from Accumulated Other Comprehensive Income (Loss) into income (effective portion) and amounts recognized in income (ineffective portion) for the threemonths endedMarch 31, 2013, if any, are reported in Operating Revenues. For derivatives not designated as hedges in the tables above, amounts recognized in income for the threemonths endedMarch 31, 2013, if any, are reported in Operating Revenues.

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Stock-Based Compensation

3 Months Ended

Mar. 31, 2014

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

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

Stock-Based Compensation

The following table summarizes the Company's pre-tax compensation expense and related income tax benefit during thethreemonths endedMarch 31, 2014 and 2013related to the Company's performance units and restricted stock.

	Three Months Ended
	March 31,
(In millions)	2014		2013
Performance units
Total shareholder return	$	2.0	$	2.0
Earnings per share	1.7		0.6
Total performance units	3.7		2.6
Restricted stock	0.1		0.1
Total compensation expense	3.8		2.7
Less: Amount paid by unconsolidated affiliates	1.2		—
Net compensation expense	$	2.6	$	2.7
Income tax benefit	$	1.0	$	1.0

The Company has issued new shares to satisfy restricted stock grants and payouts of earned performance units. During thethreemonths endedMarch 31, 2014, there were495,185sharesof new common stock issued, respectively,pursuant to the Company's stock incentive plans related to restricted stock grants (net of forfeitures) and payouts of earned performance units.During thethreemonths endedMarch 31, 2014, there were1,411sharesof restricted stock, respectively, returned to the Company to satisfy tax liabilities.

The following table summarizes the activity of the Company's stock-based compensation during the three months ended March 31, 2014.

	Units/Shares	Fair Value
Grants
Performance units (Total shareholder return)	207,880	$	34.68
Performance units (Earnings per share)	69,295	$	34.69
Restricted stock	1,164	$	35.56
Conversions
Performance units (Total shareholder return) (A)	355,233	N/A
Performance units (Earnings per share) (A)	118,404	N/A

(A)Performance units were converted based on a payout ratio of 170 percent of the target number of performance units granted in February 2011 and are included in the 495,185 shares of common stock issued during the three months ended March 31, 2014 as discussed above.

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Common Equity

3 Months Ended

Mar. 31, 2014

Common Equity [Text Block]

Common Equity

Forward Stock Split

On May 16, 2013, the Company's Board of Directors approved a 2-for-1 forward stock split of the Company's common stock, effective July 1, 2013, which entitled each shareholder of record to receive two shares for every one share of Company stock owned by the shareholder.  In connection with the stock split, an amendment to the Company's Articles of Incorporation was approved on May 16, 2013 which increased the number of authorized shares of common stock from225 millionto450 million. All share and per share amounts within this Form 10-Q reflect the effects of the stock split.

Automatic Dividend Reinvestment and Stock Purchase Plan

The Company issued 98,476 shares of common stock under its Automatic Dividend Reinvestment and Stock Purchase Plan during the threemonths endedMarch 31, 2014 and received proceeds of $3.4 million.  The Company may, from time to time, issue additional shares under its Automatic Dividend Reinvestment and Stock Purchase Plan to fund capital requirements or working capital needs.  At March 31, 2014, there were 3,747,027 shares of unissued common stock reserved for issuance under the Company's Automatic Dividend Reinvestment and Stock Purchase Plan.

Earnings Per Share

Basic earnings per share is calculated by dividing net income attributable to OGE Energy by the weighted average number of the Company's common shares outstanding during the period. In the calculation of diluted earnings per share, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock. Potentially dilutive securities for the Company consist of performance units. Basic and diluted earnings per share for the Company were calculated as follows:

	Three Months Ended
	March 31,
(In millions except per share data)	2014		2013
Net Income Attributable to OGE Energy	$	49.3	$	23.1
Average Common Shares Outstanding
Basic average common shares outstanding	198.8		197.8
Effect of dilutive securities:
Contingently issuable shares (performance units)	0.7		1.0
Diluted average common shares outstanding	199.5		198.8
Basic Earnings Per Average Common Share Attributable to OGE Energy Common Shareholders	$	0.25	$	0.12
Diluted Earnings Per Average Common Share Attributable to OGE Energy Common Shareholders	$	0.25	$	0.12
Anti-dilutive shares excluded from earnings per share calculation	—		—

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Short-Term Debt and Credit Facilities (Tables)

3 Months Ended

Mar. 31, 2014

Short-term Debt [Abstract]

Schedule of Line of Credit Facilities [Table Text Block]

The following table provides information regarding the Company's revolving credit agreements at March 31, 2014.

	Aggregate		Amount		Weighted-Average
Entity	Commitment		Outstanding (A)		Interest Rate			Maturity
	(In millions)
OGE Energy (B)	$	750.0	$	377.8	0.28	%	(D)	December 13, 2017
OG&E (C)	400.0		2.0		0.47	%	(D)	December 13, 2017
Total	$	1,150.0	$	379.8	0.28	%

(A) Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at March 31, 2014.

