10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2020

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: 1-1097

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).

OKLAHOMA GAS AND ELECTRIC COMPANY

(Exact name of registrant as specified in its charter)

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

321 North Harvey

P.O. Box 321

Oklahoma City, Oklahoma 73101-0321

(Address of principal executive offices)

(Zip Code)

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

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

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
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.  ☑ 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).  ☑ 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.

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). ☐ Yes   ☑ No

At March 31, 2020, there were 40,378,745 shares of 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 registrant outstanding at such date.

OKLAHOMA GAS AND ELECTRIC COMPANY

FORM 10-Q

FOR THE QUARTER ENDED MARCH 31, 2020

TABLE OF CONTENTS

	Page
GLOSSARY OF TERMS	ii
FORWARD-LOOKING STATEMENTS	1
Part I - FINANCIAL INFORMATION
Item 1. Financial Statements (Unaudited)
Condensed Statements of Income and Comprehensive Income	2
Condensed Statements of Cash Flows	3
Condensed Balance Sheets	4
Condensed Statements of Changes in Stockholder's Equity	6
Notes to Condensed Financial Statements	7
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	18
Item 3. Quantitative and Qualitative Disclosures About Market Risk	30
Item 4. Controls and Procedures	30
Part II - OTHER INFORMATION
Item 1. Legal Proceedings	31
Item 1A. Risk Factors	31
Item 6. Exhibits	31
Signature	32

i

GLOSSARY OF TERMS

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

Abbreviation	Definition
2019 Form 10-K	Annual Report on Form 10-K for the year ended December 31, 2019
APSC	Arkansas Public Service Commission
ASU	FASB Accounting Standards Update
CO2	Carbon dioxide
COVID-19	Novel Coronavirus disease
Dry Scrubber	Dry flue gas desulfurization unit with spray dryer absorber
Enable	Enable Midstream Partners, LP, a midstream partnership formed between OGE Energy and CenterPoint Energy, Inc.
EPA	U.S. Environmental Protection Agency
FASB	Financial Accounting Standards Board
Federal Clean Air Act	Federal Clean Air Act of 1970, as amended
Federal Clean Water Act	Federal Water Pollution Control Act of 1972, as amended
FERC	Federal Energy Regulatory Commission
FIP	Federal Implementation Plan
GAAP	Accounting principles generally accepted in the U.S.
MATS	Mercury and Air Toxics Standards
MW	Megawatt
MWh	Megawatt-hour
NAAQS	National Ambient Air Quality Standards
NOX	Nitrogen oxide
OCC	Oklahoma Corporation Commission
OG&E	Oklahoma Gas and Electric Company, wholly owned subsidiary of OGE Energy
OGE Energy	OGE Energy Corp., parent company of OG&E
Pension Plan	Qualified defined benefit retirement plan
Regional Haze Rule	The EPA's Regional Haze Rule
Restoration of Retirement Income Plan	Supplemental retirement plan to the Pension Plan
SIP	State Implementation Plan
SO2	Sulfur dioxide
SPP	Southwest Power Pool
System sales	Sales to OG&E's customers
U.S.	United States of America

ii

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" 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 OG&E's 2019 Form 10-K and within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" and "Item 1A. Risk Factors" of "Part II - Other Information" 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 and their impact on capital expenditures;

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

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

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

•business conditions in the energy industry;

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

•the impact on demand for our 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 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 OG&E's markets;

•environmental laws, safety laws or other regulations that may impact the cost of operations or restrict or change the way OG&E operates its facilities;

•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 and other catastrophic events;

•creditworthiness of suppliers, customers and other contractual parties;

•social attitudes regarding the utility industry;

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

•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 our markets;

•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; and

•other risk factors listed in the reports filed by OG&E with the Securities and Exchange Commission, including those listed within "Item 1A. Risk Factors" in OG&E's 2019 Form 10-K and "Item 1A. Risk Factors" of "Part II - Other Information" herein.

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

1

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements.

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2020		2019
OPERATING REVENUES
Revenues from contracts with customers	$	420.4	$	477.4
Other revenues	10.9		12.6
Operating revenues	431.3		490.0
COST OF SALES	135.0		212.6
OPERATING EXPENSES
Other operation and maintenance	121.0		120.3
Depreciation and amortization	94.4		82.4
Taxes other than income	23.9		24.4
Operating expenses	239.3		227.1
OPERATING INCOME	57.0		50.3
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction	1.3		1.5
Other net periodic benefit income (expense)	(0.5)		0.4
Other income	1.5		1.4
Other expense	(0.5)		(0.7)
Net other income	1.8		2.6
INTEREST EXPENSE
Interest on long-term debt	36.6		32.6
Allowance for borrowed funds used during construction	(0.5)		(1.0)
Interest on short-term debt and other interest charges	0.8		0.8
Interest expense	36.9		32.4
INCOME BEFORE TAXES	21.9		20.5
INCOME TAX EXPENSE	2.0		0.9
NET INCOME	$	19.9	$	19.6
Other comprehensive income, net of tax	—		—
COMPREHENSIVE INCOME	$	19.9	$	19.6

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

2

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2020		2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	19.9	$	19.6
Adjustments to reconcile net income to net cash provided from operating activities:
Depreciation and amortization	94.4		82.4
Deferred income taxes and investment tax credits, net	1.1		0.4
Allowance for equity funds used during construction	(1.3)		(1.5)
Stock-based compensation expense	0.9		1.0
Regulatory assets	0.3		(7.3)
Regulatory liabilities	(11.7)		(7.0)
Other assets	(0.1)		0.5
Other liabilities	(2.5)		2.2
Change in certain current assets and liabilities:
Accounts receivable and accrued unbilled revenues, net	18.9		26.0
Fuel, materials and supplies inventories	(5.0)		9.1
Fuel recoveries	50.3		(22.8)
Other current assets	(4.5)		(3.9)
Accounts payable	(27.0)		(32.4)
Income taxes payable - parent	0.8		0.5
Other current liabilities	(45.5)		(48.5)
Net cash provided from operating activities	89.0		18.3
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(127.2)		(152.9)
Net cash used in investing activities	(127.2)		(152.9)
CASH FLOWS FROM FINANCING ACTIVITIES
Changes in advances with parent	38.2		384.6
Payment of long-term debt	—		(250.0)
Net cash provided from financing activities	38.2		134.6
NET CHANGE IN CASH AND CASH EQUIVALENTS	—		—
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	—		—
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	—	$	—

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

3

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED BALANCE SHEETS

(Unaudited)

	March 31,		December 31,
(In millions)	2020		2019
ASSETS
CURRENT ASSETS
Accounts receivable, less reserve of $1.1 and $1.5, respectively	$	140.7	$	153.8
Accrued unbilled revenues	58.9		64.7
Advances to parent	265.8		304.8
Fuel inventories	45.5		46.3
Materials and supplies, at average cost	97.2		90.6
Fuel clause under recoveries	—		39.5
Other	24.1		19.6
Total current assets	632.2		719.3
OTHER PROPERTY AND INVESTMENTS	4.6		4.7
PROPERTY, PLANT AND EQUIPMENT
In service	12,856.4		12,765.0
Construction work in progress	149.5		141.6
Total property, plant and equipment	13,005.9		12,906.6
Less: accumulated depreciation	3,920.9		3,868.1
Net property, plant and equipment	9,085.0		9,038.5
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	300.0		306.0
Other	8.9		8.1
Total deferred charges and other assets	308.9		314.1
TOTAL ASSETS	$	10,030.7	$	10,076.6

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

4

OKLAHOMA GAS AND ELECTRIC COMPANY

CONDENSED BALANCE SHEETS (Continued)

(Unaudited)

	March 31,		December 31,
(In millions)	2020		2019
LIABILITIES AND STOCKHOLDER'S EQUITY
CURRENT LIABILITIES
Accounts payable	$	143.1	$	175.0
Customer deposits	83.2		83.0
Accrued taxes	24.8		41.9
Accrued interest	35.8		37.9
Accrued compensation	19.7		29.5
Fuel clause over recoveries	15.6		4.8
Other	48.4		65.1
Total current liabilities	370.6		437.2
LONG-TERM DEBT	3,195.6		3,195.2
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	129.7		133.3
Deferred income taxes	961.0		951.4
Deferred investment tax credits	7.1		7.1
Regulatory liabilities	1,216.1		1,223.5
Other	171.5		170.6
Total deferred credits and other liabilities	2,485.4		2,485.9
Total liabilities	6,051.6		6,118.3
COMMITMENTS AND CONTINGENCIES (NOTE 11)
STOCKHOLDER'S EQUITY
Common stockholder's equity	1,037.5		1,036.6
Retained earnings	2,941.6		2,921.7
Total stockholder's equity	3,979.1		3,958.3
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY	$	10,030.7	$	10,076.6

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

5

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, 2019	40.4	$	100.9	$	935.7	$	2,921.7	$	3,958.3
Net income	—	—		—		19.9		19.9
Stock-based compensation	—	—		0.9		—		0.9
Balance at March 31, 2020	40.4	$	100.9	$	936.6	$	2,941.6	$	3,979.1
Balance at December 31, 2018	40.4	$	100.9	$	930.9	$	2,571.5	$	3,603.3
Net income	—	—		—		19.6		19.6
Stock-based compensation	—	—		1.0		—		1.0
Balance at March 31, 2019	40.4	$	100.9	$	931.9	$	2,591.1	$	3,623.9

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

6

OKLAHOMA GAS AND ELECTRIC COMPANY

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1.Summary of Significant Accounting Policies

OG&E's significant accounting policies are detailed in "Note 1. Summary of Significant Accounting Policies" in OG&E's 2019 Form 10-K. Changes to OG&E's accounting policies as a result of adopting ASU 2016-13, "Financial Instruments - Credit Losses: Measurement of Credit Losses on Financial Information" are incorporated within "Allowance for Uncollectible Accounts Receivables" below and discussed in Note 2 in this Form 10-Q.

Organization

OG&E generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. Its operations 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. 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. OG&E is a wholly-owned subsidiary of OGE Energy, a holding company with investments in energy and energy services providers offering physical delivery and related services for both electricity and natural gas primarily in the south-central U.S.

Basis of Presentation

The Condensed Financial Statements included herein have been prepared by OG&E, 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, OG&E believes that the disclosures are adequate to prevent the information presented from being misleading.

In the opinion of management, all adjustments necessary to fairly present the financial position of OG&E at March 31, 2020 and December 31, 2019, the results of its operations for the three months ended March 31, 2020 and 2019 and its cash flows for the three months ended March 31, 2020 and 2019 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, 2020 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, OG&E's operating results for the three months ended March 31, 2020 are not necessarily indicative of the results that may be expected for the year ending December 31, 2020 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 OG&E's 2019 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.

7

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

	March 31,		December 31,
(In millions)	2020		2019
REGULATORY ASSETS
Current:
Generation Capacity Replacement rider under recovery (A)	$	4.6	$	3.7
Fuel clause under recoveries	—		39.5
Other (A)	8.2		5.5
Total current regulatory assets	$	12.8	$	48.7
Non-current:
Benefit obligations regulatory asset	$	165.2	$	167.2
Deferred storm expenses	63.9		65.5
Sooner Dry Scrubbers	20.4		20.6
Smart Grid	16.6		18.4
Unamortized loss on reacquired debt	10.4		10.6
Arkansas deferred pension expenses	7.8		8.0
Pension tracker	0.9		2.3
Other	14.8		13.4
Total non-current regulatory assets	$	300.0	$	306.0
REGULATORY LIABILITIES
Current:
Fuel clause over recoveries	$	15.6	$	4.8
Reserve for tax refund and interim surcharge (B)	4.8		12.7
Oklahoma demand program rider over recovery (B)	4.4		2.0
SPP cost tracker over recovery (B)	—		2.6
Other (B)	5.6		6.9
Total current regulatory liabilities	$	30.4	$	29.0
Non-current:
Income taxes refundable to customers, net	$	890.9	$	899.2
Accrued removal obligations, net	319.7		318.5
Other	5.5		5.8
Total non-current regulatory liabilities	$	1,216.1	$	1,223.5

(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 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. 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 the Other Operation and Maintenance 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 may be refunded based on customer protection rules defined by the OCC and

8

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.

OG&E considered COVID-19 pandemic impacts when calculating its reserve on accounts receivable as of March 31, 2020, as further discussed in "Item 2. Management's Discussion and Analysis - Recent Developments."

Reclassifications

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

2.Accounting Pronouncements

Recently Adopted Accounting Standards

Financial Instruments - Credit Losses. In June 2016, the FASB issued ASU 2016-13, "Financial Instruments - Credit Losses: Measurement of Credit Losses on Financial Information." The amendments in this update require entities to measure all expected credit losses of financial assets held at a reporting date based on historical experience, current conditions and reasonable and supportable forecasts in order to record credit losses in a more timely manner. ASU 2016-13 also amends the accounting for credit losses on available-for-sale debt securities and purchased financial assets with credit deterioration. OG&E adopted this standard in the first quarter of 2020 utilizing a modified-retrospective approach and determined the only financial instrument that OG&E currently holds and is required to measure under ASU 2016-13 is its trade receivables. Under this standard, OG&E considers forecasts of future economic conditions in addition to the historical data utilized prior to ASU 2016-13 when measuring the reserve for trade receivables. OG&E evaluated its reserve for trade receivables in light of the new guidance and determined that no adjustment was necessary to the amount recorded as of January 1, 2020.

Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract. In August 2018, the FASB issued ASU 2018-15, "Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract." The new guidance aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. OG&E adopted and prospectively applied the new guidance in the first quarter of 2020, which did not have a material effect on the Condensed Financial Statements upon adoption. Beginning in the first quarter of 2020, OG&E records capitalized implementation costs incurred in a hosting arrangement that is a service contract in Other Current Assets and records the related amortization expense in Other Operation and Maintenance in OG&E's Condensed Balance Sheet and Statement of Income, respectively.

Disclosure Framework. In August 2018, the FASB issued ASU 2018-13, "Fair Value Measurement (Topic 820): Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement" and ASU 2018-14, "Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans." The new guidance removes, adds, modifies or clarifies disclosure requirements that impact all levels of the fair value hierarchy, as well as investments measured using the net asset value practical expedient, and disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans, respectively. OG&E adopted these standards in the first quarter of 2020 and applied the new guidance either retrospectively or prospectively, depending upon the specific disclosure change. ASU 2018-13 and ASU 2018-14 did not have a significant impact on OG&E's financial statement disclosures.

Reference Rate Reform. In March 2020, the FASB issued ASU 2020-04, "Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting." The new guidance provides optional expedients and exceptions, if certain criteria are met, for applying GAAP to contracts, hedging relationships and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. Contracts modified between March 12, 2020 and December 31, 2022 as a result of reference rate reform are eligible for these expedients and exceptions. OG&E adopted ASU 2020-04 in the first quarter of 2020 and does not expect this standard to have a material impact on OG&E's financial statements.

9

3.Revenue Recognition

The following table disaggregates OG&E's revenues from contracts with customers by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "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)	2020		2019
Residential	$	166.9	$	191.2
Commercial	91.3		95.4
Industrial	41.5		52.3
Oilfield	38.2		49.4
Public authorities and street light	34.7		40.1
System sales revenues	372.6		428.4
Provision for rate refund	(0.6)		(0.1)
Integrated market	7.2		6.7
Transmission	34.2		36.1
Other	7.0		6.3
Revenues from contracts with customers	$	420.4	$	477.4

4.Related Party Transactions

OGE Energy charges operating costs to OG&E based on several factors, and operating costs directly related to OG&E 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 charged operating costs to OG&E of $37.9 million and $37.0 million during the three months ended March 31, 2020 and 2019, respectively.

Enable provides gas transportation services to OG&E pursuant to an agreement that grants 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 purchases gas from Enable when Enable's deliveries exceed OG&E's pipeline receipts. Enable purchases gas from OG&E when OG&E's pipeline receipts exceed Enable's deliveries. The following table summarizes related party transactions between OG&E and Enable during the three months ended March 31, 2020 and 2019.

	Three Months Ended
	March 31,
(In millions)	2020		2019
Operating revenues:
Electricity to power electric compression assets	$	3.7	$	3.8
Cost of sales:
Natural gas transportation services	$	4.7	$	14.8
Natural gas purchases (sales)	$	0.7	$	(1.0)

5.Fair Value Measurements

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

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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, 2020 and December 31, 2019. The following table summarizes the carrying amount and fair value of OG&E's financial instruments at March 31, 2020 and December 31, 2019.

	March 31,				December 31,
	2020				2019
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Classification
Long-term Debt (including Long-term Debt due within one year):
Senior Notes	$	3,050.7	$	3,240.1	$	3,050.3	$	3,500.4	Level 2
Industrial Authority Bonds	$	135.4	$	135.4	$	135.4	$	135.4	Level 2
Tinker Debt	$	9.5	$	9.7	$	9.5	$	10.0	Level 3

6.Stock-Based Compensation

The following table summarizes OG&E's pre-tax compensation expense and related income tax benefit during the three months ended March 31, 2020 and 2019 related to OGE Energy's performance units and restricted stock units for OG&E employees.

	Three Months Ended March 31,
(In millions)	2020		2019
Performance units:
Total shareholder return	$	0.7	$	0.8
Earnings per share	0.1		0.1
Total performance units	0.8		0.9
Restricted stock units	0.1		0.1
Total compensation expense	$	0.9	$	1.0
Income tax benefit	$	0.2	$	0.3

During the three months ended March 31, 2020, OGE Energy purchased 255,000 shares of its common stock at an average cost of $38.04 per share on the open market, and 89,225 of these shares were used during the same period to satisfy payouts of earned performance units and restricted stock unit grants to OG&E employees pursuant to OGE Energy's Stock Incentive Plan.

During the three months ended March 31, 2020, OGE Energy granted 67,975 performance units (based on total shareholder return over a three-year period) and 22,665 restricted stock units (three-year cliff vesting period) to OG&E employees at $38.03 and $43.69 fair value per share, respectively.

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7.Income Taxes

OG&E is a member of an affiliated group that files consolidated income tax returns in the U.S. federal jurisdiction and various state jurisdictions. With few exceptions, OG&E is no longer subject to U.S. federal tax or state and local examinations by tax authorities for years prior to 2016. Income taxes are generally allocated to each company in the affiliated group based on its stand-alone taxable income or loss. Federal investment tax credits previously claimed on electric utility property have been deferred and will be amortized to income over the life of the related property. Additionally, OG&E earns federal tax credits associated with production from its wind facilities. 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.Long-Term Debt

At March 31, 2020, OG&E was in compliance with all of its debt agreements.

Industrial Authority Bonds

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

Series			Date Due	Amount
				(In millions)
1.00%	-	5.35%	Garfield Industrial Authority, January 1, 2025	$	47.0
1.00%	-	4.31%	Muskogee Industrial Authority, January 1, 2025	32.4
1.00%	-	5.35%	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 OG&E's Condensed Balance Sheets. OG&E believes that it has sufficient liquidity to meet these obligations.

Issuance of Long-Term Debt

In April 2020, OG&E issued $300.0 million of 3.25 percent senior notes due April 1, 2030. The proceeds from the issuance were added to OG&E's general funds to be used for general corporate purposes, including to fund ongoing capital expenditures and working capital.

9.Short-Term Debt and Credit Facility

OG&E has a $450.0 million revolving credit facility that matures on March 8, 2023. This facility is available to back up OG&E's commercial paper borrowings, to provide revolving credit borrowings and can also be used as a letter of credit facility. At March 31, 2020, there were $0.3 million supporting letters of credit outstanding at a weighted-average interest rate of 1.00 percent. There were no outstanding commercial paper borrowings at March 31, 2020.

At March 31, 2020, there were $265.8 million in advances to OGE Energy compared to $304.8 million at December 31, 2019. 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 March 8, 2023. At March 31, 2020, there were no intercompany borrowings under this agreement.

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OGE Energy's and OG&E's ability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions. Pricing grids associated with OGE Energy's and OG&E'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 and OG&E's short-term borrowings, but a reduction in OGE Energy's and OG&E's credit ratings would not result in any defaults or accelerations. Any future downgrade of OG&E could also lead to higher long-term borrowing costs and, if below investment grade, would require OG&E 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, 2019 and ending December 31, 2020.

10.Retirement Plans and Postretirement Benefit Plans

Net Periodic Benefit Cost

The following table presents the net periodic benefit cost components, before consideration of capitalized amounts, of OG&E's portion 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, and the remaining net periodic benefit cost components as listed in the table below are presented within Other Net Periodic Benefit Income (Expense) in OG&E's Condensed 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 Income (Expense) in OG&E's Condensed Statements of Income.

	Pension Plan				Restoration of Retirement Income Plan				Postretirement Benefit Plans
	Three Months Ended				Three Months Ended				Three Months Ended
	March 31,				March 31,				March 31,
(In millions)	2020		2019		2020		2019		2020		2019
Service cost	$	2.6	$	2.4	$	0.1	$	—	$	—	$	—
Interest cost	3.4		4.3		—		0.1		0.8		1.0
Expected return on plan assets	(7.1)		(6.6)		—		—		(0.4)		(0.4)
Amortization of net loss	2.8		2.8		0.1		0.1		0.7		0.7
Amortization of unrecognized prior service cost (A)	—		—		—		—		(1.5)		(1.5)
Settlement cost	—		10.9		—		—		—		—
Total net periodic benefit cost	1.7		13.8		0.2		0.2		(0.4)		(0.2)
Plus: Amount allocated from OGE Energy	0.5		2.0		0.2		0.1		(0.2)		(0.2)
Net periodic benefit cost	$	2.2	$	15.8	$	0.4	$	0.3	$	(0.6)	$	(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.

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In addition to the net periodic benefit cost amounts recognized, as presented in the table above, for the Pension and Restoration of Retirement Income Plans for the three months ended March 31, 2020 and 2019, OG&E recognized the following:

	Three Months Ended
	March 31,
(In millions)	2020		2019
Increase (decrease) of pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	1.7	$	(1.0)
Deferral of pension expense related to pension settlement charges:
Oklahoma jurisdiction (A)	$	—	$	11.2
Arkansas jurisdiction (A)	$	—	$	1.0

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

In addition to the net periodic benefit income amounts recognized, as presented in the table above, for the postretirement benefit plans for the three months ended March 31, 2020 and 2019, OG&E recognized the following:

	Three Months Ended
	March 31,
(In millions)	2020		2019
Increase of postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	0.2	$	0.3

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

	Three Months Ended
	March 31,
(In millions)	2020		2019
Capitalized portion of net periodic pension benefit cost	$	0.9	$	0.8
Capitalized portion of net periodic postretirement benefit cost	$	—	$	0.1

11.Commitments and Contingencies

Except as set forth below, in Note 12 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 14 and 15 to OG&E's Financial Statements included in OG&E's 2019 Form 10-K appropriately represent, in all material respects, the current status of OG&E's material commitments and contingent liabilities.

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 its 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.

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Other

In the normal course of business, OG&E is 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, OG&E has incurred a probable loss as set forth by GAAP, an estimate is made of the loss, and the appropriate accounting entries are reflected in OG&E's Condensed Financial Statements. At the present time, based on currently available information, OG&E believes that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect on OG&E's financial position, results of operations or cash flows.

12.Rate Matters and Regulation

Except as set forth below, the circumstances set forth in Note 15 to the Financial Statements included in OG&E's 2019 Form 10-K appropriately represent, in all material respects, the current status of OG&E's regulatory matters.

Completed Regulatory Matters

Arkansas 2019 Formula Rate Plan Filing

OG&E filed its second evaluation report under its Formula Rate Plan in October 2019. On January 29, 2020, OG&E, the General Staff of the APSC and the Office of the Arkansas Attorney General filed a settlement agreement requesting the APSC approve a $5.2 million revenue increase, with rates effective April 1, 2020. The settling parties agreed that the Series I grid modernization projects are prudent in both action and cost and that the Series II grid modernization projects are prudent in action only and the determination of prudence of costs will be reserved until the actual historical costs are reviewed. The settling parties also agreed that OG&E will no longer use projections for the remaining initial term or extension of its current Formula Rate Plan and that all costs will be included for recovery for the first time in the historical year. On February 28, 2020, the APSC approved the settlement agreement.

Pending Regulatory Matters

Set forth below is a list of various proceedings pending before state or federal regulatory agencies. Unless stated otherwise, OG&E cannot predict when the regulatory agency will act or what action the regulatory agency will take. OG&E's financial results are dependent in part on timely and adequate 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 - 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

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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.

On February 20, 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 - 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. On March 2, 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 appeal will likely be heard later this year.

OG&E cannot predict the outcome of this proceeding based on currently available information, and as of March 31, 2020 and at present time, OG&E has not reserved an amount for a potential refund. If the reversal of the July 2016 FERC order remains intact, 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. If refunds were required, recovery of these upgrade credits would shift to future periods. Of the $13.0 million, OG&E would be impacted by $5.0 million in expense that initially benefited OG&E 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.

The SPP has recently proposed eliminating Attachment Z2 revenue crediting and replacing it with a different mechanism that would provide project sponsors such as OG&E the same level of recovery they would receive if payments continued under Attachment Z2. The FERC rejected that proposal to the extent it would limit recovery to the amount of the upgrade sponsor's directly assigned upgrade costs with interest, finding that providing the possibility of recovering greater than the cost of the investment could serve as an incentive for entities to build merchant transmission projects. The SPP is allowed to resubmit a proposal without this limited recovery.

APSC Proceedings

Environmental Compliance Plan Rider

In May 2019, OG&E filed an environmental compliance plan rider in Arkansas to recover its investment for the environmentally mandated costs associated with the Sooner Dry Scrubbers project and the conversion of Muskogee Units 4 and 5 to natural gas. The filing is an interim surcharge, subject to refund, that began with the first billing cycle of June 2019. OG&E is reserving the amounts collected through the interim surcharge, pending APSC approval of OG&E's filing. A hearing on the merits was held in December 2019, and parties submitted additional briefs to the APSC in March 2020. The primary question before the APSC is whether a company can utilize an environmental compliance plan rider while also being regulated under a formula rate plan. OG&E is awaiting a final decision from the APSC.

Order Regarding COVID-19

On April 10, 2020, the APSC issued Order No. 1 related to COVID-19 and the provision of safe, adequate and reliable utility service at just and reasonable rates. Among other things, the APSC ordered the suspension of disconnects during the pendency of the Arkansas Governor's emergency declaration or until the directive is rescinded by the APSC, as well as encouraging reasonable payment arrangements once the prohibition is lifted. The APSC also authorized utilities to establish regulatory assets to record costs resulting from the suspension of disconnections. These regulatory assets will be reviewed in future proceedings for reasonableness. The APSC ordered the General Staff of the APSC to consult with utilities to create a quarterly report to be used to report the costs incurred and saved that have been booked to the regulatory asset. OG&E is monitoring the regulatory activity regarding COVID-19 at the APSC and will consider the request for additional regulatory action by the APSC as needed.

