10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended March 31, 2022

OR

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

For the transition period from _____to_____

Commission File Number	Exact name of registrants as specified in their charters, address of principal executive offices and registrants' telephone number	I.R.S. Employer Identification No.
1-12579	OGE ENERGY CORP.	73-1481638
1-1097	OKLAHOMA GAS AND ELECTRIC COMPANY	73-0382390

321 North Harvey

P.O. Box 321

Oklahoma City, Oklahoma 73101-0321

405-553-3000

State or other jurisdiction of incorporation or organization: Oklahoma

Securities registered pursuant to Section 12(b) of the Act:

Registrant	Title of each class	Trading Symbol(s)	Name of each exchange on which registered
OGE Energy Corp.	Common Stock	OGE	New York Stock Exchange
Oklahoma Gas and Electric Company	None	N/A	N/A

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.  

OGE Energy Corp. ☑ Yes  ☐ No        Oklahoma Gas and Electric Company ☑ Yes  ☐ No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).  

OGE Energy Corp. ☑ Yes  ☐ No        Oklahoma Gas and Electric Company ☑ Yes  ☐ No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act.

OGE Energy Corp.	Large accelerated filer	☑	Accelerated filer	☐	Non-accelerated filer	☐	Smaller reporting company	☐	Emerging growth company	☐
Oklahoma Gas and Electric Company	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☑	Smaller reporting company	☐	Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

OGE Energy Corp. ☐  Yes  ☑ No        Oklahoma Gas and Electric Company ☐  Yes  ☑ No    

At March 31, 2022, there were 200,202,672 shares of OGE Energy Corp.'s common stock, par value $0.01 per share, outstanding.

At March 31, 2022, there were 40,378,745 of Oklahoma Gas and Electric Company's common stock, par value $2.50 per share, outstanding, all of which were held by OGE Energy Corp. There were no other shares of capital stock of the registrants outstanding at such date.

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

FORM 10-Q

FOR THE QUARTER ENDED MARCH 31, 2022

TABLE OF CONTENTS

	Page
GLOSSARY OF TERMS	ii
FORWARD-LOOKING STATEMENTS	1
Part I - FINANCIAL INFORMATION
Item 1. Financial Statements (Unaudited)
OGE Energy Corp. Consolidated Condensed Financial Statements	3
Oklahoma Gas and Electric Company Condensed Financial Statements	9
Combined Notes to Condensed Financial Statements	14
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	32
Item 3. Quantitative and Qualitative Disclosures About Market Risk	44
Item 4. Controls and Procedures	44
Part II - OTHER INFORMATION
Item 1. Legal Proceedings	45
Item 1A. Risk Factors	45
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	45
Item 6. Exhibits	45
Signature	46

i

GLOSSARY OF TERMS

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

Abbreviation Definition

2021 Form 10-K	Annual Report on Form 10-K for the year ended December 31, 2021
APSC	Arkansas Public Service Commission
ASC	Financial Accounting Standards Board Accounting Standards Codification
CO2	Carbon dioxide
COVID-19	Novel Coronavirus disease
Dry Scrubber	Dry flue gas desulfurization unit with spray dryer absorber
Enable	Enable Midstream Partners, LP, partnership formed to own and operate the midstream businesses of OGE Energy and CenterPoint Energy, Inc. (prior to December 2, 2021)
Energy Transfer	Energy Transfer LP, a Delaware limited partnership, collectively with its subsidiaries
EPA	U.S. Environmental Protection Agency
Federal Clean Water Act	Federal Water Pollution Control Act of 1972, as amended
FERC	Federal Energy Regulatory Commission
GAAP	Accounting principles generally accepted in the U.S.
IRP	Integrated Resource Plan
ISO	Independent system operator
MWh	Megawatt-hour
NGLs	Natural gas liquids, which are the hydrocarbon liquids contained within the natural gas stream
NOPR	Notice of proposed rulemaking
NOX	Nitrogen oxide
OCC	Oklahoma Corporation Commission
ODEQ	Oklahoma Department of Environmental Quality
ODFA	Oklahoma Development Finance Authority
OG&E	Oklahoma Gas and Electric Company, wholly-owned subsidiary of OGE Energy
OGE Energy	OGE Energy Corp., collectively with its subsidiaries, holding company and parent company of OG&E
OGE Holdings	OGE Enogex Holdings, LLC, wholly-owned subsidiary of OGE Energy and 25.5 percent owner of Enable (prior to December 2, 2021)
Pension Plan	Qualified defined benefit retirement plan
Regional Haze	The EPA's Regional Haze Rule
Registrants	OGE Energy and OG&E
Restoration of Retirement Income Plan	Supplemental retirement plan to the Pension Plan
RTO	Regional transmission organization
SIP	State Implementation Plan
SO2	Sulfur dioxide
SPP	Southwest Power Pool
System sales	Sales to OG&E's customers
U.S.	United States of America
USFWS	United States Fish and Wildlife Service
Winter Storm Uri	Unprecedented, prolonged extreme cold weather event in February 2021

ii

FILING FORMAT

This combined Form 10-Q is separately filed by OGE Energy and OG&E. Information in this combined Form 10-Q relating to each individual Registrant is filed by such Registrant on its own behalf. OG&E makes no representation regarding information relating to any other companies affiliated with OGE Energy. Neither OGE Energy, nor any of OGE Energy's subsidiaries, other than OG&E, has any obligation in respect of OG&E's debt securities, and holders of such debt securities should not consider the financial resources or results of operations of OGE Energy nor any of OGE Energy's subsidiaries, other than OG&E (in relevant circumstances), in making a decision with respect to OG&E's debt securities. Similarly, none of OG&E nor any other subsidiary of OGE Energy has any obligation with respect to debt securities of OGE Energy. This combined Form 10-Q should be read in its entirety. No one section of this combined Form 10-Q deals with all aspects of the subject matter of this combined Form 10-Q.

FORWARD-LOOKING STATEMENTS

Except for the historical statements contained herein, the matters discussed within this Form 10-Q, including those matters discussed within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," are forward-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," "target" and similar expressions. Actual results may vary materially from those expressed in forward-looking statements. In addition to the specific risk factors discussed within "Item 1A. Risk Factors" in the Registrants' 2021 Form 10-K and within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" herein, factors that could cause actual results to differ materially from the forward-looking statements include, 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, inflation rates and their impact on capital expenditures;

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

•the ability to obtain timely and sufficient rate relief to allow for recovery, including through securitization, of items such as capital expenditures, fuel costs, operating costs, transmission costs and deferred expenditures;

•prices and availability of electricity, coal and natural gas;

•competitive factors, including the extent and timing of the entry of additional competition in the markets served by the Registrants;

•the impact on demand for services resulting from cost-competitive advances in technology, such as distributed electricity generation and customer energy efficiency programs;

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

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

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

•the effect of retroactive pricing of transactions in the SPP markets or adjustments in market pricing mechanisms by the SPP;

•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 enters the Registrants' markets;

•environmental laws, safety laws or other regulations that may impact the cost of operations, restrict or change the way the Registrants' facilities are operated or result in stranded assets;

•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 cyberattacks, including losing control of our assets and potential ransoms, and other catastrophic events;

•creditworthiness of suppliers, customers and other contractual parties, including large, new customers from emerging industries such as cryptocurrency;

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

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

1

•increased pension and healthcare costs;

•the impact of extraordinary external events, such as the current pandemic health event resulting from COVID-19, and their collateral consequences, including extended disruption of economic activity in the Registrants' markets with an unclear path to national and global economic recovery;

•potential employee engagement issues and/or increased rates of employee turnover if federal or state authorities impose COVID-19-related vaccine or testing mandates;

•global events that could adversely affect and/or exacerbate macroeconomic conditions, including inflationary pressures, supply chain disruptions and uncertainty surrounding continued hostilities or sustained military campaigns;

•costs and other effects of legal and administrative proceedings, settlements, investigations, claims and matters, including, but not limited to, those described in this Form 10-Q;

•business conditions in the energy and natural gas midstream industries, including specifically for Energy Transfer that may affect the fair value of OGE Energy's investment in Energy Transfer's equity securities and the level of distributions OGE Energy receives from Energy Transfer;

•difficulty in making accurate assumptions and projections regarding future distributions associated with OGE Energy's investment in Energy Transfer's equity securities, as OGE Energy does not control Energy Transfer; and

•other risk factors listed in the reports filed by the Registrants with the Securities and Exchange Commission, including those listed within "Item 1A. Risk Factors" in the Registrants' 2021 Form 10-K.

The Registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

2

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)	2022		2021
OPERATING REVENUES
Revenues from contracts with customers	$	578.1	$	1,621.0
Other revenues	11.2		9.6
Operating revenues	589.3		1,630.6
FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE	255.7		1,346.8
OPERATING EXPENSES
Other operation and maintenance	115.0		109.3
Depreciation and amortization	107.4		98.7
Taxes other than income	28.1		27.2
Operating expenses	250.5		235.2
OPERATING INCOME	83.1		48.6
OTHER INCOME (EXPENSE)
Gain (loss) on equity securities (Note 1)	282.3		—
Equity in earnings of unconsolidated affiliates	—		53.2
Allowance for equity funds used during construction	1.3		1.3
Other net periodic benefit expense	(9.4)		(1.4)
Other income	22.6		3.0
Other expense	(5.2)		(2.0)
Net other income	291.6		54.1
INTEREST EXPENSE
Interest on long-term debt	39.4		38.4
Allowance for borrowed funds used during construction	(1.2)		(0.8)
Interest on short-term debt and other interest charges	1.9		1.8
Interest expense	40.1		39.4
INCOME BEFORE TAXES	334.6		63.3
INCOME TAX EXPENSE	55.1		10.6
NET INCOME	$	279.5	$	52.7
BASIC AVERAGE COMMON SHARES OUTSTANDING	200.2		200.1
DILUTED AVERAGE COMMON SHARES OUTSTANDING	200.6		200.1
BASIC EARNINGS PER AVERAGE COMMON SHARE	$	1.40	$	0.26
DILUTED EARNINGS PER AVERAGE COMMON SHARE	$	1.39	$	0.26

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

3

OGE ENERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2022		2021
Net income	$	279.5	$	52.7
Other comprehensive income (loss), net of tax:
Pension Plan and Restoration of Retirement Income Plan:
Amortization of prior service cost, net of tax of $0.0 and $0.0, respectively	0.1		—
Amortization of deferred net loss, net of tax of $0.1 and $0.2, respectively	0.3		0.6
Settlement cost, net of tax of $2.2 and $1.0, respectively	7.4		3.1
Postretirement benefit plans:
Amortization of prior service credit, net of tax of $0.0 and ($0.1), respectively	—		(0.3)
Other comprehensive gain from unconsolidated affiliates, net of tax of $0.0 and $0.0, respectively	—		0.1
Other comprehensive income, net of tax	7.8		3.5
Comprehensive income	$	287.3	$	56.2

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

4

OGE ENERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	279.5	$	52.7
Adjustments to reconcile net income to net cash provided from (used in) operating activities:
Depreciation and amortization	107.4		98.7
Deferred income taxes and other tax credits, net	47.5		8.7
(Gain) loss on investment in equity securities	(282.3)		—
Equity in earnings of unconsolidated affiliates	—		(53.2)
Distributions from unconsolidated affiliates	—		18.3
Allowance for equity funds used during construction	(1.3)		(1.3)
Stock-based compensation expense	2.3		2.5
Regulatory assets	(35.5)		(859.9)
Regulatory liabilities	(19.1)		(16.3)
Other assets	4.3		(5.5)
Other liabilities	(6.4)		(45.4)
Change in certain current assets and liabilities:
Accounts receivable and accrued unbilled revenues, net	0.4		26.0
Income taxes receivable	1.6		1.7
Fuel, materials and supplies inventories	(25.3)		(7.0)
Fuel recoveries	(30.4)		(104.9)
Other current assets	10.0		(2.5)
Accounts payable	24.5		(28.7)
Other current liabilities	(18.3)		(24.1)
Net cash provided from (used in) operating activities	58.9		(940.2)
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(220.1)		(158.4)
Other	(0.3)		(0.6)
Net cash used in investing activities	(220.4)		(159.0)
CASH FLOWS FROM FINANCING ACTIVITIES
Increase in short-term debt	244.6		1,183.1
Dividends paid on common stock	(82.3)		(81.7)
Cash paid for employee equity-based compensation and expense of common stock	(0.8)		(3.3)
Net cash provided from financing activities	161.5		1,098.1
NET CHANGE IN CASH AND CASH EQUIVALENTS	—		(1.1)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	—		1.1
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	—	$	—

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

5

OGE ENERGY CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	March 31,		December 31,
(In millions)	2022		2021
ASSETS
CURRENT ASSETS
Accounts receivable, less reserve of $1.5 and $2.4, respectively	$	164.6	$	162.3
Accrued unbilled revenues	62.3		65.0
Income taxes receivable	1.0		2.6
Fuel inventories	64.3		40.6
Materials and supplies, at average cost	119.5		117.9
Fuel clause under recoveries	182.3		151.9
Other	63.4		73.3
Total current assets	657.4		613.6
OTHER PROPERTY AND INVESTMENTS
Equity securities investment in Energy Transfer	1,067.4		785.1
Other	116.6		120.0
Total other property and investments	1,184.0		905.1
PROPERTY, PLANT AND EQUIPMENT
In service	14,111.7		13,899.8
Construction work in progress	229.6		252.0
Total property, plant and equipment	14,341.3		14,151.8
Less: accumulated depreciation	4,370.0		4,318.9
Net property, plant and equipment	9,971.3		9,832.9
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	1,256.7		1,230.8
Other	24.2		24.0
Total deferred charges and other assets	1,280.9		1,254.8
TOTAL ASSETS	$	13,093.6	$	12,606.4

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

6

OGE ENERGY CORP.

CONDENSED CONSOLIDATED BALANCE SHEETS (Continued)

(Unaudited)

	March 31,		December 31,
(In millions)	2022		2021
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Short-term debt	$	731.5	$	486.9
Accounts payable	300.9		274.0
Dividends payable	82.1		82.1
Customer deposits	81.5		81.1
Accrued taxes	39.9		52.9
Accrued interest	42.6		40.8
Accrued compensation	26.0		37.7
Other	38.3		34.1
Total current liabilities	1,342.8		1,089.6
LONG-TERM DEBT	4,497.0		4,496.4
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	148.8		159.8
Deferred income taxes	1,385.6		1,333.3
Deferred investment tax credits	14.2		12.8
Regulatory liabilities	1,223.3		1,231.1
Other	219.2		227.1
Total deferred credits and other liabilities	2,991.1		2,964.1
Total liabilities	8,830.9		8,550.1
COMMITMENTS AND CONTINGENCIES (NOTE 13)
STOCKHOLDERS' EQUITY
Common stockholders' equity	1,127.2		1,125.8
Retained earnings	3,152.6		2,955.4
Accumulated other comprehensive loss, net of tax	(17.0)		(24.8)
Treasury stock, at cost	(0.1)		(0.1)
Total stockholders' equity	4,262.7		4,056.3
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$	13,093.6	$	12,606.4

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

7

OGE ENERGY CORP.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY

(Unaudited)

	Common Stock			Treasury Stock
(In millions)	Shares	Value		Shares	Value		Premium on Common Stock		Retained Earnings		Accumulated Other Comprehensive (Loss) Income		Total
Balance at December 31, 2021	200.1	$	2.0	—	$	(0.1)	$	1,123.8	$	2,955.4	$	(24.8)	$	4,056.3
Net income	—	—		—	—		—		279.5		—		279.5
Other comprehensive income, net of tax	—	—		—	—		—		—		7.8		7.8
Dividends declared on common stock ($0.4100 per share)	—	—		—	—		—		(82.3)		—		(82.3)
Stock-based compensation	—	—		—	—		1.4		—		—		1.4
Balance at March 31, 2022	200.1	$	2.0	—	$	(0.1)	$	1,125.2	$	3,152.6	$	(17.0)	$	4,262.7
Balance at December 31, 2020	200.1	$	2.0	0.1	$	(5.3)	$	1,122.6	$	2,544.6	$	(32.1)	$	3,631.8
Net income	—	—		—	—		—		52.7		—		52.7
Other comprehensive income, net of tax	—	—		—	—		—		—		3.5		3.5
Dividends declared on common stock ($0.4025 per share)	—	—		—	—		—		(81.7)		—		(81.7)
Stock-based compensation	—	—		(0.1)	5.2		(6.0)		—		—		(0.8)
Balance at March 31, 2021	200.1	$	2.0	—	$	(0.1)	$	1,116.6	$	2,515.6	$	(28.6)	$	3,605.5

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

8

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2022		2021
OPERATING REVENUES
Revenues from contracts with customers	$	578.1	$	1,621.0
Other revenues	11.2		9.6
Operating revenues	589.3		1,630.6
FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE	255.7		1,346.8
OPERATING EXPENSES
Other operation and maintenance	115.5		110.3
Depreciation and amortization	107.4		98.7
Taxes other than income	26.8		25.7
Operating expenses	249.7		234.7
OPERATING INCOME	83.9		49.1
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction	1.3		1.3
Other net periodic benefit expense	(1.4)		(0.9)
Other income	1.2		1.7
Other expense	(0.4)		(0.4)
Net other income	0.7		1.7
INTEREST EXPENSE
Interest on long-term debt	38.5		38.4
Allowance for borrowed funds used during construction	(1.2)		(0.8)
Interest on short-term debt and other interest charges	0.9		0.8
Interest expense	38.2		38.4
INCOME BEFORE TAXES	46.4		12.4
INCOME TAX EXPENSE	7.4		1.2
NET INCOME	$	39.0	$	11.2
Other comprehensive income, net of tax	—		—
COMPREHENSIVE INCOME	$	39.0	$	11.2

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

9

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2022		2021
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	39.0	$	11.2
Adjustments to reconcile net income to net cash provided from (used in) operating activities:
Depreciation and amortization	107.4		98.7
Deferred income taxes and other tax credits, net	4.5		0.8
Allowance for equity funds used during construction	(1.3)		(1.3)
Stock-based compensation expense	0.8		0.4
Regulatory assets	(35.5)		(859.9)
Regulatory liabilities	(19.1)		(16.3)
Other assets	0.5		(4.4)
Other liabilities	(8.5)		(34.8)
Change in certain current assets and liabilities:
Accounts receivable and accrued unbilled revenues, net	0.2		27.7
Fuel, materials and supplies inventories	(25.3)		(7.0)
Fuel recoveries	(30.4)		(104.9)
Other current assets	9.2		0.6
Accounts payable	27.6		(29.1)
Income taxes payable - parent	2.8		0.8
Other current liabilities	(20.5)		(22.4)
Net cash provided from (used in) operating activities	51.4		(939.9)
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(220.1)		(158.4)
Net cash used in investing activities	(220.1)		(158.4)
CASH FLOWS FROM FINANCING ACTIVITIES
Increase in short-term debt	182.5		—
Changes in advances with parent	(13.8)		568.3
Capital contribution from OGE Energy	—		530.0
Net cash provided from financing activities	168.7		1,098.3
NET CHANGE IN CASH AND CASH EQUIVALENTS	—		—
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	—		—
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	—	$	—

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

10

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED BALANCE SHEETS

(Unaudited)

	March 31,		December 31,
(In millions)	2022		2021
ASSETS
CURRENT ASSETS
Accounts receivable, less reserve of $1.5 and $2.4, respectively	$	164.5	$	162.0
Accrued unbilled revenues	62.3		65.0
Fuel inventories	64.3		40.6
Materials and supplies, at average cost	119.5		117.9
Fuel clause under recoveries	182.3		151.9
Other	58.5		67.7
Total current assets	651.4		605.1
OTHER PROPERTY AND INVESTMENTS	3.8		3.9
PROPERTY, PLANT AND EQUIPMENT
In service	14,105.6		13,893.7
Construction work in progress	229.6		252.0
Total property, plant and equipment	14,335.2		14,145.7
Less: accumulated depreciation	4,370.0		4,318.9
Net property, plant and equipment	9,965.2		9,826.8
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	1,256.7		1,230.8
Other	21.7		21.4
Total deferred charges and other assets	1,278.4		1,252.2
TOTAL ASSETS	$	11,898.8	$	11,688.0

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED BALANCE SHEETS (Continued)

(Unaudited)

	March 31,		December 31,
(In millions)	2022		2021
LIABILITIES AND STOCKHOLDER'S EQUITY
CURRENT LIABILITIES
Short-term debt	$	182.5	$	—
Accounts payable	270.5		240.6
Advances from parent	90.3		101.3
Customer deposits	81.5		81.1
Accrued taxes	31.9		50.8
Accrued interest	41.3		40.4
Accrued compensation	20.5		27.8
Other	38.2		33.8
Total current liabilities	756.7		575.8
LONG-TERM DEBT	3,997.1		3,996.5
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	70.7		75.1
Deferred income taxes	1,007.2		1,000.4
Deferred investment tax credits	14.2		12.8
Regulatory liabilities	1,223.3		1,231.1
Other	187.0		193.5
Total deferred credits and other liabilities	2,502.4		2,512.9
Total liabilities	7,256.2		7,085.2
COMMITMENTS AND CONTINGENCIES (NOTE 13)
STOCKHOLDER'S EQUITY
Common stockholder's equity	1,572.5		1,571.7
Retained earnings	3,070.1		3,031.1
Total stockholder's equity	4,642.6		4,602.8
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY	$	11,898.8	$	11,688.0

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

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OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED STATEMENTS OF CHANGES IN STOCKHOLDER'S EQUITY

(Unaudited)

(In millions)	Shares Outstanding	Common Stock		Premium on Common Stock		Retained Earnings		Total
Balance at December 31, 2021	40.4	$	100.9	$	1,470.8	$	3,031.1	$	4,602.8
Net income	—	—		—		39.0		39.0
Stock-based compensation	—	—		0.8		—		0.8
Balance at March 31, 2022	40.4	$	100.9	$	1,471.6	$	3,070.1	$	4,642.6
Balance at December 31, 2020	40.4	$	100.9	$	938.6	$	2,936.1	$	3,975.6
Net income	—	—		—		11.2		11.2
Capital contribution from OGE Energy	—	—		530.0		—		530.0
Stock-based compensation	—	—		0.5		—		0.5
Balance at March 31, 2021	40.4	$	100.9	$	1,469.1	$	2,947.3	$	4,517.3

The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.

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COMBINED NOTES TO THE CONDENSED FINANCIAL STATEMENTS

(Unaudited)

Index of Combined Notes to Condensed Financial Statements

The Combined Notes to the Condensed Financial Statements are a combined presentation for OGE Energy and OG&E. The following table indicates the Registrant(s) to which each Note applies.

	OGE Energy	OG&E
Note 1. Summary of Significant Accounting Policies	X	X
Note 2. Accounting Pronouncements	X	X
Note 3. Revenue Recognition	X	X
Note 4. Related Party Transactions	X	X
Note 5. Fair Value Measurements	X	X
Note 6. Stock-Based Compensation	X	X
Note 7. Income Taxes	X	X
Note 8. Common Equity	X
Note 9. Long-Term Debt	X	X
Note 10. Short-Term Debt and Credit Facilities	X	X
Note 11. Retirement Plans and Postretirement Benefit Plans	X	X
Note 12. Report of Business Segments	X
Note 13. Commitments and Contingencies	X	X
Note 14. Rate Matters and Regulation	X	X

1.Summary of Significant Accounting Policies

Organization

OGE Energy is a holding company with investments in energy and energy services providers offering physical delivery and related services for electricity in Oklahoma and western Arkansas and natural gas, crude oil and NGLs across the U.S. OGE Energy conducts these activities through two business segments: (i) electric utility and (ii) natural gas midstream operations. The accounts of OGE Energy and its wholly-owned subsidiaries, including OG&E, are included in OGE Energy's condensed consolidated financial statements. All intercompany transactions and balances are eliminated in such consolidation. On December 2, 2021, Energy Transfer and Enable closed their merger transaction. For periods prior to the closing date, OGE Energy accounted for its investment in Enable as an equity method investment and reported it within OGE Energy's natural gas midstream operations segment.

Electric Utility Operations. OGE Energy's electric utility operations are conducted through OG&E, which generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. OG&E's rates are subject to regulation by the OCC, the APSC and the FERC. OG&E was incorporated in 1902 under the laws of the Oklahoma Territory and is a wholly-owned subsidiary of OGE Energy. OG&E is the largest electric utility in Oklahoma, and its franchised service territory includes Fort Smith, Arkansas and the surrounding communities. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.

Natural Gas Midstream Operations. As indicated above, on December 2, 2021, Enable and Energy Transfer closed their merger transaction. As a result of such transaction, OGE Energy exchanged its investment in Enable for limited partner units of Energy Transfer, and Sean Trauschke and Luke Corbett, OGE Energy's representatives on the board of Enable's general partner, ceased serving as directors of the general partner of Enable. Subsequent to the merger, OGE Energy's natural gas midstream operations segment includes OGE Energy's investment in Energy Transfer's equity securities and legacy Enable seconded employee pension and postretirement costs. The investment in Energy Transfer's equity securities is held through wholly-owned subsidiaries and ultimately OGE Holdings. At March 31, 2022, OGE Energy owned 95,389,721 of Energy Transfer's limited partner units, which represented an approximately three percent ownership based on the latest publicly available information filed by Energy Transfer. OGE Energy does not own general partner units in or have board representation at Energy Transfer. As such, OGE Energy accounts for its investment in Energy Transfer as an investment in equity securities, as further discussed below. OGE Energy intends to exit the midstream segment in a prudent manner.