(B) This bank facility is available to back up OGE Energy's commercial paper borrowings and to provide revolving credit borrowings.  This bank facility can also be used as a letter of credit facility.  

(C) This bank facility 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.

(D) Represents the weighted-average interest rate for the outstanding borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit.

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Derivative Instruments and Hedging Activities, Income Statement Presentation Related to Derivative Instruments (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2013
Enogex [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount Recognized in Other Comprehensive Income	$ 0
Amount Reclassifed from Accumulated Other Comprehensive Income (Loss) into Income	0
Amount Recognized in Income	0
Enogex [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount Recognized in Income	(0.3)
Enogex [Member] | Natural gas [Member] | Fixed Swaps/Futures [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount Recognized in Other Comprehensive Income	0
Amount Reclassifed from Accumulated Other Comprehensive Income (Loss) into Income	0.2
Amount Recognized in Income	0
Enogex [Member] | Natural gas [Member] | Fixed Swaps/Futures [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount Recognized in Income	(0.3)
OGE Energy Corp. [Member] | Interest Rate Swap [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount Recognized in Other Comprehensive Income	0
Amount Reclassifed from Accumulated Other Comprehensive Income (Loss) into Income	(0.2)
Amount Recognized in Income	$ 0

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2014

Long-term Purchase Commitment [Line Items]

Commitments and Contingencies Disclosure [Text Block]

Commitments and Contingencies

Except as set forth below, in Note 14 and under "Environmental Laws and Regulations" in Item 2 of Part I and in Item 1 of Part II of this Form 10-Q, the circumstances set forth in Notes 16 and 17 to the Company's Consolidated Financial Statements included in the Company's 2013Form 10-K appropriately represent, in all material respects, the current status of the Company's material commitments and contingent liabilities.

OG&E Minimum Fuel Purchase Commitments

OG&E has coal contracts for purchases through December 2016. Also, as previously reported, OG&E had entered into multiple-month term natural gas contracts for31.5 percentof its 2014 annual forecasted natural gas requirements. In March 2014, through a request for proposal, OG&E entered into various multiple-month term natural gas contracts for42.6 percentof its remaining forecasted 2014 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 mid-2014, along with monthly and daily purchases, all of which are expected to be made at market prices.

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. On March 17, 2014, OG&E entered into a new contract effective May 1, 2014 and expiring April 30, 2019.

Environmental Laws and Regulations

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. On March 4, 2014, the United States District Court for the Eastern District of Oklahoma dismissed the prevention of significant deterioration permit claim because it was filed after the statute of limitations expired, but the court allowed the opacity and particulate matter claims to proceed. 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,the Companyis 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,the Companyhas incurred a probable loss as set forth by GAAP, an estimate is made of the loss and the appropriate accounting entries are reflected in the Company's Condensed Consolidated Financial Statements.At the present time, based on currently available information, except as otherwise stated above, in Note 13 below, under "Environmental Laws and Regulations" in Item 2 of Part 1 and in Item 1 of Part II of this Form 10-Q, in Notes 15 and 16 of Notes to Consolidated Financial Statements and in Item 3 of Part I of the Company's 2013Form 10-K, the Company believes 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 on the Company's consolidated financial position, results of operations or cash flows.

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Investment in Unconsolidated Affiliates Summarized Balance Sheet Information of Equity Method Investment (Tables)

Mar. 31, 2014

Summarized Financial Information of Equity Method Investment [Line Items]

Summarized Balance Sheet Financial Information, Equity Method Investment [Table Text Block]

Summarized unaudited financial information for 100 percent of Enable is presented below at March 31, 2014 and for the three months endedMarch 31, 2014.

Balance Sheet	March 31, 2014
	(In millions)
Current assets	$	500.6
Non-current assets	10,757.6
Current liabilities	1,038.9
Non-current liabilities	2,002.0

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Fair Value Measurements Carrying and Fair Value Amounts (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
OG&E Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-Term Debt, Carrying Amount	$ 2,403.8	$ 2,154.5
Long-Term Debt, Fair Value	2,728.0	2,405.0
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	10.3
Long-Term Debt, Fair Value	9.2	9.1
OGE Energy Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-Term Debt, Carrying Amount	99.9	99.9
Long-Term Debt, Fair Value	$ 101.7	$ 103.1

