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Oklahoma Gas And Electric

Filed: 4 Aug 21, 8:00pm

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
 QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2021
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 NumberExact name of registrants as specified in their charters, address of principal executive offices and registrants' telephone numberI.R.S. Employer Identification No.
1-12579OGE ENERGY CORP.73-1481638
1-1097OKLAHOMA GAS AND ELECTRIC COMPANY73-0382390
321 North Harvey
P.O. Box 321
Oklahoma City, Oklahoma 73101-0321
405-553-3000

State or other jurisdiction of incorporation or organization: Oklahoma
Securities registered pursuant to Section 12(b) of the Act:
RegistrantTitle of each classTrading Symbol(s)Name of each exchange on which registered
OGE Energy Corp.Common StockOGENew York Stock Exchange
Oklahoma Gas and Electric CompanyNoneN/AN/A

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).  
OGE Energy Corp.  Yes   No        Oklahoma Gas and Electric Company  Yes   No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act.
OGE Energy Corp.Large accelerated filerAccelerated filerNon-accelerated filerSmaller reporting companyEmerging growth company
Oklahoma Gas and Electric CompanyLarge accelerated filerAccelerated filerNon-accelerated filerSmaller reporting companyEmerging growth company
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
OGE Energy Corp.   Yes   No        Oklahoma Gas and Electric Company ☐  Yes   No    

At June 30, 2021, there were 200,174,361 shares of OGE Energy Corp.'s common stock, par value $0.01 per share, outstanding.

At June 30, 2021, there were 40,378,745 of Oklahoma Gas and Electric Company's common stock, par value $2.50 per share, outstanding, all of which were held by OGE Energy Corp. There were no other shares of capital stock of the registrants outstanding at such date.

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




FORM 10-Q

FOR THE QUARTER ENDED JUNE 30, 2021

TABLE OF CONTENTS

i


GLOSSARY OF TERMS

The following is a glossary of frequently used abbreviations that are found throughout this Form 10-Q.
AbbreviationDefinition
2020 Form 10-KAnnual Report on Form 10-K for the year ended December 31, 2020
APSCArkansas Public Service Commission
ASCFinancial Accounting Standards Board Accounting Standards Codification
CenterPointCenterPoint Energy Resources Corp., wholly-owned subsidiary of CenterPoint Energy, Inc.
CO2
Carbon dioxide
COVID-19Novel Coronavirus disease
Dry ScrubberDry flue gas desulfurization unit with spray dryer absorber
EnableEnable Midstream Partners, LP, partnership formed to own and operate the midstream businesses of OGE Energy and CenterPoint
Energy TransferEnergy Transfer LP, a Delaware limited partnership
Enogex HoldingsEnogex Holdings LLC, the parent company of Enogex LLC and a majority-owned subsidiary of OGE Holdings, LLC (prior to May 1, 2013)
Enogex LLCEnogex LLC, collectively with its subsidiaries (effective July 31, 2013, the name was changed to Enable Oklahoma Intrastate Transmission, LLC)
EPAU.S. Environmental Protection Agency
Federal Clean Air ActFederal Clean Air Act of 1970, as amended
Federal Clean Water ActFederal Water Pollution Control Act of 1972, as amended
FERCFederal Energy Regulatory Commission
FIPFederal Implementation Plan
GAAPAccounting principles generally accepted in the U.S.
IRPIntegrated Resource Plan
ISOIndependent system operator
MATSMercury and Air Toxics Standards
MBbl/dThousand barrels per day
MWMegawatt
MWhMegawatt-hour
NAAQSNational Ambient Air Quality Standards
NGLsNatural gas liquids, which are the hydrocarbon liquids contained within the natural gas stream
NOPRNotice of proposed rulemaking
NOX
Nitrogen oxide
OCCOklahoma Corporation Commission
ODEQOklahoma Department of Environmental Quality
OG&EOklahoma Gas and Electric Company, wholly-owned subsidiary of OGE Energy
OGE EnergyOGE Energy Corp., collectively with its subsidiaries, holding company and parent company of OG&E
OGE HoldingsOGE Enogex Holdings, LLC, wholly-owned subsidiary of OGE Energy, parent company of Enogex Holdings (prior to May 1, 2013) and 25.5 percent owner of Enable
Pension PlanQualified defined benefit retirement plan
Regional Haze RuleThe EPA's Regional Haze Rule
RegistrantsOGE Energy and OG&E
Restoration of Retirement Income PlanSupplemental retirement plan to the Pension Plan
RTORegional transmission organization
SIPState Implementation Plan
SO2
Sulfur dioxide
SPPSouthwest Power Pool
System salesSales to OG&E's customers
TBtu/dTrillion British thermal units per day
U.S.United States of America
USFWSUnited States Fish and Wildlife Service
Winter Storm UriUnprecedented, prolonged extreme cold weather event in February 2021
ii


FILING FORMAT

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

FORWARD-LOOKING STATEMENTS

Except for the historical statements contained herein, the matters discussed within this Form 10-Q, including those matters discussed within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations," are forward-looking statements that are subject to certain risks, uncertainties and assumptions. Such forward-looking statements are intended to be identified in this document by the words "anticipate," "believe," "estimate," "expect," "intend," "objective," "plan," "possible," "potential," "project," "target" and similar expressions. Actual results may vary materially from those expressed in forward-looking statements. In addition to the specific risk factors discussed within "Item 1A. Risk Factors" in the Registrants' 2020 Form 10-K and within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" herein, factors that could cause actual results to differ materially from the forward-looking statements include, but are not limited to:

general economic conditions, including the availability of credit, access to existing lines of credit, access to the commercial paper markets, actions of rating agencies and their impact on capital expenditures;
the ability of OGE Energy and its subsidiaries to access the capital markets and obtain financing on favorable terms as well as inflation rates and monetary fluctuations;
the ability to obtain timely and sufficient rate relief to allow for recovery of items such as capital expenditures, fuel costs, operating costs, transmission costs and deferred expenditures;
prices and availability of electricity, coal, natural gas and NGLs;
for OGE Energy, the timing and extent of changes in commodity prices, particularly natural gas and NGLs, the competitive effects of the available pipeline capacity in the regions Enable serves and the effects of geographic and seasonal commodity price differentials, including the effects of these circumstances on re-contracting available capacity on Enable's interstate pipelines;
for OGE Energy, the timing and extent of changes in the supply of natural gas, particularly supplies available for gathering by Enable's gathering and processing business and transporting by Enable's interstate and intrastate pipelines, including the impact of natural gas and NGLs prices on the level of drilling and production activities in the regions Enable serves;
for OGE Energy, business conditions in the energy and natural gas midstream industries, including the demand for natural gas, NGLs, crude oil and midstream services;
competitive factors, including the extent and timing of the entry of additional competition in the markets served by the Registrants;
the impact on demand for services resulting from cost-competitive advances in technology, such as distributed electricity generation and customer energy efficiency programs;
technological developments, changing markets and other factors that result in competitive disadvantages and create the potential for impairment of existing assets;
factors affecting utility operations such as unusual weather conditions; catastrophic weather-related damage; unscheduled generation outages, unusual maintenance or repairs; unanticipated changes to fossil fuel, natural gas or coal supply costs or availability due to higher demand, shortages, transportation problems or other developments; environmental incidents; or electric transmission or gas pipeline system constraints;
availability and prices of raw materials for current and future construction projects;
the effect of retroactive pricing of transactions in the SPP markets or adjustments in market pricing mechanisms by the SPP;
federal or state legislation and regulatory decisions and initiatives that affect cost and investment recovery, have an impact on rate structures or affect the speed and degree to which competition enters the Registrants' markets;
environmental laws, safety laws or other regulations that may impact the cost of operations or restrict or change the way the Registrants' facilities are operated;
1


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, natural gas and power industries;
identification of suitable investment opportunities to enhance shareholder returns and achieve long-term financial objectives through business acquisitions and divestitures;
increased pension and healthcare costs;
the impact of extraordinary external events, such as the current pandemic health event resulting from COVID-19, and their collateral consequences, including extended disruption of economic activity in the Registrants' markets;
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;
difficulty in making accurate assumptions and projections regarding future revenues and costs associated with OGE Energy's equity investment in Enable that OGE Energy does not control;
Enable's pending merger with Energy Transfer and the expected timing of the consummation of the merger; and
other risk factors listed in the reports filed by the Registrants with the Securities and Exchange Commission, including those listed within "Item 1A. Risk Factors" in the Registrants' 2020 Form 10-K.

The Registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.
2


PART I. FINANCIAL INFORMATION

Item 1. Financial Statements.