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Basis of Presentation

The condensed financial statements included herein have been prepared by the Registrants, 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 Registrants believe 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 financial position of the Registrants at March 31, 2022 and December 31, 2021, the results of the Registrants' operations for the three months ended March 31, 2022 and 2021 and the Registrants' cash flows for the three months ended March 31, 2022 and 2021 have been included and are of a normal, recurring nature except as otherwise disclosed. Management also has evaluated the impact of events occurring after March 31, 2022 up to the date of issuance of these condensed financial statements, and these statements contain all necessary adjustments and disclosures resulting from that evaluation.

Due to seasonal fluctuations and other factors, the Registrants' operating results for the three months ended March 31, 2022 are not necessarily indicative of the results that may be expected for the year ending December 31, 2022 or for any future period. The condensed financial statements and notes thereto should be read in conjunction with the audited financial statements and notes thereto included in the Registrants' 2021 Form 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 incurred 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 incurred costs and obligations as regulatory assets or liabilities if, based on regulatory orders or other available evidence, it is probable that the costs or obligations will be included in amounts allowable for recovery or refund in future rates.

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The following table presents a summary of OG&E's regulatory assets and liabilities.

	March 31,		December 31,
(In millions)	2022		2021
REGULATORY ASSETS
Current:
Fuel clause under recoveries	$	182.3	$	151.9
SPP cost tracker under recovery (A)	9.4		9.3
Oklahoma Energy Efficiency Rider under recoveries (A)	3.4		11.7
Other (A)	8.3		9.7
Total current regulatory assets	$	203.4	$	182.6
Non-current:
Oklahoma Winter Storm Uri costs	$	749.2	$	747.9
Oklahoma deferred storm expenses	204.6		172.8
Benefit obligations regulatory asset	104.4		109.2
Arkansas Winter Storm Uri costs	86.3		88.9
Pension tracker	45.4		42.9
Sooner Dry Scrubbers	18.7		18.9
Arkansas deferred pension expenses	12.3		12.1
Unamortized loss on reacquired debt	8.7		8.9
COVID-19 impacts	8.1		8.2
Frontier Plant deferred expenses	6.4		6.7
Smart Grid	2.2		3.9
Other	10.4		10.4
Total non-current regulatory assets	$	1,256.7	$	1,230.8
REGULATORY LIABILITIES
Current:
Other (B)	$	1.6	$	2.5
Total current regulatory liabilities	$	1.6	$	2.5
Non-current:
Income taxes refundable to customers, net	$	927.3	$	930.7
Accrued removal obligations, net	292.7		296.8
Other	3.3		3.6
Total non-current regulatory liabilities	$	1,223.3	$	1,231.1

(A)Included in Other Current Assets in the condensed balance sheets.

(B)Included in Other Current Liabilities in the condensed 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 or liabilities, which could have significant financial effects.

Allowance for Uncollectible Accounts Receivable

Customer balances are generally written off if not collected within six months after the final billing date. The allowance for uncollectible accounts receivable for OG&E is generally calculated by multiplying the last six months of electric revenue by the provision rate, which is based on a 12-month historical average of actual balances written off and is adjusted for current conditions and supportable forecasts as necessary. To the extent the historical collection rates, when incorporating forecasted conditions, are not representative of future collections, there could be an effect on the amount of uncollectible expense recognized, such as in response to COVID-19 impacts. Also, a portion of the uncollectible provision related to fuel within the Oklahoma jurisdiction is being recovered through the fuel adjustment clause. The allowance for uncollectible

16

accounts receivable is a reduction to Accounts Receivable in the condensed balance sheets and is included in Other Operation and Maintenance Expense in the condensed statements of income.

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

Investment in Equity Securities of Energy Transfer

OGE Energy accounts for its investment in Energy Transfer's equity securities as an equity investment with a readily determinable fair value under ASC 321, "Investments – Equity Securities." OGE Energy presents the Energy Transfer equity securities at estimated fair value in its balance sheet. OGE Energy presents realized and unrealized gains and losses of the equity securities, as well as dividend income from the investment, within the Other Income (Expense) section in its statement of income, as appropriate. For the three months ended March 31, 2022, OGE Energy recognized a pre-tax unrealized gain of $282.3 million related to its investment in Energy Transfer's equity securities.

Distributions received from Energy Transfer were $16.7 million during the three months ended March 31, 2022, which are presented within Other Income in OGE Energy's 2022 condensed consolidated income statement. On April 26, 2022, Energy Transfer announced an approximately 14 percent increase in its quarterly cash distribution, resulting in a distribution of $0.20 per unit on its outstanding common units that will be paid on May 19, 2022 to unitholders of record as of the close of business on May 9, 2022.

As previously disclosed, OGE Energy intends to become a pure play electric utility by exiting its investment in Energy Transfer's equity securities, and unit sales commenced subsequent to March 31, 2022. Through the end of April 2022, OGE Energy has sold 21.75 million Energy Transfer limited partner units, resulting in pre-tax net proceeds of $246.0 million and a remaining ownership percentage of approximately two percent based on the latest publicly available information filed by Energy Transfer.

Investment in Unconsolidated Affiliates (Enable)

For more information concerning OGE Energy's former equity method investment in Enable, including the merger transaction with Energy Transfer and OGE Energy's previous accounting for its investment in Enable, see Notes 1 and 5 within "Item 8. Financial Statements and Supplementary Data" in OGE Energy's 2021 Form 10-K. Prior to December 2, 2021, OGE Energy's investment in Enable was considered to be a variable interest entity; however, OGE Energy was not considered the primary beneficiary of Enable. Under the equity method of accounting, the investment was adjusted each period for contributions made, distributions received and OGE Energy's share of the investee's comprehensive income as adjusted for basis differences. In this Form 10-Q, Enable activity is included for the relevant portion of OGE Energy's 2021 information presented through December 2, 2021.

OGE Energy considered distributions received from Enable which did not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and were classified as operating activities in the statements of cash flows. OGE Energy considered distributions received from Enable in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment and are classified as investing activities in the statements of cash flows. Distributions received from Enable were $18.3 million during the three months ended March 31, 2021.

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The following table presents a reconciliation of OGE Energy's equity in earnings of unconsolidated affiliates for the three months ended March 31, 2021.

	Three Months Ended
(In millions)	March 31, 2021
Enable net income	$	155.0
OGE Energy's percent ownership at period end	25.5		%
OGE Energy's portion of Enable net income	$	39.5
Amortization of basis difference and dilution recognition (A)	13.7
Equity in earnings of unconsolidated affiliates	$	53.2

(A)Includes loss on dilution, net of proportional basis difference recognition.

Accumulated Other Comprehensive Income (Loss)

The following tables present changes in the components of accumulated other comprehensive income (loss) attributable to OGE Energy during the three months ended March 31, 2022 and 2021. All amounts below are presented net of tax.

(In millions)	Pension Plan and Restoration of Retirement Income Plan		Postretirement Benefit Plans		Total
Balance at December 31, 2021	$	(26.1)	$	1.3	$	(24.8)
Other comprehensive income (loss) before reclassifications	—		—		—
Amounts reclassified from accumulated other comprehensive income	0.4		—		0.4
Settlement cost	7.4		—		7.4
Balance at March 31, 2022	$	(18.3)	$	1.3	$	(17.0)

(In millions)	Pension Plan and Restoration of Retirement Income Plan		Postretirement Benefit Plans		Other Comprehensive Gain (Loss) from Unconsolidated Affiliates		Total
Balance at December 31, 2020	$	(34.1)	$	3.3	$	(1.3)	$	(32.1)
Other comprehensive income before reclassifications	—		—		0.1		0.1
Amounts reclassified from accumulated other comprehensive income (loss)	0.6		(0.3)		—		0.3
Settlement cost	3.1		—		—		3.1
Balance at March 31, 2021	$	(30.4)	$	3.0	$	(1.2)	$	(28.6)

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The following table presents significant amounts reclassified out of accumulated other comprehensive income (loss) attributable to OGE Energy by the respective line items in net income (loss) during the three months ended March 31, 2022 and 2021.

Details about Accumulated Other Comprehensive Income (Loss) Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)				Affected Line Item in OGE Energy's Statements of Income
	Three Months Ended
	March 31,
(In millions)	2022		2021
Amortization of Pension Plan and Restoration of Retirement Income Plan items:
Actuarial losses	$	(0.4)	$	(0.8)	(A)
Prior service cost	(0.1)		—		(A)
Settlement cost	(9.6)		(4.1)		(A)
	(10.1)		(4.9)		Income Before Taxes
	(2.3)		(1.2)		Income Tax Expense
	$	(7.8)	$	(3.7)	Net Income
Amortization of postretirement benefit plans items:
Prior service credit	$	—	$	0.4	(A)
	—		0.4		Income Before Taxes
	—		0.1		Income Tax Expense
	$	—	$	0.3	Net Income
Total reclassifications for the period, net of tax	$	(7.8)	$	(3.4)	Net Income

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

Reclassifications

Certain prior year amounts have been reclassified to conform to current year presentation.

2.Accounting Pronouncements

The Registrants believe that recently adopted and recently issued accounting standards that are not yet effective do not appear to have a material impact on the Registrants' financial position, results of operations or cash flows upon adoption.

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3.Revenue Recognition

The following table presents OG&E's revenues from contracts with customers disaggregated by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "OG&E (Electric Utility) Results of Operations" within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations."

	Three Months Ended March 31,
(In millions)	2022		2021
Residential	$	226.8	$	568.2
Commercial	128.1		307.5
Industrial	57.4		146.7
Oilfield	53.2		160.8
Public authorities and street light	48.0		123.1
System sales revenues	513.5		1,306.3
Provision for tax refund	(0.6)		—
Integrated market	22.8		302.1
Transmission	35.8		36.3
Other	6.6		(23.7)
Revenues from contracts with customers (A)	$	578.1	$	1,621.0

(A)In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. Operating revenues for the three months ended March 31, 2021 significantly increased due to increased fuel, purchased power and direct transmission expenses, which are generally recoverable from customers, as a result of Winter Storm Uri. For further discussion, see Note 14 and "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operation."

4.Related Party Transactions

OGE Energy charges operating costs to OG&E, and prior to December 2, 2021, charged operating costs to 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 are allocated either as overhead based primarily on labor costs or using the "Distrigas" method, which is a three-factor formula that uses an equal weighting of payroll, net operating revenues and gross property, plant and equipment.

OGE Energy and OG&E

OGE Energy charged operating costs to OG&E of $32.9 million and $35.8 million during the three months ended March 31, 2022 and 2021, respectively.

OGE Energy and Enable

Prior to December 2, 2021, OGE Energy and Enable were parties to several agreements whereby OGE Energy provided specified support services to Enable, such as certain information technology, payroll and benefits administration. Under these agreements, OGE Energy charged operating costs to Enable of $0.1 million during the three months ended March 31, 2021. OGE Energy had accounts receivable from Enable for amounts billed for support services of $0.3 million as of December 31, 2021, which is included in Accounts Receivable in OGE Energy's 2021 consolidated balance sheet.

OG&E and Enable

Enable provided gas transportation services to OG&E pursuant to agreements, which expire in May 2024 and December 2038, that granted Enable the responsibility of delivering natural gas to OG&E's generating facilities and performing an imbalance service. With this imbalance service, in accordance with the cash-out provision of the contract, OG&E purchased gas from Enable when Enable's deliveries exceeded OG&E's pipeline receipts. Enable purchased gas from OG&E when OG&E's pipeline receipts exceeded Enable's deliveries. Further, an additional gas transportation services contract with Enable became effective in December 2018 related to the project to convert Muskogee Units 4 and 5 from coal to natural gas. Upon the

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closing of the merger between Enable and Energy Transfer, these contracts were assumed by Energy Transfer. The following table presents summarized related party transactions between OG&E and Enable during the three months ended March 31, 2021.

	Three Months Ended
(In millions)	March 31, 2021
Operating revenues:
Electricity to power electric compression assets	$	2.6
Fuel, purchased power and direct transmission expense:
Natural gas transportation services	$	4.7
Natural gas purchases (sales)	$	(12.2)

5.Fair Value Measurements

The classification of the Registrants' 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).

OG&E had no financial instruments measured at fair value on a recurring basis at March 31, 2022 and December 31, 2021. The following table presents OGE Energy's financial instrument measured at fair value on a recurring basis and the carrying amount and fair value of the Registrants' financial instruments at March 31, 2022 and December 31, 2021, as well as the classification level within the fair value hierarchy.

	March 31,				December 31,
	2022				2021
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Classification
Financial instrument measured at fair value on a recurring basis:
OGE Energy investment in Energy Transfer's equity securities	$	1,067.4	$	1,067.4	$	785.1	$	785.1	Level 1
Financial instruments for which fair value is only disclosed:
Long-term Debt (including Long-term Debt due within one year):
OGE Energy Senior Notes	$	499.9	$	489.9	$	499.9	$	497.8	Level 2
OG&E Senior Notes	$	3,852.4	$	4,045.6	$	3,851.8	$	4,460.2	Level 2
OG&E Industrial Authority Bonds	$	135.4	$	135.4	$	135.4	$	135.4	Level 2
OG&E Tinker Debt	$	9.3	$	9.1	$	9.3	$	10.0	Level 3

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6.Stock-Based Compensation

The following table presents the Registrants' pre-tax compensation expense and related income tax benefit for the three months ended March 31, 2022 and 2021 related to performance units and restricted stock units for the Registrants' employees.

	OGE Energy				OG&E
	Three Months Ended March 31,				Three Months Ended March 31,
(In millions)	2022		2021		2022		2021
Performance units - total shareholder return	$	1.8	$	2.0	$	0.6	$	0.4
Restricted stock units	0.5		0.5		0.2		—
Total compensation expense	$	2.3	$	2.5	$	0.8	$	0.4
Income tax benefit	$	0.6	$	0.6	$	0.2	$	0.1

During the three months ended March 31, 2022, OGE Energy issued 27,278 shares of new common stock pursuant to OGE Energy's Stock Incentive Plan and issued an immaterial amount of treasury stock to satisfy payouts of restricted stock unit grants to the Registrants' employees.

During the three months ended March 31, 2022, OGE Energy granted 216,437 performance units (based on total shareholder return over a three-year period) and 116,539 restricted stock units (primarily a three-year cliff vesting period) to employees at $41.10 and $35.72 fair value per share, respectively. Of those performance units and restricted stock units granted, 60,923 and 32,804 were granted to OG&E employees, respectively, at $41.10 and $35.72 fair value per share, respectively.

7.Income Taxes

OGE Energy files consolidated income tax returns in the U.S. federal jurisdiction and various state jurisdictions. OG&E is a part of the consolidated income tax return of OGE Energy. With few exceptions, the Registrants are no longer subject to U.S. federal tax or state and local examinations by tax authorities for years prior to 2018. Income taxes are generally allocated to each company in the affiliated group, including OG&E, based on its stand-alone taxable income or loss. Federal investment tax credits previously claimed on electric utility property have been deferred and will be amortized to income over the life of the related property. Additionally, OG&E earned federal tax credits associated with production from its wind facilities through January 2022. Oklahoma production and investment state tax credits are also earned on investments in electric and solar generating facilities which further reduce OG&E's effective tax rate.

8.Common Equity

Automatic Dividend Reinvestment and Stock Purchase Plan

OGE Energy issued no shares of common stock under its Automatic Dividend Reinvestment and Stock Purchase Plan during the three months ended March 31, 2022.

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Earnings Per Share

Basic earnings per share is calculated by dividing net income attributable to OGE Energy by the weighted-average number of OGE Energy'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 OGE Energy consist of performance units and restricted stock units. The following table presents the calculation of basic and diluted earnings per share for OGE Energy.

	Three Months Ended March 31,
(In millions except per share data)	2022		2021
Net income	$	279.5	$	52.7
Average common shares outstanding:
Basic average common shares outstanding	200.2		200.1
Effect of dilutive securities:
Contingently issuable shares (performance and restricted stock units)	0.4		—
Diluted average common shares outstanding	200.6		200.1
Basic earnings per average common share	$	1.40	$	0.26
Diluted earnings per average common share	$	1.39	$	0.26
Anti-dilutive shares excluded from earnings per share calculation	—		—

9.Long-Term Debt

At March 31, 2022, the Registrants were in compliance with all of their 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 following table presents information about these bonds, which can be tendered at the option of the holder during the next 12 months.

Series			Date Due	Amount
				(In millions)
0.11%	-	0.64%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.11%	-	0.57%	Muskogee Industrial Authority, January 1, 2025	32.4
0.11%	-	0.64%	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, at 100 percent of 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 condensed balance sheets. OG&E believes that it has sufficient liquidity to meet these obligations.

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10.Short-Term Debt and Credit Facilities

The Registrants borrow on a short-term basis, as necessary, by the issuance of commercial paper and by borrowings under their revolving credit agreements. OGE Energy also borrows under term credit agreements maturing in one year or less, as necessary. OGE Energy had $731.5 million and $486.9 million of short-term debt at March 31, 2022 and December 31, 2021, respectively. OG&E had $90.3 million and $101.3 million in advances from OGE Energy at March 31, 2022 and December 31, 2021, respectively.

The following table presents information regarding the Registrants' revolving credit agreements at March 31, 2022.

	Aggregate		Amount		Weighted-Average
Entity	Commitment		Outstanding (A)		Interest Rate			Expiration
	(In millions)
OGE Energy (B)	$	550.0	$	549.0	1.14	%	(E)	December 17, 2026
OG&E (C)(D)	550.0		182.9		1.11	%	(E)	December 17, 2026
Total	$	1,100.0	$	731.9	1.14	%

(A)Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at March 31, 2022.

(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)OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $350.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of December 17, 2026. At March 31, 2022, there were $48.7 million in intercompany borrowings under this agreement.

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

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

OG&E must obtain regulatory approval from the FERC in order to borrow on a short-term basis. OG&E has the necessary regulatory approvals to incur up to $800.0 million in short-term borrowings at any one time for a two-year period beginning January 1, 2021 and ending December 31, 2022.

11.Retirement Plans and Postretirement Benefit Plans

In accordance with ASC Topic 715, "Compensation - Retirement Benefits," a one-time settlement charge is required to be recorded by an organization when lump sum payments or other settlements that relieve the organization from the responsibility for the pension benefit obligation during the plan year exceed the service cost and interest cost components of the organization's net periodic pension cost. During the three months ended March 31, 2022, the Registrants experienced an increase in both the number of employees electing to retire and the amount of lump sum payments paid to such employees upon retirement, which resulted in the Registrants recording pension plan settlement charges as presented in the Pension Plan net periodic benefit cost tables below. The pension settlement charges did not require a cash outlay by the Registrants and did not increase total pension expense over time, as the charge was an acceleration of costs that otherwise would be recognized as pension expense in future periods.

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Net Periodic Benefit Cost

The following tables present the net periodic benefit cost components, before consideration of capitalized amounts, of OGE Energy's Pension Plan, Restoration of Retirement Income Plan and postretirement benefit plans that are included in the condensed financial statements. Service cost is presented within Other Operation and Maintenance Expense, and the remaining net periodic benefit cost components as listed in the following tables are presented within Other Net Periodic Benefit Expense in the statements of income. OG&E recovers specific amounts of pension and postretirement medical costs in rates approved in its Oklahoma rate reviews. In accordance with approved orders, OG&E defers the difference between actual pension and postretirement medical expenses and the amount approved in its last Oklahoma rate review as a regulatory asset or regulatory liability. These amounts have been recorded in the Pension tracker in the regulatory assets and liabilities table in Note 1 and within Other Net Periodic Benefit Expense in the statements of income.

	Pension Plan				Restoration of Retirement Income Plan
	Three Months Ended				Three Months Ended
OGE Energy	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	2.2	$	3.0	$	0.3	$	0.1
Interest cost	3.4		3.5		—		—
Expected return on plan assets	(6.8)		(8.4)		—		—
Amortization of net loss	1.9		2.8		—		0.1
Amortization of unrecognized prior service cost (A)	—		—		0.1		—
Settlement cost	13.2		26.4		—		—
Total net periodic benefit cost	13.9		27.3		0.4		0.2
Less: Amount paid by unconsolidated affiliates	—		0.1		—		—
Net periodic benefit cost	$	13.9	$	27.2	$	0.4	$	0.2

(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.

	Pension Plan				Restoration of Retirement Income Plan
	Three Months Ended				Three Months Ended
OG&E	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	1.7	$	2.1	$	—	$	—
Interest cost	2.6		2.5		—		—
Expected return on plan assets	(5.3)		(6.1)		—		—
Amortization of net loss	1.6		2.0		—		—
Settlement cost	3.6		22.2		—		—
Total net periodic benefit cost	4.2		22.7		—		—
Plus: Amount allocated from OGE Energy	1.8		3.9		0.4		0.2
Net periodic benefit cost	$	6.0	$	26.6	$	0.4	$	0.2

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In addition to the net periodic benefit cost amounts recognized, as presented in the tables above, for the Pension and Restoration of Retirement Income Plans for the three months ended March 31, 2022 and 2021, the Registrants recognized the following:

	Three Months Ended March 31,
(In millions)	2022		2021
Increase of regulatory asset related to pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	1.9	$	20.7
Deferral of pension expense related to pension settlement charges:
Oklahoma jurisdiction (A)	$	4.7	$	23.7
Arkansas jurisdiction (A)	$	0.4	$	2.2

(A) Included in the pension regulatory asset or liability in each jurisdiction, as indicated in the regulatory assets and liabilities table in Note 1.

	OGE Energy				OG&E
	Postretirement Benefit Plans				Postretirement Benefit Plans
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	0.1	$	0.1	$	—	$	0.1
Interest cost	0.9		0.8		0.7		0.6
Expected return on plan assets	(0.4)		(0.5)		(0.4)		(0.4)
Amortization of net loss	0.5		0.7		0.5		0.7
Amortization of unrecognized prior service cost (A)	(1.0)		(1.7)		(0.9)		(1.3)
Total net periodic benefit cost	0.1		(0.6)		(0.1)		(0.3)
Less: Amount paid by unconsolidated affiliates (B)	—		(0.1)
Plus: Amount allocated from OGE Energy (B)					—		(0.1)
Net periodic benefit cost	$	0.1	$	(0.5)	$	(0.1)	$	(0.4)

(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)"Amount paid by unconsolidated affiliates" is only applicable to OGE Energy. "Amount allocated from OGE Energy" is only applicable to OG&E.

In addition to the net periodic benefit cost or income amounts recognized, as presented in the table above, for the postretirement benefit plans for the three months ended March 31, 2022 and 2021, the Registrants recognized the following:

	Three Months Ended March 31,
(In millions)	2022		2021
Increase (decrease) of regulatory liability related to postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	(0.3)	$	0.1

(A) Included in the Pension tracker, as presented in the regulatory assets and liabilities table in Note 1.

	OGE Energy				OG&E
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Capitalized portion of net periodic pension benefit cost	$	0.8	$	0.8	$	0.7	$	0.7
Capitalized portion of net periodic postretirement benefit cost	$	0.1	$	0.1	$	—	$	—

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12.Report of Business Segments

OGE Energy 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. Prior to the Enable and Energy Transfer merger closing on December 2, 2021, OGE Energy's natural gas midstream operations segment included its equity method investment in Enable. Subsequent to December 2, 2021, OGE Energy's natural gas midstream operations segment includes its investment in Energy Transfer's equity securities and legacy Enable seconded employee pension and postretirement costs. 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. The following tables present the results of OGE Energy's business segments for the three months ended March 31, 2022 and 2021.

Three Months Ended March 31, 2022	Electric Utility		Natural Gas Midstream Operations		Other Operations		Eliminations		Total
(In millions)
Operating revenues	$	589.3	$	—	$	—	$	—	$	589.3
Fuel, purchased power and direct transmission expense	255.7		—		—		—		255.7
Other operation and maintenance	115.5		0.7		(1.2)		—		115.0
Depreciation and amortization	107.4		—		—		—		107.4
Taxes other than income	26.8		—		1.3		—		28.1
Operating income (loss)	83.9		(0.7)		(0.1)		—		83.1
Gain (loss) on equity securities	—		282.3		—		—		282.3
Other income	0.7		8.7		—		(0.1)		9.3
Interest expense	38.2		—		2.0		(0.1)		40.1
Income tax expense (benefit)	7.4		60.2		(12.5)		—		55.1
Net income	$	39.0	$	230.1	$	10.4	$	—	$	279.5
Total assets	$	11,898.8	$	1,068.8	$	320.9	$	(194.9)	$	13,093.6

Three Months Ended March 31, 2021	Electric Utility		Natural Gas Midstream Operations		Other Operations		Eliminations		Total
(In millions)
Operating revenues	$	1,630.6	$	—	$	—	$	—	$	1,630.6
Fuel, purchased power and direct transmission expense	1,346.8		—		—		—		1,346.8
Other operation and maintenance	110.3		0.4		(1.4)		—		109.3
Depreciation and amortization	98.7		—		—		—		98.7
Taxes other than income	25.7		0.1		1.4		—		27.2
Operating income (loss)	49.1		(0.5)		—		—		48.6
Equity in earnings of unconsolidated affiliates	—		53.2		—		—		53.2
Other income (expense)	1.7		(0.5)		(0.1)		(0.2)		0.9
Interest expense	38.4		—		1.2		(0.2)		39.4
Income tax expense (benefit)	1.2		14.3		(4.9)		—		10.6
Net income	$	11.2	$	37.9	$	3.6	$	—	$	52.7
Investment in unconsolidated affiliates	$	—	$	409.2	$	—	$	—	$	409.2
Total assets	$	11,248.2	$	415.4	$	521.6	$	(396.5)	$	11,788.7

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 15 and 16 to the financial statements included in the

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Registrants' 2021 Form 10-K appropriately represent, in all material respects, the current status of the Registrants' material commitments and contingent liabilities.

Environmental Laws and Regulations

The activities of the Registrants 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 the Registrants' business activities in many ways, including the handling or disposal of waste material, planning for future construction activities to avoid or mitigate harm to threatened or endangered species and requiring the installation and operation of emissions or 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. Management believes that all of the Registrants' operations are in substantial compliance with current federal, state and local environmental standards.