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Summary of Significant Accounting Policies Accumulated Other Comprehensive Income (Loss) Reclassifications out of AOCI (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014		Mar. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	$ 0		$ (0.1)
Amounts Reclassified from accumulated other comprehensive income (loss), net of tax	0		0.1
Amounts reclassified from accumulated other comprehensive income (loss), net of tax	(0.3)
Derivative [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, before Tax	(0.2)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Tax	(0.1)
Amounts Reclassified from accumulated other comprehensive income (loss), net of tax	(0.1)
Postretirement Benefit Plan [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), before Tax	(0.3)	[1]
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), before Tax	0.7	[1]
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, before Tax	0.4
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, Tax	0.2
Amounts reclassified from accumulated other comprehensive income (loss), net of tax	0.2
Pension Plan [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), before Tax	(0.7)	[1]
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, before Tax	(0.7)
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, Tax	(0.3)
Amounts reclassified from accumulated other comprehensive income (loss), net of tax	(0.4)
Interest Expense [Member] | Interest Rate Swap [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, before Tax	$ (0.2)

[1] These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost (see Note 11 for additional information).

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 49.3	$ 28.0
Adjustments to reconcile net income to net cash provided from operating activities
Depreciation and amortization	67.2	92.9
Deferred income taxes and investment tax credits, net	22.0	15.4
Equity in earnings of unconsolidated affiliates	(47.9)	0
Distributions from unconsolidated affiliates	32.5	0
Allowance for equity funds used during construction	(1.1)	(1.2)
Gain on disposition and abandonment of assets	(0.2)	(8.7)
Stock-based compensation	(8.6)	(8.3)
Regulatory assets	3.5	5.5
Regulatory liabilities	(1.9)	(4.1)
Other assets	(7.2)	(0.1)
Other liabilities	26.2	6.3
Change in certain current assets and liabilities
Accounts receivable, net	(12.5)	8.4
Accounts receivable - unconsolidated affiliates	2.1	0
Accrued unbilled revenues	7.0	7.8
Fuel, materials and supplies inventories	(4.0)	(7.7)
Fuel clause under recoveries	(35.8)	(0.4)
Other current assets	3.7	(7.7)
Accounts payable	(29.6)	16.5
Fuel clause over recoveries	(0.4)	(27.6)
Other current liabilities	(41.1)	(55.8)
Net Cash Provided from Operating Activities	23.2	59.2
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(171.8)	(325.1)
Proceeds from sale of assets	0.4	35.6
Net Cash Used in Investing Activities	(171.4)	(289.5)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	246.9	0
Issuance of common stock	3.4	3.2
Distributions to noncontrolling interest partners	0	(2.5)
Dividends paid on common stock	(44.7)	(41.2)
(Decrease) increase in short-term debt	(61.8)	276.1
Net Cash Provided from Financing Activities	143.8	235.6
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(4.4)	5.3
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	6.8	1.8
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$ 2.4	$ 7.1

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Accounting Pronouncement

3 Months Ended

Mar. 31, 2014

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements and Changes in Accounting Principles [Text Block]

Accounting Pronouncement

There were no significant accounting pronouncements issued during the threemonths endedMarch 31, 2014 that had or will have a material impact on our consolidated results of operations, financial position or cash flows.

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Short-Term Debt and Credit Facilities (Details) (USD $) In Millions, unless otherwise specified				3 Months Ended
	Mar. 31, 2014		Dec. 31, 2013	Mar. 31, 2014 OGE Energy [Member]		Mar. 31, 2014 OG&E [Member]
Line of Credit Facility [Line Items]
Short-term debt	$ 377.8		$ 439.6
Line of Credit Facility [Abstract]
Aggregate Commitment	1,150.0			750.0	[1]	400.0	[2]
Amount Outstanding	379.8	[3]		377.8	[1],[3]
Weighted Average Interest Rate	0.28%			0.28%	[1],[4]	0.47%	[2],[4]
Maturity				Dec. 13, 2017		Dec. 13, 2017
Letters of Credit Outstanding, Amount						2.0	[2],[3]
Short Term Borrowing Capacity That Has Regulatory Approval						$ 800
Period For Which Regulatory Approval Has Been Given to Acquire Short Term Debt						2 years

[1] This bank facility is available to back up OGE Energy's commercial paper borrowings and to provide revolving credit borrowings. This bank facility can also be used as a letter of credit facility.

[2] This bank facility 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.

[3] Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at March 31, 2014.

[4] Represents the weighted-average interest rate for the outstanding borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit.