OGE ENERGY CORP.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
Three Months Ended June 30,Six Months Ended June 30,
(In millions, except per share data)2021202020212020
OPERATING REVENUES
Revenues from contracts with customers$564.5 $492.0 $2,185.5 $912.4 
Other revenues12.9 11.5 22.5 22.4 
Operating revenues577.4 503.5 2,208.0 934.8 
FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE200.0 137.4 1,546.8 272.4 
OPERATING EXPENSES  
Other operation and maintenance119.2 117.5 228.5 237.5 
Depreciation and amortization102.9 97.3 201.6 191.7 
Taxes other than income25.8 25.9 53.0 51.5 
Operating expenses247.9 240.7 483.1 480.7 
OPERATING INCOME129.5 125.4 178.1 181.7 
OTHER INCOME (EXPENSE)  
Equity in earnings (losses) of unconsolidated affiliates33.5 26.9 86.7 (719.6)
Allowance for equity funds used during construction1.6 1.3 2.9 2.6 
Other net periodic benefit expense(1.3)(1.0)(2.7)(1.5)
Other income6.3 14.1 9.3 21.5 
Other expense(6.7)(12.4)(8.7)(18.5)
Net other income (expense)33.4 28.9 87.5 (715.5)
INTEREST EXPENSE  
Interest on long-term debt37.8 38.8 76.2 75.4 
Allowance for borrowed funds used during construction(0.7)(0.5)(1.5)(1.0)
Interest on short-term debt and other interest charges2.8 2.5 4.6 4.7 
Interest expense39.9 40.8 79.3 79.1 
INCOME (LOSS) BEFORE TAXES123.0 113.5 186.3 (612.9)
INCOME TAX EXPENSE (BENEFIT)10.1 27.6 20.7 (207.0)
NET INCOME (LOSS)$112.9 $85.9 $165.6 $(405.9)
BASIC AVERAGE COMMON SHARES OUTSTANDING200.2 200.2 200.1 200.2 
DILUTED AVERAGE COMMON SHARES OUTSTANDING200.4 200.5 200.2 200.2 
BASIC EARNINGS (LOSS) PER AVERAGE COMMON SHARE$0.56 $0.43 $0.83 $(2.03)
DILUTED EARNINGS (LOSS) PER AVERAGE COMMON SHARE$0.56 $0.43 $0.83 $(2.03)









The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
3


OGE ENERGY CORP.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2021202020212020
Net income (loss)$112.9 $85.9 $165.6 $(405.9)
Other comprehensive income (loss), net of tax:  
Pension Plan and Restoration of Retirement Income Plan:  
Amortization of deferred net loss, net of tax of $0.2, $0.3, $0.4 and $0.6, respectively0.2 1.2 0.8 2.0 
Settlement cost, net of tax of $0.6, $0.1, $1.6 and $0.1, respectively0.6 0.2 3.7 0.2 
Postretirement benefit plans:  
Amortization of prior service credit, net of tax of ($0.1), ($0.1), ($0.2) and ($0.3), respectively(0.4)(0.4)(0.7)(0.8)
Amortization of deferred net gain, net of tax of $0.0, $0.0, $0.0 and $0.0, respectively0.1 (0.1)0.1 (0.1)
Other comprehensive gain (loss) from unconsolidated affiliates, net of tax of $0.1, $0.0, $0.1 and ($0.4), respectively0.2 0.3 (1.3)
Other comprehensive income (loss), net of tax0.7 0.9 4.2 
Comprehensive income (loss)$113.6 $86.8 $169.8 $(405.9)






























The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
4


OGE ENERGY CORP.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
Six Months Ended June 30,
(In millions)20212020
CASH FLOWS FROM OPERATING ACTIVITIES  
Net income (loss)$165.6 $(405.9)
Adjustments to reconcile net income (loss) to net cash provided from operating activities:
Depreciation and amortization201.6 191.7 
Deferred income taxes and investment tax credits, net15.5 (226.7)
Equity in (earnings) losses of unconsolidated affiliates(86.7)719.6 
Distributions from unconsolidated affiliates36.7 55.0 
Allowance for equity funds used during construction(2.9)(2.6)
Stock-based compensation expense4.8 4.3 
Regulatory assets(879.5)(6.1)
Regulatory liabilities(34.4)(26.7)
Other assets(5.8)1.3 
Other liabilities(43.3)(15.6)
Change in certain current assets and liabilities:  
Accounts receivable and accrued unbilled revenues, net(41.9)(35.8)
Income taxes receivable4.0 10.4 
Fuel, materials and supplies inventories(10.4)(1.5)
Fuel recoveries(24.3)71.9 
Other current assets(5.6)(10.8)
Accounts payable(71.1)(51.2)
Other current liabilities9.9 (8.0)
Net cash (used in) provided from operating activities(767.8)263.3 
CASH FLOWS FROM INVESTING ACTIVITIES  
Capital expenditures (less allowance for equity funds used during construction)(353.5)(280.8)
Investment in unconsolidated affiliates(3.3)(1.5)
Net cash used in investing activities(356.8)(282.3)
CASH FLOWS FROM FINANCING ACTIVITIES  
Proceeds from long-term debt999.6 297.2 
Increase (decrease) in short-term debt289.5 (37.0)
Dividends paid on common stock(162.2)(156.8)
Cash paid for employee equity-based compensation and expense of common stock(3.4)(7.2)
Purchase of treasury stock0 (9.7)
Net cash provided from financing activities1,123.5 86.5 
NET CHANGE IN CASH AND CASH EQUIVALENTS(1.1)67.5 
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD1.1 
CASH AND CASH EQUIVALENTS AT END OF PERIOD$0 $67.5 







The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
5


OGE ENERGY CORP.
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
June 30,December 31,
(In millions)20212020
ASSETS  
CURRENT ASSETS  
Cash and cash equivalents$0 $1.1 
Accounts receivable, less reserve of $1.8 and $2.6, respectively173.2 157.8 
Accrued unbilled revenues94.7 67.6 
Income taxes receivable4.1 8.1 
Fuel inventories46.1 36.5 
Materials and supplies, at average cost119.0 116.2 
Fuel clause under recoveries0.4 
Other47.1 41.2 
Total current assets484.6 428.5 
OTHER PROPERTY AND INVESTMENTS
Investment in unconsolidated affiliates451.7 397.4 
Other90.3 86.7 
Total other property and investments542.0 484.1 
PROPERTY, PLANT AND EQUIPMENT  
In service13,582.7 13,296.7 
Construction work in progress181.0 145.5 
Total property, plant and equipment13,763.7 13,442.2 
Less: accumulated depreciation4,188.5 4,067.6 
Net property, plant and equipment9,575.2 9,374.6 
DEFERRED CHARGES AND OTHER ASSETS  
Regulatory assets1,278.3 415.6 
Other19.4 16.0 
Total deferred charges and other assets1,297.7 431.6 
TOTAL ASSETS$11,899.5 $10,718.8 





















The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
6


OGE ENERGY CORP.
CONDENSED CONSOLIDATED BALANCE SHEETS (Continued)
(Unaudited)
June 30,December 31,
(In millions)20212020
LIABILITIES AND STOCKHOLDERS' EQUITY  
CURRENT LIABILITIES  
Short-term debt$384.5 $95.0 
Accounts payable189.8 251.5 
Dividends payable80.6 80.5 
Customer deposits80.9 81.1 
Accrued taxes56.5 55.7 
Accrued interest40.8 40.2 
Accrued compensation36.0 31.1 
Fuel clause over recoveries4.7 28.6 
Other37.5 33.7 
Total current liabilities911.3 697.4 
LONG-TERM DEBT4,495.2 3,494.4 
DEFERRED CREDITS AND OTHER LIABILITIES  
Accrued benefit obligations179.8 231.4 
Deferred income taxes1,206.5 1,268.6 
Deferred investment tax credits10.9 10.9 
Regulatory liabilities1,259.7 1,188.9 
Other195.3 195.4 
Total deferred credits and other liabilities2,852.2 2,895.2 
Total liabilities8,258.7 7,087.0 
COMMITMENTS AND CONTINGENCIES (NOTE 14)00
STOCKHOLDERS' EQUITY  
Common stockholders' equity1,120.9 1,124.6 
Retained earnings2,547.9 2,544.6 
Accumulated other comprehensive loss, net of tax(27.9)(32.1)
Treasury stock, at cost(0.1)(5.3)
Total stockholders' equity3,640.8 3,631.8 
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY$11,899.5 $10,718.8 

















The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
7


OGE ENERGY CORP.
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY
(Unaudited)
Common StockTreasury Stock



(In millions)
SharesValueSharesValuePremium on Common StockRetained EarningsAccumulated Other Comprehensive (Loss) IncomeTotal
Balance at December 31, 2020200.1 $2.0 0.1 $(5.3)$1,122.6 $2,544.6 $(32.1)$3,631.8 
Net income0 0 0 0 0 52.7 0 52.7 
Other comprehensive income, net of tax0 0 0 0 0 0 3.5 3.5 
Dividends declared on common stock ($0.4025 per share)0 0 0 0 0 (81.7)0 (81.7)
Stock-based compensation0 0 (0.1)5.2 (6.0)0 0 (0.8)
Balance at March 31, 2021200.1 $2.0 0 $(0.1)$1,116.6 $2,515.6 $(28.6)$3,605.5 
Net income0 0 0 0 0 112.9 0 112.9 
Other comprehensive income, net of tax0 0 0 0 0 0 0.7 0.7 
Dividends declared on common stock ($0.4025 per share)0 0 0 0 0 (80.6)0 (80.6)
Stock-based compensation0 0 0 0 2.3 0 0 2.3 
Balance at June 30, 2021200.1$2.0 0 $(0.1)$1,118.9 $2,547.9 $(27.9)$3,640.8 
Balance at December 31, 2019200.1 $2.0 $$1,129.3 $3,036.1 $(27.9)$4,139.5 
Net loss(491.8)(491.8)
Other comprehensive loss, net of tax(0.9)(0.9)
Dividends declared on common stock ($0.3875 per share)(79.3)(79.3)
Stock-based compensation(0.2)9.4 (14.5)(5.1)
Purchase of treasury stock0.2 (9.7)(9.7)
Balance at March 31, 2020200.1 $2.0 $(0.3)$1,114.8 $2,465.0 $(28.8)$3,552.7 
Net income85.9 85.9 
Other comprehensive income, net of tax0.9 0.9 
Dividends declared on common stock ($0.3875 per share)(77.6)(77.6)
Stock-based compensation2.3 2.3 
Balance at June 30, 2020200.1$2.0 $(0.3)$1,117.1 $2,473.3 $(27.9)$3,564.2 
