Environmental regulation can increase the cost of planning, design, initial installation and operation of OG&E's facilities. Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

Other

In the normal course of business, the Registrants are 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 experts to assess the claim. If, in management's opinion, the Registrants have 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 condensed financial statements. At the present time, based on currently available information, the Registrants believe 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 their condensed financial statements and would not have a material adverse effect on their 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 financial statements included in the Registrants' 2021 Form 10-K appropriately represent, in all material respects, the current status of the Registrants' regulatory matters.

Completed Regulatory Matters

APSC Proceedings

Arkansas 2021 Formula Rate Plan Filing

In October 2021, OG&E filed its fourth evaluation report under its Formula Rate Plan, and on February 1, 2022, OG&E, the APSC General Staff and the Office of the Arkansas Attorney General filed a non-unanimous joint settlement agreement, which includes an annual electric revenue increase of $4.2 million. The only non-signatory to the settlement agreement agreed not to oppose the settlement. On March 4, 2022, the APSC issued a final order approving the non-unanimous settlement agreement, and new rates became effective April 1, 2022.

Pending Regulatory Matters

Various proceedings pending before state or federal regulatory agencies are described below. Unless stated otherwise, the Registrants cannot predict when the regulatory agency will act or what action the regulatory agency will take. The Registrants' financial results are dependent in part on timely and constructive decisions by the regulatory agencies that set OG&E's rates.

FERC Proceedings

Order for Sponsored Transmission Upgrades within SPP

Under the SPP Open Access Transmission Tariff, costs of participant-funded, or "sponsored," transmission upgrades may be recovered from other SPP customers whose transmission service depends on capacity enabled by the upgrade. The SPP

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Open Access Transmission Tariff required the SPP to charge for these upgrades beginning in 2008, but the SPP had not been charging its customers for these upgrades due to information system limitations. However, the SPP had informed participants in the market that these charges would be forthcoming. In July 2016, the FERC granted the SPP's request to recover the charges not billed since 2008. The SPP subsequently billed OG&E for these charges and credited OG&E related to transmission upgrades that OG&E had sponsored, which resulted in OG&E being a net receiver of sponsored upgrade credits. The majority of these net credits were refunded to customers through OG&E's various rate riders that include SPP activity with the remaining amounts retained by OG&E.

Several companies that were net payers of Z2 charges sought rehearing of the FERC's July 2016 order; however, in November 2017, the FERC denied the rehearing requests. In January 2018, one of the impacted companies appealed the FERC's decision to the U.S. Court of Appeals for the District of Columbia Circuit. In July 2018, that court granted a motion requested by the FERC that the case be remanded back to the FERC for further examination and proceedings. In February 2019, the FERC reversed its July 2016 order and November 2017 rehearing denial, ruled that the SPP violated its tariff to charge for the 2008 through 2015 period in 2016, held that the SPP tariff provision that prohibited those charges could not be waived and ordered the SPP to develop a plan to refund the payments but not to implement the refunds until further ordered to do so. In response, in April 2019, OG&E filed a request for rehearing with the FERC, and in May 2019, OG&E filed a FERC 206 complaint against the SPP, alleging that the SPP's forced unwinding of the revenue credit payments to OG&E would violate the provisions of the Sponsored Upgrade Agreement and of the applicable tariff. OG&E's filing requested that the FERC rule that the SPP is not entitled to seek refunds or in any other way seek to unwind the revenue credit payments it had paid to OG&E pursuant to the Sponsored Upgrade Agreement. The SPP's response to OG&E's filing agreed that OG&E should be entitled to keep its Z2 payments and argued that the SPP should not be held responsible for those payments if refunds are ordered. Further, the SPP has requested the FERC to negotiate a global settlement with all impacted parties, including other project sponsors who, like OG&E, have also filed complaints at FERC contending that the payments they have received cannot properly be unwound.

In February 2020, the FERC denied OG&E's request for rehearing of its February 2019 order, denying the waiver and ruling that the SPP must seek refunds from project sponsors for Z2 payments for the 2008 through 2015 period and pay them back to transmission owners. The FERC also denied the SPP's request for a stay and for institution of settlement procedures. The FERC stated it would not institute settlement procedures unless parties on both sides of the matter requested them. The FERC did not rule on OG&E's complaint or the complaints of other project sponsors, or consider the SPP's refund plan. The FERC thus has not set any date for payment of refunds. In March 2020, OG&E petitioned the U.S. Court of Appeals for the District of Columbia Circuit for review of the FERC's order denying the waiver and requiring refunds. The court issued a decision on August 27, 2021, denying review and holding that the SPP was prohibited by the filed rate doctrine from imposing Z2 charges during the 2008 through 2015 historical period. The court further held that the FERC reasonably exercised its remedial authority to order the SPP to refund the retroactive upgrade charge. The court did not direct a time frame or procedures for the SPP to implement refunds. OG&E and the SPP filed a petition for rehearing of the court's decision, which was denied in October 2021. The court returned the matter to the FERC for action in accordance with its opinion in November 2021.

If the FERC proceeds to order refunds in full, OG&E estimates it would be required to refund $13.0 million, which is net of amounts paid to other utilities for upgrades and would be subject to interest at the FERC-approved rate. The SPP has stated in filings it made with the FERC while the appeal was pending that there are considerable complexities in implementing the refunds that will have to be resolved before they can be paid. Payment of refunds would shift recovery of these upgrade credits to future periods. The SPP filed an update on January 4, 2022 confirming that administering refunds would be complex and could take years unless the SPP is allowed to make certain simplifying assumptions. It also urged that all pending complaint proceedings, including four complaints against the SPP, be resolved before the refund process is ordered to begin. OG&E and other parties filed responses to the SPP report, and the matter remains pending at the FERC. Of the $13.0 million, the Registrants would be impacted by $5.0 million in expense that initially benefited the Registrants in 2016, and OG&E customers would incur a net impact of $8.0 million in expense through rider mechanisms or the FERC formula rate. As of March 31, 2022, the Registrants have reserved $13.0 million plus estimated interest for a potential refund.

In January 2020, the FERC acted on an SPP proposal to eliminate Attachment Z2 revenue crediting and replace it with a different rate mechanism that would provide project sponsors, such as OG&E, the same level of recovery, and rejected the proposal to the extent it would limit recovery to the amount of the upgrade sponsor's directly assigned upgrade costs with interest. The SPP resubmitted a proposal in April 2020 without this limited recovery, and with the alternative rate mechanism, and the FERC approved it in June 2020, effective July 1, 2020. No party sought rehearing of the order, and it is now final. This order would only prospectively impact OG&E and its recovery of any future upgrade costs that it may incur as a project sponsor subsequent to July 2020. All of the existing projects that are eligible to receive revenue credits under Attachment Z2, which includes the $13.0 million at issue in OG&E's appeal as discussed above, will continue to do so.

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Incentive Adders for Transmission Rates

The FERC issued a NOPR in March 2020, and issued a supplemental NOPR in April 2021, proposing to update its transmission incentives policy. Among other things, the NOPR proposes (i) the current 50-basis point return on equity adder for RTO/ISO participation would be applicable only to transmitting utilities that join an RTO/ISO, and this incentive would only apply for the first three years in which the utility is an RTO/ISO member and (ii) transmitting utilities that have been members of an RTO/ISO for three years or more, such as OG&E, would be required to make a compliance filing to remove the existing return on equity adder from their rates. OG&E is currently evaluating the potential impacts of this proposed rule. Currently, there is no specific deadline for the FERC to take further action, and it is unknown whether the FERC will address the RTO participation adder individually or as part of a larger order on transmission incentives.

APSC Proceedings

Winter Storm Uri

In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. On April 1, 2021, OG&E filed with the APSC a Motion for Authority to Establish Special Regulatory Treatment within the Energy Cost Recovery Rider to Defer Extraordinary Fuel Costs Incurred Due to Winter Storm Uri. More specifically, OG&E's motion sought approval to defer, amortize and recover the extraordinary fuel costs over a ten-year period with a carrying charge of OG&E's pre-tax rate of return of 6.60 percent, through a special factor within OG&E's Energy Cost Recovery Rider beginning with the first billing cycle of May 2021. On April 13, 2021, the APSC issued an order allowing OG&E interim recovery at an interest rate equal to the customer deposit interest rate, which is currently 0.8 percent, over a period of ten years beginning with the first billing cycle of May 2021. Recovery is subject to a true-up after the APSC determines the appropriate allocation, length of recovery and carrying charge. On May 4, 2021, OG&E filed testimony further supporting its 10-year amortization period and a carrying charge of OG&E's pre-tax rate of return of 6.60 percent.

In April 2021, Arkansas enacted legislation to amend its storm recovery securitization statute to allow for both electric and gas utilities to recover through securitization extraordinary natural gas, fuel and purchased power costs caused by storms. The amended statute authorizes the APSC to issue a financing order for the issuance of securitization bonds upon a finding it is reasonably expected to lower overall costs or mitigate rate impacts as compared with traditional utility financing. Upon the initiation of a securitization application, the APSC has 135 days to issue an order. The requesting utility has two years from the date of the financing order to issue the securitization bonds. The amended statute allows carrying costs at a utility's weighted average cost of capital from the date of when the costs were incurred until the date when bonds are ultimately issued.

On May 20, 2021, OG&E filed a motion for suspension of procedural schedule, which the APSC approved, to investigate and evaluate the potential securitization recovery of the Arkansas jurisdictional portion of the Winter Storm Uri costs. OG&E may apply for securitization in mid-2022 if it is deemed to strike the right balance between protecting the credit strength of OG&E and providing customer savings. As of March 31, 2022, OG&E has deferred $86.3 million to a regulatory asset, as indicated in Note 1.

Arkansas 2021 Formula Rate Plan Filing - Extension

In October 2021, OG&E filed a request to extend its Formula Rate Plan Rider for an additional five years. On April 1, 2022, the APSC issued an order granting OG&E an extension of the Formula Rate Plan Rider under the terms and conditions to be detailed in a subsequent order no later than May 18, 2022.

OCC Proceedings

Winter Storm Uri

In December 2021, the OCC approved a settlement agreement in a final financing order authorizing the issuance of securitization bonds in an amount up to $760.0 million, which includes estimated finance costs and is subject to change for carrying costs, any updates from the SPP settlement process and actual securitization issuance costs. On December 22, 2021, the ODFA requested the Oklahoma Supreme Court to certify the proposed securitization bonds. On May 3, 2022, the Oklahoma Supreme Court issued a decision approving the securitization bonds. OG&E continues to work with the ODFA to issue bonds consistent with the OCC's order. The securitization process is expected to be completed in mid-2022.

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Oklahoma Retail Electric Supplier Certified Territory Act Causes

Several rural electric cooperative electricity suppliers have filed complaints with the OCC alleging that OG&E has violated the Oklahoma Retail Electric Supplier Certified Territory Act. OG&E believes it is lawfully serving customers specifically exempted from this act and has presented evidence and testimony to the OCC supporting its position. There have been five complaint cases initiated at the OCC, and the OCC has issued decisions on each of them. The OCC ruled in favor of the electric cooperatives in three of those cases and ruled in favor of OG&E in two of those cases. All five of those cases have been appealed to the Oklahoma Supreme Court, where they have been made companion cases but will be individually briefed and have individual final decisions.

If the Oklahoma Supreme Court ultimately were to find that some or all of the customers being served are not exempted from the Oklahoma Retail Electric Supplier Certified Territory Act, OG&E would have to evaluate the recoverability of some plant investments made to serve these customers. The total amount of OG&E's plant investments made to serve the customers in all five cases is approximately $28.0 million, of which $11.7 million applies to the three cases where the OCC ruled in favor of the electric cooperatives. In addition to the evaluation of the recoverability of the investments, OG&E may also be required to reimburse certified territory suppliers for an amount of lost revenue. The amount of such lost revenue would depend on how the OCC calculates the revenue requirement but could range from approximately $31.4 million to $42.7 million for all five cases, of which $3.2 million to $5.1 million would apply to the three cases where the OCC ruled in favor of the electric cooperatives.

2021 Oklahoma General Rate Review

In December 2021, OG&E filed a general rate review in Oklahoma seeking a rate increase of $163.5 million and a 10.2 percent return on equity based on a common equity percentage of 53.37 percent. The rate review includes a request for recovery of $1.2 billion of capital investment since the last general rate review. On April 27, 2022, initial intervenor testimony was filed with the OCC, and a hearing on the merits is expected to be held toward the end of the second quarter of 2022.

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

The following combined discussion is separately filed by OGE Energy and OG&E. However, OG&E does not make any representations as to information related solely to OGE Energy or the subsidiaries of OGE Energy other than itself.

Introduction

OGE Energy is a holding company with investments in energy and energy services providers offering physical delivery and related services for electricity in Oklahoma and western Arkansas and natural gas, crude oil and NGLs across the U.S. OGE Energy conducts these activities through two business segments: (i) electric utility and (ii) natural gas midstream operations. The accounts of OGE Energy and its wholly-owned subsidiaries, including OG&E, are included in OGE Energy's condensed consolidated financial statements. All intercompany transactions and balances are eliminated in such consolidation. On December 2, 2021, Energy Transfer and Enable closed their merger transaction. For periods prior to the closing date, OGE Energy accounted for its investment in Enable as an equity method investment and reported it within OGE Energy's natural gas midstream operations segment.

Electric Utility Operations. OGE Energy's electric utility operations are conducted through OG&E, which generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. OG&E's rates are subject to regulation by the OCC, the APSC and the FERC. OG&E was incorporated in 1902 under the laws of the Oklahoma Territory and is a wholly-owned subsidiary of OGE Energy. OG&E is the largest electric utility in Oklahoma, and its franchised service territory includes Fort Smith, Arkansas and the surrounding communities. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.

Natural Gas Midstream Operations. OGE Energy's natural gas midstream operations segment includes OGE Energy's investment in Energy Transfer's equity securities and legacy Enable seconded employee pension and postretirement costs. The investment in Energy Transfer's equity securities is held through wholly-owned subsidiaries and ultimately OGE Holdings. At March 31, 2022, OGE Energy owned 95,389,721 of Energy Transfer's limited partner units, which represented an approximately three percent ownership based on the latest publicly available information filed by Energy Transfer. OGE Energy does not own general partner units in or have board representation at Energy Transfer. As such, OGE Energy accounts for its investment in Energy Transfer as an investment in equity securities. OGE Energy intends to exit the midstream segment in a prudent manner. As disclosed in OGE Energy's 2021 Form 10-K, Energy Transfer is subject to risks including the reliance on the drilling and production decisions of others and the volatility of natural gas, NGLs and crude oil prices. The effects of COVID-19 or other global macroeconomic pressures, including negative impacts on demand and commodity prices and rising inflation, could exacerbate these risks, as experienced currently and within the last two years. If any of those risks were to occur or reoccur, OGE Energy's business, financial condition, results of operations or cash flows could be materially adversely affected.

Overview

Strategy

OGE Energy's purpose is to energize life, providing life-sustaining and life-enhancing products and services that enrich its communities and encourage growth and a higher quality of life. OGE Energy's purpose comes with a balanced approach to multifaceted stewardship: keeping its employees (internally referred to as "members") safe, reducing its environmental impact, strengthening its diverse communities and ensuring its effective corporate governance. OGE Energy's business model is centered around growth and sustainability for members, communities and customers and the owners of OGE Energy, its shareholders. OGE Energy's vision for a more sustainable future includes protecting the environment through innovative solutions, serving the needs of customers by adopting cleaner energy, minimizing OGE Energy's reliance on freshwater resources and preserving the biodiversity of OGE Energy's region to reduce its environmental footprint.

OGE Energy is focused on creating long-term shareholder value by targeting the consistent growth of earnings per share of five to seven percent at the electric utility, supported by strong load growth enabled by low customer rates and a strategy of investing in lower risk infrastructure projects that improve the economic vitality of the communities it serves in Oklahoma and Arkansas. OGE Energy plans to fully exit its natural gas midstream operations segment by prudently selling its Energy Transfer units. OGE Energy will continue to utilize cash distributions from its natural gas midstream operations segment and reinvest the proceeds from the sale of Energy Transfer units to help fund its business. In the next five years, OGE Energy expects to continue to grow the dividend, targeting a dividend payout ratio of 65 to 70 percent based on utility earnings. Over the next several years, OGE Energy expects earnings per share growth to exceed the dividend growth rate to help achieve

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this target. OGE Energy's financial objectives also include maintaining investment grade credit ratings and providing a strong and reliable dividend for shareholders.

OGE Energy's long-term sustainability is predicated on providing exceptional customer experiences, investing in grid improvements and increasingly cleaner generation resources, environmental stewardship, strong governance practices and caring for and supporting its members and communities.

Recent Developments

Winter Storm Uri - Oklahoma Securitization

In December 2021, the OCC approved a settlement agreement in a final financing order authorizing the issuance of securitization bonds in an amount up to $760.0 million, which includes estimated finance costs and is subject to change for carrying costs, any updates from the SPP settlement process and actual securitization issuance costs. On December 22, 2021, the ODFA requested the Oklahoma Supreme Court to certify the proposed securitization bonds. On May 3, 2022, the Oklahoma Supreme Court issued a decision approving the securitization bonds. OG&E continues to work with the ODFA to issue bonds consistent with the OCC's order. The securitization process is expected to be completed in mid-2022.

COVID-19 Pandemic and Global Macroeconomic Pressures

The ongoing global COVID-19 pandemic, geopolitical events and related governmental and business responses continue to have an impact on the Registrants' operations, supply chains and end-user customers. The Registrants have experienced raw material inflation, logistical challenges and certain component shortages. Supply chain disruption, including the Anti-Dumping and Countervailing Duty review by the U.S. Department of Commerce, may increase the risk of delays in construction activities and equipment deliveries related to OGE Energy's capital projects. The timing and extent of the financial impact from these events are still uncertain, and the Registrants cannot predict the magnitude of the impact to the results of their business and results of operations.

OG&E's Regulatory Matters

Completed regulatory matters affecting current period results are discussed in Note 14 within "Item 1. Financial Statements."

Summary of OGE Energy Operating Results

OGE Energy's net income was $279.5 million, or $1.39 per diluted share, during the three months ended March 31, 2022 as compared to $52.7 million, or $0.26 per diluted share, during the same period in 2021. The increase in net income of $226.8 million, or $1.13 per diluted share, is further discussed below.

•An increase in net income at OG&E of $27.8 million, or $0.13 per diluted share of OGE Energy's common stock, was primarily due to higher operating revenues driven by the loss from the Guaranteed Flat Bill program in 2021 during Winter Storm Uri and revenues from the recovery of capital investments (excluding impacts of recoverable fuel, purchased power and direct transmission expense not impacting earnings), partially offset by higher depreciation and amortization expense due to additional assets being placed into service, higher income tax expense and higher other operation and maintenance expense.

•An increase in net income at OGE Holdings of $192.2 million, or $0.96 per diluted share of OGE Energy's common stock, was primarily due to a $282.3 million pre-tax unrealized gain on OGE Energy's investment in Energy Transfer's equity securities, partially offset by a decrease in equity in earnings of Enable, which was driven by the merger of Enable and Energy Transfer closing in December 2021, and higher income tax expense.

•An increase in net income of other operations (holding company) of $6.8 million, or $0.04 per diluted share of OGE Energy's common stock, was primarily due to higher income tax benefit in 2022 as a result of a consolidating tax adjustment related to the unrealized gain on OGE Energy's investment in Energy Transfer's equity securities during the interim period that will reverse over the course of the year.

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2022 Outlook

OG&E's 2022 earnings guidance is unchanged and is between approximately $375 million to $395 million, or $1.87 to $1.97 per average diluted share. As indicated in its 2021 Form 10-K, OGE Energy did not issue guidance for its natural gas midstream operations segment and therefore did not issue 2022 consolidated earnings guidance. See OGE Energy's 2021 Form 10-K for other key factors and assumptions underlying its 2022 earnings guidance.

Results of Operations

The following discussion and analysis presents factors that affected the Registrants' results of operations for the three months ended March 31, 2022 as compared to the same period in 2021 and the Registrants' financial position at March 31, 2022. Due to seasonal fluctuations and other factors, the Registrants' operating results for the three months ended March 31, 2022 are not necessarily indicative of the results that may be expected for the year ending December 31, 2022 or for any future period. The following information should be read in conjunction with the condensed financial statements and notes thereto. Known trends and contingencies of a material nature are discussed to the extent considered relevant.

	Three Months Ended
OGE Energy	March 31,
(In millions, except per share data)	2022		2021
Net income	$	279.5	$	52.7
Basic average common shares outstanding	200.2		200.1
Diluted average common shares outstanding	200.6		200.1
Basic earnings per average common share	$	1.40	$	0.26
Diluted earnings per average common share	$	1.39	$	0.26
Dividends declared per common share	$	0.41000	$	0.40250

Results by Business Segment

	Three Months Ended
	March 31,
(In millions)	2022		2021
Net income:
OG&E (Electric Utility)	$	39.0	$	11.2
OGE Holdings (Natural Gas Midstream Operations)	230.1		37.9
Other operations (A)	10.4		3.6
OGE Energy net income	$	279.5	$	52.7

(A)Other operations primarily includes the operations of the holding company and consolidating eliminations. For the three months ended March 31, 2022, other operations includes a tax benefit impact due to a consolidating tax adjustment of $11.9 million primarily related to the unrealized gain on OGE Energy's investment in Energy Transfer's equity securities during the interim period that will reverse over the course of the year.

The following discussion of results of operations by business segment includes intercompany transactions that are eliminated in OGE Energy's condensed consolidated financial statements. 

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OG&E (Electric Utility)

	Three Months Ended
	March 31,
(Dollars in millions)	2022		2021
Operating revenues	$	589.3	$	1,630.6
Fuel, purchased power and direct transmission expense	255.7		1,346.8
Other operation and maintenance	115.5		110.3
Depreciation and amortization	107.4		98.7
Taxes other than income	26.8		25.7
Operating income	83.9		49.1
Allowance for equity funds used during construction	1.3		1.3
Other net periodic benefit expense	1.4		0.9
Other income	1.2		1.7
Other expense	0.4		0.4
Interest expense	38.2		38.4
Income tax expense	7.4		1.2
Net income	$	39.0	$	11.2
Operating revenues by classification:
Residential	$	231.7	$	573.3
Commercial	131.5		309.7
Industrial	58.7		147.7
Oilfield	53.4		161.3
Public authorities and street light	49.4		123.9
System sales revenues	524.7		1,315.9
Provision for tax refund	(0.6)		—
Integrated market	22.8		302.1
Transmission	35.8		36.3
Other	6.6		(23.7)
Total operating revenues	$	589.3	$	1,630.6
MWh sales by classification (In millions)
Residential	2.5		2.5
Commercial	1.6		1.5
Industrial	1.0		1.0
Oilfield	1.0		1.0
Public authorities and street light	0.7		0.6
System sales	6.8		6.6
Integrated market	0.3		0.3
Total sales	7.1		6.9
Number of customers	882,499		871,494
Weighted-average cost of energy per kilowatt-hour (In cents)
Natural gas (A)	6.064		43.843
Coal	2.752		1.786
Total fuel (A)	4.220		21.168
Total fuel and purchased power (A)	3.436		18.401
Degree days (B)
Heating - Actual	2,010		2,066
Heating - Normal	1,887		1,800
Cooling - Actual	3		6
Cooling - Normal	10		13

(A)Decreased primarily due to both elevated pricing from Winter Storm Uri and higher market prices related to increased natural gas prices in 2021.

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

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day. The daily calculations are then totaled for the particular reporting period. The calculation of heating and cooling degree normal days is based on a 30-year average and updated every ten years, which most recently occurred in mid-2021.

OG&E's net income increased $27.8 million during the three months ended March 31, 2022, as compared to the same period in 2021. The following section discusses the primary drivers for the change in net income during the three months ended March 31, 2022, as compared to the same period in 2021.

Operating revenues decreased $1,041.3 million, or 63.9 percent, primarily driven by the below factors.

(In millions)	$ Change
Fuel, purchased power and direct transmission expense (A)	$	(1,091.1)
Other	(0.1)
Guaranteed Flat Bill program (B)	28.9
Price variance (C)	15.7
Quantity impacts (includes weather)	2.0
New customer growth	1.9
Industrial and oilfield sales	1.4
Change in operating revenues	$	(1,041.3)

(A)These expenses are generally recoverable from customers through regulatory mechanisms and are offset in Fuel, Purchased Power and Direct Transmission Expense in the statements of income, as further described below. The primary drivers of the decrease in fuel, purchased power and direct transmission expense during the period are further detailed in the table below.

(B)Increased primarily due to the loss from the Guaranteed Flat Bill program in 2021 related to Winter Storm Uri. The Guaranteed Flat Bill program allows qualifying customers the opportunity to purchase their electricity needs at a set monthly price for an entire year, which resulted in those customers not being allocated incremental fuel and purchased power costs incurred during Winter Storm Uri.

(C)Increased primarily due to increased recovery through rider mechanisms, such as the Storm Cost Recovery Rider and the Oklahoma Production Tax Credit Rider.

Fuel, purchased power and direct transmission expense for OG&E consists of fuel used in electric generation, purchased power and transmission related charges. As described above, the actual cost of fuel used in electric generation and certain purchased power costs are generally recoverable from OG&E's customers through fuel adjustment clauses. The fuel adjustment clauses are subject to periodic review by the OCC and the APSC. OG&E's fuel, purchased power and direct transmission expense decreased $1,091.1 million, or 81.0 percent, primarily driven by the below factors.

(In millions)	$ Change		% Change
Fuel expense (A)	$	(605.0)	(83.6)	%
Purchased power costs:
Purchases from SPP (B)	(483.2)		(82.2)	%
Wind	(0.3)		(2.0)	%
Other	(3.3)		(99.7)	%
Transmission expense	0.7		4.0	%
Change in fuel, purchased power and direct transmission expense	$	(1,091.1)

(A)Decreased primarily due to inflated fuel costs in 2021 during Winter Storm Uri.