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Investment in Unconsolidated Affiliates Summarized Income Statement of Equity Method Investment (Tables)

3 Months Ended

Mar. 31, 2014

Summarized Financial Information of Equity Method Investment [Line Items]

Summarized Income Statement Financial Information, Equity Method Investment [Table Text Block]

	Three Months Ended
Income Statement	March 31, 2014
	(In millions)
Operating revenues	$	1,001.6
Cost of sales	632.6
Operating income	161.9
Net income attributable to Enable	149.2

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Summary of Significant Accounting Policies, Regulated Operations (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2014		Dec. 31, 2013
Schedule of Regulatory Assets and Liabilities [Line Items]
Fuel clause under recoveries	$ 62.0		$ 26.2
Total Current Regulatory Assets	80.0		48.8
Total Non-Current Regulatory Assets	374.4		379.1
Fuel clause over recoveries	0		0.4
Total Current Regulatory Liabilities	18.3		20.2
Total Non-Current Regulatory Liabilities	237.6		234.2
Smart Grid rider over recovery [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Current Regulatory Liabilities	15.7	[1]	16.7	[1]
Other [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Current Regulatory Liabilities	2.6	[1]	3.1	[1]
Accrued removal obligations, net
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Liabilities	230.8		227.7
Deferred pension credits
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Liabilities	3.7		6.5
Pension tracker
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Liabilities	3.1		0
Oklahoma demand program rider under recovery [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Current Regulatory Assets	8.8	[2]	10.6	[2]
Crossroads wind farm rider under recovery [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Current Regulatory Assets	0	[2]	4.7	[2]
Other [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Current Regulatory Assets	9.2	[2]	7.3	[2]
Total Non-Current Regulatory Assets	16.1		16.2
Benefit obligations regulatory asset
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Assets	224.8		227.4
Income taxes recoverable from customers, net
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Assets	56.4		56.5
Smart Grid
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Assets	44.1		44.2
Deferred storm expenses
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Assets	21.5		21.6
Unamortized loss on reacquired debt
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Assets	11.5		11.8
Pension tracker
Schedule of Regulatory Assets and Liabilities [Line Items]
Total Non-Current Regulatory Assets	$ 0		$ 1.4

[1] Included in Other Current Liabilities on the Condensed Consolidated Balance Sheets.

[2] Included in Other Current Assets on the Condensed Consolidated Balance Sheets.

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Report of Business Segments

3 Months Ended

Mar. 31, 2014

Segment Reporting [Abstract]

Report of Business Segments

Report of Business Segments

The Company reports its operations in two business segments: (i) the electric utility segment, which is engaged in the generation, transmission, distribution and sale of electric energy, and (ii) natural gas midstream operations segment.

The natural gas midstream operations segment reflects the Company's equity interest in Enable since its formation on May 1, 2013. Prior to May 1, 2013, the Company reported the results of Enogex Holdings in two separate segments: the natural gas transportation and storage segment, and the natural gas gathering and processing segment. After the deconsolidation, these segments were combined into the natural gas midstream operations segment.The presentation of results for the three months ended March 31, 2013 have been revised to reflect this change. Equity in earnings of unconsolidated affiliates in the natural gas midstream operations segment includes OGE Energy's equity interest in Enable since May 1, 2013. Other than equity in earnings of unconsolidated affiliates, all amounts for the natural gas midstream operations segment represent the operation results of Enogex Holdings through April 30, 2013. Investment in unconsolidated affiliates in the natural gas midstream operations segment represents OGE Energy's investment in Enable at March 31, 2014.

Other Operations primarily includes the operations of the holding company. 

Intersegment revenues are recorded at prices comparable to those of unaffiliated customers and are affected by regulatory considerations.

In reviewing its segment operating results, the Company focuses on operating income and equity in earnings of unconsolidated affiliates as measures of segment profit and loss, and, therefore, has presented this information below.  The following tables summarize the results of the Company's business segments during the threemonths endedMarch 31, 2014 and 2013.

Three Months Ended March 31, 2014	Electric Utility		Natural Gas Midstream Operations		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	560.4	$	—	$	—		$	—		$	560.4
Cost of sales	293.4		—		—			—			293.4
Other operation and maintenance	117.1		—		(4.7		)	—			112.4
Depreciation and amortization	64.3		—		2.9			—			67.2
Taxes other than income	23.8		—		1.8			—			25.6
Operating income (loss)	$	61.8	$	—	$	—		$	—		$	61.8
Equity in earnings of unconsolidated affiliates	$	—	$	47.9	$	—		$	—		$	47.9
Investment in unconsolidated affiliates (at historical cost)	$	—	$	1,314.2	$	—		$	—		$	1,314.2
Total assets	$	7,826.8	$	1,367.4	$	127.9		$	(71.4	)	$	9,250.7

Three Months Ended March 31, 2013	Electric Utility		Natural Gas Midstream Operations		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	455.5	$	464.3	$	—		$	(18.4	)	$	901.4
Cost of sales	213.0		359.2		—			(19.2		)	553.0
Other operation and maintenance	105.1		45.2		(2.3		)	—			148.0
Depreciation and amortization	61.3		27.6		3.0			—			91.9
Taxes other than income	23.2		8.0		1.9			—			33.1
Operating income (loss)	$	52.9	$	24.3	$	(2.6	)	$	0.8		$	75.4
Total assets	$	7,138.4	$	2,729.9	$	381.6		$	(268.1	)	$	9,981.8