The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
8


OKLAHOMA GAS AND ELECTRIC COMPANY
CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2021202020212020
OPERATING REVENUES
Revenues from contracts with customers$564.5 $492.0 $2,185.5 $912.4 
Other revenues12.9 11.5 22.5 22.4 
Operating revenues577.4 503.5 2,208.0 934.8 
FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE200.0 137.4 1,546.8 272.4 
OPERATING EXPENSES  
Other operation and maintenance118.3 117.7 228.6 238.7 
Depreciation and amortization102.9 97.3 201.6 191.7 
Taxes other than income25.0 25.0 50.7 48.9 
Operating expenses246.2 240.0 480.9 479.3 
OPERATING INCOME131.2 126.1 180.3 183.1 
OTHER INCOME (EXPENSE)  
Allowance for equity funds used during construction1.6 1.3 2.9 2.6 
Other net periodic benefit expense(1.2)(1.0)(2.1)(1.5)
Other income1.1 1.1 2.8 2.6 
Other expense(0.3)(0.9)(0.7)(1.4)
Net other income1.2 0.5 2.9 2.3 
INTEREST EXPENSE  
Interest on long-term debt37.4 38.8 75.8 75.4 
Allowance for borrowed funds used during construction(0.7)(0.5)(1.5)(1.0)
Interest on short-term debt and other interest charges1.2 1.0 2.0 1.8 
Interest expense37.9 39.3 76.3 76.2 
INCOME BEFORE TAXES94.5 87.3 106.9 109.2 
INCOME TAX EXPENSE9.4 8.4 10.6 10.4 
NET INCOME$85.1 $78.9 $96.3 $98.8 
Other comprehensive income, net of tax0  
COMPREHENSIVE INCOME$85.1 $78.9 $96.3 $98.8 



















The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
9


OKLAHOMA GAS AND ELECTRIC COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
Six Months Ended June 30,
(In millions)20212020
CASH FLOWS FROM OPERATING ACTIVITIES  
Net income$96.3 $98.8 
Adjustments to reconcile net income to net cash provided from operating activities:  
Depreciation and amortization201.6 191.7 
Deferred income taxes and investment tax credits, net10.3 6.7 
Allowance for equity funds used during construction(2.9)(2.6)
Stock-based compensation expense1.0 1.6 
Regulatory assets(879.5)(6.1)
Regulatory liabilities(34.4)(26.7)
Other assets(1.4)(2.3)
Other liabilities(38.3)(7.0)
Change in certain current assets and liabilities:  
Accounts receivable and accrued unbilled revenues, net(43.9)(34.2)
Fuel, materials and supplies inventories(10.4)(1.5)
Fuel recoveries(24.3)71.9 
Other current assets(1.3)(6.8)
Accounts payable(66.4)(45.6)
Income taxes payable - parent2.6 5.0 
Other current liabilities8.2 (19.0)
Net cash (used in) provided from operating activities(782.8)223.9 
CASH FLOWS FROM INVESTING ACTIVITIES  
Capital expenditures (less allowance for equity funds used during construction)(353.5)(280.8)
Net cash used in investing activities(353.5)(280.8)
CASH FLOWS FROM FINANCING ACTIVITIES  
Capital contribution from OGE Energy530.0 
Proceeds from long-term debt499.8 297.2 
Changes in advances with parent106.5 (172.8)
Net cash provided from financing activities1,136.3 124.4 
NET CHANGE IN CASH AND CASH EQUIVALENTS0 67.5 
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD0 
CASH AND CASH EQUIVALENTS AT END OF PERIOD$0 $67.5 






















The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
10


OKLAHOMA GAS AND ELECTRIC COMPANY
CONDENSED BALANCE SHEETS
(Unaudited)
June 30,December 31,
(In millions)20212020
ASSETS  
CURRENT ASSETS  
Accounts receivable, less reserve of $1.8 and $2.6, respectively$173.2 $156.3 
Accrued unbilled revenues94.7 67.7 
Advances to parent118.0 272.0 
Fuel inventories46.1 36.5 
Materials and supplies, at average cost119.0 116.2 
Fuel clause under recoveries0.4 
Other38.3 36.9 
Total current assets589.7 685.6 
OTHER PROPERTY AND INVESTMENTS3.9 4.1 
PROPERTY, PLANT AND EQUIPMENT  
In service13,576.6 13,290.6 
Construction work in progress181.0 145.5 
Total property, plant and equipment13,757.6 13,436.1 
Less: accumulated depreciation4,188.5 4,067.6 
Net property, plant and equipment9,569.1 9,368.5 
DEFERRED CHARGES AND OTHER ASSETS  
Regulatory assets1,278.3 415.6 
Other18.3 15.2 
Total deferred charges and other assets1,296.6 430.8 
TOTAL ASSETS$11,459.3 $10,489.0 




























The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
11


OKLAHOMA GAS AND ELECTRIC COMPANY
CONDENSED BALANCE SHEETS (Continued)
(Unaudited)
June 30,December 31,
(In millions)20212020
LIABILITIES AND STOCKHOLDER'S EQUITY  
CURRENT LIABILITIES  
Accounts payable$178.9 $236.7 
Customer deposits80.9 81.1 
Accrued taxes53.4 53.3 
Accrued interest40.5 40.2 
Accrued compensation26.6 22.5 
Fuel clause over recoveries4.7 28.6 
Other37.4 33.5 
Total current liabilities422.4 495.9 
LONG-TERM DEBT3,995.4 3,494.4 
DEFERRED CREDITS AND OTHER LIABILITIES  
Accrued benefit obligations98.0 135.4 
Deferred income taxes951.2 1,020.8 
Deferred investment tax credits10.9 10.9 
Regulatory liabilities1,259.7 1,188.9 
Other163.7 167.1 
Total deferred credits and other liabilities2,483.5 2,523.1 
Total liabilities6,901.3 6,513.4 
COMMITMENTS AND CONTINGENCIES (NOTE 14)00
STOCKHOLDER'S EQUITY  
Common stockholder's equity1,570.6 1,039.5 
Retained earnings2,987.4 2,936.1 
Total stockholder's equity4,558.0 3,975.6 
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY$11,459.3 $10,489.0 
























The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
12


OKLAHOMA GAS AND ELECTRIC COMPANY
CONDENSED STATEMENTS OF CHANGES IN STOCKHOLDER'S EQUITY
(Unaudited)
(In millions)Shares OutstandingCommon StockPremium on Common StockRetained EarningsTotal
Balance at December 31, 202040.4 $100.9 $938.6 $2,936.1 $3,975.6 
Net income0 0 0 11.2 11.2 
Capital contribution from OGE Energy0 0 530.0 0 530.0 
Stock-based compensation0 0 0.5 0 0.5 
Balance at March 31, 202140.4 $100.9 $1,469.1 $2,947.3 $4,517.3 
Net income0 0 0 85.1 85.1 
Dividends declared on common stock0 0 0 (45.0)(45.0)
Stock-based compensation0 0 0.6 0 0.6 
Balance at June 30, 202140.4 $100.9 $1,469.7 $2,987.4 $4,558.0 
Balance at December 31, 201940.4 $100.9 $935.7 $2,921.7 $3,958.3 
Net income19.9 19.9 
Stock-based compensation0.9 0.9 
Balance at March 31, 202040.4 $100.9 $936.6 $2,941.6 $3,979.1 
Net income78.9 78.9 
Dividends declared on common stock(75.0)(75.0)
Stock-based compensation0.7 0.7 
Balance at June 30, 202040.4 $100.9 $937.3 $2,945.5 $3,983.7 





























The accompanying Combined Notes to Condensed Financial Statements are an integral part hereof.
13


COMBINED NOTES TO THE CONDENSED FINANCIAL STATEMENTS
(Unaudited)

Index of Combined Notes to Condensed Financial Statements

The Combined Notes to the Condensed Financial Statements are a combined presentation for OGE Energy and OG&E. The following table indicates the Registrant(s) to which each Note applies.
OGE EnergyOG&E
Note 1. Summary of Significant Accounting PoliciesXX
Note 2. Accounting PronouncementsXX
Note 3. Revenue RecognitionXX
Note 4. Investment in Unconsolidated AffiliatesX
Note 5. Related Party TransactionsXX
Note 6. Fair Value MeasurementsXX
Note 7. Stock-Based CompensationXX
Note 8. Income TaxesXX
Note 9. Common EquityX
Note 10. Long-Term DebtXX
Note 11. Short-Term Debt and Credit FacilitiesXX
Note 12. Retirement Plans and Postretirement Benefit PlansXX
Note 13. Report of Business SegmentsX
Note 14. Commitments and ContingenciesXX
Note 15. Rate Matters and RegulationXX

1.Summary of Significant Accounting Policies

Organization

OGE Energy is a holding company with investments in energy and energy services providers offering physical delivery and related services for both electricity and natural gas primarily in the south-central U.S. OGE Energy conducts these activities through two business segments: (i) electric utility and (ii) natural gas midstream operations. The accounts of OGE Energy and its wholly-owned subsidiaries, including OG&E, are included in OGE Energy's condensed consolidated financial statements. All intercompany transactions and balances are eliminated in such consolidation. OGE Energy generally uses the equity method of accounting for investments where its ownership interest is between 20 percent and 50 percent and it lacks the power to direct activities that most significantly impact economic performance.