(B)Decreased primarily due to higher market prices in 2021 during Winter Storm Uri.

Other operation and maintenance expense increased $5.2 million, or 4.7 percent, primarily driven by the below factors.

(In millions)	$ Change		% Change
Payroll and benefits	$	3.9	6.3	%
Vegetation management	1.9		25.2	%
Other	3.5		4.8	%
Capitalized labor	(4.1)		12.9	%
Change in other operation and maintenance expense	$	5.2

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Depreciation and amortization expense increased $8.7 million, or 8.8 percent, primarily due to increased amortization of the regulatory asset related to storms and additional assets being placed into service.

Income tax expense increased $6.2 million, reflecting additional income taxes primarily related to higher pre-tax income, partially offset by increased amortization of regulatory deferred taxes.

OGE Holdings (Natural Gas Midstream Operations)

On December 2, 2021, Energy Transfer completed its previously announced acquisition of Enable. Prior to the Energy Transfer and Enable merger closing, OGE Energy's natural gas midstream operations segment included its equity method investment in Enable, and subsequent to December 2, 2021, this segment includes OGE Energy's investment in Energy Transfer's equity securities and legacy Enable seconded employee pension and postretirement costs. Therefore, results of operations for the natural gas midstream operations segment are not comparable for the three months ended March 31, 2022 compared to the three months ended March 31, 2021. See "Investment in Equity Securities of Energy Transfer" in Note 1 within "Item 1. Financial Statements" for further discussion of the unrealized gain on Energy Transfer's equity securities and dividend income recognized by OGE Energy for the three months ended March 31, 2022. See Enable's Form 10-Q for the quarterly period ended March 31, 2021 for further discussion of the primary drivers for Enable's operating results for the three months ended March 31, 2021.

OGE Holdings' income tax expense increased $45.9 million, or 76.2 percent, primarily due to higher pre-tax income, partially offset by state deferred tax adjustments related to OGE Energy's midstream investments in Energy Transfer.

Liquidity and Capital Resources

Cash Flows

OGE Energy

	Three Months Ended
	March 31,				2022 vs. 2021
(Dollars in millions)	2022		2021		$ Change		% Change
Net cash provided from (used in) operating activities (A)	$	58.9	$	(940.2)	$	999.1	*
Net cash used in investing activities (B)	$	(220.4)	$	(159.0)	$	(61.4)	38.6	%
Net cash provided from financing activities (C)	$	161.5	$	1,098.1	$	(936.6)	(85.3)	%

* Change is greater than 100 percent.

(A)Changed primarily due to a decrease in vendor payments, including payments for fuel and purchased power costs related to Winter Storm Uri in 2021.

(B)Changed primarily due to increased spending on power delivery projects at OG&E.

(C)Changed primarily due to decreased short-term debt, which was used to provide additional liquidity for the fuel and purchased power costs incurred by OG&E related to Winter Storm Uri in 2021.

Working Capital

Working capital is defined as the difference in current assets and current liabilities. OGE Energy'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 OG&E's customers, the level and timing of spending for maintenance and expansion activity, inventory levels and fuel recoveries. The following discussion addresses changes in OGE Energy's working capital balances at March 31, 2022 compared to December 31, 2021.

Fuel Inventories increased $23.7 million, or 58.4 percent, primarily due to higher volumes and prices of coal and gas purchases.

Fuel Clause Recoveries increased $30.4 million, or 20.0 percent, primarily due to lower recoveries from OG&E retail customers as compared to the actual cost of fuel and purchased power.

Other Current Assets decreased $9.9 million, or 13.5 percent, primarily due to a decrease in under-recovered riders and prepayments.

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Short-term Debt increased $244.6 million, or 50.2 percent, primarily due to increased fuel and purchased power costs and working capital needs. OGE Energy borrows on a short-term basis, as necessary, by the issuance of commercial paper and borrowings under its revolving credit agreements and term credit agreements.

Accounts Payable increased $26.9 million, or 9.8 percent, primarily due to the timing of vendor payments.

Accrued Taxes decreased $13.0 million, or 24.6 percent, primarily due to the timing of ad valorem payments, partially offset by tax accruals.

Accrued Compensation decreased $11.7 million, or 31.0 percent, primarily due to 2021 incentive compensation payouts that occurred in the first quarter of 2022, partially offset by 2022 accruals.

Other Current Liabilities increased $4.2 million, or 12.3 percent, primarily due to changes in amounts of taxes due.

Future Material Cash Requirements

OGE Energy's primary, material cash requirements 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. OGE Energy 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.

Capital Expenditures

OGE Energy's estimates of capital expenditures for the years 2022 through 2026 are discussed in detail within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Registrants' 2021 Form 10-K and have not been updated at this time. The capital investments are customer-focused and targeted to maintain and improve the safety and reliability of OG&E's distribution and transmission grid and generation fleet, enhance the ability of OG&E's system to perform during extreme weather events and to serve OG&E's growing customer base. Additional capital expenditures beyond those identified in the Registrants' 2021 Form 10-K, including additional incremental growth opportunities, will be evaluated based upon the requirements of OG&E's power supply, transmission and distribution operational teams and the resultant customer benefits. OGE Energy is evaluating infrastructure investments incremental to the amounts identified in the Registrants' 2021 Form 10-K related to new generation capacity needs as outlined in OG&E's October 2021 IRP, as well as additional grid investments to address customer growth and grid resiliency. Supply chain disruption may increase the risk of delays in construction activities and equipment deliveries related to OGE Energy's capital projects.

Financing Activities and Future Sources of Financing

Management expects that cash generated from operations, proceeds from the issuance of long- and short-term debt, proceeds from the sales of common stock to the public through OGE Energy's Automatic Dividend Reinvestment and Stock Purchase Plan or other offerings will be adequate over the short-term and the long-term to meet anticipated cash needs and to fund future growth opportunities. In addition, distributions from Energy Transfer as well as proceeds from OGE Energy's sales of Energy Transfer limited partner units will be utilized to meet anticipated cash needs until OGE Energy exits its investment in Energy Transfer's equity securities. OGE Energy 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 Credit Facilities

OGE Energy borrows on a short-term basis, as necessary, by issuance of commercial paper and borrowings under its revolving credit agreements and term credit agreements.

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OGE Energy has unsecured five-year revolving credit facilities totaling $1.1 billion ($550.0 million for OGE Energy and $550.0 million for OG&E), which can also be used as letter of credit facilities. The following table presents information about OGE Energy's revolving credit agreements at March 31, 2022.

(Dollars in millions)	March 31, 2022
Balance of outstanding supporting letters of credit	$	0.4
Weighted-average interest rate of outstanding supporting letters of credit	1.20		%
Net available liquidity under revolving credit agreements	$	368.1
Balance of cash and cash equivalents	$	—

The following table presents information about OGE Energy's total short-term debt activity for the three months ended March 31, 2022.

(Dollars in millions)	Three Months Ended March 31, 2022
Average balance of short-term debt	$	624.5
Weighted-average interest rate of average balance of short-term debt	0.53		%
Maximum month-end balance of short-term debt	$	731.5

OG&E has the necessary regulatory approvals to incur up to $800.0 million in short-term borrowings at any one time for a two-year period beginning January 1, 2021 and ending December 31, 2022.

Expected Issuance of Long-Term Debt

OG&E expects to issue $300.0 million in long-term debt in the second half of 2022 to support its current year capital investment plan.

Securitization of Oklahoma Winter Storm Uri Extreme Purchase Costs

In December 2021, the OCC approved a settlement agreement in a final financing order authorizing the issuance of securitization bonds in an amount up to $760.0 million, which includes estimated finance costs and is subject to change for carrying costs, any updates from the SPP settlement process and actual securitization issuance costs. On December 22, 2021, the ODFA requested the Oklahoma Supreme Court to certify the proposed securitization bonds. On May 3, 2022, the Oklahoma Supreme Court issued a decision approving the securitization bonds. OG&E continues to work with the ODFA to issue bonds consistent with the OCC's order. The securitization process is expected to be completed in mid-2022.

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

Distributions by Energy Transfer

During the three months ended March 31, 2022, Energy Transfer made a distribution of $16.7 million to OGE Energy. On April 26, 2022, Energy Transfer announced an approximately 14 percent increase in its quarterly cash distribution, resulting in a distribution of $0.20 per unit on its outstanding common units that will be paid on May 19, 2022 to unitholders of record as of the close of business on May 9, 2022.

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Sale of Energy Transfer's Equity Securities

As previously disclosed, OGE Energy intends to become a pure play electric utility by exiting its investment in Energy Transfer's equity securities, and unit sales commenced subsequent to March 31, 2022. Through the end of April 2022, OGE Energy has sold 21.75 million Energy Transfer limited partner units, resulting in pre-tax net proceeds of $246.0 million and a remaining ownership percentage of approximately two percent based on the latest publicly available information filed by Energy Transfer.

Critical Accounting Policies and Estimates

The condensed financial statements and notes thereto contain information that is pertinent to Management's Discussion and Analysis. In preparing the condensed 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 financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Changes to these assumptions and estimates could have a material effect on the condensed financial statements. The Registrants believe they have taken reasonable positions where assumptions and estimates are used in order to minimize the negative financial impact to the Registrants that could result if actual results vary from the assumptions and estimates. 

In management's opinion, the areas where the most significant judgment is exercised for the Registrants include the determination of Pension Plan assumptions, income taxes, contingency reserves, asset retirement obligations, regulatory assets and liabilities, unbilled revenues and the allowance for uncollectible accounts receivable. The selection, application and disclosure of the critical accounting estimates have been discussed with the Audit Committee of OGE Energy's Board of Directors and are discussed in detail within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Registrants' 2021 Form 10-K.

Commitments and Contingencies

In the normal course of business, the Registrants are 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 experts to assess the claim. If, in management's opinion, the Registrants have 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 condensed financial statements. At the present time, based on available information, the Registrants believe 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 their condensed financial statements and would not have a material adverse effect on their financial position, results of operations or cash flows. See Notes 13 and 14 within "Item 1. Financial Statements" for further discussion of the Registrants' commitments and contingencies.

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, planning for future construction activities to avoid or mitigate harm to threatened or endangered species and requiring the installation and operation of emissions or 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. Management believes that all of the Registrants' operations are in substantial compliance with current federal, state and local environmental standards.

President Biden's Administration has taken a number of actions that adopt policies and affect environmental regulations, including issuance of executive orders that instruct the EPA and other executive agencies to review certain rules that affect OG&E with a view to achieving nationwide reductions in greenhouse gas emissions. OG&E is monitoring these actions which are in various stages of being implemented. At this point in time, the impacts of these actions on the Registrants' results of operations, if any, cannot be determined with any certainty.

Environmental regulation can increase the cost of planning, design, initial installation and operation of OG&E's facilities. Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

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Air

OG&E's operations are subject to the Federal Clean Air Act of 1970, as amended, and comparable state laws and regulations. These laws and regulations regulate emissions of air pollutants from various industrial sources, including electric generating units and also impose various monitoring and reporting requirements. Such laws and regulations may require that OG&E obtain pre-approval for the construction or modification of certain projects or facilities expected to produce air emissions or result in the increase of existing air emissions, obtain and strictly comply with air permits containing various emissions and operational limitations or install emission control equipment. OG&E likely will be required to incur certain capital expenditures in the future for air pollution control equipment and technology in connection with obtaining and maintaining operating permits and approvals for air emissions.

OG&E is working cooperatively with federal and state environmental agencies to create emission limits for OG&E's operations that are consistent with legal requirements for protecting health and the environment while being cost effective for OG&E to implement. Although various court proceedings are pending that challenge the validity or stringency of rules issued by federal and state environmental agencies, OG&E is not currently a party to any of these proceedings. At this time, OG&E does not anticipate additional material capital expenditures for compliance with the existing rules.

The EPA revised the National Ambient Air Quality Standard for ozone in 2015. Although Oklahoma complies with the revised standard, the Federal Clean Air Act of 1970, as amended, requires states to submit to the EPA for approval a SIP to prohibit in-state sources from contributing significantly to nonattainment of the National Ambient Air Quality Standard in another state. In response to litigation, on April 6, 2022, the EPA published a proposed federal implementation plan under the Cross State Air Pollution Rule intended to reduce interstate NOx emissions contributions. The federal implementation plan, which includes Oklahoma among 24 other states, proposes to limit the current emissions budgets over four years for certain generating units including ten of OG&E's units beginning in 2023. OG&E is currently reviewing the proposal; comments will be due to the EPA by June 6, 2022. OG&E is closely monitoring this issue due to possible future impacts; however, it is unknown at this time what, if any, potential material impacts will result from the EPA action.

In July 2020, the ODEQ notified OG&E that the Horseshoe Lake generating units would be included in Oklahoma's second Regional Haze implementation period evaluation of visibility impairment impacts to the Wichita Mountains. OG&E submitted an analysis of all potential control measures for NOx on these units to the ODEQ. The ODEQ was to identify any cost-effective control measures in a Regional Haze SIP to be submitted to the EPA for approval by July 31, 2021. To date, the ODEQ has not submitted its SIP to the EPA for review and approval. It is unknown at this time what the outcome, or any potential material impacts, if any, will be from the evaluations by OG&E, the ODEQ and the EPA.

OG&E continues to monitor these processes and their possible impact on its operations. Future rules could adopt additional reductions in the emissions budget for Oklahoma or the areas where OG&E's facilities are located. In particular, OG&E monitors possible changes in legal standards for emissions of greenhouse gases, including CO2, sulfur hexafluoride and methane, including the Biden Administration's target of a 50 to 52 percent reduction in economy-wide net greenhouse gas emissions from 2005 levels by 2030 with full decarbonization of the electric power industry fully by 2035. If legislation or regulations are passed at the federal or state levels in the future requiring mandatory reductions of CO2 and other greenhouse gases at OG&E's facilities, this could result in significant additional compliance costs that would affect OG&E's future financial position, results of operations and cash flows if such costs are not recovered through regulated rates.

OG&E has reduced carbon dioxide emissions by over 40 percent compared to 2005 levels, and during the same period, emissions of ozone-forming NOx have been reduced by approximately 70 percent and emissions of SO2 have been reduced by approximately 85 percent. OG&E expects to further reduce carbon dioxide emissions to 50 percent of 2005 levels by 2030. To comply with the EPA rules, OG&E converted two coal-fired generating units at the Muskogee Station to natural gas, among other measures. OG&E's deployment of Smart Grid technology helps to reduce the peak load demand. OG&E is also deploying more renewable energy sources that do not emit greenhouse gases.

In October 2021, OG&E issued its most recent IRP to the OCC and APSC that proposes to expand its renewable generation fleet, including the development of additional solar resources. OG&E has leveraged its geographic position to develop renewable energy resources and completed transmission investments to deliver the renewable energy. The SPP has authorized the construction of transmission lines capable of bringing renewable energy out of the wind resource areas in western Oklahoma, the Texas Panhandle and western Kansas to load centers by planning for more transmission to be built in the area. In addition to increasing overall system reliability, these new transmission resources should provide greater access to additional wind resources that are currently constrained due to existing transmission delivery limitations.

41

Endangered Species

Certain federal laws, including the Bald and Golden Eagle Protection Act, the Migratory Bird Treaty Act and the Endangered Species Act, provide special protection to certain designated species. These laws and any state equivalents provide for significant civil and criminal penalties for unpermitted activities that result in harm to or harassment of certain protected animals and plants, including damage to their habitats. If such species are located in an area in which OG&E conducts operations, or if additional species in those areas become subject to protection, OG&E's operations and development projects, particularly transmission, wind or pipeline projects, could be restricted or delayed, or OG&E could be required to implement expensive mitigation measures.

On June 1, 2021, the USFWS published a proposed rule to list two distinct population segments of the Lesser Prairie Chicken; the southern distinct population segment located in west Texas and eastern New Mexico is proposed as endangered status, and the northern distinct population located in northwest Texas, Oklahoma, Kansas and Colorado is proposed to be listed as threatened status with a 4(d) rule which would prohibit take of the chicken, such as destroying its habitat by building a transmission line or substation, without a permit or special authorization from the USFWS. The final rule for the listing decision is expected to occur in June 2022.

On November 9, 2021, the USFWS published a proposed rule to list the Alligator Snapping Turtle as threatened under the Endangered Species Act, along with a 4(d) rule that would provide conservation of the species. The habitat located within the OG&E service territory is limited to eastern Oklahoma and western Arkansas; however, the USFWS is proposing to exempt incidental take by industry for operation and maintenance and other routine activities that are conducted by using best management practices that reduce incidental take and conserve the habitat. The final rule for the listing decision is expected to occur in November 2022.

On March 23, 2022, the USFWS published a proposed rule to reclassify the Northern Long-Eared Bat as endangered under the Endangered Species Act. The historical habitat located within OG&E service territory is limited to eastern Oklahoma and western Arkansas. The final rule for the listing decision is expected to occur by March 2023.

OG&E is closely monitoring each of these issues due to possible future impacts; however, it is unknown at this time what, if any, material impacts will result from the USFWS action.

Waste

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

Over 95 percent of the ash from OG&E's Muskogee and Sooner facilities was recovered and sold to the concrete and cement industries in the last three years, and in 2021, River Valley became OG&E's third power plant to enter an agreement to have its fly ash reused. Using ash in this way also helps cement manufacturers minimize their impact on the environment by avoiding the need to extract and process other natural resources. Based on estimates from the American Coal Ash Association, OG&E fly ash reuse helped avoid over three million tons of CO2 emissions in the last 14 years.

OG&E has sought and will continue to seek pollution prevention opportunities and to evaluate the effectiveness of its waste reduction, reuse and recycling efforts. OG&E obtains refunds from the recycling of scrap metal, salvaged transformers and used transformer oil. Additional savings are expected to be gained through the reduction and/or avoidance of disposal costs and the reduction in material purchases due to the reuse of existing materials.

Water

OG&E's operations are subject to the Federal Clean Water Act and comparable state laws and regulations. These laws and regulations impose detailed requirements and strict controls regarding the discharge of pollutants into state and federal waters.

In 2015, the EPA issued a final rule addressing the effluent limitation guidelines for power plants under the Federal Clean Water Act. The final rule establishes technology- and performance-based standards that may apply to discharges of six waste streams including bottom ash transport water. Compliance with this rule will occur by 2023; however, on April 12, 2017, the EPA granted a Petition for Reconsideration of the 2015 Rule. On October 13, 2020, the EPA published a final rule to revise the technology-based effluent limitations for flue gas desulfurization waste water and bottom ash transport water. On August 3,

42

2021, the EPA published notice in the Federal Register that it will undertake a supplemental rulemaking to revise the effluent limitation guidelines rule after completing its review of the October 2020 rule. The existing effluent limitation guidelines will remain in effect while the EPA undertakes this new rulemaking. OG&E is evaluating what, if any, compliance actions are needed but is not able to quantify with any certainty what costs may be incurred. OG&E expects to be able to provide a reasonable estimate of any material costs associated with the rule's implementation following issuance of the permits from the State of Oklahoma.

Since the purchase of the Redbud facility in 2008, OG&E's average use of treated municipal effluent for all of the needed cooling water at Redbud and McClain is approximately 2.5 billion gallons per year. This use of treated municipal effluent offsets the need for fresh water as cooling water, making fresh water available for other beneficial uses like drinking water, irrigation and recreation.

Site Remediation

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

For further discussion regarding contingencies relating to environmental laws and regulations, see Note 13 within "Item 1. Financial Statements."

43

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

There have been no significant changes in the market risks affecting the Registrants from those discussed in the Registrants' 2021 Form 10-K.

Item 4. Controls and Procedures.

The Registrants maintain a set of disclosure controls and procedures designed to ensure that information required to be disclosed by the Registrants in reports that they file or submit under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission rules and forms. In addition, the disclosure controls and procedures ensure that information required to be disclosed is accumulated and communicated to management, including the chief executive officer and chief financial officer, allowing timely decisions regarding required disclosure. As of the end of the period covered by this report, based on an evaluation carried out under the supervision and with the participation of the Registrants' management, including the chief executive officer and chief financial officer, of the effectiveness of the Registrants' 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 Registrants' disclosure controls and procedures are effective.

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

44

PART II. OTHER INFORMATION

Item 1. Legal Proceedings.

Reference is made to Item 3 of Part I of the Registrants' 2021 Form 10-K for a description of certain legal proceedings presently pending. Except as described in Note 14 within "Part I - Item 1. Financial Statements," there are no new significant cases to report against the Registrants, and there have been no material changes in the previously reported proceedings.

Item 1A. Risk Factors.

There have been no significant changes in the Registrants' risk factors from those discussed in the Registrants' 2021 Form 10-K, which are incorporated herein by reference.

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

None.

Item 6. Exhibits.

Exhibit No.	Description	OGE Energy	OG&E
10.01*	OGE Energy's 2022 Annual Executive Incentive Compensation Plan (Filed as Exhibit 10.13 to OGE Energy's Form 10-K for the year ended December 31, 2021 (File No. 1-12579) and incorporated by reference herein).	X	X
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.	X
31.02+	Certifications Pursuant to Rule 13a-14(a)/15d-14(a) As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.		X
32.01+	Certification Pursuant to 18 U.S.C. Section 1350 As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.	X
32.02+	Certification Pursuant to 18 U.S.C. Section 1350 As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.		X
101.INS	Inline XBRL Instance Document - the instance document does not appear in the interactive data file because its XBRL tags are embedded within the Inline XBRL document.	X	X
101.SCH	Inline XBRL Taxonomy Schema Document.	X	X
101.PRE	Inline XBRL Taxonomy Presentation Linkbase Document.	X	X
101.LAB	Inline XBRL Taxonomy Label Linkbase Document.	X	X
101.CAL	Inline XBRL Taxonomy Calculation Linkbase Document.	X	X
101.DEF	Inline XBRL Definition Linkbase Document.	X	X
104	Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document (included in Exhibit 101).	X	X
* Represents executive compensation plans and arrangements.
+ Represents exhibits filed herewith. All exhibits not so designated are incorporated by reference to a prior filing, as indicated.

45

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.

	OGE ENERGY CORP.
	OKLAHOMA GAS AND ELECTRIC COMPANY
	(Registrant)
By:	/s/ Sarah R. Stafford
	Sarah R. Stafford
	Controller and Chief Accounting Officer
	(On behalf of the Registrants and in her capacity as Chief Accounting Officer)

May 4, 2022

46

EX-31.01

Exhibit 31.01

CERTIFICATIONS

I, Sean Trauschke, certify that:

1. I have reviewed this quarterly report on Form 10-Q of OGE 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 4, 2022

  /s/ Sean Trauschke

Sean Trauschke

President and Chief Executive Officer

Exhibit 31.01

CERTIFICATIONS

I, W. Bryan Buckler, certify that:

1. I have reviewed this quarterly report on Form 10-Q of OGE 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 4, 2022

  /s/ W. Bryan Buckler

W. Bryan Buckler

Chief Financial Officer

EX-31.02

Exhibit 31.02

CERTIFICATIONS

I, Sean Trauschke, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Oklahoma Gas and Electric Company;

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

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

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

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

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

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

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

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

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

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

Date: May 4, 2022

  /s/ Sean Trauschke

Sean Trauschke

President and Chief Executive Officer

Exhibit 31.02

CERTIFICATIONS

I, W. Bryan Buckler, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Oklahoma Gas and Electric Company;

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

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

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

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

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

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

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

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

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

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

Date: May 4, 2022

  /s/ W. Bryan Buckler

W. Bryan Buckler

Chief Financial Officer

EX-32.01

Exhibit 32.01

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

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

In connection with the Quarterly Report of OGE Energy Corp. ("OGE Energy") on Form 10-Q for the period ended March 31, 2022, 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 OGE Energy.

May 4, 2022

          /s/ Sean Trauschke

               Sean Trauschke

President and Chief Executive Officer

          /s/ W. Bryan Buckler

               W. Bryan Buckler

Chief Financial Officer

EX-32.02

Exhibit 32.02

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 Oklahoma Gas and Electric Company ("OG&E") on Form 10-Q for the period ended March 31, 2022, 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 OG&E.