On May 1, 2020, OG&E filed a Request for Additional Actions and Tariff Deviation seeking relief from the Arkansas General Service Rules and OG&E's Terms and Conditions under the tariff, in order to allow for: more flexible deferred payment agreements for all customer classes, suspension of increased deposits due to non-payment and suspension of the removal of customers from certain billing and extended due date plans for late payments. In addition, OG&E requested that incremental expenses, such as additional personal protective equipment, increased sanitation efforts at facilities, implementing health-screening processes and securing temporary facilities for potential sequestration of critical operation personnel, be

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tracked in a regulatory asset. OG&E noted that all possible cost categories are not known currently and reserved the right to file subsequent requests as needed.

OCC Proceedings

Oklahoma Grid Enhancement Plan

On February 24, 2020, OG&E filed an application with the OCC for approval of a mechanism that allows for interim recovery of the costs associated with its grid enhancement plan. The plan includes approximately $800.0 million of strategic, data-driven investments, over five years, covering grid resiliency, grid automation, communication systems and technology platforms and applications. A hearing on the merits is scheduled to begin on July 7, 2020.

Oklahoma Retail Electric Supplier Certified Territory Act Causes

Certain 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. If the OCC were to ultimately find that some or all of the customers being served are not exempted, then OG&E would have to evaluate the recoverability of some plant investments made to serve these customers. OG&E may also be required to reimburse certified territory suppliers for an amount of lost revenue.

OCC Public Utility Division Motion Regarding COVID-19

On April 28, 2020, the Director of the Public Utility Division filed an application requesting an order from the OCC authorizing action in response to COVID-19. The application requests the OCC to authorize the State's utilities to record as a regulatory asset increased bad debt expenses, costs associated with expanded payment plans, waived fees and incremental expenses that are directly related to the suspension of or delay in disconnection of service beginning March 15, 2020, with the issuance of the Oklahoma Governors' emergency declaration. The application also requests the OCC to allow utilities to defer additional expenses associated with ensuring the continuity of utility service, such as additional personal protective equipment, increased sanitation efforts at facilities, implementing heath-screening processes and securing temporary facilities for potential sequestration of critical operation personnel. The application asks the OCC to consider in future proceedings whether each utility's request for recovery of these regulatory assets is reasonable and necessary and to consider issues such as the incremental bad debt experienced over normal periods, the appropriate period of recovery for any approved amount of regulatory asset, any amount of carrying costs and other related matters. The application is scheduled to be heard by the OCC on May 7, 2020.

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

Introduction

OG&E generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. Its operations 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. 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. OG&E is a wholly-owned subsidiary of OGE Energy, a holding company with investments in energy and energy services providers offering physical delivery and related services for both electricity and natural gas primarily in the south-central U.S.

Overview

OG&E Mission and Focus

OGE Energy's mission, through OG&E and OGE Energy's equity interest in Enable, is to fulfill its critical role in the nation's electric utility and natural gas midstream pipeline infrastructure and meet individual customer's needs for energy and related services, focusing on safety, efficiency, reliability, customer service and risk management.

Recent Developments

COVID-19 Pandemic

In March 2020, the World Health Organization declared the outbreak of COVID-19 as a pandemic, which continues to spread throughout the U.S. and world. In an effort to contain COVID-19 or slow its spread, the U.S. federal, state and local governments have enacted various measures, including orders to close businesses not deemed "essential," enact "shelter in place" restrictions on residents and practice social distancing when engaging in essential activities. The COVID-19 outbreak has adversely impacted global markets and activity, including the energy industry, and it is impossible to predict the ultimate impact of the COVID-19 pandemic, as the situation is rapidly evolving. OG&E's current and potential future responses to the COVID-19 impacts on our employees, customers and shareholders are further discussed below.

•Our top priority is to protect our employees and their families, as well as our customers. We are taking all precautionary measures as directed by health authorities and local and national governments. We continue to monitor the outbreak of COVID-19, and other closures, or closures for a longer period of time, may be required to help ensure the health and safety of our employees and our customers.

•As a precautionary measure in order to increase our cash position and preserve financial flexibility in light of current uncertainty resulting from the COVID-19 pandemic, OGE Energy entered into a one-year $75.0 million term loan agreement in April 2020. Further, OG&E issued $300.0 million in senior notes in April 2020.

•In March 2020, President Trump signed into U.S. federal law the Coronavirus Aid, Relief, and Economic Security Act, or the "CARES Act," which is aimed at addressing the economic disruption resulting from the COVID-19 pandemic and providing certain tax relief to businesses in the U.S. The CARES Act, among other things, includes provisions relating to refundable payroll tax credits, deferment of the employer portion of FICA payroll taxes, net operating loss carryback periods, alternative minimum tax credit refunds, modifications to the net interest deduction limitations and technical corrections to tax depreciation methods for qualified improvement property. OG&E concluded that the financial impact of the provisions it adopted is immaterial.

•OG&E announced that it would voluntarily suspend all disconnects for nonpayment, effective March 16, 2020. OG&E adjusted its reserve on accounts receivable as of March 31, 2020 in light of the current expected credit loss model (ASU 2016-13) and the COVID-19 pandemic. The adjustment, which was not material, incorporated concerns of slower customer payment due to unemployment. Overall, the financial impact of COVID-19 was relatively minor for the three months ended March 31, 2020; however, we expect continued instances of slower payment or non-payment by customers and reduced commercial and industrial demand, depending upon the length and severity of "shelter in place" orders. OG&E will continue to monitor the reserve as we gain better clarity on the impacts of COVID-19 on our customers and business. OG&E is also monitoring customer usage to determine any impact on load forecasts, in terms of both energy and demand usage. Due to different customer characteristics, the contribution to margin varies by customer class and applicable tariffs. The below table presents a one percent annual gross margin sensitivity by class, based on the gross margin guidance OG&E provided in its 2019 Form 10-K.

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This analysis only incorporates retail gross margin and excludes transmission and other gross margin sensitivities.

Customer Class	1% Margin Sensitivity (In millions)
Residential	$	6.5
Commercial	$	3.6
Industrial	$	1.3
Oilfield	$	1.1
Public authorities	$	1.2

Regulatory Matters

Further discussion can be found in Note 12 within "Item 1. Financial Statements."

Arkansas 2019 Formula Rate Plan Filing

OG&E filed its second evaluation report under its Formula Rate Plan in October 2019. On January 29, 2020, OG&E, the General Staff of the APSC and the Office of the Arkansas Attorney General filed a settlement agreement requesting the APSC approve a $5.2 million revenue increase, with rates effective April 1, 2020. The settling parties agreed that the Series I grid modernization projects are prudent in both action and cost and that the Series II grid modernization projects are prudent in action only and the determination of prudence of costs will be reserved until the actual historical costs are reviewed. The settling parties also agreed that OG&E will no longer use projections for the remaining initial term or extension of its current Formula Rate Plan and that all costs will be included for recovery for the first time in the historical year. On February 28, 2020, the APSC approved the settlement agreement.

Summary of Operating Results

OG&E reported net income of $19.9 million and $19.6 million during the three months ended March 31, 2020 and 2019, respectively, an increase of $0.3 million, or 1.5 percent, primarily due to higher gross margin (driven by the expiration of the cogeneration credit rider), partially offset by higher depreciation and amortization expense due to additional assets being placed into service and higher interest expense driven by increased long-term debt outstanding.

2020 Outlook

OG&E's 2020 earnings guidance remains unchanged and is between $346 million to $357 million of net income. The guidance assumes, among other things, normal weather for the year. See OG&E's 2019 Form 10-K for other key factors and assumptions underlying its 2020 earnings guidance.

Non-GAAP Financial Measures

Gross margin is defined by OG&E as operating revenues less cost of sales. Cost of sales, as reflected on the income statement, includes fuel, purchased power and certain transmission expenses. Gross margin is a non-GAAP financial measure because it excludes depreciation and amortization and other operation and maintenance expenses. Expenses for fuel and purchased power are recovered through fuel adjustment clauses, and as a result, changes in these expenses are offset in operating revenues with no impact on net income. OG&E believes gross margin provides a more meaningful basis for evaluating its operations across periods than operating revenues because gross margin excludes the revenue effect of fluctuations in these expenses. Gross margin is used internally to measure performance against budget and in reports for management and the Board of Directors. OG&E's definition of gross margin may be different from similar terms used by other companies. Further, gross margin is not intended to replace operating revenues as determined in accordance with GAAP as an indicator of operating performance. For a reconciliation of gross margin to revenue, which is the most directly comparable financial measure calculated and presented in accordance with GAAP, for the three months ended March 31, 2020 and 2019, see "Results of Operations" below.

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Results of Operations

The following discussion and analysis presents factors that affected OG&E's results of operations for the three months ended March 31, 2020 as compared to the same period in 2019 and OG&E's financial position at March 31, 2020. Due to seasonal fluctuations and other factors, OG&E's operating results for the three months ended March 31, 2020 are not necessarily indicative of the results that may be expected for the year ending December 31, 2020 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. 

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	Three Months Ended
	March 31,
(Dollars in millions)	2020		2019
Operating revenues	$	431.3	$	490.0
Cost of sales	135.0		212.6
Other operation and maintenance	121.0		120.3
Depreciation and amortization	94.4		82.4
Taxes other than income	23.9		24.4
Operating income	57.0		50.3
Allowance for equity funds used during construction	1.3		1.5
Other net periodic benefit income (expense)	(0.5)		0.4
Other income	1.5		1.4
Other expense	0.5		0.7
Interest expense	36.9		32.4
Income tax expense	2.0		0.9
Net income	$	19.9	$	19.6
Operating revenues by classification:
Residential	$	172.3	$	195.4
Commercial	94.1		100.2
Industrial	42.6		53.7
Oilfield	39.0		50.2
Public authorities and street light	35.6		41.5
Sales for resale	(0.1)		—
System sales revenues	383.5		441.0
Provision for rate refund	(0.6)		(0.1)
Integrated market	7.2		6.7
Transmission	34.2		36.1
Other	7.0		6.3
Total operating revenues	$	431.3	$	490.0
Reconciliation of gross margin to revenue:
Operating revenues	$	431.3	$	490.0
Cost of sales	135.0		212.6
Gross margin	$	296.3	$	277.4
MWh sales by classification (In millions)
Residential	2.2		2.4
Commercial	1.5		1.3
Industrial	1.1		1.1
Oilfield	1.1		1.2
Public authorities and street light	0.6		0.7
System sales	6.5		6.7
Integrated market	0.3		0.3
Total sales	6.8		7.0
Number of customers	859,628		852,141
Weighted-average cost of energy per kilowatt-hour (In cents)
Natural gas	1.663		3.064
Coal	1.905		1.958
Total fuel	1.531		2.306
Total fuel and purchased power	1.887		2.868
Degree days (A)
Heating - Actual	1,649		2,084
Heating - Normal	1,800		1,798
Cooling - Actual	23		—
Cooling - Normal	13		13

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

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OG&E's net income increased $0.3 million, or 1.5 percent, during the three months ended March 31, 2020 as compared to the same period in 2019. Primary drivers for this increase in net income are further discussed below.

Gross margin increased $18.9 million, or 6.8 percent, during the three months ended March 31, 2020 as compared to the same period in 2019, primarily due to the below factors.

(In millions)	$ Change
Price variance (A)	$	23.2
New customer growth	6.2
Other	0.8
Weather (price and quantity) (B)	(11.3)
Change in gross margin	$	18.9

(A)Increased primarily due to the expiration of the cogeneration credit rider in 2019.

(B)Decreased primarily due to a 20.9 percent decrease in heating degree days for the three months ended March 31, 2020.

Cost of sales for OG&E consists of fuel used in electric generation, purchased power and transmission related charges. The actual cost of fuel used in electric generation and certain purchased power costs are passed through to 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 cost of sales decreased $77.6 million, or 36.5 percent, during the three months ended March 31, 2020 as compared to the same period in 2019, primarily due to the below factors.

(In millions)	$ Change		% Change
Fuel expense (A)	$	(38.9)	(42.8)	%
Purchased power costs:
Purchases from SPP (B)	(32.3)		(39.2)	%
Cogeneration (C)	(7.2)		(100.0)	%
Wind (D)	2.2		17.5	%
Transmission expense (E)	(1.4)		(7.5)	%
Change in cost of sales	$	(77.6)

(A)Decreased primarily due to lower fuel costs related to the generating assets utilized during the three months ended March 31, 2020.

(B)Decreased primarily due to lower market prices primarily due to decreased fuel costs for generators for the three months ended March 31, 2020.

(C)Decreased primarily due to the expiration of cogeneration contracts in 2019.

(D)Increased primarily due to a 16.5 percent increase in MWs purchased during the three months ended March 31, 2020.

(E)Decreased primarily due to lower SPP charges for the base plan projects of other utilities.

Other operation and maintenance expense increased $0.7 million, or 0.6 percent, during the three months ended March 31, 2020 as compared to the same period in 2019, primarily due to the below factors.

(In millions)	$ Change		% Change
New expenses related to River Valley power plant (A)	$	4.2	*
Contract technical and construction services	(1.4)		(12.0)	%
Vegetation management	(1.1)		(10.6)	%
Other	(1.0)		(1.1)	%
Change in other operation and maintenance expense	$	0.7

* Not applicable, as prior year expenses were zero.