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

Enable. OGE Energy's natural gas midstream operations segment represents OGE Energy's investment in Enable. The investment in Enable is held through wholly-owned subsidiaries and ultimately OGE Holdings. Formed in 2013, Enable is primarily engaged in the business of gathering, processing, transporting and storing natural gas. Enable's natural gas gathering and processing assets are strategically located in four states and serve natural gas production in the Anadarko, Arkoma and Ark-La-Tex Basins. Enable also owns crude oil gathering assets in the Anadarko and Williston Basins. Enable has intrastate natural gas transportation and storage assets that are located in Oklahoma as well as interstate assets that extend from western Oklahoma and the Texas Panhandle to Louisiana, from Louisiana to Illinois and from Louisiana to Alabama. Enable's general partner is equally controlled by OGE Energy and CenterPoint, who each have 50 percent management ownership. Based on the 50/50 management ownership, with neither company having control, OGE Energy accounts for its interest in Enable using the
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equity method of accounting. In February 2021, Enable entered into a definitive merger agreement with Energy Transfer. For further discussion, see Note 4.

Basis of Presentation

The condensed financial statements included herein have been prepared by the Registrants, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations; however, the Registrants believe that the disclosures are adequate to prevent the information presented from being misleading.
In the opinion of management, all adjustments necessary to fairly present the financial position of the Registrants at June 30, 2021 and December 31, 2020, the results of the Registrants' operations for the three and six months ended June 30, 2021 and 2020 and the Registrants' cash flows for the six months ended June 30, 2021 and 2020 have been included and are of a normal, recurring nature except as otherwise disclosed. Management also has evaluated the impact of events occurring after June 30, 2021 up to the date of issuance of these condensed financial statements, and these statements contain all necessary adjustments and disclosures resulting from that evaluation.

Due to seasonal fluctuations and other factors, the Registrants' operating results for the three and six months ended June 30, 2021 are not necessarily indicative of the results that may be expected for the year ending December 31, 2021 or for any future period. The condensed financial statements and notes thereto should be read in conjunction with the audited financial statements and notes thereto included in the Registrants' 2020 Form 10-K.

Accounting Records

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

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

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The following table presents a summary of OG&E's regulatory assets and liabilities.
June 30,December 31,
(In millions)20212020
REGULATORY ASSETS  
Current:  
SPP cost tracker under recoveries (A)$10.9 $7.0 
Generation Capacity Replacement rider under recoveries (A)4.1 4.4 
Fuel clause under recoveries0.4 
Other (A)6.4 8.4 
Total current regulatory assets$21.8 $19.8 
  
Non-current:
Oklahoma Winter Storm Uri costs$754.8 $
Oklahoma deferred storm expenses181.8 158.8 
Benefit obligations regulatory asset135.6 164.9 
Arkansas Winter Storm Uri costs92.3 
Pension tracker40.6 18.1 
Sooner Dry Scrubbers19.3 19.7 
Arkansas deferred pension expenses11.6 9.3 
Unamortized loss on reacquired debt9.3 9.7 
Smart Grid7.6 11.2 
Frontier Plant deferred expenses7.5 6.4 
COVID-19 impacts7.1 6.4 
Other10.8 11.1 
Total non-current regulatory assets$1,278.3 $415.6 
REGULATORY LIABILITIES  
Current:  
Fuel clause over recoveries$4.7 $28.6 
Oklahoma energy efficiency rider over recoveries (B)4.3 1.5 
Other (B)1.0 5.0 
Total current regulatory liabilities$10.0 $35.1 
Non-current:  
Income taxes refundable to customers, net$947.5 $867.4 
Accrued removal obligations, net308.1 316.8 
Other4.1 4.7 
Total non-current regulatory liabilities$1,259.7 $1,188.9 
(A)Included in Other Current Assets in the balance sheets.
(B)Included in Other Current Liabilities in the balance sheets.    

In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. OG&E's natural gas costs for the month of February 2021 exceeded the total cost for all of 2020. The OCC allowed OG&E to create a regulatory asset for the Oklahoma portion of all deferred costs with an initial carrying charge based on the effective cost of the related debt financing for an amortization period to be determined at a later date. The APSC allowed OG&E to create a regulatory asset for the Arkansas portion of all deferred costs with an initial carrying charge equal to the current customer deposit interest rate to be recovered over a period of 10 years beginning in May 2021. For additional information, see Note 15.

The Oklahoma deferred storm expenses regulatory asset is recovered through the Storm Cost Recovery Rider. Operation and maintenance expenses resulting from storm damage exceeding the amounts included in OG&E's base rates are deferred and typically amortized over a five-year period. To mitigate customer impact, OG&E has agreed to recover the portion related to 2020 excess storm costs through the Storm Cost Recovery Rider over a ten-year period.
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Management continuously monitors the future recoverability of regulatory assets. When in management's judgment future recovery becomes impaired, the amount of the regulatory asset is adjusted, as appropriate. If OG&E were required to discontinue the application of accounting principles for certain types of rate-regulated activities for some or all of its operations, it could result in writing off the related regulatory assets or liabilities, which could have significant financial effects.

Allowance for Uncollectible Accounts Receivable

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

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

Investment in Unconsolidated Affiliates

OGE Energy's investment in Enable is considered to be a variable interest entity because the owners of the equity at risk in this entity have disproportionate voting rights in relation to their obligations to absorb the entity's expected losses or to receive its expected residual returns. However, OGE Energy is not considered the primary beneficiary of Enable since it does not have the power to direct the activities of Enable that are considered most significant to the economic performance of Enable; therefore, OGE Energy accounts for its investment in Enable using the equity method of accounting. Under the equity method, the investment will be adjusted each period for contributions made, distributions received and OGE Energy's share of the investee's comprehensive income as adjusted for basis differences. OGE Energy's maximum exposure to loss related to Enable is limited to its equity investment in Enable at June 30, 2021 as presented in Note 13.

OGE Energy considers distributions received from Enable which do not exceed cumulative equity in earnings subsequent to the date of investment to be a return on investment and are classified as operating activities in the condensed statements of cash flows. OGE Energy considers distributions received from Enable in excess of cumulative equity in earnings subsequent to the date of investment to be a return of investment and are classified as investing activities in the condensed statements of cash flows.

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Accumulated Other Comprehensive Income (Loss)
The following tables present changes in the components of accumulated other comprehensive income (loss) attributable to OGE Energy during the six months ended June 30, 2021 and 2020. All amounts below are presented net of tax.
(In millions)Pension Plan and Restoration of Retirement Income PlanPostretirement Benefit PlansOther Comprehensive Gain (Loss) from Unconsolidated AffiliatesTotal
Balance at December 31, 2020$(34.1)$3.3 $(1.3)$(32.1)
Other comprehensive income before reclassifications0 0 0.3 0.3 
Amounts reclassified from accumulated other comprehensive income (loss)0.8 (0.6)0 0.2 
Settlement cost3.7 0 0 3.7 
Balance at June 30, 2021$(29.6)$2.7 $(1.0)$(27.9)
(In millions)Pension Plan and Restoration of Retirement Income PlanPostretirement Benefit PlansOther Comprehensive Loss from Unconsolidated AffiliatesTotal
Balance at December 31, 2019$(35.1)$7.8 $(0.6)$(27.9)
Other comprehensive loss before reclassifications(1.3)(1.3)
Amounts reclassified from accumulated other comprehensive income (loss)2.0 (0.9)1.1 
Settlement cost0.2 0.2 
Balance at June 30, 2020$(32.9)$6.9 $(1.9)$(27.9)

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The following table presents significant amounts reclassified out of accumulated other comprehensive income (loss) attributable to OGE Energy by the respective line items in net income (loss) during the three and six months ended June 30, 2021 and 2020.
Details about Accumulated Other Comprehensive Income (Loss) ComponentsAmount Reclassified from Accumulated Other Comprehensive Income (Loss)Affected Line Item in
OGE Energy's Statements of Income
Three Months EndedSix Months Ended
June 30,June 30,
(In millions)2021202020212020
Amortization of Pension Plan
and Restoration of Retirement Income Plan items:
Actuarial losses$(0.4)$(1.5)$(1.2)$(2.6)(A)
Settlement cost(1.2)(0.3)(5.3)(0.3)(A)
(1.6)(1.8)(6.5)(2.9)Income (Loss) Before Taxes
(0.8)(0.4)(2.0)(0.7)Income Tax Expense (Benefit)
$(0.8)$(1.4)$(4.5)$(2.2)Net Income (Loss)
Amortization of postretirement benefit plans items:
Prior service credit$0.5 $0.5 $0.9 $1.1 (A)
Actuarial gains(0.1)0.1 (0.1)0.1 (A)
0.4 0.6 0.8 1.2 Income (Loss) Before Taxes
0.1 0.1 0.2 0.3 Income Tax Expense (Benefit)
$0.3 $0.5 $0.6 $0.9 Net Income (Loss)
Total reclassifications for the period, net of tax$(0.5)$(0.9)$(3.9)$(1.3)Net Income (Loss)
(A)These accumulated other comprehensive income (loss) components are included in the computation of net periodic benefit cost (see Note 12 for additional information).