May 4, 2022

          /s/ Sean Trauschke

               Sean Trauschke

President and Chief Executive Officer

          /s/ W. Bryan Buckler

               W. Bryan Buckler

Chief Financial Officer

XML

Document and Entity Information Document	3 Months Ended
	Mar. 31, 2022 shares
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2022
Document Transition Report	false
Entity File Number	1-12579
Entity Registrant Name	OGE ENERGY CORP.
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-1481638
Entity Central Index Key	0001021635
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
Amendment Flag	false
Title of 12(b) Security	Common Stock
Trading Symbol	OGE
Security Exchange Name	NYSE
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Address, Address Line One	321 North Harvey
Entity Address, Address Line Two	P.O. Box 321
Entity Address, City or Town	Oklahoma City
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	73101-0321
City Area Code	405
Local Phone Number	553-3000
Entity Common Stock, Shares Outstanding	200,202,672
OG&E [Member]
Entity Information [Line Items]
Entity File Number	1-1097
Entity Registrant Name	OKLAHOMA GAS AND ELECTRIC COMPANY
Entity Tax Identification Number	73-0382390
Entity Central Index Key	0000074145
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Common Stock, Shares Outstanding	40,378,745

XML

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Revenues from contracts with customers	[1]	$ 578.1	$ 1,621.0
Other revenues		11.2	9.6
Operating revenues		589.3	1,630.6
FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE		255.7	1,346.8
OPERATING EXPENSES
Other operation and maintenance		115.0	109.3
Depreciation and amortization		107.4	98.7
Taxes other than income		28.1	27.2
Operating expenses		250.5	235.2
OPERATING INCOME		83.1	48.6
OTHER INCOME (EXPENSE)
Equity Securities, FV-NI, Gain (Loss)		282.3	0.0
Equity in earnings of unconsolidated affiliates		0.0	53.2
Allowance for equity funds used during construction		1.3	1.3
Other net periodic benefit expense		(9.4)	(1.4)
Other income		22.6	3.0
Other expense		(5.2)	(2.0)
Net other income		291.6	54.1
INTEREST EXPENSE
Interest on long-term debt		39.4	38.4
Allowance for borrowed funds used during construction		(1.2)	(0.8)
Interest on short-term debt and other interest charges		1.9	1.8
Interest expense		40.1	39.4
INCOME BEFORE TAXES		334.6	63.3
INCOME TAX EXPENSE		55.1	10.6
NET INCOME		$ 279.5	$ 52.7
BASIC AVERAGE COMMON SHARES OUTSTANDING		200.2	200.1
DILUTED AVERAGE COMMON SHARES OUTSTANDING		200.6	200.1
BASIC EARNINGS PER AVERAGE COMMON SHARE		$ 1.40	$ 0.26
DILUTED EARNINGS PER AVERAGE COMMON SHARE		$ 1.39	$ 0.26
Other Comprehensive Income (Loss), Net of Tax		$ 7.8	$ 3.5
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		287.3	56.2
OG&E [Member]
Revenues from contracts with customers		578.1	1,621.0
Other revenues		11.2	9.6
Operating revenues		589.3	1,630.6
FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE		255.7	1,346.8
OPERATING EXPENSES
Other operation and maintenance		115.5	110.3
Depreciation and amortization		107.4	98.7
Taxes other than income		26.8	25.7
Operating expenses		249.7	234.7
OPERATING INCOME		83.9	49.1
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction		1.3	1.3
Other net periodic benefit expense		(1.4)	(0.9)
Other income		1.2	1.7
Other expense		(0.4)	(0.4)
Net other income		0.7	1.7
INTEREST EXPENSE
Interest on long-term debt		38.5	38.4
Allowance for borrowed funds used during construction		(1.2)	(0.8)
Interest on short-term debt and other interest charges		0.9	0.8
Interest expense		38.2	38.4
INCOME BEFORE TAXES		46.4	12.4
INCOME TAX EXPENSE		7.4	1.2
NET INCOME		39.0	11.2
Other Comprehensive Income (Loss), Net of Tax		0.0	0.0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		$ 39.0	$ 11.2

[1] In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. Operating revenues for the three months ended March 31, 2021 significantly increased due to increased fuel, purchased power and direct transmission expenses, which are generally recoverable from customers, as a result of Winter Storm Uri. For further discussion, see Note 14 and "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operation."

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Other comprehensive income (loss), net of tax
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 279.5	$ 52.7
Pension Plan and Restoration of Retirement Income Plan:
Amortization of prior service cost, net of tax of $0.0 and $0.0, respectively	0.1	0.0
Amortization of deferred net loss, net of tax of $0.1 and $0.2, respectively	0.3	0.6
Settlement cost, net of tax of $2.2 and $1.0, respectively	7.4	3.1
Postretirement Benefit Plans:
Amortization of prior service credit, net of tax of $0.0 and ($0.1), respectively	0.0	(0.3)
Other comprehensive gain from unconsolidated affiliates, net of tax of $0.0 and $0.0, respectively	0.0	(0.1)
Other comprehensive income, net of tax	7.8	3.5
Comprehensive income	$ 287.3	$ 56.2

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) Parenthetical - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Pension Plan and Restoration of Retirement Income Plan:
Other Comprehensive Income Amortization Of Defined Benefit Pension Plans Net Prior Service Cost Recognized in Net Periodic Pension Cost, Tax	$ 0.0	$ 0.0
Amortization of deferred net loss	0.1	0.2
Other Comprehensive Income (Loss), Defined Benefit Plan, Adjustment for Settlement or Curtailment Gain (Loss), Tax	2.2	1.0
Postretirement Benefit Plans:
Amortization of prior service cost	0.0	(0.1)
Other Comprehensive Income (Loss), Tax, Portion Attributable to Noncontrolling Interest	$ 0.0	$ 0.0

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Adjustments to reconcile net income to net cash provided from (used in) operating activities:
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 279.5	$ 52.7
Depreciation and amortization	107.4	98.7
Deferred income taxes and other tax credits, net	47.5	8.7
Equity Securities, FV-NI, Gain (Loss)	(282.3)	0.0
Equity in earnings of unconsolidated affiliates	0.0	(53.2)
Distributions from unconsolidated affiliates	0.0	18.3
Allowance for equity funds used during construction	(1.3)	(1.3)
Stock-based compensation expense	2.3	2.5
Regulatory assets	(35.5)	(859.9)
Regulatory liabilities	(19.1)	(16.3)
Other assets	4.3	(5.5)
Other liabilities	(6.4)	(45.4)
Change in certain current assets and liabilities:
Accounts receivable and accrued unbilled revenues, net	0.4	26.0
Increase (Decrease) in Income Taxes Receivable	1.6	1.7
Fuel, materials and supplies inventories	(25.3)	(7.0)
Fuel recoveries	(30.4)	(104.9)
Other current assets	10.0	(2.5)
Accounts payable	24.5	(28.7)
Other current liabilities	(18.3)	(24.1)
Net cash provided from (used in) operating activities	58.9	(940.2)
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(220.1)	(158.4)
Other	(0.3)	(0.6)
Net cash used in investing activities	(220.4)	(159.0)
CASH FLOWS FROM FINANCING ACTIVITIES
Increase in short-term debt	244.6	1,183.1
Dividends paid on common stock	(82.3)	(81.7)
Net cash provided from financing activities	161.5	1,098.1
NET CHANGE IN CASH AND CASH EQUIVALENTS	0.0	(1.1)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	0.0	1.1
CASH AND CASH EQUIVALENTS AT END OF PERIOD	0.0	0.0
Proceeds from (Payments for) Other Financing Activities	(0.8)	(3.3)
Net Income (Loss) Attributable to Parent	279.5	52.7
OG&E [Member]
Adjustments to reconcile net income to net cash provided from (used in) operating activities:
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	39.0	11.2
Depreciation and amortization	107.4	98.7
Deferred income taxes and other tax credits, net	4.5	0.8
Allowance for equity funds used during construction	(1.3)	(1.3)
Stock-based compensation expense	0.8	0.4
Regulatory assets	(35.5)	(859.9)
Regulatory liabilities	(19.1)	(16.3)
Other assets	0.5	(4.4)
Other liabilities	(8.5)	(34.8)
Change in certain current assets and liabilities:
Accounts receivable and accrued unbilled revenues, net	0.2	27.7
Fuel, materials and supplies inventories	(25.3)	(7.0)
Fuel recoveries	(30.4)	(104.9)
Other current assets	9.2	0.6
Accounts payable	27.6	(29.1)
Increase (Decrease) in Income Taxes Payable	2.8	0.8
Other current liabilities	(20.5)	(22.4)
Net cash provided from (used in) operating activities	51.4	(939.9)
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(220.1)	(158.4)
Net cash used in investing activities	(220.1)	(158.4)
CASH FLOWS FROM FINANCING ACTIVITIES
Increase in short-term debt	182.5	0.0
Increase (Decrease) in Due from Related Parties, Current	(13.8)	568.3
Proceeds from Contributions from Parent	0.0	530.0
Net cash provided from financing activities	168.7	1,098.3
NET CHANGE IN CASH AND CASH EQUIVALENTS	0.0	0.0
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	0.0	0.0
CASH AND CASH EQUIVALENTS AT END OF PERIOD	0.0	0.0
Net Income (Loss) Attributable to Parent	$ 39.0	$ 11.2

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
CURRENT ASSETS
Accounts Receivable, after Allowance for Credit Loss, Current	$ 164.6	$ 162.3
Accrued unbilled revenues	62.3	65.0
Income taxes receivable	1.0	2.6
Fuel inventories	64.3	40.6
Materials and supplies, at average cost	119.5	117.9
Fuel clause under recoveries	182.3	151.9
Other	63.4	73.3
Total current assets	657.4	613.6
OTHER PROPERTY AND INVESTMENTS
Other	116.6	120.0
Total other property and investments	1,184.0	905.1
PROPERTY, PLANT AND EQUIPMENT
In service	14,111.7	13,899.8
Construction work in progress	229.6	252.0
Total property, plant and equipment	14,341.3	14,151.8
Less: accumulated depreciation	4,370.0	4,318.9
Net property, plant and equipment	9,971.3	9,832.9
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	1,256.7	1,230.8
Other	24.2	24.0
Total deferred charges and other assets	1,280.9	1,254.8
TOTAL ASSETS	13,093.6	12,606.4
CURRENT LIABILITIES
Short-term debt	731.5	486.9
Accounts payable	300.9	274.0
Dividends payable	82.1	82.1
Customer deposits	81.5	81.1
Accrued taxes	39.9	52.9
Accrued interest	42.6	40.8
Accrued compensation	26.0	37.7
Other	38.3	34.1
Total current liabilities	1,342.8	1,089.6
LONG-TERM DEBT	4,497.0	4,496.4
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	148.8	159.8
Deferred income taxes	1,385.6	1,333.3
Deferred investment tax credits	14.2	12.8
Regulatory liabilities	1,223.3	1,231.1
Other	219.2	227.1
Total deferred credits and other liabilities	2,991.1	2,964.1
Total liabilities	8,830.9	8,550.1
COMMITMENTS AND CONTINGENCIES (NOTE 13)
STOCKHOLDERS' EQUITY
Common stockholders' equity	1,127.2	1,125.8
Retained earnings	3,152.6	2,955.4
Accumulated other comprehensive loss, net of tax	(17.0)	(24.8)
Treasury Stock, Carrying Basis	0.1	(0.1)
Total stockholders' equity	4,262.7	4,056.3
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	13,093.6	12,606.4
OG&E [Member]
CURRENT ASSETS
Accounts Receivable, after Allowance for Credit Loss, Current	164.5	162.0
Accrued unbilled revenues	62.3	65.0
Fuel inventories	64.3	40.6
Materials and supplies, at average cost	119.5	117.9
Fuel clause under recoveries	182.3	151.9
Other	58.5	67.7
Total current assets	651.4	605.1
OTHER PROPERTY AND INVESTMENTS
Total other property and investments	3.8	3.9
PROPERTY, PLANT AND EQUIPMENT
In service	14,105.6	13,893.7
Construction work in progress	229.6	252.0
Total property, plant and equipment	14,335.2	14,145.7
Less: accumulated depreciation	4,370.0	4,318.9
Net property, plant and equipment	9,965.2	9,826.8
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	1,256.7	1,230.8
Other	21.7	21.4
Total deferred charges and other assets	1,278.4	1,252.2
TOTAL ASSETS	11,898.8	11,688.0
CURRENT LIABILITIES
Short-term debt	182.5	0.0
Accounts payable	270.5	240.6
Advances from parent	90.3	101.3
Customer deposits	81.5	81.1
Accrued taxes	31.9	50.8
Accrued interest	41.3	40.4
Accrued compensation	20.5	27.8
Other	38.2	33.8
Total current liabilities	756.7	575.8
LONG-TERM DEBT	3,997.1	3,996.5
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	70.7	75.1
Deferred income taxes	1,007.2	1,000.4
Deferred investment tax credits	14.2	12.8
Regulatory liabilities	1,223.3	1,231.1
Other	187.0	193.5
Total deferred credits and other liabilities	2,502.4	2,512.9
Total liabilities	7,256.2	7,085.2
STOCKHOLDERS' EQUITY
Common stockholders' equity	1,572.5	1,571.7
Retained earnings	3,070.1	3,031.1
Total stockholders' equity	4,642.6	4,602.8
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$ 11,898.8	$ 11,688.0

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) Parenthetical - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Accounts Receivable, Allowance for Credit Loss	$ 1.5	$ 2.4
OG&E [Member]
Accounts Receivable, Allowance for Credit Loss	$ 1.5	$ 2.4

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CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Unaudited) - USD ($) shares in Thousands, $ in Millions	Total	OG&E [Member]	Common Stock	Common Stock OG&E [Member]	Treasury Stock [Member]	Premium on Common Stock	Premium on Common Stock OG&E [Member]	Retained Earnings	Retained Earnings OG&E [Member]	Accumulated Other Comprehensive Income (Loss)
Changes in Stockholders' Equity
Balance	$ 3,631.8	$ 3,975.6	$ 2.0	$ 100.9	$ (5.3)	$ 1,122.6	$ 938.6	$ 2,544.6	$ 2,936.1	$ (32.1)
Common Stock, Shares, Outstanding			200,100	40,400
Treasury Stock, Common, Shares					100
Net Income (Loss), Including portion attributable to noncontrolling interest, Number of Shares			0	0	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	52.7	$ 11.2	$ 0.0	$ 0.0	$ 0.0	0.0	0.0	52.7	11.2	0.0
Proceeds from Contributed Capital, Shares		0
Other Comprehensive Income (Loss), Net of Tax, Number of Shares			0		0
Dividends, Common Stock, Cash, Number of Shares			0		0
Other comprehensive income, net of tax	3.5	$ 0.0	$ 0.0		$ 0.0	0.0		0.0		3.5
Dividends, Common Stock, Cash	(81.7)		$ 0.0		$ 0.0	0.0		(81.7)		0.0
Adjustments to Additional Paid in Capital, Share-based Compensation, Requisite Service Period Recognition, Number of Shares			0	0	(100)
Stock-based compensation	$ (0.8)	0.5	$ 0.0	$ 0.0	$ 5.2	(6.0)	0.5	0.0	0.0	0.0
Proceeds from Contributed Capital		530.0		0.0			530.0		0.0
Common Stock, Dividends, Per Share, Declared	$ 0.4025
Balance	$ 3,605.5	4,517.3	$ 2.0	$ 100.9	$ (0.1)	1,116.6	1,469.1	2,515.6	2,947.3	(28.6)
Common Stock, Shares, Outstanding			200,100	40,400
Treasury Stock, Common, Shares					0
Balance	4,056.3	4,602.8	$ 2.0	$ 100.9	$ (0.1)	1,123.8	1,470.8	2,955.4	3,031.1	(24.8)
Common Stock, Shares, Outstanding			200,100	40,400
Treasury Stock, Common, Shares					0
Net Income (Loss), Including portion attributable to noncontrolling interest, Number of Shares			0	0	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	279.5	39.0	$ 0.0	$ 0.0	$ 0.0	0.0	0.0	279.5	39.0	0.0
Other Comprehensive Income (Loss), Net of Tax, Number of Shares			0		0
Dividends, Common Stock, Cash, Number of Shares			0		0
Other comprehensive income, net of tax	7.8	0.0	$ 0.0		$ 0.0	0.0		0.0		7.8
Dividends, Common Stock, Cash	(82.3)		$ 0.0		$ 0.0	0.0		(82.3)		0.0
Adjustments to Additional Paid in Capital, Share-based Compensation, Requisite Service Period Recognition, Number of Shares			0	0	0
Stock-based compensation	$ 1.4	0.8	$ 0.0	$ 0.0	$ 0.0	1.4	0.8	0.0	0.0	0.0
Common Stock, Dividends, Per Share, Declared	$ 0.4100
Balance	$ 4,262.7	$ 4,642.6	$ 2.0	$ 100.9	$ (0.1)	$ 1,125.2	$ 1,471.6	$ 3,152.6	$ 3,070.1	$ (17.0)
Common Stock, Shares, Outstanding			200,100	40,400
Treasury Stock, Common, Shares					0

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CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Unaudited) Parenthetical - $ / shares	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 0.4100	$ 0.4025

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Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Significant Accounting Policies [Text Block]

Summary of Significant Accounting Policies

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 incurred 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 incurred costs and obligations as regulatory assets or liabilities if, based on regulatory orders or other available evidence, it is probable that the costs or obligations will be included in amounts allowable for recovery or refund in future rates.

The following table presents a summary of OG&E's regulatory assets and liabilities.

	March 31,		December 31,
(In millions)	2022		2021
REGULATORY ASSETS
Current:
Fuel clause under recoveries	$	182.3	$	151.9
SPP cost tracker under recovery (A)	9.4		9.3
Oklahoma Energy Efficiency Rider under recoveries (A)	3.4		11.7
Other (A)	8.3		9.7
Total current regulatory assets	$	203.4	$	182.6
Non-current:
Oklahoma Winter Storm Uri costs	$	749.2	$	747.9
Oklahoma deferred storm expenses	204.6		172.8
Benefit obligations regulatory asset	104.4		109.2
Arkansas Winter Storm Uri costs	86.3		88.9
Pension tracker	45.4		42.9
Sooner Dry Scrubbers	18.7		18.9
Arkansas deferred pension expenses	12.3		12.1
Unamortized loss on reacquired debt	8.7		8.9
COVID-19 impacts	8.1		8.2
Frontier Plant deferred expenses	6.4		6.7
Smart Grid	2.2		3.9
Other	10.4		10.4
Total non-current regulatory assets	$	1,256.7	$	1,230.8
REGULATORY LIABILITIES
Current:
Other (B)	$	1.6	$	2.5
Total current regulatory liabilities	$	1.6	$	2.5
Non-current:
Income taxes refundable to customers, net	$	927.3	$	930.7
Accrued removal obligations, net	292.7		296.8
Other	3.3		3.6
Total non-current regulatory liabilities	$	1,223.3	$	1,231.1

(A)Included in Other Current Assets in the condensed balance sheets.

(B)Included in Other Current Liabilities in the condensed 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 or liabilities, which could have significant financial effects.

Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]

Organization

OGE Energy is a holding company with investments in energy and energy services providers offering physical delivery and related services for electricity in Oklahoma and western Arkansas and natural gas, crude oil and NGLs across the U.S. OGE Energy conducts these activities through two business segments: (i) electric utility and (ii) natural gas midstream operations. The accounts of OGE Energy and its wholly-owned subsidiaries, including OG&E, are included in OGE Energy's condensed consolidated financial statements. All intercompany transactions and balances are eliminated in such consolidation. On December 2, 2021, Energy Transfer and Enable closed their merger transaction. For periods prior to the closing date, OGE Energy accounted for its investment in Enable as an equity method investment and reported it within OGE Energy's natural gas midstream operations segment.

Electric Utility Operations. OGE Energy's electric utility operations are conducted through OG&E, which generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. OG&E's rates are subject to regulation by the OCC, the APSC and the FERC. OG&E was incorporated in 1902 under the laws of the Oklahoma Territory and is a wholly-owned subsidiary of OGE Energy. OG&E is the largest electric utility in Oklahoma, and its franchised service territory includes Fort Smith, Arkansas and the surrounding communities. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.

Natural Gas Midstream Operations. As indicated above, on December 2, 2021, Enable and Energy Transfer closed their merger transaction. As a result of such transaction, OGE Energy exchanged its investment in Enable for limited partner units of Energy Transfer, and Sean Trauschke and Luke Corbett, OGE Energy's representatives on the board of Enable's general partner, ceased serving as directors of the general partner of Enable. Subsequent to the merger, OGE Energy's natural gas midstream operations segment includes OGE Energy's investment in Energy Transfer's equity securities and legacy Enable seconded employee pension and postretirement costs. The investment in Energy Transfer's equity securities is held through wholly-owned subsidiaries and ultimately OGE Holdings. At March 31, 2022, OGE Energy owned 95,389,721 of Energy Transfer's limited partner units, which represented an approximately three percent ownership based on the latest publicly available information filed by Energy Transfer. OGE Energy does not own general partner units in or have board representation at Energy Transfer. As such, OGE Energy accounts for its investment in Energy Transfer as an investment in equity securities, as further discussed below. OGE Energy intends to exit the midstream segment in a prudent manner.

Basis of Accounting [Text Block]

Basis of Presentation

The condensed financial statements included herein have been prepared by the Registrants, 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 Registrants believe 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 financial position of the Registrants at March 31, 2022 and December 31, 2021, the results of the Registrants' operations for the three months ended March 31, 2022 and 2021 and the Registrants' cash flows for the three months ended March 31, 2022 and 2021 have been included and are of a normal, recurring nature except as otherwise disclosed. Management also has evaluated the impact of events occurring after March 31, 2022 up to the date of issuance of these condensed financial statements, and these statements contain all necessary adjustments and disclosures resulting from that evaluation.

Due to seasonal fluctuations and other factors, the Registrants' operating results for the three months ended March 31, 2022 are not necessarily indicative of the results that may be expected for the year ending December 31, 2022 or for any future period. The condensed financial statements and notes thereto should be read in conjunction with the audited financial statements and notes thereto included in the Registrants' 2021 Form 10-K.

Schedule of Regulatory Assets and Liabilities

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 or liabilities, which could have significant financial effects.

Comprehensive Income (Loss) Note [Text Block]

Accumulated Other Comprehensive Income (Loss)

The following tables present changes in the components of accumulated other comprehensive income (loss) attributable to OGE Energy during the three months ended March 31, 2022 and 2021. All amounts below are presented net of tax.

(In millions)	Pension Plan and Restoration of Retirement Income Plan		Postretirement Benefit Plans		Total
Balance at December 31, 2021	$	(26.1)	$	1.3	$	(24.8)
Other comprehensive income (loss) before reclassifications	—		—		—
Amounts reclassified from accumulated other comprehensive income	0.4		—		0.4
Settlement cost	7.4		—		7.4
Balance at March 31, 2022	$	(18.3)	$	1.3	$	(17.0)

(In millions)	Pension Plan and Restoration of Retirement Income Plan		Postretirement Benefit Plans		Other Comprehensive Gain (Loss) from Unconsolidated Affiliates		Total
Balance at December 31, 2020	$	(34.1)	$	3.3	$	(1.3)	$	(32.1)
Other comprehensive income before reclassifications	—		—		0.1		0.1
Amounts reclassified from accumulated other comprehensive income (loss)	0.6		(0.3)		—		0.3
Settlement cost	3.1		—		—		3.1
Balance at March 31, 2021	$	(30.4)	$	3.0	$	(1.2)	$	(28.6)

The following table presents significant amounts reclassified out of accumulated other comprehensive income (loss) attributable to OGE Energy by the respective line items in net income (loss) during the three months ended March 31, 2022 and 2021.

Details about Accumulated Other Comprehensive Income (Loss) Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)				Affected Line Item in OGE Energy's Statements of Income
	Three Months Ended
	March 31,
(In millions)	2022		2021
Amortization of Pension Plan and Restoration of Retirement Income Plan items:
Actuarial losses	$	(0.4)	$	(0.8)	(A)
Prior service cost	(0.1)		—		(A)
Settlement cost	(9.6)		(4.1)		(A)
	(10.1)		(4.9)		Income Before Taxes
	(2.3)		(1.2)		Income Tax Expense
	$	(7.8)	$	(3.7)	Net Income
Amortization of postretirement benefit plans items:
Prior service credit	$	—	$	0.4	(A)
	—		0.4		Income Before Taxes
	—		0.1		Income Tax Expense
	$	—	$	0.3	Net Income
Total reclassifications for the period, net of tax	$	(7.8)	$	(3.4)	Net Income

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

Allowance for Credit Losses

Allowance for Uncollectible Accounts Receivable

Customer balances are generally written off if not collected within six months after the final billing date. The allowance for uncollectible accounts receivable for OG&E is generally calculated by multiplying the last six months of electric revenue by the provision rate, which is based on a 12-month historical average of actual balances written off and is adjusted for current conditions and supportable forecasts as necessary. To the extent the historical collection rates, when incorporating forecasted conditions, are not representative of future collections, there could be an effect on the amount of uncollectible expense recognized, such as in response to COVID-19 impacts. Also, a portion of the uncollectible provision related to fuel within the Oklahoma jurisdiction is being recovered through the fuel adjustment clause. The allowance for uncollectible

accounts receivable is a reduction to Accounts Receivable in the condensed balance sheets and is included in Other Operation and Maintenance Expense in the condensed statements of income.

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

Reclassifications [Text Block]

Reclassifications

Certain prior year amounts have been reclassified to conform to current year presentation.

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Accounting Pronouncements	3 Months Ended
	Mar. 31, 2022
Accounting Standards Update and Change in Accounting Principle [Abstract]
New Accounting Pronouncements and Changes in Accounting Principles [Text Block]	Accounting PronouncementsThe Registrants believe that recently adopted and recently issued accounting standards that are not yet effective do not appear to have a material impact on the Registrants' financial position, results of operations or cash flows upon adoption.

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Revenue from Contracts with Customers (Notes)

3 Months Ended

Mar. 31, 2022

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer [Text Block]

Revenue Recognition

The following table presents OG&E's revenues from contracts with customers disaggregated by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "OG&E (Electric Utility) Results of Operations" within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations."

	Three Months Ended March 31,
(In millions)	2022		2021
Residential	$	226.8	$	568.2
Commercial	128.1		307.5
Industrial	57.4		146.7
Oilfield	53.2		160.8
Public authorities and street light	48.0		123.1
System sales revenues	513.5		1,306.3
Provision for tax refund	(0.6)		—
Integrated market	22.8		302.1
Transmission	35.8		36.3
Other	6.6		(23.7)
Revenues from contracts with customers (A)	$	578.1	$	1,621.0

(A)In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. Operating revenues for the three months ended March 31, 2021 significantly increased due to increased fuel, purchased power and direct transmission expenses, which are generally recoverable from customers, as a result of Winter Storm Uri. For further discussion, see Note 14 and "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operation."