(A)Additional other operation and maintenance expenses related to the purchase of the River Valley plant are primarily recovered through a rider mechanism, as approved by the OCC in 2019.

Depreciation and amortization expense increased $12.0 million, or 14.6 percent, during the three months ended March 31, 2020, as compared to the same period in 2019, primarily due to additional assets being placed into service and depreciation expense for the Sooner Dry Scrubbers no longer being deferred to a regulatory asset.

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Interest on long-term debt increased $4.0 million, or 12.3 percent, during the three months ended March 31, 2020, as compared to the same period in 2019, primarily due to increased long-term debt outstanding and interest expense for the Sooner Dry Scrubbers no longer being deferred to a regulatory asset.

Income tax expense increased $1.1 million during the three months ended March 31, 2020, as compared to the same period in 2019, primarily due to higher pretax income and reduced tax credit generation.

Off-Balance Sheet Arrangements

There have been no significant changes in OG&E's off-balance sheet arrangements from those discussed in OG&E's 2019 Form 10-K.

Liquidity and Capital Resources

Cash Flows

	Three Months Ended
	March 31,				2020 vs. 2019
(Dollars in millions)	2020		2019		$ Change		% Change
Net cash provided from operating activities (A)	$	89.0	$	18.3	$	70.7	*
Net cash used in investing activities (B)	$	(127.2)	$	(152.9)	$	25.7	(16.8)	%
Net cash provided from financing activities (C)	$	38.2	$	134.6	$	(96.4)	(71.6)	%

* Change is greater than 100 percent variance.

(A)Increased primarily due to a decrease in vendor payments and increased amounts received from customers.

(B)Decreased primarily due to environmental projects being completed and placed into service as well as fewer plant outages in 2020.

(C)Decreased primarily due to changes in cash advances with parent, partially offset by the payment of long-term debt in January 2019.

Working Capital

Working capital is defined as the difference in current assets and current liabilities. OG&E's working capital requirements are driven generally by changes in accounts receivable, accounts payable, commodity prices, credit extended to and the timing of collections from customers, the level and timing of spending for maintenance and expansion activity, inventory levels and fuel recoveries. The following discussion addresses changes in working capital balances at March 31, 2020 compared to December 31, 2019.

Accounts Receivable and Accrued Unbilled Revenues decreased $18.9 million, or 8.6 percent, primarily due to a decrease in billings to OG&E's retail customers reflecting lower seasonal usage in March 2020 as compared to December 2019.

Advances to Parent decreased $39.0 million, or 12.8 percent, primarily due to daily operational expenses and capital expenditures, partially offset by an increase in cash from customers.

Fuel Clause Under Recoveries decreased $39.5 million, primarily due to increased collections from customers and lower fuel costs.

Other Current Assets increased $4.5 million, or 23.0 percent, primarily due to an increase in under-recovered riders.

Accounts Payable decreased $31.9 million, or 18.2 percent, primarily due to the timing of vendor payments and lower fuel costs.

Accrued Taxes decreased $17.1 million, or 40.8 percent, primarily resulting from the timing of ad valorem payments, partially offset by tax accruals.

Accrued Compensation decreased $9.8 million, or 33.2 percent, primarily due to 2019 incentive compensation payouts that occurred in the first quarter of 2020, partially offset by 2020 accruals.

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Fuel Clause Over Recoveries increased $10.8 million, primarily due to increased collections from customers and lower fuel costs.

Other Current Liabilities decreased $16.7 million, or 25.7 percent, primarily due to changes in amounts owed to customers.

Future Capital Requirements

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

Capital Expenditures

OG&E's estimates of capital expenditures, which represent base maintenance capital expenditures plus capital expenditures for known and committed projects, for the years 2020 through 2024 are discussed in detail within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in OG&E's 2019 Form 10-K. Additional capital expenditures beyond those identified in OG&E's 2019 Form 10-K, including additional incremental growth opportunities in electric transmission assets, will be evaluated based upon their impact upon achieving OG&E's financial objectives. OG&E remains on track for its approximately $575.0 million in capital investment planned for 2020 as disclosed in OG&E's 2019 Form 10-K. However, the progression of, and global response to, the COVID-19 outbreak increases the risk of delays in construction activities and equipment deliveries related to OG&E's capital projects, including potential delays in obtaining permits from government agencies, resulting in potential deferral of capital expenditures.

Financing Activities and Future Sources of Financing

Management expects that cash generated from operations, proceeds from the issuance of long- and short-term debt and funds received from OGE Energy (from proceeds from the sales of OGE Energy's common stock to the public through OGE Energy's Automatic Dividend Reinvestment and Stock Purchase Plan or other offerings) will be adequate over the next three years to meet anticipated cash needs and to fund future growth opportunities. OG&E utilizes short-term borrowings (through a combination of bank borrowings, commercial paper and borrowings from OGE Energy) to satisfy temporary working capital needs and as an interim source of financing capital expenditures until permanent financing is arranged. As indicated above, as a precautionary measure in order to increase OG&E's cash position and preserve financial flexibility in light of current uncertainty resulting from the COVID-19 pandemic, OGE Energy entered into a one-year $75.0 million term loan agreement in April 2020. Further, OG&E issued $300.0 million in senior notes in April 2020. The disruption in the capital markets and the commercial paper markets caused by the COVID-19 outbreak could make additional financing more challenging, and there can be no assurance that OG&E will be able to obtain such financing on commercially reasonable terms or at all.

Short-Term Debt and Credit Facility

OG&E has a $450.0 million revolving credit facility that matures on March 8, 2023. This facility is available to back up OG&E's commercial paper borrowings, to provide revolving credit borrowings and can also be used as a letter of credit facility. At March 31, 2020, there were $265.8 million in advances to OGE Energy compared to $304.8 million at December 31, 2019. 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 March 8, 2023. The following table highlights OG&E's short-term debt activity as of March 31, 2020.

(Dollars in millions)	March 31, 2020
Balance of outstanding supporting letters of credit	$	0.3
Weighted-average interest rate of outstanding supporting letters of credit	1.00		%
Balance of outstanding commercial paper borrowings	$	—
Net available liquidity under revolving credit agreements	$	449.7
Balance of outstanding intercompany borrowings with OGE Energy	$	—

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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, 2019 and ending December 31, 2020. See Note 9 within "Item 1. Financial Statements" for further discussion of OG&E's short-term debt activity.

Issuance of Long-Term Debt

In April 2020, OG&E issued $300.0 million of 3.25 percent senior notes due April 1, 2030. The proceeds from the issuance were added to OG&E's general funds to be used for general corporate purposes, including to fund ongoing capital expenditures and working capital.

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 and OG&E'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 and OG&E's short-term borrowings, but a reduction in OGE Energy's and OG&E's credit ratings would not result in any defaults or accelerations. Any future downgrade of OGE Energy or OG&E could also lead to higher long-term borrowing costs and, if below investment grade, would require OG&E 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.

On April 3, 2020, S&P's Global Ratings affirmed its issuer credit and commercial paper ratings, as listed in OGE Energy's 2019 Form 10-K, for both OGE Energy and OG&E. S&P's Global Ratings also affirmed both companies' stable outlooks. S&P's Global Ratings' affirmation follows the announcement that Enable will increase the level of cash it retains, which effectively reduces dividend distributions for OGE Energy by as much as half. However, S&P's Global Ratings indicated it does not expect OGE Energy's credit quality to weaken materially, given the cushion in its current financial measures. Further, S&P's Global Ratings indicated they continue to view OG&E as insulated from OGE Energy, reflecting the combination of OG&E's stronger stand-alone credit profile and sufficient separateness between OG&E and OGE Energy.

On April 21, 2020, Moody's Investors Service did not take direct action but did issue a comment in response to Enable's decision to reduce dividend distributions. Moody's Investors Service stated that, despite the reduction in cash flow, OGE Energy's credit profile is manageable, as it is primarily supported by the stable operations and supportive regulatory environment of OG&E.

Critical Accounting Policies and Estimates

The Condensed Financial Statements and Notes to Condensed Financial Statements 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. Changes to these assumptions and estimates could have a material effect on OG&E's Condensed Financial Statements. However, OG&E believes it has taken reasonable positions where assumptions and estimates are used in order to minimize the negative financial impact to OG&E that could result if actual results vary from the assumptions and estimates.  

In management's opinion, the areas of OG&E where the most significant judgment is exercised include the determination of Pension Plan assumptions, income taxes, contingency reserves, asset retirement obligations, depreciable lives of property, plant and equipment, regulatory assets and liabilities and unbilled revenues. The selection, application and disclosure of OG&E's critical accounting estimates have been discussed with OGE Energy's Audit Committee and are discussed in detail within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in OG&E's 2019 Form 10-K.

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Commitments and Contingencies

In the normal course of business, OG&E is 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, OG&E has incurred a probable loss as set forth by GAAP, an estimate is made of the loss, and the appropriate accounting entries are reflected in OG&E's Condensed Financial Statements. At the present time, based on available information, OG&E believes that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect on OG&E's financial position, results of operations or cash flows. See Notes 11 and 12 within "Item 1. Financial Statements" for a discussion of OG&E's 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 its operations are in substantial compliance with current federal, state and local environmental standards. These environmental laws and regulations are also discussed in detail within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in OG&E's 2019 Form 10-K.

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.

Air

Federal Clean Air Act Overview

OG&E's operations are subject to the Federal Clean Air Act as amended and comparable state laws and regulations. These laws and regulations regulate emissions of air pollutants from various industrial sources, including electric generating units and also impose various monitoring and reporting requirements. Such laws and regulations may require that OG&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.

Cross-State Air Pollution Rule

On September 7, 2016, the EPA finalized an update to the 2011 Cross-State Air Pollution Rule. The new rule applies to ozone-season NO_X emissions from power plants in 22 eastern states (including Oklahoma). The rule utilizes a cap and trade program for NO_X emissions and went into effect on May 1, 2017 in Oklahoma. The 2016 rule reduces the 2011 Cross-State Air Pollution Rule emissions cap for all of OG&E's coal and gas facilities (except the River Valley and Frontier facilities which were not owned by OG&E until 2019) by 47 percent combined. OG&E and numerous other parties filed petitions for judicial and administrative review of the 2016 rule. On September 13, 2019, the U.S. Court of Appeals for the District of Columbia Circuit issued an opinion that deferred a decision on our challenges to the rule pending an EPA review and decision on a separate administrative petition that we filed. Subsequently, all of OG&E's judicial challenges were voluntarily dismissed, but the administrative petitions for reconsideration remain pending at the EPA.

OG&E is in compliance with the 2016 rule requirements which remain in effect. OG&E does not anticipate, at this time, additional capital expenditures for compliance with the 2016 rule.

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Hazardous Air Pollutants Emission Standards

On February 16, 2012, the EPA published the final MATS rule regulating the emissions of certain hazardous air pollutants from electric generating units. OG&E complied with the MATS rule by the April 16, 2016 deadline that applied to OG&E's coal units. On April 16, 2020, the EPA released a final rule which reconsidered certain elements of the 2012 rule in response to litigation in the D.C. Circuit Court. In the final rule, the EPA concluded that it is not "appropriate and necessary" to regulate MATS-related emissions from coal-fired units. Nonetheless, the EPA retained the emissions limits that were established in the 2012 rule, which remains in effect today.

National Ambient Air Quality Standards

The EPA is required to set NAAQS for certain pollutants considered to be harmful to public health or the environment. The Clean Air Act requires the EPA to review each NAAQS every five years. As a result of these reviews, the EPA periodically has taken action to adopt more stringent NAAQS for those pollutants. If any areas of Oklahoma were to be designated as not attaining the NAAQS for a particular pollutant, OG&E could be required to install additional emission controls on its facilities to help the state achieve attainment with the NAAQS. As of March 31, 2020, no areas of Oklahoma had been designated as non-attainment for pollutants that are likely to affect OG&E's operations. Several processes are under way to designate areas in Oklahoma as attaining or not attaining revised NAAQS.

The EPA proposed to designate part of Muskogee County, in which OG&E's Muskogee Power Plant is located, as non-attainment for the 2010 SO₂ NAAQS on March 1, 2016, even though nearby monitors indicated compliance with the NAAQS. The proposed designation was based on modeling that did not reflect the conversion of two of the coal units at Muskogee to natural gas. The State of Oklahoma's monitoring preliminarily indicates that ambient SO₂ emissions in the area are well within the NAAQS. The EPA has indicated that it anticipates finalizing a designation at the end of 2020. At this time, OG&E cannot determine with any certainty whether the proposed designation of Muskogee County will cause a material impact to OG&E's financial results.

OG&E continues to monitor these processes and their possible impact on its operations but, at this time, cannot determine with any certainty whether they will cause a material impact to OG&E's financial results.

Climate Change and Greenhouse Gas Emissions

There is continuing discussion and evaluation of possible global climate change in certain regulatory and legislative arenas. The focus is generally on emissions of greenhouse gases, including CO_2, sulfur hexafluoride and methane, and whether these emissions are contributing to the warming of the earth's atmosphere. On November 4, 2019, President Trump announced that the U.S. has officially notified the United Nations that the U.S. will withdraw from the "Paris Agreement" on climate change after having announced in 2017 that the U.S. would begin negotiations to re-enter the agreement with different terms. A new agreement may result in future additional emissions reductions in the U.S.; however, it is not possible to determine what the international legal standards for greenhouse gas emissions will be in the future and the extent to which these commitments will be implemented through the Clean Air Act or any other existing statutes and new legislation.