2.Accounting Pronouncements

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

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3.Revenue Recognition

The following table presents OG&E's revenues from contracts with customers disaggregated by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "OG&E (Electric Utility) Results of Operations" within "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations."
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2021202020212020
Residential$178.5 $202.8 $746.7 $369.7 
Commercial108.3 113.0 415.8 204.3 
Industrial37.5 44.7 184.2 86.2 
Oilfield28.7 38.4 189.5 76.6 
Public authorities and street light37.0 40.6 160.1 75.3 
   System sales revenues390.0 439.5 1,696.3 812.1 
Provision for rate refund0 (1.0)0 (1.6)
Integrated market128.3 8.5 430.4 15.7 
Transmission36.7 39.8 73.0 74.0 
Other9.5 5.2 (14.2)12.2 
Revenues from contracts with customers (A)$564.5 $492.0 $2,185.5 $912.4 
(A) In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. Operating revenues significantly increased due to increased fuel, purchased power and direct transmission expenses, which are recoverable from customers, as a result of Winter Storm Uri. For further discussion, see Note 15 and "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operation."

4.Investment in Unconsolidated Affiliates

At June 30, 2021, OGE Energy owned 111.0 million common units, or 25.5 percent, of Enable's outstanding common units. On June 30, 2021, Enable's common unit price closed at $9.11. OGE Energy recorded equity in earnings of unconsolidated affiliates of $33.5 million and $86.7 million for the three and six months ended June 30, 2021, respectively, compared to equity in earnings of unconsolidated affiliates of $26.9 million for the three months ended June 30, 2020 and equity in losses of unconsolidated affiliates of $719.6 million for the six months ended June 30, 2020. Equity in earnings (losses) of unconsolidated affiliates includes OGE Energy's share of Enable's earnings adjusted for the amortization of the basis difference of OGE Energy's original investment in Enogex LLC and its underlying equity in the net assets of Enable, as well as any impairment OGE Energy records on its investment in Enable. Equity in earnings (losses) of unconsolidated affiliates is also adjusted for the elimination of the Enogex Holdings fair value adjustments. These amortizations may also include gain or loss on dilution, net of proportional basis difference recognition. For more information concerning the formation of Enable and OGE Energy's accounting for its investment in Enable, see Note 5 within "Item 8. Financial Statements and Supplementary Data" in OGE Energy's 2020 Form 10-K.

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The following tables present summarized unaudited financial information for 100 percent of Enable as of June 30, 2021 and December 31, 2020 and for the three and six months ended June 30, 2021 and 2020.
June 30,December 31,
Balance Sheet20212020
(In millions)
Current assets$475 $381 
Non-current assets$11,284 $11,348 
Current liabilities$1,317 $582 
Non-current liabilities$3,249 $4,052 
Three Months EndedSix Months Ended
June 30,June 30,
Income Statement2021202020212020
(In millions)
Total revenues$787 $515 $1,757 $1,163 
Cost of natural gas and NGLs (excluding depreciation and amortization)$426 $177 $945 $403 
Operating income$124 $80 $330 $226 
Net income$79 $35 $234 $138 

The following table presents a reconciliation of OGE Energy's equity in earnings (losses) of unconsolidated affiliates for the three and six months ended June 30, 2021 and 2020.
Three Months EndedSix Months Ended
June 30,June 30,
(In millions)2021202020212020
Enable net income$79.0 $35.0 $234.0 $138.0 
OGE Energy's percent ownership at period end25.5 %25.5 %25.5 %25.5 %
OGE Energy's portion of Enable net income$20.0 $8.8 $59.5 $35.1 
Amortization of basis difference and dilution recognition (A)13.5 18.1 27.2 25.3 
Impairment of OGE Energy's equity method investment in Enable (B)0 0 (780.0)
Equity in earnings (losses) of unconsolidated affiliates$33.5 $26.9 $86.7 $(719.6)
(A) Includes loss on dilution, net of proportional basis difference recognition.
(B) Effective March 31, 2020, OGE Energy estimated the fair value of its investment in Enable was below the book value and concluded the decline in value was not temporary due to the severity of the decline and recent rapid deterioration, as well as the near term future outlook, of the midstream oil and gas industry. Accordingly, OGE Energy recorded a $780.0 million impairment on its investment in Enable in 2020. Further discussion can be found in OGE Energy's 2020 Form 10-K.

The following table presents a reconciliation of the difference between OGE Energy's investment in Enable and its underlying equity in the net assets of Enable (basis difference) from December 31, 2020 to June 30, 2021. The basis difference is amortized over approximately 30 years.
(In millions)
Basis difference at December 31, 2020$1,332.3 
Amortization of basis difference (A)(28.4)
Basis difference at June 30, 2021$1,303.9 
(A) Includes proportional basis difference recognition due to dilution.

Distributions received from Enable were $18.4 million and $18.3 million during the three months ended June 30, 2021 and 2020, respectively, and $36.7 million and $55.0 million during the six months ended June 30, 2021 and 2020, respectively.

On July 30, 2021, Enable announced a quarterly dividend distribution of $0.16525 per unit on its outstanding common units, which is unchanged from the previous quarter. If cash distributions to Enable's unitholders exceed $0.330625 per unit in any quarter, the general partner will receive increasing percentages, up to 50 percent, of the cash Enable distributes in excess of that amount. OGE Energy is entitled to 60 percent of those "incentive distributions." In certain circumstances, the general
21


partner has the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable's cash distributions at the time of the exercise of this reset election.

Enable Merger Agreement with Energy Transfer

On February 16, 2021, Enable entered into a definitive merger agreement with Energy Transfer, pursuant to which, and subject to the conditions of the merger agreement, all outstanding common units of Enable will be acquired by Energy Transfer in an all-equity transaction. Under the terms of the merger agreement, Enable's common unitholders, including OGE Energy, will receive 0.8595 of one common unit representing limited partner interests in Energy Transfer for each common unit of Enable. The transaction is subject to the receipt of the required approvals from the holders of a majority of Enable's common units. Contemporaneously with the execution of the merger agreement, OGE Energy entered into a support agreement with Enable and Energy Transfer in which OGE Energy agreed to vote its common units in favor of the merger. In April 2021, CenterPoint and OGE Energy, who collectively own approximately 79.2 percent of Enable's common units, delivered written consents approving the merger agreement, and those consents are sufficient to approve the merger. The transaction also is subject to the receipt of anti-trust approvals and other customary closing conditions. The transaction is anticipated to close in 2021. Assuming the transaction closes, OGE Energy will own approximately three percent of Energy Transfer's outstanding limited partner units in lieu of the 25.5 percent interest in Enable that it currently owns.

The merger agreement contemplates a registration rights agreement with Energy Transfer to be executed at the closing of the merger that provides for customary resale registration, demand registration and piggy-back registration rights with respect to Energy Transfer common units issued to OGE Energy in the merger. Assuming the successful completion of the merger, OGE Energy intends to exit the midstream segment in a prudent manner.

5.Related Party Transactions

OGE Energy charges operating costs to OG&E and Enable based on several factors, and operating costs directly related to OG&E and/or Enable are assigned as such. Operating costs incurred for the benefit of OG&E are allocated either as overhead based primarily on labor costs or using the "Distrigas" method, which is a three-factor formula that uses an equal weighting of payroll, net operating revenues and gross property, plant and equipment.

OGE Energy and OG&E

OGE Energy charged operating costs to OG&E of $33.4 million and $36.9 million during the three months ended June 30, 2021 and 2020, respectively, and $69.1 million and $74.8 million during the six months ended June 30, 2021 and 2020, respectively.

OGE Energy and Enable

OGE Energy and Enable are currently parties to several agreements whereby OGE Energy provides specified support services to Enable, such as certain information technology, payroll and benefits administration. Under these agreements, OGE Energy charged operating costs to Enable of $0.1 million during both the three months ended June 30, 2021 and 2020 and $0.2 million during both the six months ended June 30, 2021 and 2020.

Pursuant to a seconding agreement, OGE Energy provides seconded employees to Enable to support Enable's operations. As of June 30, 2021, 67 employees that participate in OGE Energy's defined benefit and retirement plans are seconded to Enable. OGE Energy billed Enable for reimbursement of $2.5 million and $3.8 million during the three months ended June 30, 2021 and 2020, respectively, and $7.8 million and $10.1 million during the six months ended June 30, 2021 and 2020, respectively, under the seconding agreement for employment costs. If the seconding agreement were terminated, and those employees were no longer employed by OGE Energy, and lump sum payments were made to those employees, OGE Energy would recognize a settlement or curtailment of the pension/retiree health care charges, which would increase expense at OGE Energy by $18.1 million. Settlement and curtailment charges associated with the Enable seconded employees are not reimbursable to OGE Energy by Enable. The seconding agreement can be terminated by mutual agreement of OGE Energy and Enable or solely by OGE Energy upon 120 days' notice.