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Investment in Unconsolidated Affiliates

3 Months Ended

Mar. 31, 2022

Related Party Transactions [Abstract]

Equity Method Investments and Joint Ventures Disclosure [Text Block]

Investment in Equity Securities of Energy Transfer

OGE Energy accounts for its investment in Energy Transfer's equity securities as an equity investment with a readily determinable fair value under ASC 321, "Investments – Equity Securities." OGE Energy presents the Energy Transfer equity securities at estimated fair value in its balance sheet. OGE Energy presents realized and unrealized gains and losses of the equity securities, as well as dividend income from the investment, within the Other Income (Expense) section in its statement of income, as appropriate. For the three months ended March 31, 2022, OGE Energy recognized a pre-tax unrealized gain of $282.3 million related to its investment in Energy Transfer's equity securities.

Distributions received from Energy Transfer were $16.7 million during the three months ended March 31, 2022, which are presented within Other Income in OGE Energy's 2022 condensed consolidated income statement. On April 26, 2022, Energy Transfer announced an approximately 14 percent increase in its quarterly cash distribution, resulting in a distribution of $0.20 per unit on its outstanding common units that will be paid on May 19, 2022 to unitholders of record as of the close of business on May 9, 2022.

As previously disclosed, OGE Energy intends to become a pure play electric utility by exiting its investment in Energy Transfer's equity securities, and unit sales commenced subsequent to March 31, 2022. Through the end of April 2022, OGE Energy has sold 21.75 million Energy Transfer limited partner units, resulting in pre-tax net proceeds of $246.0 million and a remaining ownership percentage of approximately two percent based on the latest publicly available information filed by Energy Transfer.

Investment in Unconsolidated Affiliates (Enable)

For more information concerning OGE Energy's former equity method investment in Enable, including the merger transaction with Energy Transfer and OGE Energy's previous accounting for its investment in Enable, see Notes 1 and 5 within "Item 8. Financial Statements and Supplementary Data" in OGE Energy's 2021 Form 10-K. Prior to December 2, 2021, OGE Energy's investment in Enable was considered to be a variable interest entity; however, OGE Energy was not considered the primary beneficiary of Enable. Under the equity method of accounting, the investment was adjusted each period for contributions made, distributions received and OGE Energy's share of the investee's comprehensive income as adjusted for basis differences. In this Form 10-Q, Enable activity is included for the relevant portion of OGE Energy's 2021 information presented through December 2, 2021.

OGE Energy considered distributions received from Enable which did not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and were classified as operating activities in the statements of cash flows. OGE Energy considered distributions received from Enable in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment and are classified as investing activities in the statements of cash flows. Distributions received from Enable were $18.3 million during the three months ended March 31, 2021.

The following table presents a reconciliation of OGE Energy's equity in earnings of unconsolidated affiliates for the three months ended March 31, 2021.

	Three Months Ended
(In millions)	March 31, 2021
Enable net income	$	155.0
OGE Energy's percent ownership at period end	25.5		%
OGE Energy's portion of Enable net income	$	39.5
Amortization of basis difference and dilution recognition (A)	13.7
Equity in earnings of unconsolidated affiliates	$	53.2

(A)Includes loss on dilution, net of proportional basis difference recognition.

Related Party Transactions

OGE Energy charges operating costs to OG&E, and prior to December 2, 2021, charged operating costs to 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 are allocated either as overhead based primarily on labor costs or using the "Distrigas" method, which is a three-factor formula that uses an equal weighting of payroll, net operating revenues and gross property, plant and equipment.

OGE Energy and OG&E

OGE Energy charged operating costs to OG&E of $32.9 million and $35.8 million during the three months ended March 31, 2022 and 2021, respectively.

OGE Energy and Enable

Prior to December 2, 2021, OGE Energy and Enable were parties to several agreements whereby OGE Energy provided specified support services to Enable, such as certain information technology, payroll and benefits administration. Under these agreements, OGE Energy charged operating costs to Enable of $0.1 million during the three months ended March 31, 2021. OGE Energy had accounts receivable from Enable for amounts billed for support services of $0.3 million as of December 31, 2021, which is included in Accounts Receivable in OGE Energy's 2021 consolidated balance sheet.

OG&E and Enable

Enable provided gas transportation services to OG&E pursuant to agreements, which expire in May 2024 and December 2038, that granted Enable the responsibility of delivering natural gas to OG&E's generating facilities and performing an imbalance service. With this imbalance service, in accordance with the cash-out provision of the contract, OG&E purchased gas from Enable when Enable's deliveries exceeded OG&E's pipeline receipts. Enable purchased gas from OG&E when OG&E's pipeline receipts exceeded Enable's deliveries. Further, an additional gas transportation services contract with Enable became effective in December 2018 related to the project to convert Muskogee Units 4 and 5 from coal to natural gas. Upon the

closing of the merger between Enable and Energy Transfer, these contracts were assumed by Energy Transfer. The following table presents summarized related party transactions between OG&E and Enable during the three months ended March 31, 2021.

	Three Months Ended
(In millions)	March 31, 2021
Operating revenues:
Electricity to power electric compression assets	$	2.6
Fuel, purchased power and direct transmission expense:
Natural gas transportation services	$	4.7
Natural gas purchases (sales)	$	(12.2)

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Fair Value Measurements

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

The classification of the Registrants' 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).

OG&E had no financial instruments measured at fair value on a recurring basis at March 31, 2022 and December 31, 2021. The following table presents OGE Energy's financial instrument measured at fair value on a recurring basis and the carrying amount and fair value of the Registrants' financial instruments at March 31, 2022 and December 31, 2021, as well as the classification level within the fair value hierarchy.

	March 31,				December 31,
	2022				2021
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Classification
Financial instrument measured at fair value on a recurring basis:
OGE Energy investment in Energy Transfer's equity securities	$	1,067.4	$	1,067.4	$	785.1	$	785.1	Level 1
Financial instruments for which fair value is only disclosed:
Long-term Debt (including Long-term Debt due within one year):
OGE Energy Senior Notes	$	499.9	$	489.9	$	499.9	$	497.8	Level 2
OG&E Senior Notes	$	3,852.4	$	4,045.6	$	3,851.8	$	4,460.2	Level 2
OG&E Industrial Authority Bonds	$	135.4	$	135.4	$	135.4	$	135.4	Level 2
OG&E Tinker Debt	$	9.3	$	9.1	$	9.3	$	10.0	Level 3

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Stock-Based Compensation

3 Months Ended

Mar. 31, 2022

Share-based Payment Arrangement [Abstract]

Share-based Payment Arrangement [Text Block]

Stock-Based Compensation

The following table presents the Registrants' pre-tax compensation expense and related income tax benefit for the three months ended March 31, 2022 and 2021 related to performance units and restricted stock units for the Registrants' employees.

	OGE Energy				OG&E
	Three Months Ended March 31,				Three Months Ended March 31,
(In millions)	2022		2021		2022		2021
Performance units - total shareholder return	$	1.8	$	2.0	$	0.6	$	0.4
Restricted stock units	0.5		0.5		0.2		—
Total compensation expense	$	2.3	$	2.5	$	0.8	$	0.4
Income tax benefit	$	0.6	$	0.6	$	0.2	$	0.1

During the three months ended March 31, 2022, OGE Energy issued 27,278 shares of new common stock pursuant to OGE Energy's Stock Incentive Plan and issued an immaterial amount of treasury stock to satisfy payouts of restricted stock unit grants to the Registrants' employees.

During the three months ended March 31, 2022, OGE Energy granted 216,437 performance units (based on total shareholder return over a three-year period) and 116,539 restricted stock units (primarily a three-year cliff vesting period) to employees at $41.10 and $35.72 fair value per share, respectively. Of those performance units and restricted stock units granted, 60,923 and 32,804 were granted to OG&E employees, respectively, at $41.10 and $35.72 fair value per share, respectively.

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Income Taxes	3 Months Ended
	Mar. 31, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes OGE Energy files consolidated income tax returns in the U.S. federal jurisdiction and various state jurisdictions. OG&E is a part of the consolidated income tax return of OGE Energy. With few exceptions, the Registrants are no longer subject to U.S. federal tax or state and local examinations by tax authorities for years prior to 2018. Income taxes are generally allocated to each company in the affiliated group, including OG&E, based on its stand-alone taxable income or loss. Federal investment tax credits previously claimed on electric utility property have been deferred and will be amortized to income over the life of the related property. Additionally, OG&E earned federal tax credits associated with production from its wind facilities through January 2022. Oklahoma production and investment state tax credits are also earned on investments in electric and solar generating facilities which further reduce OG&E's effective tax rate.

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Common Equity

3 Months Ended

Mar. 31, 2022

Common Equity [Text Block]

Common Equity

Automatic Dividend Reinvestment and Stock Purchase Plan

OGE Energy issued no shares of common stock under its Automatic Dividend Reinvestment and Stock Purchase Plan during the three months ended March 31, 2022.

Earnings Per Share

Basic earnings per share is calculated by dividing net income attributable to OGE Energy by the weighted-average number of OGE Energy'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 OGE Energy consist of performance units and restricted stock units. The following table presents the calculation of basic and diluted earnings per share for OGE Energy.

	Three Months Ended March 31,
(In millions except per share data)	2022		2021
Net income	$	279.5	$	52.7
Average common shares outstanding:
Basic average common shares outstanding	200.2		200.1
Effect of dilutive securities:
Contingently issuable shares (performance and restricted stock units)	0.4		—
Diluted average common shares outstanding	200.6		200.1
Basic earnings per average common share	$	1.40	$	0.26
Diluted earnings per average common share	$	1.39	$	0.26
Anti-dilutive shares excluded from earnings per share calculation	—		—

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Long-Term Debt

3 Months Ended

Mar. 31, 2022

Long-term Debt, Unclassified [Abstract]

Long-Term Debt

Long-Term Debt

At March 31, 2022, the Registrants were in compliance with all of their 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 following table presents information about these bonds, which can be tendered at the option of the holder during the next 12 months.

Series			Date Due	Amount
				(In millions)
0.11%	-	0.64%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.11%	-	0.57%	Muskogee Industrial Authority, January 1, 2025	32.4
0.11%	-	0.64%	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, at 100 percent of 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 condensed balance sheets. OG&E believes that it has sufficient liquidity to meet these obligations.

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Short-Term Debt and Credit Facilities

3 Months Ended

Mar. 31, 2022

Short-term Debt [Abstract]

Short-Term Debt and Credit Facilities

Short-Term Debt and Credit Facilities

The Registrants borrow on a short-term basis, as necessary, by the issuance of commercial paper and by borrowings under their revolving credit agreements. OGE Energy also borrows under term credit agreements maturing in one year or less, as necessary. OGE Energy had $731.5 million and $486.9 million of short-term debt at March 31, 2022 and December 31, 2021, respectively. OG&E had $90.3 million and $101.3 million in advances from OGE Energy at March 31, 2022 and December 31, 2021, respectively.

The following table presents information regarding the Registrants' revolving credit agreements at March 31, 2022.

	Aggregate		Amount		Weighted-Average
Entity	Commitment		Outstanding (A)		Interest Rate			Expiration
	(In millions)
OGE Energy (B)	$	550.0	$	549.0	1.14	%	(E)	December 17, 2026
OG&E (C)(D)	550.0		182.9		1.11	%	(E)	December 17, 2026
Total	$	1,100.0	$	731.9	1.14	%

(A)Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at March 31, 2022.

(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)OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $350.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of December 17, 2026. At March 31, 2022, there were $48.7 million in intercompany borrowings under this agreement.

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

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

OG&E must obtain regulatory approval from the FERC in order to borrow on a short-term basis. OG&E has the necessary regulatory approvals to incur up to $800.0 million in short-term borrowings at any one time for a two-year period beginning January 1, 2021 and ending December 31, 2022.

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Retirement Plans and Postretirement Benefit Plans

3 Months Ended

Mar. 31, 2022

Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

Retirement Plans and Postretirement Benefit Plans In accordance with ASC Topic 715, "Compensation - Retirement Benefits," a one-time settlement charge is required to be recorded by an organization when lump sum payments or other settlements that relieve the organization from the responsibility for the pension benefit obligation during the plan year exceed the service cost and interest cost components of the organization's net periodic pension cost. During the three months ended March 31, 2022, the Registrants experienced an increase in both the number of employees electing to retire and the amount of lump sum payments paid to such employees upon retirement, which resulted in the Registrants recording pension plan settlement charges as presented in the Pension Plan net periodic benefit cost tables below. The pension settlement charges did not require a cash outlay by the Registrants and did not increase total pension expense over time, as the charge was an acceleration of costs that otherwise would be recognized as pension expense in future periods.

Net Periodic Benefit Cost

The following tables present the net periodic benefit cost components, before consideration of capitalized amounts, of OGE Energy's Pension Plan, Restoration of Retirement Income Plan and postretirement benefit plans that are included in the condensed financial statements. Service cost is presented within Other Operation and Maintenance Expense, and the remaining net periodic benefit cost components as listed in the following tables are presented within Other Net Periodic Benefit Expense in the statements of income. OG&E recovers specific amounts of pension and postretirement medical costs in rates approved in its Oklahoma rate reviews. In accordance with approved orders, OG&E defers the difference between actual pension and postretirement medical expenses and the amount approved in its last Oklahoma rate review as a regulatory asset or regulatory liability. These amounts have been recorded in the Pension tracker in the regulatory assets and liabilities table in Note 1 and within Other Net Periodic Benefit Expense in the statements of income.

	Pension Plan				Restoration of Retirement Income Plan
	Three Months Ended				Three Months Ended
OGE Energy	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	2.2	$	3.0	$	0.3	$	0.1
Interest cost	3.4		3.5		—		—
Expected return on plan assets	(6.8)		(8.4)		—		—
Amortization of net loss	1.9		2.8		—		0.1
Amortization of unrecognized prior service cost (A)	—		—		0.1		—
Settlement cost	13.2		26.4		—		—
Total net periodic benefit cost	13.9		27.3		0.4		0.2
Less: Amount paid by unconsolidated affiliates	—		0.1		—		—
Net periodic benefit cost	$	13.9	$	27.2	$	0.4	$	0.2

(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.

	Pension Plan				Restoration of Retirement Income Plan
	Three Months Ended				Three Months Ended
OG&E	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	1.7	$	2.1	$	—	$	—
Interest cost	2.6		2.5		—		—
Expected return on plan assets	(5.3)		(6.1)		—		—
Amortization of net loss	1.6		2.0		—		—
Settlement cost	3.6		22.2		—		—
Total net periodic benefit cost	4.2		22.7		—		—
Plus: Amount allocated from OGE Energy	1.8		3.9		0.4		0.2
Net periodic benefit cost	$	6.0	$	26.6	$	0.4	$	0.2

In addition to the net periodic benefit cost amounts recognized, as presented in the tables above, for the Pension and Restoration of Retirement Income Plans for the three months ended March 31, 2022 and 2021, the Registrants recognized the following:

	Three Months Ended March 31,
(In millions)	2022		2021
Increase of regulatory asset related to pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	1.9	$	20.7
Deferral of pension expense related to pension settlement charges:
Oklahoma jurisdiction (A)	$	4.7	$	23.7
Arkansas jurisdiction (A)	$	0.4	$	2.2

(A) Included in the pension regulatory asset or liability in each jurisdiction, as indicated in the regulatory assets and liabilities table in Note 1.

	OGE Energy				OG&E
	Postretirement Benefit Plans				Postretirement Benefit Plans
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	0.1	$	0.1	$	—	$	0.1
Interest cost	0.9		0.8		0.7		0.6
Expected return on plan assets	(0.4)		(0.5)		(0.4)		(0.4)
Amortization of net loss	0.5		0.7		0.5		0.7
Amortization of unrecognized prior service cost (A)	(1.0)		(1.7)		(0.9)		(1.3)
Total net periodic benefit cost	0.1		(0.6)		(0.1)		(0.3)
Less: Amount paid by unconsolidated affiliates (B)	—		(0.1)
Plus: Amount allocated from OGE Energy (B)					—		(0.1)
Net periodic benefit cost	$	0.1	$	(0.5)	$	(0.1)	$	(0.4)

(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)"Amount paid by unconsolidated affiliates" is only applicable to OGE Energy. "Amount allocated from OGE Energy" is only applicable to OG&E.

In addition to the net periodic benefit cost or income amounts recognized, as presented in the table above, for the postretirement benefit plans for the three months ended March 31, 2022 and 2021, the Registrants recognized the following:

	Three Months Ended March 31,
(In millions)	2022		2021
Increase (decrease) of regulatory liability related to postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	(0.3)	$	0.1

(A) Included in the Pension tracker, as presented in the regulatory assets and liabilities table in Note 1.

	OGE Energy				OG&E
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Capitalized portion of net periodic pension benefit cost	$	0.8	$	0.8	$	0.7	$	0.7
Capitalized portion of net periodic postretirement benefit cost	$	0.1	$	0.1	$	—	$	—

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Report of Business Segments

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

Report of Business Segments

Report of Business SegmentsOGE Energy 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. Prior to the Enable and Energy Transfer merger closing on December 2, 2021, OGE Energy's natural gas midstream operations segment included its equity method investment in Enable. Subsequent to December 2, 2021, OGE Energy's natural gas midstream operations segment includes its investment in Energy Transfer's equity securities and legacy Enable seconded employee pension and postretirement costs. 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. The following tables present the results of OGE Energy's business segments for the three months ended March 31, 2022 and 2021.

Three Months Ended March 31, 2022	Electric Utility		Natural Gas Midstream Operations		Other Operations		Eliminations		Total
(In millions)
Operating revenues	$	589.3	$	—	$	—	$	—	$	589.3
Fuel, purchased power and direct transmission expense	255.7		—		—		—		255.7
Other operation and maintenance	115.5		0.7		(1.2)		—		115.0
Depreciation and amortization	107.4		—		—		—		107.4
Taxes other than income	26.8		—		1.3		—		28.1
Operating income (loss)	83.9		(0.7)		(0.1)		—		83.1
Gain (loss) on equity securities	—		282.3		—		—		282.3
Other income	0.7		8.7		—		(0.1)		9.3
Interest expense	38.2		—		2.0		(0.1)		40.1
Income tax expense (benefit)	7.4		60.2		(12.5)		—		55.1
Net income	$	39.0	$	230.1	$	10.4	$	—	$	279.5
Total assets	$	11,898.8	$	1,068.8	$	320.9	$	(194.9)	$	13,093.6

Three Months Ended March 31, 2021	Electric Utility		Natural Gas Midstream Operations		Other Operations		Eliminations		Total
(In millions)
Operating revenues	$	1,630.6	$	—	$	—	$	—	$	1,630.6
Fuel, purchased power and direct transmission expense	1,346.8		—		—		—		1,346.8
Other operation and maintenance	110.3		0.4		(1.4)		—		109.3
Depreciation and amortization	98.7		—		—		—		98.7
Taxes other than income	25.7		0.1		1.4		—		27.2
Operating income (loss)	49.1		(0.5)		—		—		48.6
Equity in earnings of unconsolidated affiliates	—		53.2		—		—		53.2
Other income (expense)	1.7		(0.5)		(0.1)		(0.2)		0.9
Interest expense	38.4		—		1.2		(0.2)		39.4
Income tax expense (benefit)	1.2		14.3		(4.9)		—		10.6
Net income	$	11.2	$	37.9	$	3.6	$	—	$	52.7
Investment in unconsolidated affiliates	$	—	$	409.2	$	—	$	—	$	409.2
Total assets	$	11,248.2	$	415.4	$	521.6	$	(396.5)	$	11,788.7

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2022

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 15 and 16 to the financial statements included in the

Registrants' 2021 Form 10-K appropriately represent, in all material respects, the current status of the Registrants' material commitments and contingent liabilities.

Environmental Laws and Regulations

The activities of the Registrants 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 the Registrants' business activities in many ways, including the handling or disposal of waste material, planning for future construction activities to avoid or mitigate harm to threatened or endangered species and requiring the installation and operation of emissions or 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. Management believes that all of the Registrants' operations are in substantial compliance with current federal, state and local environmental standards.

Environmental regulation can increase the cost of planning, design, initial installation and operation of OG&E's facilities. Management continues to evaluate its compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market.

Other

In the normal course of business, the Registrants are 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 experts to assess the claim. If, in management's opinion, the Registrants have 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 condensed financial statements. At the present time, based on currently available information, the Registrants believe 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 their condensed financial statements and would not have a material adverse effect on their financial position, results of operations or cash flows.

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Regulated Operations

3 Months Ended

Mar. 31, 2022

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 financial statements included in the Registrants' 2021 Form 10-K appropriately represent, in all material respects, the current status of the Registrants' regulatory matters.

Completed Regulatory Matters

APSC Proceedings

Arkansas 2021 Formula Rate Plan Filing

In October 2021, OG&E filed its fourth evaluation report under its Formula Rate Plan, and on February 1, 2022, OG&E, the APSC General Staff and the Office of the Arkansas Attorney General filed a non-unanimous joint settlement agreement, which includes an annual electric revenue increase of $4.2 million. The only non-signatory to the settlement agreement agreed not to oppose the settlement. On March 4, 2022, the APSC issued a final order approving the non-unanimous settlement agreement, and new rates became effective April 1, 2022.

Pending Regulatory Matters

Various proceedings pending before state or federal regulatory agencies are described below. Unless stated otherwise, the Registrants cannot predict when the regulatory agency will act or what action the regulatory agency will take. The Registrants' financial results are dependent in part on timely and constructive decisions by the regulatory agencies that set OG&E's rates.

FERC Proceedings

Order for Sponsored Transmission Upgrades within SPP

Under the SPP Open Access Transmission Tariff, costs of participant-funded, or "sponsored," transmission upgrades may be recovered from other SPP customers whose transmission service depends on capacity enabled by the upgrade. The SPP

Open Access Transmission Tariff required the SPP to charge for these upgrades beginning in 2008, but the SPP had not been charging its customers for these upgrades due to information system limitations. However, the SPP had informed participants in the market that these charges would be forthcoming. In July 2016, the FERC granted the SPP's request to recover the charges not billed since 2008. The SPP subsequently billed OG&E for these charges and credited OG&E related to transmission upgrades that OG&E had sponsored, which resulted in OG&E being a net receiver of sponsored upgrade credits. The majority of these net credits were refunded to customers through OG&E's various rate riders that include SPP activity with the remaining amounts retained by OG&E.

Several companies that were net payers of Z2 charges sought rehearing of the FERC's July 2016 order; however, in November 2017, the FERC denied the rehearing requests. In January 2018, one of the impacted companies appealed the FERC's decision to the U.S. Court of Appeals for the District of Columbia Circuit. In July 2018, that court granted a motion requested by the FERC that the case be remanded back to the FERC for further examination and proceedings. In February 2019, the FERC reversed its July 2016 order and November 2017 rehearing denial, ruled that the SPP violated its tariff to charge for the 2008 through 2015 period in 2016, held that the SPP tariff provision that prohibited those charges could not be waived and ordered the SPP to develop a plan to refund the payments but not to implement the refunds until further ordered to do so. In response, in April 2019, OG&E filed a request for rehearing with the FERC, and in May 2019, OG&E filed a FERC 206 complaint against the SPP, alleging that the SPP's forced unwinding of the revenue credit payments to OG&E would violate the provisions of the Sponsored Upgrade Agreement and of the applicable tariff. OG&E's filing requested that the FERC rule that the SPP is not entitled to seek refunds or in any other way seek to unwind the revenue credit payments it had paid to OG&E pursuant to the Sponsored Upgrade Agreement. The SPP's response to OG&E's filing agreed that OG&E should be entitled to keep its Z2 payments and argued that the SPP should not be held responsible for those payments if refunds are ordered. Further, the SPP has requested the FERC to negotiate a global settlement with all impacted parties, including other project sponsors who, like OG&E, have also filed complaints at FERC contending that the payments they have received cannot properly be unwound.

In February 2020, the FERC denied OG&E's request for rehearing of its February 2019 order, denying the waiver and ruling that the SPP must seek refunds from project sponsors for Z2 payments for the 2008 through 2015 period and pay them back to transmission owners. The FERC also denied the SPP's request for a stay and for institution of settlement procedures. The FERC stated it would not institute settlement procedures unless parties on both sides of the matter requested them. The FERC did not rule on OG&E's complaint or the complaints of other project sponsors, or consider the SPP's refund plan. The FERC thus has not set any date for payment of refunds. In March 2020, OG&E petitioned the U.S. Court of Appeals for the District of Columbia Circuit for review of the FERC's order denying the waiver and requiring refunds. The court issued a decision on August 27, 2021, denying review and holding that the SPP was prohibited by the filed rate doctrine from imposing Z2 charges during the 2008 through 2015 historical period. The court further held that the FERC reasonably exercised its remedial authority to order the SPP to refund the retroactive upgrade charge. The court did not direct a time frame or procedures for the SPP to implement refunds. OG&E and the SPP filed a petition for rehearing of the court's decision, which was denied in October 2021. The court returned the matter to the FERC for action in accordance with its opinion in November 2021.

If the FERC proceeds to order refunds in full, OG&E estimates it would be required to refund $13.0 million, which is net of amounts paid to other utilities for upgrades and would be subject to interest at the FERC-approved rate. The SPP has stated in filings it made with the FERC while the appeal was pending that there are considerable complexities in implementing the refunds that will have to be resolved before they can be paid. Payment of refunds would shift recovery of these upgrade credits to future periods. The SPP filed an update on January 4, 2022 confirming that administering refunds would be complex and could take years unless the SPP is allowed to make certain simplifying assumptions. It also urged that all pending complaint proceedings, including four complaints against the SPP, be resolved before the refund process is ordered to begin. OG&E and other parties filed responses to the SPP report, and the matter remains pending at the FERC. Of the $13.0 million, the Registrants would be impacted by $5.0 million in expense that initially benefited the Registrants in 2016, and OG&E customers would incur a net impact of $8.0 million in expense through rider mechanisms or the FERC formula rate. As of March 31, 2022, the Registrants have reserved $13.0 million plus estimated interest for a potential refund.