If legislation or regulations are passed at the federal or state levels in the future requiring mandatory reductions of CO₂ and other greenhouse gases on OG&E's facilities, this could result in significant additional compliance costs that would affect OG&E's future financial position, results of operations and cash flows if such costs are not recovered through regulated rates. Several states outside the area where OG&E operates have passed laws, adopted regulations or undertaken regulatory initiatives to reduce the emission of greenhouse gases, primarily through the planned development of greenhouse gas emission inventories and/or regional greenhouse gas cap and trade programs.

OG&E's current business strategy has resulted in reduced carbon dioxide emissions by over 40 percent compared to 2005 levels, and during the same period, emissions of ozone-forming NO_x have been reduced by approximately 75 percent and emissions of SO₂ have been reduced by approximately 90 percent. OG&E expects to further reduce carbon dioxide emissions to 50 percent of 2005 levels by 2030. To comply with the EPA's MATS rule and Regional Haze Rule FIP, 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. OG&E's service territory borders one of the nation's best wind resource areas, and 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

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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.

On July 8, 2019, the EPA published the Affordable Clean Energy rule. Numerous parties, not including OG&E, have filed petitions for judicial review of the Affordable Clean Energy rule in the U.S. Court of Appeals for the District of Columbia Circuit. The Affordable Clean Energy rule requires states, including Oklahoma, to develop emission limitations for carbon dioxide for each existing coal-fired utility boiler within the state, including all of OG&E's coal units, and submit a compliance and implementation plan to the EPA by July 2022. The EPA will approve or disapprove the proposed state plan within 18 months of submittal and develop a federal implementation plan if the proposed state plan is disapproved. At this time, OG&E cannot determine with any certainty whether the implementation plan will cause a material impact to its financial results.

EPA Startup, Shutdown and Malfunction Policy

On May 22, 2015, the EPA issued a final rule to address the provisions in the SIPs of 36 states (including Oklahoma) regarding the treatment of emissions that occur during startup, shutdown and malfunction operations. The final rule clarifies the EPA's Startup, Shutdown and Malfunction Policy. Although judicial challenges to the rule are ongoing, the Oklahoma Department of Environmental Quality submitted a SIP revision for the EPA's approval on November 7, 2016 to comply with this rule. This rule has resulted in permit modifications for certain OG&E units and applications remain pending for other units. OG&E does not anticipate capital expenditures, or a material impact to its financial position, results of operations or cash flows, as a result of adoption of this rule.

Regional Haze Regulation - Second Planning Period

In January 2017, the EPA finalized a rule that would revise certain provisions of the Regional Haze Rule. Notably, the EPA extended the due date for the second Regional Haze implementation period by three years to 2021 and made changes to the provisions for impacts to national parks and other protected wilderness areas. Petitions for Reconsideration to the EPA were filed by industry groups. While not acting on the petitions, the EPA announced on January 17, 2018 that it intends to commence a notice-and-comment rulemaking revisiting certain aspects of the rule. During 2019, the EPA released technical resources to assist states in developing SIPs, including a significant non-binding guidance document and updated atmospheric modeling which will allow states to better account for international emissions affecting regional haze in the U.S. At this time, OG&E cannot predict the outcome of this rulemaking or SIP development or how it will affect OG&E.

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.

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.

In 2015, the EPA finalized a rule under the Federal Resource Conservation and Recovery Act for the handling and disposal of coal combustion residuals or coal ash. The rule regulates coal ash as a solid waste rather than a hazardous waste, which would have made the management of coal ash more costly. In August 2019, the EPA proposed revisions to the 2015 coal ash rule in response to the D.C. Circuit Court of Appeals issuing a decision regarding the ongoing Coal Combustion Residuals litigation. The proposed changes do not appear to be material to OG&E at this time. OG&E completed the clean closure of one regulated inactive coal ash impoundment in August 2019.

On June 28, 2018, the EPA approved the State of Oklahoma's application for a state coal ash permitting program that will operate in lieu of the federal coal ash program promulgated under the Federal Resource Conservation and Recovery Act. On September 26, 2018, a citizen suit was filed against the EPA in the U.S. District Court in the District of Columbia concerning the final approval. OG&E and others have moved to intervene on behalf of the EPA. OG&E is monitoring

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regulatory developments relating to this rule, none of which appear to be material to OG&E at this time. OG&E is in compliance with this rule at this time.

OG&E currently recycles and provides approximately 89 percent of its ash to the concrete and cement industries for use as a component within their products. Using fly ash in this way enables aggregate manufacturers to minimize their impact on the environment by avoiding the need to extract and process other natural resources.

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. Similar savings are anticipated in future years.

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.

The EPA issued a final rule on May 19, 2014 to implement Section 316(b) of the Federal Clean Water Act, which requires that power plant cooling water intake structure location, design, construction and capacity reflect the best available technology for minimizing their adverse environmental impact via the impingement and entrainment of aquatic organisms. The Oklahoma Department of Environmental Quality issued final permits on December 22, 2017 and August 22, 2018 for Muskogee Power Plant and Seminole Power Plant, respectively, in compliance with the final 316(b) rule, and OG&E did not incur any material costs associated with the rule's implementation at either location. OG&E expects to be able to provide a reasonable estimate of any material costs associated with the rule's implementation at other facilities following the future issuance of permits from the State of Oklahoma.

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 November 22, 2019, the EPA published a proposed rule to revise the technology-based effluent limitations for flue gas desulfurization waste water and bottom ash transport water. 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.

On April 21, 2020, the EPA and U.S. Army Corps of Engineers published in the Federal Register "The Navigable Waters Protection Rule: Definition of Waters of the United States." This final rule replaces the repealed definition of waters of the U.S. from 2015. The effective date of this final rule will be June 22, 2020. OG&E does not expect any material impacts as a result of this rule.

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 2.6 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 11 within "Item 1. Financial Statements."

29

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Under the reduced disclosure format permitted by General Instruction H(2)(c) of Form 10-Q, the information otherwise required by Item 3 has been omitted.

Item 4. Controls and Procedures.

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

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

While remote work arrangements have been implemented in response to the COVID-19 pandemic, OG&E believes there have been no material changes to the processes and procedures that impact financial reporting. OG&E continues to monitor potential internal control impacts of COVID-19 and plan accordingly to ensure the effectiveness of OG&E's internal controls over financial reporting and disclosures.

30

PART II. OTHER INFORMATION

Item 1. Legal Proceedings.

Reference is made to Item 3 of Part I of OG&E's 2019 Form 10-K for a description of certain legal proceedings presently pending. Except as described under "Environmental Laws and Regulations" within "Part I - Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," there are no new significant cases to report against OG&E and there have been no material changes in the previously reported proceedings.

Item 1A. Risk Factors.

Except as detailed below, there have been no significant changes in OG&E's risk factors from those discussed in OG&E's 2019 Form 10-K, which are incorporated herein by reference.

We face risks related to health epidemics and other outbreaks.

The recent outbreak of COVID-19 is a rapidly developing situation around the globe that has adversely impacted economic activity and conditions worldwide. In particular, efforts to control the spread of COVID-19 have led to shutdowns of various facilities as well as disrupted supply chains around the world. Efforts to control the spread of COVID-19 have also resulted in remote work arrangements and increased unemployment and will likely result in customer slow payment or non-payment and decreased commercial and industrial load. We are continuing to monitor developments involving our workforce, customers and suppliers and cannot predict whether COVID-19 will have a material impact on our results of operations, financial condition and prospects. However, an extended slowdown of the United States' economic growth, demand for commodities and/or material changes in governmental policy could result in lower economic growth and lower demand for electricity in our key markets as well as the ability of various customers, contractors, suppliers and other business partners to fulfill their obligations, which could have a material adverse effect on our results of operations, financial condition and prospects.

In addition, we cannot predict the impact that COVID-19 will have on our customers, suppliers, vendors and other business partners and each of their financial conditions; however, any material effect on these parties could adversely impact us. The impact of COVID-19 may also exacerbate other risks discussed in "Item 1A. Risk Factors" in OG&E's 2019 Form 10-K, any of which could have a material effect on us. This situation is changing rapidly and additional impacts may arise that we are not aware of currently.

Item 6. Exhibits.

Exhibit No.	Description
4.01	Supplemental Indenture No. 21 dated as of April 1, 2020 between OG&E and BOKF, NA, as trustee (Filed as Exhibit 4.01 to OG&E's Form 8-K filed April 1, 2020 (File No. 1-01097) and incorporated by reference herein).
31.01	Certifications Pursuant to Rule 13a-14(a)/15d-14(a) As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.01	Certification Pursuant to 18 U.S.C. Section 1350 As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	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.
101.SCH	Inline XBRL Taxonomy Schema Document.
101.PRE	Inline XBRL Taxonomy Presentation Linkbase Document.
101.LAB	Inline XBRL Taxonomy Label Linkbase Document.
101.CAL	Inline XBRL Taxonomy Calculation Linkbase Document.
101.DEF	Inline XBRL Definition Linkbase Document.
104	Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document (included in Exhibit 101).

31

SIGNATURE

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

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

May 6, 2020

32

EX-31.01

Exhibit 31.01

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 6, 2020

  /s/ Sean Trauschke

Sean Trauschke

President and Chief Executive Officer

Exhibit 31.01

CERTIFICATIONS

I, Stephen E. Merrill, 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 6, 2020

  /s/ Stephen E. Merrill

Stephen E. Merrill

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 Oklahoma Gas and Electric Company ("OG&E") on Form 10-Q for the period ended March 31, 2020, 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 6, 2020

          /s/ Sean Trauschke

               Sean Trauschke

President and Chief Executive Officer

          /s/ Stephen E. Merrill

               Stephen E. Merrill

Chief Financial Officer

XML

Fair Value Measurements

3 Months Ended

Mar. 31, 2020

Fair Value Disclosures [Abstract]

Fair Value Measurement [Text Block]

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

level of input that is significant to the fair value measurement. The three levels defined in the fair value hierarchy are as follows:

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

Level 2 inputs are inputs other than quoted prices in active markets included within Level 1 that are either directly or indirectly observable at the reporting date for the asset or liability for substantially the full term of the asset or liability. Level 2 inputs include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.  

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

OG&E had no financial instruments measured at fair value on a recurring basis at March 31, 2020 and December 31, 2019. The following table summarizes the carrying amount and fair value of OG&E's financial instruments at March 31, 2020 and December 31, 2019.

	March 31,				December 31,
	2020				2019
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Classification
Long-term Debt (including Long-term Debt due within one year):
Senior Notes	$	3,050.7	$	3,240.1	$	3,050.3	$	3,500.4	Level 2
Industrial Authority Bonds	$	135.4	$	135.4	$	135.4	$	135.4	Level 2
Tinker Debt	$	9.5	$	9.7	$	9.5	$	10.0	Level 3

XML

Short-Term Debt and Credit Facility

3 Months Ended

Mar. 31, 2020

Short-term Debt [Abstract]

Short-Term Debt and Credit Facility [Text Block]

Short-Term Debt and Credit Facility

OG&E has a $450.0 million revolving credit facility that matures on March 8, 2023. This facility is available to back up OG&E's commercial paper borrowings, to provide revolving credit borrowings and can also be used as a letter of credit facility. At March 31, 2020, there were $0.3 million supporting letters of credit outstanding at a weighted-average interest rate of 1.00 percent. There were no outstanding commercial paper borrowings at March 31, 2020.

At March 31, 2020, there were $265.8 million in advances to OGE Energy compared to $304.8 million at December 31, 2019. 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 March 8, 2023. At March 31, 2020, there were no intercompany borrowings under this agreement.

OGE Energy's and OG&E's ability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions. Pricing grids associated with OGE Energy's and OG&E'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 and OG&E's short-term borrowings, but a reduction in OGE Energy's and OG&E's credit ratings would not result in any defaults or accelerations. Any future downgrade of OG&E could also lead to higher long-term borrowing costs and, if below investment grade, would require OG&E 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, 2019 and ending December 31, 2020.

XML

Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Significant Accounting Policies [Text Block]

Summary of Significant Accounting PoliciesOG&E's significant accounting policies are detailed in "Note 1. Summary of Significant Accounting Policies" in OG&E's 2019 Form 10-K. Changes to OG&E's accounting policies as a result of adopting ASU 2016-13, "Financial Instruments - Credit Losses: Measurement of Credit Losses on Financial Information" are incorporated within "Allowance for Uncollectible Accounts Receivables" below and discussed in Note 2 in this Form 10-Q.

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

Organization

OG&E generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas. Its operations 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. 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. OG&E is a wholly-owned subsidiary of OGE Energy, a holding company with investments in energy and energy services providers offering physical delivery and related services for both electricity and natural gas primarily in the south-central U.S.

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

Basis of Presentation

The Condensed Financial Statements included herein have been prepared by OG&E, 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, OG&E believes that the disclosures are adequate to prevent the information presented from being misleading.

In the opinion of management, all adjustments necessary to fairly present the financial position of OG&E at March 31, 2020 and December 31, 2019, the results of its operations for the three months ended March 31, 2020 and 2019 and its cash flows for the three months ended March 31, 2020 and 2019 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, 2020 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, OG&E's operating results for the three months ended March 31, 2020 are not necessarily indicative of the results that may be expected for the year ending December 31, 2020 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 OG&E's 2019 Form 10-K.

Schedule of Regulatory Assets and Liabilities [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.