OGE Energy had accounts receivable from Enable for amounts billed for support services, including the cost of seconded employees, of $1.1 million as of June 30, 2021 and $2.0 million as of December 31, 2020, which are included in Accounts Receivable in OGE Energy's condensed balance sheets.

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Assuming the pending merger between Enable and Energy Transfer is completed, these agreements between OGE Energy and Enable, pursuant to which OGE Energy provides support services and seconded employees, will be terminated.

OG&E and Enable

Enable provides gas transportation services to OG&E pursuant to agreements that grant 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 compensates Enable when Enable's deliveries exceed OG&E's pipeline nominations. Enable compensates OG&E when OG&E's pipeline nominations exceed Enable's deliveries. The following table presents summarized related party transactions between OG&E and Enable during the three and six months ended June 30, 2021 and 2020.
Three Months EndedSix Months Ended
June 30,June 30,
(In millions)2021202020212020
Operating revenues:
Electricity to power electric compression assets$3.3 $3.5 $5.9 $7.2 
Fuel, purchased power and direct transmission expense:
Natural gas transportation services$9.3 $9.4 $14.0 $14.1 
Natural gas purchases (sales)$(8.4)$(1.7)$(20.6)$(1.0)

6.Fair Value Measurements
 
The classification of the Registrants' fair value measurements requires judgment regarding the degree to which market data is observable or corroborated by observable market data. GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to quoted prices in active markets for identical unrestricted assets or liabilities (Level 1) and the lowest priority given to unobservable inputs (Level 3). Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The three levels defined in the fair value hierarchy are as follows:
 
Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessible at the measurement date.
 
Level 2 inputs are inputs other than quoted prices in active markets included within Level 1 that are either directly or indirectly observable at the reporting date for the asset or liability for substantially the full term of the asset or liability. Level 2 inputs include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.  

Level 3 inputs are prices or valuation techniques for the asset or liability that require inputs that are both significant to the fair value measurement and unobservable (i.e., supported by little or no market activity). Unobservable inputs reflect the reporting entity's own assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk). 
The Registrants had 0 financial instruments measured at fair value on a recurring basis at June 30, 2021 and December 31, 2020. The following table presents the carrying amount and fair value of the Registrants' financial instruments at June 30, 2021 and December 31, 2020, as well as the classification level within the fair value hierarchy.
June 30,December 31,
 20212020
(In millions)Carrying Amount Fair
Value
Carrying Amount Fair
Value
Classification
Long-term Debt (including Long-term Debt due within one year):    
OGE Energy Senior Notes$499.8 $499.6 $$Level 2
OG&E Senior Notes$3,850.6 $4,510.5 $3,349.6 $4,182.1 Level 2
OG&E Industrial Authority Bonds$135.4 $135.4 $135.4 $135.4 Level 2
OG&E Tinker Debt$9.4 $10.4 $9.4 $10.7 Level 3
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7.Stock-Based Compensation

The following table presents the Registrants' pre-tax compensation expense and related income tax benefit for the three and six months ended June 30, 2021 and 2020 related to performance units and restricted stock units for the Registrants' employees.
OGE EnergyOG&E
Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
(In millions)20212020202120202021202020212020
Performance units:  
Total shareholder return$1.9 $2.0 $3.9 $3.7 $0.5 $0.6 $0.9 $1.3 
Earnings per share0 0.1 0 0.3 0 0 0.1 
Total performance units1.9 2.1 3.9 4.0 0.5 0.6 0.9 1.4 
Restricted stock units0.4 0.2 0.9 0.3 0.1 0.1 0.1 0.2 
Total compensation expense$2.3 $2.3 $4.8 $4.3 $0.6 $0.7 $1.0 $1.6 
Income tax benefit$0.6 $0.6 $1.2 $1.1 $0.2 $0.2 $0.3 $0.4 

During the six months ended June 30, 2021, OGE Energy issued 154,344 shares of its treasury stock to satisfy payouts of earned performance units and restricted stock unit grants to the Registrants' employees pursuant to OGE Energy's Stock Incentive Plan.

8.Income Taxes

OGE Energy files consolidated income tax returns in the U.S. federal jurisdiction and various state jurisdictions. OG&E is a part of the consolidated income tax return of OGE Energy. With few exceptions, the Registrants are no longer subject to U.S. federal tax or state and local examinations by tax authorities for years prior to 2017. Income taxes are generally allocated to each company in the affiliated group, including OG&E, based on its stand-alone taxable income or loss. Federal investment tax credits previously claimed on electric utility property have been deferred and will be amortized to income over the life of the related property. Additionally, OG&E 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.

Oklahoma Corporate Tax Rate Change

In May 2021, Oklahoma enacted a reduction of the corporate income tax rate to four percent from the previous six percent. This rate reduction will take effect January 1, 2022. ASC 740, "Income Taxes," requires deferred tax assets and liabilities to be measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. Therefore, during the second quarter of 2021, the Registrants revalued state deferred tax liabilities to reflect this change in tax rate. For entities subject to ASC 980, "Accounting for Regulated Entities," such as OG&E, those entities are required to recognize a regulatory liability for the decrease in taxes payable for the change in tax rates that are expected to be returned to customers through future rates and to recognize a regulatory asset for the increase in taxes receivable for the change in tax rates that are expected to be recovered from customers through future rates. The revaluation resulted in a regulatory liability of $97.7 million recorded for OG&E and an income tax benefit of $6.6 million for OGE Energy related to Enable and other operations (holding company).

9.Common Equity
 
Automatic Dividend Reinvestment and Stock Purchase Plan
 
OGE Energy issued 0 shares of common stock under its Automatic Dividend Reinvestment and Stock Purchase Plan during the three and six months ended June 30, 2021.  

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Earnings (Loss) Per Share
 
Basic earnings (loss) per share is calculated by dividing net income (loss) attributable to OGE Energy by the weighted average number of OGE Energy's common shares outstanding during the period. In the calculation of diluted earnings (loss) per share, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock. Potentially dilutive securities for OGE Energy consist of performance units and restricted stock units. The following table presents the calculation of basic and diluted earnings (loss) per share for OGE Energy.
Three Months Ended June 30,Six Months Ended June 30,
(In millions except per share data)2021202020212020
Net income (loss)$112.9 $85.9 $165.6 $(405.9)
Average common shares outstanding:  
Basic average common shares outstanding200.2 200.2 200.1 200.2 
Effect of dilutive securities:
Contingently issuable shares (performance and restricted stock units)0.2 0.3 0.1 
Diluted average common shares outstanding200.4 200.5 200.2 200.2 
Basic earnings (loss) per average common share$0.56 $0.43 $0.83 $(2.03)
Diluted earnings (loss) per average common share$0.56 $0.43 $0.83 $(2.03)
Anti-dilutive shares excluded from earnings per share calculation0 0 0.3 

10.Long-Term Debt
 
At June 30, 2021, the Registrants were in compliance with all of their debt agreements.
 
OG&E Industrial Authority Bonds

OG&E has tax-exempt pollution control bonds with optional redemption provisions that allow the holders to request repayment of the bonds on any business day. The following table presents information about these bonds, which can be tendered at the option of the holder during the next 12 months.
SeriesDate DueAmount
  (In millions)
0.17%-0.27%Garfield Industrial Authority, January 1, 2025$47.0 
0.16%-0.33%Muskogee Industrial Authority, January 1, 202532.4 
0.17%-0.27%Muskogee Industrial Authority, June 1, 202756.0 
Total (redeemable during next 12 months)$135.4 

All of these bonds are subject to an optional tender at the request of the holders, at 100 percent of the principal amount, together with accrued and unpaid interest to the date of purchase. The bond holders, on any business day, can request repayment of the bond by delivering an irrevocable notice to the tender agent stating the principal amount of the bond, payment instructions for the purchase price and the business day the bond is to be purchased. The repayment option may only be exercised by the holder of a bond for the principal amount. When a tender notice has been received by the trustee, a third-party remarketing agent for the bonds will attempt to remarket any bonds tendered for purchase. This process occurs once per week. Since the original issuance of these series of bonds in 1995 and 1997, the remarketing agent has successfully remarketed all tendered bonds. If the remarketing agent is unable to remarket any such bonds, OG&E is obligated to repurchase such unremarketed bonds. As OG&E has both the intent and ability to refinance the bonds on a long-term basis and such ability is supported by an ability to consummate the refinancing, the bonds are classified as Long-Term Debt in the condensed balance sheets. OG&E believes that it has sufficient liquidity to meet these obligations.

Issuance of Long-Term Debt

In May 2021, OGE Energy issued $500.0 million of 0.703 percent senior notes, and OG&E issued $500.0 million of 0.553 percent senior notes. Each series is due May 26, 2023 but may be redeemed by OGE Energy or OG&E on or after November 26, 2021 at a price equal to 100 percent of the principal amount of the senior notes being redeemed, plus any accrued and unpaid interest. The proceeds from these issuances were used to repay $900.0 million of the $1.0 billion term loan OGE
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Energy entered into in March 2021 to help cover the fuel and purchased power costs incurred by OG&E during Winter Storm Uri.

11.Short-Term Debt and Credit Facilities
 
The Registrants borrow on a short-term basis, as necessary, by the issuance of commercial paper and by borrowings under their revolving credit agreements. OGE Energy also borrows under term credit agreements maturing in one year or less, as necessary. OGE Energy had $384.5 million and $95.0 million of short-term debt at June 30, 2021 and December 31, 2020, respectively. At June 30, 2021, OG&E had $118.0 million in advances to OGE Energy compared to $272.0 million at December 31, 2020.