In January 2020, the FERC acted on an SPP proposal to eliminate Attachment Z2 revenue crediting and replace it with a different rate mechanism that would provide project sponsors, such as OG&E, the same level of recovery, and rejected the proposal to the extent it would limit recovery to the amount of the upgrade sponsor's directly assigned upgrade costs with interest. The SPP resubmitted a proposal in April 2020 without this limited recovery, and with the alternative rate mechanism, and the FERC approved it in June 2020, effective July 1, 2020. No party sought rehearing of the order, and it is now final. This order would only prospectively impact OG&E and its recovery of any future upgrade costs that it may incur as a project sponsor subsequent to July 2020. All of the existing projects that are eligible to receive revenue credits under Attachment Z2, which includes the $13.0 million at issue in OG&E's appeal as discussed above, will continue to do so.

Incentive Adders for Transmission Rates

The FERC issued a NOPR in March 2020, and issued a supplemental NOPR in April 2021, proposing to update its transmission incentives policy. Among other things, the NOPR proposes (i) the current 50-basis point return on equity adder for RTO/ISO participation would be applicable only to transmitting utilities that join an RTO/ISO, and this incentive would only apply for the first three years in which the utility is an RTO/ISO member and (ii) transmitting utilities that have been members of an RTO/ISO for three years or more, such as OG&E, would be required to make a compliance filing to remove the existing return on equity adder from their rates. OG&E is currently evaluating the potential impacts of this proposed rule. Currently, there is no specific deadline for the FERC to take further action, and it is unknown whether the FERC will address the RTO participation adder individually or as part of a larger order on transmission incentives.

APSC Proceedings

Winter Storm Uri

In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. On April 1, 2021, OG&E filed with the APSC a Motion for Authority to Establish Special Regulatory Treatment within the Energy Cost Recovery Rider to Defer Extraordinary Fuel Costs Incurred Due to Winter Storm Uri. More specifically, OG&E's motion sought approval to defer, amortize and recover the extraordinary fuel costs over a ten-year period with a carrying charge of OG&E's pre-tax rate of return of 6.60 percent, through a special factor within OG&E's Energy Cost Recovery Rider beginning with the first billing cycle of May 2021. On April 13, 2021, the APSC issued an order allowing OG&E interim recovery at an interest rate equal to the customer deposit interest rate, which is currently 0.8 percent, over a period of ten years beginning with the first billing cycle of May 2021. Recovery is subject to a true-up after the APSC determines the appropriate allocation, length of recovery and carrying charge. On May 4, 2021, OG&E filed testimony further supporting its 10-year amortization period and a carrying charge of OG&E's pre-tax rate of return of 6.60 percent.

In April 2021, Arkansas enacted legislation to amend its storm recovery securitization statute to allow for both electric and gas utilities to recover through securitization extraordinary natural gas, fuel and purchased power costs caused by storms. The amended statute authorizes the APSC to issue a financing order for the issuance of securitization bonds upon a finding it is reasonably expected to lower overall costs or mitigate rate impacts as compared with traditional utility financing. Upon the initiation of a securitization application, the APSC has 135 days to issue an order. The requesting utility has two years from the date of the financing order to issue the securitization bonds. The amended statute allows carrying costs at a utility's weighted average cost of capital from the date of when the costs were incurred until the date when bonds are ultimately issued.

On May 20, 2021, OG&E filed a motion for suspension of procedural schedule, which the APSC approved, to investigate and evaluate the potential securitization recovery of the Arkansas jurisdictional portion of the Winter Storm Uri costs. OG&E may apply for securitization in mid-2022 if it is deemed to strike the right balance between protecting the credit strength of OG&E and providing customer savings. As of March 31, 2022, OG&E has deferred $86.3 million to a regulatory asset, as indicated in Note 1.

Arkansas 2021 Formula Rate Plan Filing - Extension

In October 2021, OG&E filed a request to extend its Formula Rate Plan Rider for an additional five years. On April 1, 2022, the APSC issued an order granting OG&E an extension of the Formula Rate Plan Rider under the terms and conditions to be detailed in a subsequent order no later than May 18, 2022.

OCC Proceedings

Winter Storm Uri

In December 2021, the OCC approved a settlement agreement in a final financing order authorizing the issuance of securitization bonds in an amount up to $760.0 million, which includes estimated finance costs and is subject to change for carrying costs, any updates from the SPP settlement process and actual securitization issuance costs. On December 22, 2021, the ODFA requested the Oklahoma Supreme Court to certify the proposed securitization bonds. On May 3, 2022, the Oklahoma Supreme Court issued a decision approving the securitization bonds. OG&E continues to work with the ODFA to issue bonds consistent with the OCC's order. The securitization process is expected to be completed in mid-2022.

Oklahoma Retail Electric Supplier Certified Territory Act Causes

Several rural electric cooperative electricity suppliers have filed complaints with the OCC alleging that OG&E has violated the Oklahoma Retail Electric Supplier Certified Territory Act. OG&E believes it is lawfully serving customers specifically exempted from this act and has presented evidence and testimony to the OCC supporting its position. There have been five complaint cases initiated at the OCC, and the OCC has issued decisions on each of them. The OCC ruled in favor of the electric cooperatives in three of those cases and ruled in favor of OG&E in two of those cases. All five of those cases have been appealed to the Oklahoma Supreme Court, where they have been made companion cases but will be individually briefed and have individual final decisions.

If the Oklahoma Supreme Court ultimately were to find that some or all of the customers being served are not exempted from the Oklahoma Retail Electric Supplier Certified Territory Act, OG&E would have to evaluate the recoverability of some plant investments made to serve these customers. The total amount of OG&E's plant investments made to serve the customers in all five cases is approximately $28.0 million, of which $11.7 million applies to the three cases where the OCC ruled in favor of the electric cooperatives. In addition to the evaluation of the recoverability of the investments, OG&E may also be required to reimburse certified territory suppliers for an amount of lost revenue. The amount of such lost revenue would depend on how the OCC calculates the revenue requirement but could range from approximately $31.4 million to $42.7 million for all five cases, of which $3.2 million to $5.1 million would apply to the three cases where the OCC ruled in favor of the electric cooperatives.

2021 Oklahoma General Rate Review

In December 2021, OG&E filed a general rate review in Oklahoma seeking a rate increase of $163.5 million and a 10.2 percent return on equity based on a common equity percentage of 53.37 percent. The rate review includes a request for recovery of $1.2 billion of capital investment since the last general rate review. On April 27, 2022, initial intervenor testimony was filed with the OCC, and a hearing on the merits is expected to be held toward the end of the second quarter of 2022.

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Consolidation, Policy [Policy Text Block]

Organization

OGE Energy is a holding company with investments in energy and energy services providers offering physical delivery and related services for electricity in Oklahoma and western Arkansas and natural gas, crude oil and NGLs across the U.S. OGE Energy conducts these activities through two business segments: (i) electric utility and (ii) natural gas midstream operations. The accounts of OGE Energy and its wholly-owned subsidiaries, including OG&E, are included in OGE Energy's condensed consolidated financial statements. All intercompany transactions and balances are eliminated in such consolidation. On December 2, 2021, Energy Transfer and Enable closed their merger transaction. For periods prior to the closing date, OGE Energy accounted for its investment in Enable as an equity method investment and reported it within OGE Energy's natural gas midstream operations segment.

Electric Utility Operations. OGE Energy's electric utility operations are conducted through OG&E, which generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. OG&E's rates are subject to regulation by the OCC, the APSC and the FERC. OG&E was incorporated in 1902 under the laws of the Oklahoma Territory and is a wholly-owned subsidiary of OGE Energy. OG&E is the largest electric utility in Oklahoma, and its franchised service territory includes Fort Smith, Arkansas and the surrounding communities. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.

Natural Gas Midstream Operations. As indicated above, on December 2, 2021, Enable and Energy Transfer closed their merger transaction. As a result of such transaction, OGE Energy exchanged its investment in Enable for limited partner units of Energy Transfer, and Sean Trauschke and Luke Corbett, OGE Energy's representatives on the board of Enable's general partner, ceased serving as directors of the general partner of Enable. Subsequent to the merger, OGE Energy's natural gas midstream operations segment includes OGE Energy's investment in Energy Transfer's equity securities and legacy Enable seconded employee pension and postretirement costs. The investment in Energy Transfer's equity securities is held through wholly-owned subsidiaries and ultimately OGE Holdings. At March 31, 2022, OGE Energy owned 95,389,721 of Energy Transfer's limited partner units, which represented an approximately three percent ownership based on the latest publicly available information filed by Energy Transfer. OGE Energy does not own general partner units in or have board representation at Energy Transfer. As such, OGE Energy accounts for its investment in Energy Transfer as an investment in equity securities, as further discussed below. OGE Energy intends to exit the midstream segment in a prudent manner.

Basis of Accounting, Policy [Policy Text Block]

Basis of Presentation

The condensed financial statements included herein have been prepared by the Registrants, 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 Registrants believe 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 financial position of the Registrants at March 31, 2022 and December 31, 2021, the results of the Registrants' operations for the three months ended March 31, 2022 and 2021 and the Registrants' cash flows for the three months ended March 31, 2022 and 2021 have been included and are of a normal, recurring nature except as otherwise disclosed. Management also has evaluated the impact of events occurring after March 31, 2022 up to the date of issuance of these condensed financial statements, and these statements contain all necessary adjustments and disclosures resulting from that evaluation.

Due to seasonal fluctuations and other factors, the Registrants' operating results for the three months ended March 31, 2022 are not necessarily indicative of the results that may be expected for the year ending December 31, 2022 or for any future period. The condensed financial statements and notes thereto should be read in conjunction with the audited financial statements and notes thereto included in the Registrants'

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 incurred 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 incurred costs and obligations as regulatory assets or liabilities if, based on regulatory orders or other available evidence, it is probable that the costs or obligations 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 or liabilities, which could have significant financial effects.

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

The classification of the Registrants' 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).

OG&E had no financial instruments measured at fair value on a recurring basis at March 31, 2022 and December 31, 2021. The following table presents OGE Energy's financial instrument measured at fair value on a recurring basis and the carrying amount and fair value of

Income Tax, Policy [Policy Text Block]

OGE Energy files consolidated income tax returns in the U.S. federal jurisdiction and various state jurisdictions.Income taxes are generally allocated to each company in the affiliated group, including OG&E, based on its stand-alone taxable income or loss. Federal investment tax credits previously claimed on electric utility property have been deferred and will be amortized to income over the life of the related property. Additionally, OG&E earned federal tax credits associated with production from its wind facilities through January 2022. Oklahoma production and investment state tax credits are also earned on investments in electric and solar generating facilities which further reduce OG&E's effective tax rate.

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 OGE Energy'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 OGE Energy consist of performance units and restricted stock units.

Financing Receivable, Allowance for Credit Losses, Policy for Uncollectible Amounts

Allowance for Uncollectible Accounts Receivable

Customer balances are generally written off if not collected within six months after the final billing date. The allowance for uncollectible accounts receivable for OG&E is generally calculated by multiplying the last six months of electric revenue by the provision rate, which is based on a 12-month historical average of actual balances written off and is adjusted for current conditions and supportable forecasts as necessary. To the extent the historical collection rates, when incorporating forecasted conditions, are not representative of future collections, there could be an effect on the amount of uncollectible expense recognized, such as in response to COVID-19 impacts. Also, a portion of the uncollectible provision related to fuel within the Oklahoma jurisdiction is being recovered through the fuel adjustment clause. The allowance for uncollectible

accounts receivable is a reduction to Accounts Receivable in the condensed balance sheets and is included in Other Operation and Maintenance Expense in the condensed statements of income.

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

Equity Method Investments [Policy Text Block]

Investment in Unconsolidated Affiliates (Enable)

For more information concerning OGE Energy's former equity method investment in Enable, including the merger transaction with Energy Transfer and OGE Energy's previous accounting for its investment in Enable, see Notes 1 and 5 within "Item 8. Financial Statements and Supplementary Data" in OGE Energy's 2021 Form 10-K. Prior to December 2, 2021, OGE Energy's investment in Enable was considered to be a variable interest entity; however, OGE Energy was not considered the primary beneficiary of Enable. Under the equity method of accounting, the investment was adjusted each period for contributions made, distributions received and OGE Energy's share of the investee's comprehensive income as adjusted for basis differences. In this Form 10-Q, Enable activity is included for the relevant portion of OGE Energy's 2021 information presented through December 2, 2021.

OGE Energy considered distributions received from Enable which did not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and were classified as operating activities in the statements of cash flows. OGE Energy considered distributions received from Enable in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment and are classified as investing activities in the statements of cash flows. Distributions received from Enable were $18.3 million during the three months ended March 31, 2021.

The following table presents a reconciliation of OGE Energy's equity in earnings of unconsolidated affiliates for the three months ended March 31, 2021.

	Three Months Ended
(In millions)	March 31, 2021
Enable net income	$	155.0
OGE Energy's percent ownership at period end	25.5		%
OGE Energy's portion of Enable net income	$	39.5
Amortization of basis difference and dilution recognition (A)	13.7
Equity in earnings of unconsolidated affiliates	$	53.2

(A)Includes loss on dilution, net of proportional basis difference recognition.

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Fair Value Measures and Disclosures (Policies)

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

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

The classification of the Registrants' 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).

OG&E had no financial instruments measured at fair value on a recurring basis at March 31, 2022 and December 31, 2021. The following table presents OGE Energy's financial instrument measured at fair value on a recurring basis and the carrying amount and fair value of

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Regulatory Assets and Liabilities [Table Text Block]

The following table presents a summary of OG&E's regulatory assets and liabilities.

	March 31,		December 31,
(In millions)	2022		2021
REGULATORY ASSETS
Current:
Fuel clause under recoveries	$	182.3	$	151.9
SPP cost tracker under recovery (A)	9.4		9.3
Oklahoma Energy Efficiency Rider under recoveries (A)	3.4		11.7
Other (A)	8.3		9.7
Total current regulatory assets	$	203.4	$	182.6
Non-current:
Oklahoma Winter Storm Uri costs	$	749.2	$	747.9
Oklahoma deferred storm expenses	204.6		172.8
Benefit obligations regulatory asset	104.4		109.2
Arkansas Winter Storm Uri costs	86.3		88.9
Pension tracker	45.4		42.9
Sooner Dry Scrubbers	18.7		18.9
Arkansas deferred pension expenses	12.3		12.1
Unamortized loss on reacquired debt	8.7		8.9
COVID-19 impacts	8.1		8.2
Frontier Plant deferred expenses	6.4		6.7
Smart Grid	2.2		3.9
Other	10.4		10.4
Total non-current regulatory assets	$	1,256.7	$	1,230.8
REGULATORY LIABILITIES
Current:
Other (B)	$	1.6	$	2.5
Total current regulatory liabilities	$	1.6	$	2.5
Non-current:
Income taxes refundable to customers, net	$	927.3	$	930.7
Accrued removal obligations, net	292.7		296.8
Other	3.3		3.6
Total non-current regulatory liabilities	$	1,223.3	$	1,231.1

(A)Included in Other Current Assets in the condensed balance sheets.

(B)Included in Other Current Liabilities in the condensed balance sheets.

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

The following tables present changes in the components of accumulated other comprehensive income (loss) attributable to OGE Energy during the three months ended March 31, 2022 and 2021. All amounts below are presented net of tax.

(In millions)	Pension Plan and Restoration of Retirement Income Plan		Postretirement Benefit Plans		Total
Balance at December 31, 2021	$	(26.1)	$	1.3	$	(24.8)
Other comprehensive income (loss) before reclassifications	—		—		—
Amounts reclassified from accumulated other comprehensive income	0.4		—		0.4
Settlement cost	7.4		—		7.4
Balance at March 31, 2022	$	(18.3)	$	1.3	$	(17.0)

(In millions)	Pension Plan and Restoration of Retirement Income Plan		Postretirement Benefit Plans		Other Comprehensive Gain (Loss) from Unconsolidated Affiliates		Total
Balance at December 31, 2020	$	(34.1)	$	3.3	$	(1.3)	$	(32.1)
Other comprehensive income before reclassifications	—		—		0.1		0.1
Amounts reclassified from accumulated other comprehensive income (loss)	0.6		(0.3)		—		0.3
Settlement cost	3.1		—		—		3.1
Balance at March 31, 2021	$	(30.4)	$	3.0	$	(1.2)	$	(28.6)

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

The following table presents significant amounts reclassified out of accumulated other comprehensive income (loss) attributable to OGE Energy by the respective line items in net income (loss) during the three months ended March 31, 2022 and 2021.

Details about Accumulated Other Comprehensive Income (Loss) Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)				Affected Line Item in OGE Energy's Statements of Income
	Three Months Ended
	March 31,
(In millions)	2022		2021
Amortization of Pension Plan and Restoration of Retirement Income Plan items:
Actuarial losses	$	(0.4)	$	(0.8)	(A)
Prior service cost	(0.1)		—		(A)
Settlement cost	(9.6)		(4.1)		(A)
	(10.1)		(4.9)		Income Before Taxes
	(2.3)		(1.2)		Income Tax Expense
	$	(7.8)	$	(3.7)	Net Income
Amortization of postretirement benefit plans items:
Prior service credit	$	—	$	0.4	(A)
	—		0.4		Income Before Taxes
	—		0.1		Income Tax Expense
	$	—	$	0.3	Net Income
Total reclassifications for the period, net of tax	$	(7.8)	$	(3.4)	Net Income

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

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

The following table presents a reconciliation of OGE Energy's equity in earnings of unconsolidated affiliates for the three months ended March 31, 2021.

	Three Months Ended
(In millions)	March 31, 2021
Enable net income	$	155.0
OGE Energy's percent ownership at period end	25.5		%
OGE Energy's portion of Enable net income	$	39.5
Amortization of basis difference and dilution recognition (A)	13.7
Equity in earnings of unconsolidated affiliates	$	53.2

(A)Includes loss on dilution, net of proportional basis difference recognition.

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Accounting Pronouncements (Tables)	3 Months Ended
	Mar. 31, 2022
Accounting Changes and Error Corrections [Abstract]
Accounting Standards Update and Change in Accounting Principle	The Registrants believe that recently adopted and recently issued accounting standards that are not yet effective do not appear to have a material impact on the Registrants' financial position, results of operations or cash flows upon adoption.

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Revenue from Contracts with Customers (Tables)

3 Months Ended

Mar. 31, 2022

Disaggregation of Revenue [Line Items]

Disaggregation of Revenue [Table Text Block]

The following table presents OG&E's revenues from contracts with customers disaggregated by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "OG&E (Electric Utility) Results of Operations" within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations."

	Three Months Ended March 31,
(In millions)	2022		2021
Residential	$	226.8	$	568.2
Commercial	128.1		307.5
Industrial	57.4		146.7
Oilfield	53.2		160.8
Public authorities and street light	48.0		123.1
System sales revenues	513.5		1,306.3
Provision for tax refund	(0.6)		—
Integrated market	22.8		302.1
Transmission	35.8		36.3
Other	6.6		(23.7)
Revenues from contracts with customers (A)	$	578.1	$	1,621.0

(A)In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. Operating revenues for the three months ended March 31, 2021 significantly increased due to increased fuel, purchased power and direct transmission expenses, which are generally recoverable from customers, as a result of Winter Storm Uri. For further discussion, see Note 14 and "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operation."

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Investment in Unconsolidated Affiliates (Tables)

3 Months Ended

Mar. 31, 2022

Reconciliation of Basis Difference [Line Items]

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

The following table presents a reconciliation of OGE Energy's equity in earnings of unconsolidated affiliates for the three months ended March 31, 2021.

	Three Months Ended
(In millions)	March 31, 2021
Enable net income	$	155.0
OGE Energy's percent ownership at period end	25.5		%
OGE Energy's portion of Enable net income	$	39.5
Amortization of basis difference and dilution recognition (A)	13.7
Equity in earnings of unconsolidated affiliates	$	53.2

(A)Includes loss on dilution, net of proportional basis difference recognition.

Schedule of Related Party Transactions [Table Text Block]

The following table presents summarized related party transactions between OG&E and Enable during the three months ended March 31, 2021.

	Three Months Ended
(In millions)	March 31, 2021
Operating revenues:
Electricity to power electric compression assets	$	2.6
Fuel, purchased power and direct transmission expense:
Natural gas transportation services	$	4.7
Natural gas purchases (sales)	$	(12.2)

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

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

The following table presents OGE Energy's financial instrument measured at fair value on a recurring basis and the carrying amount and fair value of the Registrants' financial instruments at March 31, 2022 and December 31, 2021, as well as the classification level within the fair value hierarchy.

	March 31,				December 31,
	2022				2021
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Classification
Financial instrument measured at fair value on a recurring basis:
OGE Energy investment in Energy Transfer's equity securities	$	1,067.4	$	1,067.4	$	785.1	$	785.1	Level 1
Financial instruments for which fair value is only disclosed:
Long-term Debt (including Long-term Debt due within one year):
OGE Energy Senior Notes	$	499.9	$	489.9	$	499.9	$	497.8	Level 2
OG&E Senior Notes	$	3,852.4	$	4,045.6	$	3,851.8	$	4,460.2	Level 2
OG&E Industrial Authority Bonds	$	135.4	$	135.4	$	135.4	$	135.4	Level 2
OG&E Tinker Debt	$	9.3	$	9.1	$	9.3	$	10.0	Level 3

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Stock-Based Compensation (Tables)

3 Months Ended

Mar. 31, 2022

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Share-based Payment Arrangement, Cost by Plan [Table Text Block]

The following table presents the Registrants' pre-tax compensation expense and related income tax benefit for the three months ended March 31, 2022 and 2021 related to performance units and restricted stock units for the Registrants' employees.

	OGE Energy				OG&E
	Three Months Ended March 31,				Three Months Ended March 31,
(In millions)	2022		2021		2022		2021
Performance units - total shareholder return	$	1.8	$	2.0	$	0.6	$	0.4
Restricted stock units	0.5		0.5		0.2		—
Total compensation expense	$	2.3	$	2.5	$	0.8	$	0.4
Income tax benefit	$	0.6	$	0.6	$	0.2	$	0.1

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Common Equity (Tables)

3 Months Ended

Mar. 31, 2022

Equity [Abstract]

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

The following table presents the calculation of basic and diluted earnings per share for OGE Energy.

	Three Months Ended March 31,
(In millions except per share data)	2022		2021
Net income	$	279.5	$	52.7
Average common shares outstanding:
Basic average common shares outstanding	200.2		200.1
Effect of dilutive securities:
Contingently issuable shares (performance and restricted stock units)	0.4		—
Diluted average common shares outstanding	200.6		200.1
Basic earnings per average common share	$	1.40	$	0.26
Diluted earnings per average common share	$	1.39	$	0.26
Anti-dilutive shares excluded from earnings per share calculation	—		—

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Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2022

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 following table presents information about these bonds, which can be tendered at the option of the holder during the next 12 months.

Series			Date Due	Amount
				(In millions)
0.11%	-	0.64%	Garfield Industrial Authority, January 1, 2025	$	47.0
0.11%	-	0.57%	Muskogee Industrial Authority, January 1, 2025	32.4
0.11%	-	0.64%	Muskogee Industrial Authority, June 1, 2027	56.0
Total (redeemable during next 12 months)				$	135.4

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Short-Term Debt and Credit Facilities (Tables)

3 Months Ended

Mar. 31, 2022

Short-term Debt [Abstract]

Schedule of Line of Credit Facilities [Table Text Block]

The following table presents information regarding the Registrants' revolving credit agreements at March 31, 2022.

	Aggregate		Amount		Weighted-Average
Entity	Commitment		Outstanding (A)		Interest Rate			Expiration
	(In millions)
OGE Energy (B)	$	550.0	$	549.0	1.14	%	(E)	December 17, 2026
OG&E (C)(D)	550.0		182.9		1.11	%	(E)	December 17, 2026
Total	$	1,100.0	$	731.9	1.14	%

(A)Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at March 31, 2022.

(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)OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $350.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of December 17, 2026. At March 31, 2022, there were $48.7 million in intercompany borrowings under this agreement.

(E)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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Retirement Plans and Postretirement Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2022

Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

The following tables present the net periodic benefit cost components, before consideration of capitalized amounts, of OGE Energy's Pension Plan, Restoration of Retirement Income Plan and postretirement benefit plans that are included in the condensed financial statements. Service cost is presented within Other Operation and Maintenance Expense, and the remaining net periodic benefit cost components as listed in the following tables are presented within Other Net Periodic Benefit Expense in the statements of income. OG&E recovers specific amounts of pension and postretirement medical costs in rates approved in its Oklahoma rate reviews. In accordance with approved orders, OG&E defers the difference between actual pension and postretirement medical expenses and the amount approved in its last Oklahoma rate review as a regulatory asset or regulatory liability. These amounts have been recorded in the Pension tracker in the regulatory assets and liabilities table in Note 1 and within Other Net Periodic Benefit Expense in the statements of income.

	Pension Plan				Restoration of Retirement Income Plan
	Three Months Ended				Three Months Ended
OGE Energy	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	2.2	$	3.0	$	0.3	$	0.1
Interest cost	3.4		3.5		—		—
Expected return on plan assets	(6.8)		(8.4)		—		—
Amortization of net loss	1.9		2.8		—		0.1
Amortization of unrecognized prior service cost (A)	—		—		0.1		—
Settlement cost	13.2		26.4		—		—
Total net periodic benefit cost	13.9		27.3		0.4		0.2
Less: Amount paid by unconsolidated affiliates	—		0.1		—		—
Net periodic benefit cost	$	13.9	$	27.2	$	0.4	$	0.2

(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.