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

	March 31,		December 31,
(In millions)	2020		2019
REGULATORY ASSETS
Current:
Generation Capacity Replacement rider under recovery (A)	$	4.6	$	3.7
Fuel clause under recoveries	—		39.5
Other (A)	8.2		5.5
Total current regulatory assets	$	12.8	$	48.7
Non-current:
Benefit obligations regulatory asset	$	165.2	$	167.2
Deferred storm expenses	63.9		65.5
Sooner Dry Scrubbers	20.4		20.6
Smart Grid	16.6		18.4
Unamortized loss on reacquired debt	10.4		10.6
Arkansas deferred pension expenses	7.8		8.0
Pension tracker	0.9		2.3
Other	14.8		13.4
Total non-current regulatory assets	$	300.0	$	306.0
REGULATORY LIABILITIES
Current:
Fuel clause over recoveries	$	15.6	$	4.8
Reserve for tax refund and interim surcharge (B)	4.8		12.7
Oklahoma demand program rider over recovery (B)	4.4		2.0
SPP cost tracker over recovery (B)	—		2.6
Other (B)	5.6		6.9
Total current regulatory liabilities	$	30.4	$	29.0
Non-current:
Income taxes refundable to customers, net	$	890.9	$	899.2
Accrued removal obligations, net	319.7		318.5
Other	5.5		5.8
Total non-current regulatory liabilities	$	1,216.1	$	1,223.5

(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 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 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. 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 the Other Operation and Maintenance 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 may be 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.OG&E considered COVID-19 pandemic impacts when calculating its reserve on accounts receivable as of March 31, 2020, as further discussed in "Item 2. Management's Discussion and Analysis - Recent Developments."

Reclassifications [Text Block]

Reclassifications

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

XML

Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Significant Accounting Policies [Text Block]

Summary of Significant Accounting PoliciesOG&E's significant accounting policies are detailed in "Note 1. Summary of Significant Accounting Policies" in OG&E's 2019 Form 10-K. Changes to OG&E's accounting policies as a result of adopting ASU 2016-13, "Financial Instruments - Credit Losses: Measurement of Credit Losses on Financial Information" are incorporated within "Allowance for Uncollectible Accounts Receivables" below and discussed in Note 2 in this Form 10-Q.

Basis of Accounting [Text Block]

Basis of Presentation

The Condensed Financial Statements included herein have been prepared by OG&E, 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, OG&E believes that the disclosures are adequate to prevent the information presented from being misleading.

In the opinion of management, all adjustments necessary to fairly present the financial position of OG&E at March 31, 2020 and December 31, 2019, the results of its operations for the three months ended March 31, 2020 and 2019 and its cash flows for the three months ended March 31, 2020 and 2019 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, 2020 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, OG&E's operating results for the three months ended March 31, 2020 are not necessarily indicative of the results that may be expected for the year ending December 31, 2020 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 OG&E's 2019 Form 10-K.

Public Utilities, Policy [Policy Text Block]

Accounting Records

The accounting records of OG&E are maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the OCC and the APSC. Additionally, OG&E, as a regulated utility, is subject to accounting principles for certain types of rate-regulated activities, which provide that certain 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.

Related Party Transactions [Policy Text Block]

OGE Energy charges operating costs to OG&E based on several factors, and operating costs directly related to OG&E 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.

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

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).

Income Tax, Policy [Policy Text Block]

OG&E is a member of an affiliated group that 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 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 earns federal tax credits associated with production from its wind facilities. 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.

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 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. 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 the Other Operation and Maintenance 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 may be 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.OG&E considered COVID-19 pandemic impacts when calculating its reserve on accounts receivable as of March 31, 2020, as further discussed in "Item 2. Management's Discussion and Analysis - Recent Developments."

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CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 19.9	$ 19.6
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]
Depreciation and amortization	94.4	82.4
Deferred income taxes and investment tax credits, net	1.1	0.4
Allowance for equity funds used during construction	(1.3)	(1.5)
Stock-based compensation expense	0.9	1.0
Regulatory assets	(0.3)	7.3
Regulatory liabilities	(11.7)	(7.0)
Other assets	(0.1)	0.5
Other liabilities	(2.5)	2.2
Change in certain current assets and liabilities:
Accounts receivable and accrued unbilled revenues, net	18.9	26.0
Fuel, materials and supplies inventories	(5.0)	9.1
Fuel recoveries	50.3	(22.8)
Other current assets	(4.5)	(3.9)
Accounts payable	(27.0)	(32.4)
Income taxes payable - parent	0.8	0.5
Other current liabilities	(45.5)	(48.5)
Net cash provided from operating activities	89.0	18.3
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(127.2)	(152.9)
Net cash used in investing activities	(127.2)	(152.9)
CASH FLOWS FROM FINANCING ACTIVITIES
Payment of long-term debt	0.0	(250.0)
Changes in advances with parent	38.2	384.6
Net cash provided from financing activities	38.2	134.6
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

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Long-Term Debt (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($)
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.25%
Debt Instrument, Maturity Date	Apr. 01, 2030
Percent of Principal Amount Subject to Optional Tender	100.00%
Debt Instrument, Face Amount	$ 300.0
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 [Member]
Debt Instrument [Line Items]
Total (redeemable during next 12 months)	$ 135.4
OG&E [Member] | Redeemable during the next 12 months [Member] | Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Long-term debt, gross	47.0
OG&E [Member] | Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Long-term debt, gross	32.4
OG&E [Member] | Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 56.0
Minimum [Member] | Redeemable during the next 12 months [Member] | Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.00%
Minimum [Member] | Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.00%
Minimum [Member] | Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.00%
Maximum [Member] | Redeemable during the next 12 months [Member] | Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.35%
Maximum [Member] | Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.31%
Maximum [Member] | Redeemable during the next 12 months [Member] | Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.35%

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2020

Fair Value Disclosures [Abstract]

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

The following table summarizes the carrying amount and fair value of OG&E's financial instruments at March 31, 2020 and December 31, 2019.

	March 31,				December 31,
	2020				2019
(In millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Classification
Long-term Debt (including Long-term Debt due within one year):
Senior Notes	$	3,050.7	$	3,240.1	$	3,050.3	$	3,500.4	Level 2
Industrial Authority Bonds	$	135.4	$	135.4	$	135.4	$	135.4	Level 2
Tinker Debt	$	9.5	$	9.7	$	9.5	$	10.0	Level 3

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Summary of Significant Accounting Policies, Regulated Operations (Details) - USD ($) $ in Millions		Mar. 31, 2020	Dec. 31, 2019
Schedule of Regulatory Assets and Liabilities [Line Items]
Fuel clause under recoveries		$ 0.0	$ 39.5
Current Regulatory Assets		12.8	48.7
Non-Current Regulatory Assets		300.0	306.0
Current Regulatory Liabilities		30.4	29.0
Fuel clause over recoveries		15.6	4.8
Non-Current Regulatory Liabilities		1,216.1	1,223.5
Reserve for Tax Refund [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Liabilities	[1]	4.8	12.7
SPP Cost Tracker Rider Over Recovery [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Liabilities	[1]	0.0	2.6
Oklahoma Demand Program Over Recovery [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Liabilities	[1]	4.4	2.0
Other Regulatory Liability[Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Liabilities	[1]	5.6	6.9
Non-Current Regulatory Liabilities		5.5	5.8
Income taxes refundable to customers, net
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		890.9	899.2
Accrued removal obligations, net
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		319.7	318.5
Production Tax Credit Rider [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Assets	[2]	4.6	3.7
Benefit obligations regulatory asset
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		165.2	167.2
Deferred storm expenses
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		63.9	65.5
Dry Scrubber Regulatory Asset [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		20.4	20.6
Unamortized loss on reacquired debt
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		10.4	10.6
Deferred Pension Expenses [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		7.8	8.0
Other Regulatory Asset [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Current Regulatory Assets	[2]	8.2	5.5
Non-Current Regulatory Assets		14.8	13.4
Pension tracker
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		0.9	2.3
Smart Grid [Member]
Schedule of Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		$ 16.6	$ 18.4

[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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Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2020

Related Party Transaction [Line Items]

Schedule of Related Party Transactions [Table Text Block]

The following table summarizes related party transactions between OG&E and Enable during the three months ended March 31, 2020 and 2019.

	Three Months Ended
	March 31,
(In millions)	2020		2019
Operating revenues:
Electricity to power electric compression assets	$	3.7	$	3.8
Cost of sales:
Natural gas transportation services	$	4.7	$	14.8
Natural gas purchases (sales)	$	0.7	$	(1.0)

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Retirement Plans and Postretirement Benefit Plans (Tables)

3 Months Ended

Mar. 31, 2020

Defined Benefit Plan [Abstract]

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

The following table presents the net periodic benefit cost components, before consideration of capitalized amounts, of OG&E's portion 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, and the remaining net periodic benefit cost components as listed in the table below are presented within Other Net Periodic Benefit Income (Expense) in OG&E's Condensed 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 Income (Expense) in OG&E's Condensed Statements of Income.

	Pension Plan				Restoration of Retirement Income Plan				Postretirement Benefit Plans
	Three Months Ended				Three Months Ended				Three Months Ended
	March 31,				March 31,				March 31,
(In millions)	2020		2019		2020		2019		2020		2019
Service cost	$	2.6	$	2.4	$	0.1	$	—	$	—	$	—
Interest cost	3.4		4.3		—		0.1		0.8		1.0
Expected return on plan assets	(7.1)		(6.6)		—		—		(0.4)		(0.4)
Amortization of net loss	2.8		2.8		0.1		0.1		0.7		0.7
Amortization of unrecognized prior service cost (A)	—		—		—		—		(1.5)		(1.5)
Settlement cost	—		10.9		—		—		—		—
Total net periodic benefit cost	1.7		13.8		0.2		0.2		(0.4)		(0.2)
Plus: Amount allocated from OGE Energy	0.5		2.0		0.2		0.1		(0.2)		(0.2)
Net periodic benefit cost	$	2.2	$	15.8	$	0.4	$	0.3	$	(0.6)	$	(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.

In addition to the net periodic benefit cost amounts recognized, as presented in the table above, for the Pension and Restoration of Retirement Income Plans for the three months ended March 31, 2020 and 2019, OG&E recognized the following:

	Three Months Ended
	March 31,
(In millions)	2020		2019
Increase (decrease) of pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	1.7	$	(1.0)
Deferral of pension expense related to pension settlement charges:
Oklahoma jurisdiction (A)	$	—	$	11.2
Arkansas jurisdiction (A)	$	—	$	1.0

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

In addition to the net periodic benefit income amounts recognized, as presented in the table above, for the postretirement benefit plans for the three months ended March 31, 2020 and 2019, OG&E recognized the following:

	Three Months Ended
	March 31,
(In millions)	2020		2019
Increase of postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	0.2	$	0.3

(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]

	Three Months Ended
	March 31,
(In millions)	2020		2019
Capitalized portion of net periodic pension benefit cost	$	0.9	$	0.8
Capitalized portion of net periodic postretirement benefit cost	$	—	$	0.1

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CONDENSED STATEMENTS OF CHANGES IN STOCKHOLDER'S EQUITY (Unaudited) - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Premium on Common Stock	Retained Earnings
Common Stock, Shares, Outstanding		40.4
Net Income (Loss), Including portion attributable to noncontrolling interest, Number of Shares		0.0
Balance at Dec. 31, 2018	$ 3,603.3	$ 100.9	$ 930.9	$ 2,571.5
Changes in Stockholders' Equity
Net income	19.6	$ 0.0	0.0	19.6
Adjustments to Additional Paid in Capital, Share-based Compensation, Requisite Service Period Recognition, Number of Shares		0.0
Stock-based compensation	1.0	$ 0.0	1.0	0.0
Balance at Mar. 31, 2019	3,623.9	$ 100.9	931.9	2,591.1
Common Stock, Shares, Outstanding		40.4
Common Stock, Shares, Outstanding		40.4
Net Income (Loss), Including portion attributable to noncontrolling interest, Number of Shares		0.0
Balance at Dec. 31, 2019	3,958.3	$ 100.9	935.7	2,921.7
Changes in Stockholders' Equity
Net income	19.9	$ 0.0	0.0	19.9
Adjustments to Additional Paid in Capital, Share-based Compensation, Requisite Service Period Recognition, Number of Shares		0.0
Stock-based compensation	0.9	$ 0.0	0.9	0.0
Balance at Mar. 31, 2020	$ 3,979.1	$ 100.9	$ 936.6	$ 2,941.6
Common Stock, Shares, Outstanding		40.4

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Rate Matters and Regulation

3 Months Ended

Mar. 31, 2020

Regulated Operations [Abstract]

Rate Matters and Regulation [Text Block]

Rate Matters and Regulation

Except as set forth below, the circumstances set forth in Note 15 to the Financial Statements included in OG&E's 2019 Form 10-K appropriately represent, in all material respects, the current status of OG&E's regulatory matters.

Completed Regulatory Matters

Arkansas 2019 Formula Rate Plan Filing

OG&E filed its second evaluation report under its Formula Rate Plan in October 2019. On January 29, 2020, OG&E, the General Staff of the APSC and the Office of the Arkansas Attorney General filed a settlement agreement requesting the APSC approve a $5.2 million revenue increase, with rates effective April 1, 2020. The settling parties agreed that the Series I grid modernization projects are prudent in both action and cost and that the Series II grid modernization projects are prudent in action only and the determination of prudence of costs will be reserved until the actual historical costs are reviewed. The settling parties also agreed that OG&E will no longer use projections for the remaining initial term or extension of its current Formula Rate Plan and that all costs will be included for recovery for the first time in the historical year. On February 28, 2020, the APSC approved the settlement agreement.

Pending Regulatory Matters

Set forth below is a list of various proceedings pending before state or federal regulatory agencies. Unless stated otherwise, OG&E cannot predict when the regulatory agency will act or what action the regulatory agency will take. OG&E's financial results are dependent in part on timely and adequate 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 - 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.