In March 2021, OGE Energy entered into a $1.0 billion unsecured 364-day term loan agreement and borrowed the full $1.0 billion to help cover the increased fuel and purchased power costs incurred by OG&E during Winter Storm Uri. The term loan contained substantially the same covenants as OGE Energy's $450.0 million revolving credit agreement, including various financial ratio covenants. Contemporaneously with the closing of the term loan agreement, in March 2021, OGE Energy made a capital contribution of $530.0 million to OG&E using the term loan proceeds, and OGE Energy also loaned $470.0 million to OG&E pursuant to an intercompany note issued by OG&E to OGE Energy. In May 2021, OG&E repaid the $470.0 million to OGE Energy, and OGE Energy used this repayment and other funds from its issuance of senior notes in May 2021 to repay $900.0 million of the $1.0 billion term loan, as further discussed in Note 10.

The following table presents information regarding the Registrants' revolving credit agreements at June 30, 2021.
 AggregateAmountWeighted-Average 
EntityCommitment Outstanding (A)Interest RateExpiration
(In millions)  
OGE Energy (B)$450.0 $284.5 0.19 %(E)March 8, 2024(F)
OG&E (C)(D)450.0 0.4 1.15 %(E)March 8, 2024(F)
Total$900.0 $284.9 0.19 %
(A)Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at June 30, 2021.
(B)This bank facility is available to back up OGE Energy's commercial paper borrowings and to provide revolving credit borrowings. This bank facility can also be used as a letter of credit facility.  
(C)This bank facility is available to back up OG&E's commercial paper borrowings and to provide revolving credit borrowings. This bank facility can also be used as a letter of credit facility.  
(D)OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $350.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of March 8, 2024. At June 30, 2021, there were 0 intercompany borrowings under this agreement. 
(E)Represents the weighted-average interest rate for the outstanding borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit.
(F)In March 2017, the Registrants entered into unsecured five-year revolving credit agreements totaling $900.0 million ($450.0 million for OGE Energy and $450.0 million for OG&E). Each of the revolving credit facilities contained an option, which could be exercised up to two times, to extend the term of the respective facility for an additional year. In March 2018, the Registrants each utilized one of those extensions to extend the maturity of their respective credit facility from March 8, 2022 to March 8, 2023. In January 2021, the Registrants each utilized the second of those extensions to extend the maturity of their respective credit facility from March 8, 2023 to March 8, 2024. Commitments of a single existing lender with respect to $50.0 million of OGE Energy's credit facility, however, were not extended and, unless the non-extending lender is replaced in accordance with the terms of the credit facility, such commitments will expire March 8, 2023. The non-extending lender is not party to the OG&E facility.

In January 2021, the Registrants each entered into an amendment to their revolving credit facilities which gives each of the Registrants the option of extending such commitments for up to two additional one-year periods. In addition, the amendment addresses the establishment of an alternative rate of interest upon the occurrence of certain events related to the phase out of LIBOR.

The Registrants' ability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions. Pricing grids associated with the Registrants' credit facilities could cause annual fees and borrowing rates to increase if an adverse rating impact occurs. The impact of any future downgrade could include an increase in the costs of the Registrants' short-term borrowings, but a reduction in the Registrants' credit ratings would not result
26


in any defaults or accelerations. Any future downgrade could also lead to higher long-term borrowing costs and, if below investment grade, would require the Registrants to post collateral or letters of credit.
 
OG&E must obtain regulatory approval from the FERC in order to borrow on a short-term basis. OG&E has the necessary regulatory approvals to incur up to $800.0 million in short-term borrowings at any one time for a two-year period beginning January 1, 2021 and ending December 31, 2022.

12.Retirement Plans and Postretirement Benefit Plans

In accordance with ASC Topic 715, "Compensation - Retirement Benefits," a one-time settlement charge is required to be recorded by an organization when lump sum payments or other settlements that relieve the organization from the responsibility for the pension benefit obligation during the plan year exceed the service cost and interest cost components of the organization's net periodic pension cost. During the first six months of 2021, the Registrants experienced an increase in both the number of employees electing to retire and the amount of lump sum payments paid to such employees upon retirement, which resulted in the Registrants recording pension plan settlement charges as presented in the Pension Plan net periodic benefit cost table below. The pension settlement charges did not require a cash outlay by the Registrants and did not increase total pension expense over time, as the charge was an acceleration of costs that otherwise would be recognized as pension expense in future periods.

Net Periodic Benefit Cost

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

 Pension PlanRestoration of Retirement
Income Plan
Three Months EndedSix Months EndedThree Months EndedSix Months Ended
OGE EnergyJune 30,June 30,June 30,June 30,
(In millions)20212020202120202021202020212020
Service cost$2.6 $2.8 $5.6 $6.5 $0.2 $0.2 $0.3 $0.4 
Interest cost3.4 4.6 6.9 9.2 0.1 0.1 0.1 
Expected return on plan assets(8.7)(9.2)(17.1)(18.6)0 0 
Amortization of net loss1.9 4.6 4.7 8.4 0 0.2 0.1 0.3 
Settlement cost5.3 31.7 0.4 0.3 0.4 0.3 
Total net periodic benefit cost4.5 2.8 31.8 5.5 0.7 0.7 0.9 1.1 
Less: Amount paid by unconsolidated affiliates (A)(0.2)0.6 (0.1)1.1 0 0 
Net periodic benefit cost$4.7 $2.2 $31.9 $4.4 $0.7 $0.7 $0.9 $1.1 


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 Pension PlanRestoration of Retirement
Income Plan
Three Months EndedSix Months EndedThree Months EndedSix Months Ended
OG&EJune 30,June 30,June 30,June 30,
(In millions)20212020202120202021202020212020
Service cost$1.7 $1.9 $3.8 $4.5 $0 $$0 $0.1 
Interest cost2.5 3.4 5.0 6.8 0 0.1 0 0.1 
Expected return on plan assets(6.2)(6.8)(12.3)(13.9)0 0 
Amortization of net loss1.5 3.2 3.5 6.0 0.1 0.1 0.1 0.2 
Settlement cost4.4 26.6 0.3 0.3 
Total net periodic benefit cost3.9 1.7 26.6 3.4 0.4 0.2 0.4 0.4 
Plus: Amount allocated from OGE Energy (A)0.7 0.5 4.6 1.0 0.3 0.4 0.5 0.6 
Net periodic benefit cost$4.6 $2.2 $31.2 $4.4 $0.7 $0.6 $0.9 $1.0 
(A) "Amount paid by unconsolidated affiliates" is only applicable to OGE Energy. "Amount allocated from OGE Energy" is only applicable to OG&E.

In addition to the net periodic benefit cost amounts recognized, as presented in the tables above, for the Pension and Restoration of Retirement Income Plans for the three and six months ended June 30, 2021 and 2020, the Registrants recognized the following:
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2021202020212020
Increase of pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)$4.2 $1.6 $7.2 $3.3 
Deferral of pension expense related to pension settlement charges:
Oklahoma jurisdiction (A)$5.2 $0.3 $28.9 $0.3 
Arkansas jurisdiction (A)$0.5 $$2.7 $
(A) Included in the pension regulatory asset or liability in each jurisdiction, as indicated in the regulatory assets and liabilities table in Note 1.

OGE EnergyOG&E
Postretirement Benefit PlansPostretirement Benefit Plans
Three Months EndedSix Months EndedThree Months EndedSix Months Ended
June 30,June 30,June 30,June 30,
(In millions)20212020202120202021202020212020
Service cost$0 $$0.1 $0.1 $0 $0.1 $0.1 $0.1 
Interest cost0.9 1.0 1.7 2.1 0.7 0.8 1.3 1.6 
Expected return on plan assets(0.5)(0.4)(1.0)(0.9)(0.5)(0.4)(0.9)(0.8)
Amortization of net loss0.7 0.4 1.4 1.0 0.7 0.4 1.4 1.1 
Amortization of unrecognized prior service cost (A)(1.7)(2.1)(3.4)(4.2)(1.2)(1.6)(2.5)(3.1)
Total net periodic benefit cost(0.6)(1.1)(1.2)(1.9)(0.3)(0.7)(0.6)(1.1)
Less: Amount paid by unconsolidated affiliates (B)(0.2)(0.2)(0.3)(0.4)
Plus: Amount allocated from OGE Energy (B)(0.1)(0.2)(0.2)(0.4)
Net periodic benefit cost$(0.4)$(0.9)$(0.9)$(1.5)$(0.4)$(0.9)$(0.8)$(1.5)
(A)Unamortized prior service cost is amortized on a straight-line basis over the average remaining service period to the first eligibility age of participants who are expected to receive a benefit and are active at the date of the plan amendment.
(B)"Amount paid by unconsolidated affiliates" is only applicable to OGE Energy. "Amount allocated from OGE Energy" is only applicable to OG&E.
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In addition to the net periodic benefit income amounts recognized, as presented in the table above, for the postretirement benefit plans for the three and six months ended June 30, 2021 and 2020, the Registrants recognized the following:
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2021202020212020
Increase of postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)$0.1 $0.6 $0.2 $0.8 
(A) Included in the Pension tracker, as presented in the regulatory assets and liabilities table in Note 1.