	Pension Plan				Restoration of Retirement Income Plan
	Three Months Ended				Three Months Ended
OG&E	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	1.7	$	2.1	$	—	$	—
Interest cost	2.6		2.5		—		—
Expected return on plan assets	(5.3)		(6.1)		—		—
Amortization of net loss	1.6		2.0		—		—
Settlement cost	3.6		22.2		—		—
Total net periodic benefit cost	4.2		22.7		—		—
Plus: Amount allocated from OGE Energy	1.8		3.9		0.4		0.2
Net periodic benefit cost	$	6.0	$	26.6	$	0.4	$	0.2

In addition to the net periodic benefit cost amounts recognized, as presented in the tables above, for the Pension and Restoration of Retirement Income Plans for the three months ended March 31, 2022 and 2021, the Registrants recognized the following:

	Three Months Ended March 31,
(In millions)	2022		2021
Increase of regulatory asset related to pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	1.9	$	20.7
Deferral of pension expense related to pension settlement charges:
Oklahoma jurisdiction (A)	$	4.7	$	23.7
Arkansas jurisdiction (A)	$	0.4	$	2.2

(A) Included in the pension regulatory asset or liability in each jurisdiction, as indicated in the regulatory assets and liabilities table in Note 1.

	OGE Energy				OG&E
	Postretirement Benefit Plans				Postretirement Benefit Plans
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Service cost	$	0.1	$	0.1	$	—	$	0.1
Interest cost	0.9		0.8		0.7		0.6
Expected return on plan assets	(0.4)		(0.5)		(0.4)		(0.4)
Amortization of net loss	0.5		0.7		0.5		0.7
Amortization of unrecognized prior service cost (A)	(1.0)		(1.7)		(0.9)		(1.3)
Total net periodic benefit cost	0.1		(0.6)		(0.1)		(0.3)
Less: Amount paid by unconsolidated affiliates (B)	—		(0.1)
Plus: Amount allocated from OGE Energy (B)					—		(0.1)
Net periodic benefit cost	$	0.1	$	(0.5)	$	(0.1)	$	(0.4)

(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)"Amount paid by unconsolidated affiliates" is only applicable to OGE Energy. "Amount allocated from OGE Energy" is only applicable to OG&E.

In addition to the net periodic benefit cost or income amounts recognized, as presented in the table above, for the postretirement benefit plans for the three months ended March 31, 2022 and 2021, the Registrants recognized the following:

	Three Months Ended March 31,
(In millions)	2022		2021
Increase (decrease) of regulatory liability related to postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	(0.3)	$	0.1

(A) Included in the Pension tracker, as presented in the regulatory assets and liabilities table in Note 1.

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

	OGE Energy				OG&E
	Three Months Ended				Three Months Ended
	March 31,				March 31,
(In millions)	2022		2021		2022		2021
Capitalized portion of net periodic pension benefit cost	$	0.8	$	0.8	$	0.7	$	0.7
Capitalized portion of net periodic postretirement benefit cost	$	0.1	$	0.1	$	—	$	—

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Report of Business Segments (Tables)

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

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

The following tables present the results of OGE Energy's business segments for the three months ended March 31, 2022 and 2021.

Three Months Ended March 31, 2022	Electric Utility		Natural Gas Midstream Operations		Other Operations		Eliminations		Total
(In millions)
Operating revenues	$	589.3	$	—	$	—	$	—	$	589.3
Fuel, purchased power and direct transmission expense	255.7		—		—		—		255.7
Other operation and maintenance	115.5		0.7		(1.2)		—		115.0
Depreciation and amortization	107.4		—		—		—		107.4
Taxes other than income	26.8		—		1.3		—		28.1
Operating income (loss)	83.9		(0.7)		(0.1)		—		83.1
Gain (loss) on equity securities	—		282.3		—		—		282.3
Other income	0.7		8.7		—		(0.1)		9.3
Interest expense	38.2		—		2.0		(0.1)		40.1
Income tax expense (benefit)	7.4		60.2		(12.5)		—		55.1
Net income	$	39.0	$	230.1	$	10.4	$	—	$	279.5
Total assets	$	11,898.8	$	1,068.8	$	320.9	$	(194.9)	$	13,093.6

Three Months Ended March 31, 2021	Electric Utility		Natural Gas Midstream Operations		Other Operations		Eliminations		Total
(In millions)
Operating revenues	$	1,630.6	$	—	$	—	$	—	$	1,630.6
Fuel, purchased power and direct transmission expense	1,346.8		—		—		—		1,346.8
Other operation and maintenance	110.3		0.4		(1.4)		—		109.3
Depreciation and amortization	98.7		—		—		—		98.7
Taxes other than income	25.7		0.1		1.4		—		27.2
Operating income (loss)	49.1		(0.5)		—		—		48.6
Equity in earnings of unconsolidated affiliates	—		53.2		—		—		53.2
Other income (expense)	1.7		(0.5)		(0.1)		(0.2)		0.9
Interest expense	38.4		—		1.2		(0.2)		39.4
Income tax expense (benefit)	1.2		14.3		(4.9)		—		10.6
Net income	$	11.2	$	37.9	$	3.6	$	—	$	52.7
Investment in unconsolidated affiliates	$	—	$	409.2	$	—	$	—	$	409.2
Total assets	$	11,248.2	$	415.4	$	521.6	$	(396.5)	$	11,788.7

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Summary of Significant Accounting Policies Equity Ownership (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Equity Securities, FV-NI, Gain (Loss)	$ 282.3	$ 0.0
Investment Owned, Balance, Shares	95,389,721
Proceeds from Equity Method Investment, Distribution	$ 16.7
Equity in earnings of unconsolidated affiliates	$ 0.0	53.2
Equity Securities Sold During Period	21,750,000
Proceeds from Sales of Equity Securities	$ 246.0
Distributions from unconsolidated affiliates	$ 0.0	$ 18.3

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Regulated Operations (Details) - USD ($) $ in Millions		Mar. 31, 2022	Dec. 31, 2021
Schedule of Regulatory Assets and Liabilities [Line Items]
Fuel clause under recoveries		$ 182.3	$ 151.9
Current Regulatory Assets		203.4	182.6
Non-Current Regulatory Assets		1,256.7	1,230.8
Current Regulatory Liabilities		1.6	2.5
Non-Current Regulatory Liabilities		1,223.3	1,231.1
Other (B)
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Liabilities	[1]	1.6	2.5
Non-Current Regulatory Liabilities		3.3	3.6
Income taxes recoverable from customers, net
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		927.3	930.7
Accrued removal obligations, net
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		292.7	296.8
Winter Storm Uri costs | OKLAHOMA
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		749.2	747.9
Winter Storm Uri costs | ARKANSAS
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		86.3	88.9
Benefit obligations regulatory asset
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		104.4	109.2
Oklahoma deferred storm expenses
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		204.6	172.8
Smart Grid
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		2.2	3.9
Dry Scrubber Regulatory Asset [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		18.7	18.9
Unamortized loss on reacquired debt
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		8.7	8.9
Deferred Pension Expenses [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		12.3	12.1
Other Regulatory Asset [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Assets	[2]	8.3	9.7
Non-Current Regulatory Assets		10.4	10.4
Pension tracker
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		45.4	42.9
SPP Cost Tracker Rider Under Recovery
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Assets	[2]	9.4	9.3
COVID-19 Deferred Expenses
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		8.1	8.2
Oklahoma Energy Efficiency Rider Under Recovery
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Assets	[2]	3.4	11.7
Deferred Plant Expense
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		$ 6.4	$ 6.7

[1] Included in Other Current Liabilities in the condensed balance sheets.

[2] Included in Other Current Assets in the condensed balance sheets.

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Summary of Significant Accounting Policies Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (17.0)	$ (28.6)	$ (24.8)	$ (32.1)
Other Comprehensive Income (Loss), before Reclassifications, before Tax		0.1
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0.0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0.4	0.3
Accumulated Defined Benefit Plans Adjustment, Net Unamortized Gain (Loss) [Member]
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax		(1.2)		(1.3)
Other Comprehensive Income (Loss), before Reclassifications, before Tax		0.1
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		0.0
Accumulated Defined Benefit Plans Adjustment, Net Unamortized Gain (Loss) [Member] | Pension Plan [Member]
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax	(18.3)	(30.4)	(26.1)	(34.1)
Other Comprehensive Income (Loss), before Reclassifications, before Tax	0.0	0.0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0.4	0.6
Accumulated Defined Benefit Plans Adjustment, Net Unamortized Gain (Loss) [Member] | Other Postretirement Benefits Plan [Member]
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax	1.3	3.0	$ 1.3	$ 3.3
Other Comprehensive Income (Loss), before Reclassifications, before Tax	0.0	0.0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0.0	(0.3)
Settlement Cost [Member]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	7.4	3.1
Settlement Cost [Member] | Accumulated Defined Benefit Plans Adjustment, Net Unamortized Gain (Loss) [Member]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax		0.0
Settlement Cost [Member] | Accumulated Defined Benefit Plans Adjustment, Net Unamortized Gain (Loss) [Member] | Pension Plan [Member]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	7.4	3.1
Settlement Cost [Member] | Accumulated Defined Benefit Plans Adjustment, Net Unamortized Gain (Loss) [Member] | Other Postretirement Benefits Plan [Member]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	$ 0.0	$ 0.0

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Summary of Significant Accounting Policies Accumulated Other Comprehensive Income (Loss) Reclassifications out of AOCI (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent		$ (7.8)	$ (3.4)
Pension Plan [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax	[1]	(0.4)	(0.8)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax	[1]	(0.1)	0.0
Other Comprehensive Income (Loss), Defined Benefit Plan, Settlement and Curtailment Gain (Loss), before Tax	[1]	(9.6)	(4.1)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax		(10.1)	(4.9)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, Tax		(2.3)	(1.2)
Amounts reclassified from accumulated other comprehensive income (loss), net of tax		(7.8)	(3.7)
Other Postretirement Benefits Plan [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax	[1]	0.0	0.4
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax		0.0	0.4
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, Tax		0.0	0.1
Amounts reclassified from accumulated other comprehensive income (loss), net of tax		$ 0.0	$ 0.3

[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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Revenue from Contracts with Customers (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	[1]	$ 578.1	$ 1,621.0
Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		226.8	568.2
Commercial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		128.1	307.5
Industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		57.4	146.7
Oilfield
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		53.2	160.8
Public authorities and street light
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		48.0	123.1
System sales revenues
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		513.5	1,306.3
Provision for tax refund
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		(0.6)	0.0
Integrated market
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		22.8	302.1
Transmission
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		35.8	36.3
Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 6.6	$ (23.7)

[1] In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. Operating revenues for the three months ended March 31, 2021 significantly increased due to increased fuel, purchased power and direct transmission expenses, which are generally recoverable from customers, as a result of Winter Storm Uri. For further discussion, see Note 14 and "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operation."

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Investment in Unconsolidated Affiliates (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest		25.50%
Distributions from unconsolidated affiliates	$ 16.7
Equity in earnings of unconsolidated affiliates	$ 0.0	$ 53.2
OG&E [Member] | Enable Midstream Partners [Member]
Revenue from Related Parties		2.6
OG&E [Member] | Enable Midstream Partners [Member] | Natural Gas Transportation [Member]
Related Party Transaction, Purchases from Related Party		4.7
OG&E [Member] | Enable Midstream Partners [Member] | Natural Gas Purchases [Member]
Related Party Transaction, Purchases from Related Party		$ (12.2)

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Investment in Unconsolidated Affiliates Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Related Party Transaction [Line Items]
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	$ 32.9	$ 35.8
Enable Midstream Partners [Member] | OG&E [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties		2.6
Operating Costs Charged [Member] | Enable Midstream Partners [Member] | OGE Energy [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party		0.1
Natural Gas Transportation [Member] | Enable Midstream Partners [Member] | OG&E [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party		4.7
Natural Gas Purchases [Member] | Enable Midstream Partners [Member] | OG&E [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party		$ (12.2)
Excluding Fuel Purchases [Member]
Related Party Transaction [Line Items]
Accounts receivable - unconsolidated affiliates			$ 0.3

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Investment in Unconsolidated Affiliates Summarized Balance Sheet Information of Equity Method Investment (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Assets, Current	$ 657.4	$ 613.6
Liabilities, Current	$ 1,342.8	$ 1,089.6

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Investment in Unconsolidated Affiliates Summarized Income Statement of Equity Method Investment (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Schedule of Equity Method Investments [Line Items]
Operating revenues	$ 589.3	$ 1,630.6
Operating Income (Loss)	83.1	48.6
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 279.5	52.7
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member]
Schedule of Equity Method Investments [Line Items]
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest		$ 155.0

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Investment in Unconsolidated Affiliates Reconciliation of Equity in Earnings of Unconsolidated Affiliates (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Reconciliation of Equity in Earnings of Unconsolidated Affiliates [Line Items]
Proceeds from Equity Method Investment, Distribution		$ 16.7
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest			25.50%
Proportionate Unconsolidated Affiliate Net Income			$ 39.5
Equity in Earnings Amortization of Basis Difference	[1]		13.7
Income (Loss) from Equity Method Investments, Total		0.0	53.2
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest		$ 279.5	52.7
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member]
Reconciliation of Equity in Earnings of Unconsolidated Affiliates [Line Items]
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest			$ 155.0

[1] Includes loss on dilution, net of proportional basis difference recognition.

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Fair Value Measurements Carrying and Fair Value Amounts (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity Securities, FV-NI, Cost	$ 1,067.4	$ 785.1
Equity Securities, FV-NI	1,067.4	785.1
OG&E Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-Term Debt, Carrying Amount	3,852.4	3,851.8
Long-Term Debt, Fair Value	4,045.6	4,460.2
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	9.3	9.3
Long-Term Debt, Fair Value	9.1	10.0
Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-Term Debt, Carrying Amount	499.9	499.9
Long-Term Debt, Fair Value	489.9	497.8
Fair Value, Recurring [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0.0	$ 0.0

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Stock-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	27,278
Stock-Based Compensation Activity
Income tax benefit	$ 0.6	$ 0.6
OG&E [Member]
Stock-Based Compensation Activity
Income tax benefit	$ 0.2	0.1
Total Shareholder Return [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	216,437
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 41.10
Total Shareholder Return [Member] | OG&E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	60,923
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 41.10
Restricted stock units
Stock-Based Compensation Activity
Compensation expense	$ 0.5	0.5
Restricted stock units | OG&E [Member]
Stock-Based Compensation Activity
Compensation expense	0.2	0.0
Share-based Payment Arrangement [Member]
Stock-Based Compensation Activity
Compensation expense	2.3	2.5
Share-based Payment Arrangement [Member] | OG&E [Member]
Stock-Based Compensation Activity
Compensation expense	$ 0.8	0.4
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	116,539
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 35.72
Restricted Stock Units (RSUs) [Member] | OG&E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	32,804
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 35.72
Total Shareholder Return [Member] | Performance Shares [Member]
Stock-Based Compensation Activity
Compensation expense	$ 1.8	2.0
Total Shareholder Return [Member] | Performance Shares [Member] | OG&E [Member]
Stock-Based Compensation Activity
Compensation expense	$ 0.6	$ 0.4

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Income Taxes (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Non-Current Regulatory Liabilities	$ 1,223.3	$ 1,231.1

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Common Equity Automatic Dividend Reinvestment and Stock Purchase Plan (Details)	3 Months Ended
	Mar. 31, 2022 shares
Automatic Dividend Reinvestment and Stock Purchase Plan [Member]
Stock Issued During Period, Shares, New Issues	0

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Common Equity Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Equity [Abstract]
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 279.5	$ 52.7
Basic average common shares outstanding	200.2	200.1
Contingently issuable shares (performance and restricted stock units)	0.4	0.0
Diluted average common shares outstanding	200.6	200.1
Earnings Per Share, Basic and Diluted [Abstract]
Basic earnings per average common share	$ 1.40	$ 0.26
Diluted earnings per average common share	$ 1.39	$ 0.26
Anti-dilutive shares excluded from earnings per share calculation	0.0	0.0

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Long-Term Debt (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Debt Instrument [Line Items]
Percent of Principal Amount Subject to Optional Tender	100.00%
Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Jan. 01, 2025
Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Jan. 01, 2025
Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Jun. 01, 2027
Redeemable during the next 12 months
Debt Instrument [Line Items]
Long-term Debt	$ 135.4
OG&E [Member] | Redeemable during the next 12 months | Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Long term debt	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	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	$ 56.0
Minimum [Member] | Redeemable during the next 12 months | Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.11%
Minimum [Member] | Redeemable during the next 12 months | Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.11%
Minimum [Member] | Redeemable during the next 12 months | Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.11%
Maximum [Member] | Redeemable during the next 12 months | Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.64%
Maximum [Member] | Redeemable during the next 12 months | Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.57%
Maximum [Member] | Redeemable during the next 12 months | Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.64%

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Short-Term Debt and Credit Facilities (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Dec. 31, 2021
Line of Credit Facility [Line Items]
Short-term debt		$ 731.5	$ 486.9
Line of Credit Facility [Abstract]
Aggregate Commitment		1,100.0
Long-term Line of Credit	[1]	$ 731.9
Weighted Average Interest Rate		1.14%
Intercompany Borrowing Agreement - Maximum Borrowing Capacity		$ 350.0
Outstanding Intercompany Borrowings		48.7
OGE Energy [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Current Borrowing Capacity	[2]	550.0
Line of Credit Facility [Abstract]
Long-term Line of Credit	[1],[2]	$ 549.0
Weighted Average Interest Rate	[2]	1.14%
Maturity	[2],[3]	Dec. 17, 2026
OG&E [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Current Borrowing Capacity	[4],[5]	$ 550.0
Short-term debt		182.5	0.0
Line of Credit Facility [Abstract]
Letters of Credit Outstanding, Amount	[1],[4],[5]	$ 182.9
Weighted Average Interest Rate	[4],[5]	1.11%
Maturity	[3],[5]	Dec. 17, 2026
Short Term Borrowing Capacity That Has Regulatory Approval		$ 800.0
Period For Which Regulatory Approval Has Been Given to Acquire Short Term Debt		2 years
Advances from parent		$ 90.3	$ 101.3

[1] Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at March 31, 2022.

[2] 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.

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

[4] OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $350.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of December 17, 2026. At March 31, 2022, there were $48.7 million in intercompany borrowings under this agreement.

[5] 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. 

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Retirement Plans and Postretirement Benefit Plans (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		$ 2.2	$ 3.0
Interest cost		3.4	3.5
Expected return on plan assets		(6.8)	(8.4)
Amortization of net loss		1.9	2.8
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	[1]	0.0	0.0
Settlement cost		13.2	26.4
Total net periodic benefit cost		13.9	27.3
Amount Attributable to Unconsolidated Affiliates		0.0	0.1
Net periodic benefit cost		13.9	27.2
Capitalized portion of net periodic pension benefit cost		0.8	0.8
Other Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		0.3	0.1
Interest cost		0.0	0.0
Expected return on plan assets		0.0	0.0
Amortization of net loss		0.0	0.1
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	[1]	0.1	0.0
Settlement cost		0.0	0.0
Total net periodic benefit cost		0.4	0.2
Amount Attributable to Unconsolidated Affiliates		0.0	0.0
Net periodic benefit cost		0.4	0.2
Postretirement Benefit Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		0.1	0.1
Interest cost		0.9	0.8
Expected return on plan assets		(0.4)	(0.5)
Amortization of net loss		0.5	0.7
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	[1]	(1.0)	(1.7)
Amount Attributable to Unconsolidated Affiliates	[2]	0.0	(0.1)
Capitalized portion of net periodic pension benefit cost		0.1	0.1
Postretirement Benefit Costs
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Total net periodic benefit cost		0.1	(0.6)
Net periodic benefit cost		0.1	(0.5)
OG&E [Member] | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		1.7	2.1
Interest cost		2.6	2.5
Expected return on plan assets		(5.3)	(6.1)
Amortization of net loss		1.6	2.0
Settlement cost		3.6	22.2
Total net periodic benefit cost		4.2	22.7
Net periodic benefit cost		6.0	26.6
Capitalized portion of net periodic pension benefit cost		0.7	0.7
Amount Attributable to Parent		1.8	3.9
OG&E [Member] | Other Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		0.0	0.0
Interest cost		0.0	0.0
Expected return on plan assets		0.0	0.0
Amortization of net loss		0.0	0.0
Settlement cost		0.0	0.0
Total net periodic benefit cost		0.0	0.0
Net periodic benefit cost		0.4	0.2
Amount Attributable to Parent		0.4	0.2
OG&E [Member] | Postretirement Benefit Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		0.0	0.1
Interest cost		0.7	0.6
Expected return on plan assets		(0.4)	(0.4)
Amortization of net loss		0.5	0.7
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	[1]	(0.9)	(1.3)
Capitalized portion of net periodic pension benefit cost		0.0	0.0
Amount Attributable to Parent	[2]	0.0	(0.1)
OG&E [Member] | Postretirement Benefit Costs
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Total net periodic benefit cost		(0.1)	(0.3)
Net periodic benefit cost		(0.1)	(0.4)
OKLAHOMA | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Settlement cost	[3]	4.7	23.7
Additional Pension Expense to Meet State Requirements	[3]	1.9	20.7
OKLAHOMA | Postretirement Benefit Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Additional Pension Expense to Meet State Requirements	[4]	(0.3)	0.1
ARKANSAS | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Settlement cost	[3]	$ 0.4	$ 2.2

[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] "Amount paid by unconsolidated affiliates" is only applicable to OGE Energy. "Amount allocated from OGE Energy" is only applicable to OG&E.

[3] Included in the pension regulatory asset or liability in each jurisdiction, as indicated in the regulatory assets and liabilities table in Note 1.

[4] Included in the Pension tracker, as presented in the regulatory assets and liabilities table in Note 1.

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Report of Business Segments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Segment Reporting Information [Line Items]
Operating revenues	$ 589.3	$ 1,630.6
Fuel, purchased power and direct transmission expense	255.7	1,346.8
Other operation and maintenance	115.0	109.3
Depreciation and amortization	107.4	98.7
Taxes other than income	28.1	27.2
OPERATING INCOME	83.1	48.6
Equity in earnings of unconsolidated affiliates	0.0	53.2
Other income (expense)	9.3	0.9
Interest expense	40.1	39.4
Income tax expense (benefit)	55.1	10.6
Net income (loss)	279.5	52.7
Investment in unconsolidated affiliates		409.2
Total assets	13,093.6	11,788.7	$ 12,606.4
Gain (Loss) on Disposition of Assets		53.2
Equity Securities, FV-NI, Gain (Loss)	282.3	0.0
Electric Utility [Member]
Segment Reporting Information [Line Items]
Operating revenues	589.3	1,630.6
Fuel, purchased power and direct transmission expense	255.7	1,346.8
Other operation and maintenance	115.5	110.3
Depreciation and amortization	107.4	98.7
Taxes other than income	26.8	25.7
OPERATING INCOME	83.9	49.1
Equity in earnings of unconsolidated affiliates		0.0
Other income (expense)	0.7	1.7
Interest expense	38.2	38.4
Income tax expense (benefit)	7.4	1.2
Net income (loss)	39.0	11.2
Investment in unconsolidated affiliates		0.0
Total assets	11,898.8	11,248.2
Equity Securities, FV-NI, Gain (Loss)	0.0
Natural Gas Midstream Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0.0	0.0
Fuel, purchased power and direct transmission expense	0.0	0.0
Other operation and maintenance	0.7	0.4
Depreciation and amortization	0.0	0.0
Taxes other than income	0.0	0.1
OPERATING INCOME	(0.7)	(0.5)
Equity in earnings of unconsolidated affiliates		53.2
Other income (expense)	8.7	(0.5)
Interest expense	0.0	0.0
Income tax expense (benefit)	60.2	14.3
Net income (loss)	230.1	37.9
Investment in unconsolidated affiliates		409.2
Total assets	1,068.8	415.4
Equity Securities, FV-NI, Gain (Loss)	282.3
Other Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0.0	0.0
Fuel, purchased power and direct transmission expense	0.0	0.0
Other operation and maintenance	(1.2)	(1.4)
Depreciation and amortization	0.0	0.0
Taxes other than income	1.3	1.4
OPERATING INCOME	(0.1)	0.0
Equity in earnings of unconsolidated affiliates		0.0
Other income (expense)	0.0	(0.1)
Interest expense	2.0	1.2
Income tax expense (benefit)	(12.5)	(4.9)
Net income (loss)	10.4	3.6
Investment in unconsolidated affiliates		0.0
Total assets	320.9	521.6
Equity Securities, FV-NI, Gain (Loss)	0.0
Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0.0	0.0
Fuel, purchased power and direct transmission expense	0.0	0.0
Other operation and maintenance	0.0	0.0
Depreciation and amortization	0.0	0.0
Taxes other than income	0.0	0.0
OPERATING INCOME	0.0	0.0
Equity in earnings of unconsolidated affiliates		0.0
Other income (expense)	(0.1)	(0.2)
Interest expense	(0.1)	(0.2)
Income tax expense (benefit)	0.0	0.0
Net income (loss)	0.0	0.0
Investment in unconsolidated affiliates		0.0
Total assets	(194.9)	$ (396.5)
Equity Securities, FV-NI, Gain (Loss)	$ 0.0

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Rate Matters and Regulation Rate Matters and Regulation (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Estimated Refund to SPP	$ 13.0
Plan Investments for Customers	28.0
Requested Recovery of Capital Investment	1,200.0
Securitization Authorization Requested	760.0
Maximum [Member]
Lost Revenue on Plant Investments for Customers	42.7
Minimum [Member]
Lost Revenue on Plant Investments for Customers	31.4
In Favor Cooperatives
Plan Investments for Customers	11.7
In Favor Cooperatives | Maximum [Member]
Lost Revenues on Plant Investments for Customers	5.1
In Favor Cooperatives | Minimum [Member]
Lost Revenues on Plant Investments for Customers	3.2
OKLAHOMA
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 163.5
Public Utilities, Requested Return on Equity, Percentage	10.20%
Common Equity Percentage which ROE is based	53.37%
ARKANSAS
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 4.2
Impact to Company [Member]
Estimated Refund to SPP	5.0
Customer Impact [Member]
Estimated Refund to SPP	$ 8.0