On February 20, 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 - 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. On March 2, 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 appeal will likely be heard later this year.

OG&E cannot predict the outcome of this proceeding based on currently available information, and as of March 31, 2020 and at present time, OG&E has not reserved an amount for a potential refund. If the reversal of the July 2016 FERC order remains intact, 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. If refunds were required, recovery of these upgrade credits would shift to future periods. Of the $13.0 million, OG&E would be impacted by $5.0 million in expense that initially benefited OG&E 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.

The SPP has recently proposed eliminating Attachment Z2 revenue crediting and replacing it with a different mechanism that would provide project sponsors such as OG&E the same level of recovery they would receive if payments continued under Attachment Z2. The FERC rejected that proposal to the extent it would limit recovery to the amount of the upgrade sponsor's directly assigned upgrade costs with interest, finding that providing the possibility of recovering greater than the cost of the investment could serve as an incentive for entities to build merchant transmission projects. The SPP is allowed to resubmit a proposal without this limited recovery.

APSC Proceedings

Environmental Compliance Plan Rider

In May 2019, OG&E filed an environmental compliance plan rider in Arkansas to recover its investment for the environmentally mandated costs associated with the Sooner Dry Scrubbers project and the conversion of Muskogee Units 4 and 5 to natural gas. The filing is an interim surcharge, subject to refund, that began with the first billing cycle of June 2019. OG&E is reserving the amounts collected through the interim surcharge, pending APSC approval of OG&E's filing. A hearing on the merits was held in December 2019, and parties submitted additional briefs to the APSC in March 2020. The primary question before the APSC is whether a company can utilize an environmental compliance plan rider while also being regulated under a formula rate plan. OG&E is awaiting a final decision from the APSC.

Order Regarding COVID-19

On April 10, 2020, the APSC issued Order No. 1 related to COVID-19 and the provision of safe, adequate and reliable utility service at just and reasonable rates. Among other things, the APSC ordered the suspension of disconnects during the pendency of the Arkansas Governor's emergency declaration or until the directive is rescinded by the APSC, as well as encouraging reasonable payment arrangements once the prohibition is lifted. The APSC also authorized utilities to establish regulatory assets to record costs resulting from the suspension of disconnections. These regulatory assets will be reviewed in future proceedings for reasonableness. The APSC ordered the General Staff of the APSC to consult with utilities to create a quarterly report to be used to report the costs incurred and saved that have been booked to the regulatory asset. OG&E is monitoring the regulatory activity regarding COVID-19 at the APSC and will consider the request for additional regulatory action by the APSC as needed.

On May 1, 2020, OG&E filed a Request for Additional Actions and Tariff Deviation seeking relief from the Arkansas General Service Rules and OG&E's Terms and Conditions under the tariff, in order to allow for: more flexible deferred payment agreements for all customer classes, suspension of increased deposits due to non-payment and suspension of the removal of customers from certain billing and extended due date plans for late payments. In addition, OG&E requested that incremental expenses, such as additional personal protective equipment, increased sanitation efforts at facilities, implementing health-screening processes and securing temporary facilities for potential sequestration of critical operation personnel, be

tracked in a regulatory asset. OG&E noted that all possible cost categories are not known currently and reserved the right to file subsequent requests as needed.

OCC Proceedings

Oklahoma Grid Enhancement Plan

On February 24, 2020, OG&E filed an application with the OCC for approval of a mechanism that allows for interim recovery of the costs associated with its grid enhancement plan. The plan includes approximately $800.0 million of strategic, data-driven investments, over five years, covering grid resiliency, grid automation, communication systems and technology platforms and applications. A hearing on the merits is scheduled to begin on July 7, 2020.

Oklahoma Retail Electric Supplier Certified Territory Act Causes

Certain 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. If the OCC were to ultimately find that some or all of the customers being served are not exempted, then OG&E would have to evaluate the recoverability of some plant investments made to serve these customers. OG&E may also be required to reimburse certified territory suppliers for an amount of lost revenue.

OCC Public Utility Division Motion Regarding COVID-19

On April 28, 2020, the Director of the Public Utility Division filed an application requesting an order from the OCC authorizing action in response to COVID-19. The application requests the OCC to authorize the State's utilities to record as a regulatory asset increased bad debt expenses, costs associated with expanded payment plans, waived fees and incremental expenses that are directly related to the suspension of or delay in disconnection of service beginning March 15, 2020, with the issuance of the Oklahoma Governors' emergency declaration. The application also requests the OCC to allow utilities to defer additional expenses associated with ensuring the continuity of utility service, such as additional personal protective equipment, increased sanitation efforts at facilities, implementing heath-screening processes and securing temporary facilities for potential sequestration of critical operation personnel. The application asks the OCC to consider in future proceedings whether each utility's request for recovery of these regulatory assets is reasonable and necessary and to consider issues such as the incremental bad debt experienced over normal periods, the appropriate period of recovery for any approved amount of regulatory asset, any amount of carrying costs and other related matters. The application is scheduled to be heard by the OCC on May 7, 2020.

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CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Income Statement [Abstract]
Revenues from contracts with customers	$ 420.4	$ 477.4
Other revenues	10.9	12.6
Operating revenues	431.3	490.0
COST OF SALES	135.0	212.6
OPERATING EXPENSES
Other operation and maintenance	121.0	120.3
Depreciation and amortization	94.4	82.4
Taxes other than income	23.9	24.4
Operating expenses	239.3	227.1
OPERATING INCOME	57.0	50.3
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction	1.3	1.5
Other net periodic benefit income (expense)	(0.5)	0.4
Other income	1.5	1.4
Other expense	(0.5)	(0.7)
Net other income	1.8	2.6
INTEREST EXPENSE
Interest on long-term debt	36.6	32.6
Allowance for borrowed funds used during construction	(0.5)	(1.0)
Interest on short-term debt and other interest charges	0.8	0.8
Interest expense	36.9	32.4
INCOME BEFORE TAXES	21.9	20.5
INCOME TAX EXPENSE	2.0	0.9
NET INCOME	19.9	19.6
Other comprehensive income, net of tax	0.0	0.0
COMPREHENSIVE INCOME	$ 19.9	$ 19.6

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Related Party Transactions

3 Months Ended

Mar. 31, 2020

Related Party Transaction [Line Items]

Related Party Transactions Disclosure [Text Block]

Related Party Transactions

OGE Energy charges operating costs to OG&E based on several factors, and operating costs directly related to OG&E 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 charged operating costs to OG&E of $37.9 million and $37.0 million during the three months ended March 31, 2020 and 2019, respectively.

Enable provides gas transportation services to OG&E pursuant to an agreement that grants 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 purchases gas from Enable when Enable's deliveries exceed OG&E's pipeline receipts. Enable purchases gas from OG&E when OG&E's pipeline receipts exceed Enable's deliveries. The following table summarizes related party transactions between OG&E and Enable during the three months ended March 31, 2020 and 2019.

	Three Months Ended
	March 31,
(In millions)	2020		2019
Operating revenues:
Electricity to power electric compression assets	$	3.7	$	3.8
Cost of sales:
Natural gas transportation services	$	4.7	$	14.8
Natural gas purchases (sales)	$	0.7	$	(1.0)

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Long-Term Debt

3 Months Ended

Mar. 31, 2020

Long-term Debt, Unclassified [Abstract]

Long-Term Debt [Text Block]

Long-Term Debt

At March 31, 2020, OG&E was in compliance with all of its debt agreements.

Industrial Authority Bonds

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

Series			Date Due	Amount
				(In millions)
1.00%	-	5.35%	Garfield Industrial Authority, January 1, 2025	$	47.0
1.00%	-	4.31%	Muskogee Industrial Authority, January 1, 2025	32.4
1.00%	-	5.35%	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 OG&E's Condensed Balance Sheets. OG&E believes that it has sufficient liquidity to meet these obligations.

Issuance of Long-Term Debt

In April 2020, OG&E issued $300.0 million of 3.25 percent senior notes due April 1, 2030. The proceeds from the issuance were added to OG&E's general funds to be used for general corporate purposes, including to fund ongoing capital expenditures and working capital.

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Short-Term Debt and Credit Facilities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Short-term Debt [Line Items]
Advances to parent	$ 265.8	$ 304.8
Letters of Credit Outstanding	$ 0.3
Weighted Average Interest Rate	1.00%
OG&E [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Current Borrowing Capacity	$ 450.0
Intercomany Borrowings, Maximum Borrowing Capacity	350.0
Outstanding Intercompany Borrowings	0.0
Commercial Paper	0.0
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

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Regulatory Assets and Liabilities [Table Text Block]

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

	March 31,		December 31,
(In millions)	2020		2019
REGULATORY ASSETS
Current:
Generation Capacity Replacement rider under recovery (A)	$	4.6	$	3.7
Fuel clause under recoveries	—		39.5
Other (A)	8.2		5.5
Total current regulatory assets	$	12.8	$	48.7
Non-current:
Benefit obligations regulatory asset	$	165.2	$	167.2
Deferred storm expenses	63.9		65.5
Sooner Dry Scrubbers	20.4		20.6
Smart Grid	16.6		18.4
Unamortized loss on reacquired debt	10.4		10.6
Arkansas deferred pension expenses	7.8		8.0
Pension tracker	0.9		2.3
Other	14.8		13.4
Total non-current regulatory assets	$	300.0	$	306.0
REGULATORY LIABILITIES
Current:
Fuel clause over recoveries	$	15.6	$	4.8
Reserve for tax refund and interim surcharge (B)	4.8		12.7
Oklahoma demand program rider over recovery (B)	4.4		2.0
SPP cost tracker over recovery (B)	—		2.6
Other (B)	5.6		6.9
Total current regulatory liabilities	$	30.4	$	29.0
Non-current:
Income taxes refundable to customers, net	$	890.9	$	899.2
Accrued removal obligations, net	319.7		318.5
Other	5.5		5.8
Total non-current regulatory liabilities	$	1,216.1	$	1,223.5

(A)Included in Other Current Assets in the Condensed Balance Sheets.

(B)Included in Other Current Liabilities in the Condensed Balance Sheets.

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Stock-Based Compensation (Tables)

3 Months Ended

Mar. 31, 2020

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

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

The following table summarizes OG&E's pre-tax compensation expense and related income tax benefit during the three months ended March 31, 2020 and 2019 related to OGE Energy's performance units and restricted stock units for OG&E employees.

	Three Months Ended March 31,
(In millions)	2020		2019
Performance units:
Total shareholder return	$	0.7	$	0.8
Earnings per share	0.1		0.1
Total performance units	0.8		0.9
Restricted stock units	0.1		0.1
Total compensation expense	$	0.9	$	1.0
Income tax benefit	$	0.2	$	0.3

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Revenues from Contracts with Customers (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 420.4	$ 477.4
Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	166.9	191.2
Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	91.3	95.4
Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	41.5	52.3
Oilfield [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	38.2	49.4
Public Authority [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	34.7	40.1
System sales revenues
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	372.6	428.4
Provision for Rate Refund [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(0.6)	(0.1)
Integrated Market [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	7.2	6.7
Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	34.2	36.1
Other Contracts with Customers [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 7.0	$ 6.3

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Rate Matters and Regulation (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($)
Estimated Refund to SPP	$ 13.0
Public Utilities, Requested Rate Increase (Decrease), Amount	5.2
Investment in Grid Enhancement	800.0
Impact to Company [Member]
Estimated Refund to SPP	5.0
Customer Impact [Member]
Estimated Refund to SPP	$ 8.0

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Stock-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
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	89,225
Income tax benefit	$ 0.2	$ 0.3
Treasury Stock, Shares, Acquired	255,000
Treasury Stock Acquired, Average Cost Per Share	$ 38.04
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	67,975
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 38.03
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 0.8	0.9
Share-based Payment Arrangement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	0.9	1.0
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 0.1	0.1
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	22,665
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 43.69
Total Shareholder Return [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 0.7	0.8
Performance Units Related to Earnings Per Share [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 0.1	$ 0.1

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CONDENSED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
CURRENT ASSETS
Accounts receivable, less reserve of $1.1 and $1.5, respectively	$ 140.7	$ 153.8
Accrued unbilled revenues	58.9	64.7
Advances to parent	265.8	304.8
Fuel inventories	45.5	46.3
Materials and supplies, at average cost	97.2	90.6
Fuel clause under recoveries	0.0	39.5
Other	24.1	19.6
Total current assets	632.2	719.3
OTHER PROPERTY AND INVESTMENTS	4.6	4.7
PROPERTY, PLANT AND EQUIPMENT
In service	12,856.4	12,765.0
Construction work in progress	149.5	141.6
Total property, plant and equipment	13,005.9	12,906.6
Less: accumulated depreciation	3,920.9	3,868.1
Net property, plant and equipment	9,085.0	9,038.5
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	300.0	306.0
Other	8.9	8.1
Total deferred charges and other assets	308.9	314.1
TOTAL ASSETS	10,030.7	10,076.6
Liabilities, Current [Abstract]
Accounts payable	143.1	175.0
Customer deposits	83.2	83.0
Accrued taxes	24.8	41.9
Accrued interest	35.8	37.9
Accrued compensation	19.7	29.5
Fuel clause over recoveries	15.6	4.8
Other	48.4	65.1
Total current liabilities	370.6	437.2
Long-term Debt, Excluding Current Maturities	3,195.6	3,195.2
Liabilities, Other than Long-term Debt, Noncurrent [Abstract]
Accrued benefit obligations	129.7	133.3
Deferred income taxes	961.0	951.4
Deferred investment tax credits	7.1	7.1
Regulatory Liability, Noncurrent	1,216.1	1,223.5
Other	171.5	170.6
Liabilities, Other than Long-term Debt, Noncurrent, Total	2,485.4	2,485.9
Liabilities, Total	6,051.6	6,118.3
COMMITMENTS AND CONTINGENCIES (NOTE 11)
Stockholders' Equity Attributable to Parent [Abstract]
Common stockholder's equity	1,037.5	1,036.6
Retained earnings	2,941.6	2,921.7
Stockholders' Equity Attributable to Parent, Total	3,979.1	3,958.3
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY	$ 10,030.7	$ 10,076.6

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Stock-Based Compensation

3 Months Ended

Mar. 31, 2020

Share-based Payment Arrangement [Abstract]

Share-based Payment Arrangement [Text Block]

Stock-Based Compensation

The following table summarizes OG&E's pre-tax compensation expense and related income tax benefit during the three months ended March 31, 2020 and 2019 related to OGE Energy's performance units and restricted stock units for OG&E employees.

	Three Months Ended March 31,
(In millions)	2020		2019
Performance units:
Total shareholder return	$	0.7	$	0.8
Earnings per share	0.1		0.1
Total performance units	0.8		0.9
Restricted stock units	0.1		0.1
Total compensation expense	$	0.9	$	1.0
Income tax benefit	$	0.2	$	0.3

During the three months ended March 31, 2020, OGE Energy purchased 255,000 shares of its common stock at an average cost of $38.04 per share on the open market, and 89,225 of these shares were used during the same period to satisfy payouts of earned performance units and restricted stock unit grants to OG&E employees pursuant to OGE Energy's Stock Incentive Plan.

During the three months ended March 31, 2020, OGE Energy granted 67,975 performance units (based on total shareholder return over a three-year period) and 22,665 restricted stock units (three-year cliff vesting period) to OG&E employees at $38.03 and $43.69 fair value per share, respectively.

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Accounting Pronouncements

3 Months Ended

Mar. 31, 2020

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

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

Accounting Pronouncements

Recently Adopted Accounting Standards

Financial Instruments - Credit Losses. In June 2016, the FASB issued ASU 2016-13, "Financial Instruments - Credit Losses: Measurement of Credit Losses on Financial Information." The amendments in this update require entities to measure all expected credit losses of financial assets held at a reporting date based on historical experience, current conditions and reasonable and supportable forecasts in order to record credit losses in a more timely manner. ASU 2016-13 also amends the accounting for credit losses on available-for-sale debt securities and purchased financial assets with credit deterioration. OG&E adopted this standard in the first quarter of 2020 utilizing a modified-retrospective approach and determined the only financial instrument that OG&E currently holds and is required to measure under ASU 2016-13 is its trade receivables. Under this standard, OG&E considers forecasts of future economic conditions in addition to the historical data utilized prior to ASU 2016-13 when measuring the reserve for trade receivables. OG&E evaluated its reserve for trade receivables in light of the new guidance and determined that no adjustment was necessary to the amount recorded as of January 1, 2020.

Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract. In August 2018, the FASB issued ASU 2018-15, "Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract." The new guidance aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. OG&E adopted and prospectively applied the new guidance in the first quarter of 2020, which did not have a material effect on the Condensed Financial Statements upon adoption. Beginning in the first quarter of 2020, OG&E records capitalized implementation costs incurred in a hosting arrangement that is a service contract in Other Current Assets and records the related amortization expense in Other Operation and Maintenance in OG&E's Condensed Balance Sheet and Statement of Income, respectively.

Disclosure Framework. In August 2018, the FASB issued ASU 2018-13, "Fair Value Measurement (Topic 820): Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement" and ASU 2018-14, "Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans." The new guidance removes, adds, modifies or clarifies disclosure requirements that impact all levels of the fair value hierarchy, as well as investments measured using the net asset value practical expedient, and disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans, respectively. OG&E adopted these standards in the first quarter of 2020 and applied the new guidance either retrospectively or prospectively, depending upon the specific disclosure change. ASU 2018-13 and ASU 2018-14 did not have a significant impact on OG&E's financial statement disclosures.

Reference Rate Reform. In March 2020, the FASB issued ASU 2020-04, "Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting." The new guidance provides optional expedients and exceptions, if certain criteria are met, for applying GAAP to contracts, hedging relationships and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. Contracts modified between March 12, 2020 and December 31, 2022 as a result of reference rate reform are eligible for these expedients and exceptions. OG&E adopted ASU 2020-04 in the first quarter of 2020 and does not expect this standard to have a material impact on OG&E's financial statements.

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Retirement Plans and Postretirement Benefit Plans

3 Months Ended

Mar. 31, 2020

Defined Benefit Plan [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

Retirement Plans and Postretirement Benefit Plans

Net Periodic Benefit Cost

The following table presents the net periodic benefit cost components, before consideration of capitalized amounts, of OG&E's portion 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, and the remaining net periodic benefit cost components as listed in the table below are presented within Other Net Periodic Benefit Income (Expense) in OG&E's Condensed 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 Income (Expense) in OG&E's Condensed Statements of Income.

	Pension Plan				Restoration of Retirement Income Plan				Postretirement Benefit Plans
	Three Months Ended				Three Months Ended				Three Months Ended
	March 31,				March 31,				March 31,
(In millions)	2020		2019		2020		2019		2020		2019
Service cost	$	2.6	$	2.4	$	0.1	$	—	$	—	$	—
Interest cost	3.4		4.3		—		0.1		0.8		1.0
Expected return on plan assets	(7.1)		(6.6)		—		—		(0.4)		(0.4)
Amortization of net loss	2.8		2.8		0.1		0.1		0.7		0.7
Amortization of unrecognized prior service cost (A)	—		—		—		—		(1.5)		(1.5)
Settlement cost	—		10.9		—		—		—		—
Total net periodic benefit cost	1.7		13.8		0.2		0.2		(0.4)		(0.2)
Plus: Amount allocated from OGE Energy	0.5		2.0		0.2		0.1		(0.2)		(0.2)
Net periodic benefit cost	$	2.2	$	15.8	$	0.4	$	0.3	$	(0.6)	$	(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.

In addition to the net periodic benefit cost amounts recognized, as presented in the table above, for the Pension and Restoration of Retirement Income Plans for the three months ended March 31, 2020 and 2019, OG&E recognized the following:

	Three Months Ended
	March 31,
(In millions)	2020		2019
Increase (decrease) of pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	1.7	$	(1.0)
Deferral of pension expense related to pension settlement charges:
Oklahoma jurisdiction (A)	$	—	$	11.2
Arkansas jurisdiction (A)	$	—	$	1.0

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

In addition to the net periodic benefit income amounts recognized, as presented in the table above, for the postretirement benefit plans for the three months ended March 31, 2020 and 2019, OG&E recognized the following:

	Three Months Ended
	March 31,
(In millions)	2020		2019
Increase of postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	0.2	$	0.3

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

	Three Months Ended
	March 31,
(In millions)	2020		2019
Capitalized portion of net periodic pension benefit cost	$	0.9	$	0.8
Capitalized portion of net periodic postretirement benefit cost	$	—	$	0.1

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Retirement Plans and Postretirement Benefit Plans (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2020	Mar. 31, 2019
Other Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		$ 0.1	$ 0.0
Interest cost		0.0	0.1
Expected return on plan assets		0.0	0.0
Amortization of net loss		0.1	0.1
Amortization of unrecognized prior service cost	[1]	0.0	0.0
Settlement cost		0.0	0.0
Net periodic benefit cost		0.2	0.2
Amount Attributable to Unconsolidated Affiliates		0.2	0.1
Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		2.6	2.4
Interest cost		3.4	4.3
Expected return on plan assets		(7.1)	(6.6)
Amortization of net loss		2.8	2.8
Amortization of unrecognized prior service cost	[1]	0.0	0.0
Settlement cost		0.0	10.9
Net periodic benefit cost		1.7	13.8
Amount Attributable to Unconsolidated Affiliates		0.5	2.0
Capitalized Portion of Net Periodic Benefit Cost		0.9	0.8
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost		0.0	0.0
Interest cost		0.8	1.0
Expected return on plan assets		(0.4)	(0.4)
Amortization of net loss		0.7	0.7
Amortization of unrecognized prior service cost	[1]	(1.5)	(1.5)
Settlement cost		0.0	0.0
Net periodic benefit cost		(0.4)	(0.2)
Amount Attributable to Unconsolidated Affiliates		(0.2)	(0.2)
Capitalized Portion of Net Periodic Benefit Cost		0.0	0.1
Defined Benefit Plan, Net Periodic Benefit Cost, Net of Unconsolidated Affiliates		(0.6)	(0.4)
OKLAHOMA | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Settlement cost	[2]	0.0	(11.2)
Additional Pension Expense to Meet State Requirements	[2]	1.7	(1.0)
OKLAHOMA | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Additional Pension Expense to Meet State Requirements	[3]	0.2	0.3
ARKANSAS | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Settlement cost	[2]	0.0	1.0
Og and E [Member] | Other Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Net periodic benefit cost		0.4	0.3
Og and E [Member] | Pension Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Net periodic benefit cost		$ 2.2	$ 15.8

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

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

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Fair Value Measurements (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019
OG&E Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 3,050.7	$ 3,050.3
Long-term Debt, Fair Value	3,240.1	3,500.4
OG&E Industrial Authority Bonds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	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	9.5	9.5
Long-term Debt, Fair Value	9.7	$ 10.0
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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Income Taxes	3 Months Ended
	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]	Income TaxesOG&E is a member of an affiliated group that files consolidated income tax returns in the U.S. federal jurisdiction and various state jurisdictions. With few exceptions, OG&E is no longer subject to U.S. federal tax or state and local examinations by tax authorities for years prior to 2016. Income taxes are generally allocated to each company in the affiliated group based on its stand-alone taxable income or loss. Federal investment tax credits previously claimed on electric utility property have been deferred and will be amortized to income over the life of the related property. Additionally, OG&E earns federal tax credits associated with production from its wind facilities. 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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Revenues from Contracts with Customers (Notes)

3 Months Ended

Mar. 31, 2020

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer [Text Block]

Revenue Recognition

The following table disaggregates OG&E's revenues from contracts with customers by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "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)	2020		2019
Residential	$	166.9	$	191.2
Commercial	91.3		95.4
Industrial	41.5		52.3
Oilfield	38.2		49.4
Public authorities and street light	34.7		40.1
System sales revenues	372.6		428.4
Provision for rate refund	(0.6)		(0.1)
Integrated market	7.2		6.7
Transmission	34.2		36.1
Other	7.0		6.3
Revenues from contracts with customers	$	420.4	$	477.4

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies [Text Block]

Commitments and Contingencies

Except as set forth below, in Note 12 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 14 and 15 to OG&E's Financial Statements included in OG&E's 2019 Form 10-K appropriately represent, in all material respects, the current status of OG&E's material commitments and contingent liabilities.

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 its 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.

OtherIn the normal course of business, OG&E is 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, OG&E has incurred a probable loss as set forth by GAAP, an estimate is made of the loss, and the appropriate accounting entries are reflected in OG&E's Condensed Financial Statements. At the present time, based on currently available information, OG&E believes that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to its financial statements and would not have a material adverse effect on OG&E's financial position, results of operations or cash flows.

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CONDENSED BALANCE SHEETS (Unaudited) Parenthetical - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Accounts Receivable, Allowance for Credit Loss	$ 1.1	$ 1.5

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Document And Entity Information	3 Months Ended
	Mar. 31, 2020 shares
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2020
Document Transition Report	false
Entity File Number	1-1097
Entity Registrant Name	OKLAHOMA GAS AND ELECTRIC COMPANY
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-0382390
Entity Central Index Key	0000074145
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Amendment Flag	false
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 Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	40,378,745

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Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Operating Costs Charged [Member] | OG&E [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	$ 37.9	$ 37.0
OG&E [Member] | Enable Midstream Partners [Member]
Related Party Transaction [Line Items]
Electricity to power electric compression assets	3.7	3.8
OG&E [Member] | Natural Gas Transportation [Member] | Enable Midstream Partners [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from related party	4.7	14.8
OG&E [Member] | Natural Gas Purchases [Member] | Enable Midstream Partners [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from related party	$ 0.7	$ (1.0)

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Revenues from Contracts with Customers (Tables)

3 Months Ended

Mar. 31, 2020

Revenues from Contracts with Customers [Abstract]

Disaggregation of Revenue [Table Text Block]

The following table disaggregates OG&E's revenues from contracts with customers by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "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)	2020		2019
Residential	$	166.9	$	191.2
Commercial	91.3		95.4
Industrial	41.5		52.3
Oilfield	38.2		49.4
Public authorities and street light	34.7		40.1
System sales revenues	372.6		428.4
Provision for rate refund	(0.6)		(0.1)
Integrated market	7.2		6.7
Transmission	34.2		36.1
Other	7.0		6.3
Revenues from contracts with customers	$	420.4	$	477.4

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Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2020

Long-term Debt, Unclassified [Abstract]

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

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

Series			Date Due	Amount
				(In millions)
1.00%	-	5.35%	Garfield Industrial Authority, January 1, 2025	$	47.0
1.00%	-	4.31%	Muskogee Industrial Authority, January 1, 2025	32.4
1.00%	-	5.35%	Muskogee Industrial Authority, June 1, 2027	56.0
Total (redeemable during next 12 months)				$	135.4