OGE EnergyOG&E
Three Months EndedSix Months EndedThree Months EndedSix Months Ended
June 30,June 30,June 30,June 30,
(In millions)20212020202120202021202020212020
Capitalized portion of net periodic pension benefit cost$0.8 $0.8 $1.6 $1.8 $0.7 $0.6 $1.4 $1.5 
Capitalized portion of net periodic postretirement benefit cost$0 $0.1 $0.1 $0.1 $0.1 $0.1 $0.1 $0.1 

Pension Plan Funding

In January 2021, OGE Energy made a $40.0 million contribution to its Pension Plan, of which $30.0 million was attributed to OG&E. No additional contributions are expected in 2021.

13.Report of Business Segments

OGE Energy reports its operations in two business segments: (i) the electric utility segment, which is engaged in the generation, transmission, distribution and sale of electric energy and (ii) the natural gas midstream operations segment. Other operations primarily includes the operations of the holding company. Intersegment revenues are recorded at prices comparable to those of unaffiliated customers and are affected by regulatory considerations. The following tables present the results of OGE Energy's business segments for the three and six months ended June 30, 2021 and 2020.
Three Months Ended June 30, 2021Electric UtilityNatural Gas Midstream OperationsOther
Operations
EliminationsTotal
(In millions)     
Operating revenues$577.4 $0 $0 $0 $577.4 
Fuel, purchased power and direct transmission expense200.0 0 0 0 200.0 
Other operation and maintenance118.3 1.6 (0.7)0 119.2 
Depreciation and amortization102.9 0 0 0 102.9 
Taxes other than income25.0 0.1 0.7 0 25.8 
Operating income (loss)131.2 (1.7)0 0 129.5 
Equity in earnings of unconsolidated affiliates0 33.5 0 0 33.5 
Other income (expense)1.2 (0.2)(0.5)(0.6)(0.1)
Interest expense37.9 0 2.6 (0.6)39.9 
Income tax expense (benefit)9.4 (0.6)1.3 0 10.1 
Net income (loss)$85.1 $32.2 $(4.4)$0 $112.9 
Investment in unconsolidated affiliates$0 $425.4 $26.3 $0 $451.7 
Total assets$11,459.3 $427.8 $127.4 $(115.0)$11,899.5 
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Three Months Ended June 30, 2020Electric UtilityNatural Gas Midstream OperationsOther
Operations
EliminationsTotal
(In millions)     
Operating revenues$503.5 $$$$503.5 
Fuel, purchased power and direct transmission expense137.4 137.4 
Other operation and maintenance117.7 0.3 (0.5)117.5 
Depreciation and amortization97.3 97.3 
Taxes other than income25.0 0.1 0.8 25.9 
Operating income (loss)126.1 (0.4)(0.3)125.4 
Equity in earnings of unconsolidated affiliates26.9 26.9 
Other income (expense)0.5 1.7 (0.2)2.0 
Interest expense39.3 1.7 (0.2)40.8 
Income tax expense8.4 7.5 11.7 27.6 
Net income (loss)$78.9 $19.0 $(12.0)$$85.9 
Investment in unconsolidated affiliates$$356.4 $20.1 $$376.5 
Total assets$10,367.6 $360.2 $109.1 $(397.8)$10,439.1 

Six Months Ended June 30, 2021Electric UtilityNatural Gas Midstream OperationsOther
Operations
EliminationsTotal
(In millions)     
Operating revenues$2,208.0 $0 $0 $0 $2,208.0 
Fuel, purchased power and direct transmission expense1,546.8 0 0 0 1,546.8 
Other operation and maintenance228.6 2.0 (2.1)0 228.5 
Depreciation and amortization201.6 0 0 0 201.6 
Taxes other than income50.7 0.2 2.1 0 53.0 
Operating income (loss)180.3 (2.2)0 0 178.1 
Equity in earnings of unconsolidated affiliates0 86.7 0 0 86.7 
Other income (expense)2.9 (0.7)(0.6)(0.8)0.8 
Interest expense76.3 0 3.8 (0.8)79.3 
Income tax expense (benefit)10.6 13.7 (3.6)0 20.7 
Net income (loss)$96.3 $70.1 $(0.8)$0 $165.6 
Investment in unconsolidated affiliates$0 $425.4 $26.3 $0 $451.7 
Total assets$11,459.3 $427.8 $127.4 $(115.0)$11,899.5 
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Six Months Ended June 30, 2020Electric UtilityNatural Gas Midstream OperationsOther
Operations
EliminationsTotal
(In millions)     
Operating revenues$934.8 $$$$934.8 
Fuel, purchased power and direct transmission expense272.4 272.4 
Other operation and maintenance238.7 0.9 (2.1)237.5 
Depreciation and amortization191.7 191.7 
Taxes other than income48.9 0.2 2.4 51.5 
Operating income (loss)183.1 (1.1)(0.3)181.7 
Equity in losses of unconsolidated affiliates (A)(719.6)(719.6)
Other income (expense)2.3 3.0 (1.2)4.1 
Interest expense76.2 4.1 (1.2)79.1 
Income tax expense (benefit)10.4 (171.7)(45.7)(207.0)
Net income (loss)$98.8 $(549.0)$44.3 $$(405.9)
Investment in unconsolidated affiliates$$356.4 $20.1 $$376.5 
Total assets$10,367.6 $360.2 $109.1 $(397.8)$10,439.1 
(A) In 2020, OGE Energy recorded a $780.0 million impairment on its investment in Enable, as further discussed in Note 4.

14.Commitments and Contingencies
 
Except as set forth below, in Note 15 and under "Environmental Laws and Regulations" in Item 2 of Part I and in Item 1 of Part II of this Form 10-Q, the circumstances set forth in Notes 15 and 16 to the financial statements included in the Registrants' 2020 Form 10-K appropriately represent, in all material respects, the current status of the Registrants' material commitments and contingent liabilities.

Environmental Laws and Regulations

The activities of the Registrants are subject to numerous stringent and complex federal, state and local laws and regulations governing environmental protection. These laws and regulations can change, restrict or otherwise impact the Registrants' business activities in many ways, including the handling or disposal of waste material, planning for future construction activities to avoid or mitigate harm to threatened or endangered species and requiring the installation and operation of emissions or pollution control equipment. Failure to comply with these laws and regulations could result in the assessment of administrative, civil and criminal penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations. Management believes that all of the Registrants' operations are in substantial compliance with current federal, state and local environmental standards.

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

Other
 
In the normal course of business, the Registrants are confronted with issues or events that may result in a contingent liability. These generally relate to lawsuits or claims made by third parties, including governmental agencies. When appropriate, management consults with legal counsel and other experts to assess the claim. If, in management's opinion, the Registrants have incurred a probable loss as set forth by GAAP, an estimate is made of the loss, and the appropriate accounting entries are reflected in the condensed financial statements. At the present time, based on currently available information, the Registrants believe that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to their condensed financial statements and would not have a material adverse effect on their financial position, results of operations or cash flows.

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15.Rate Matters and Regulation

Except as set forth below, the circumstances set forth in Note 16 to the financial statements included in the Registrants' 2020 Form 10-K appropriately represent, in all material respects, the current status of the Registrants' regulatory matters.

Completed Regulatory Matters

APSC Proceedings

Arkansas 2020 Formula Rate Plan Filing

In October 2020, OG&E filed its third evaluation report under its Formula Rate Plan, and on January 28, 2021, OG&E entered into a non-unanimous settlement agreement with the APSC General Staff and the Office of the Arkansas Attorney General. The only non-signatory to the settlement agreement agreed not to oppose the settlement. The settlement agreement included a revenue increase of $6.7 million, which is the maximum amount statutorily allowed in this filing. Additionally, the settling parties did not object to OG&E's request for a finding that the Arkansas Series II grid modernization projects included in this filing are prudent in cost. On March 9, 2021, the APSC issued a final order approving the non-unanimous settlement agreement, and new rates became effective April 1, 2021.

Disconnection Procedures Related to COVID-19

In September 2020, the APSC invited comments from all jurisdictional utilities and any other interested stakeholders on specific questions related to whether a moratorium on service terminations should be lifted and if so, how the resumption of disconnections should occur. The APSC also ordered utilities to submit a detailed "Transitional Plan" outlining how utilities proposed to reinstate routine service disconnection activities and collection of past due amounts once the moratorium was lifted. OG&E submitted its proposed Transitional Plan in October 2020.

On February 8, 2021, the APSC announced a target date of May 3, 2021 to lift the moratorium on disconnections and specified certain conditions and requirements that utilities must meet before disconnections may resume. Such requirements include, among other things, immediate communication to customers, notice periods for disconnections and deferred payment arrangements. On March 26, 2021, the APSC confirmed the lifting of the moratorium on disconnections on May 3, 2021 and directed utilities to take specific steps prior to resuming disconnections. OG&E resumed disconnections on May 3, 2021.

Arkansas Approval to Construct Out of State Generation

On March 3, 2021, OG&E filed an application with the APSC to request approval to construct a 5 MW solar facility in Oklahoma. The APSC issued an order on April 6, 2021, finding OG&E's application in the public interest, conditioned on Arkansas customers being held harmless and not subject to cost recovery associated with the project. OG&E expects the costs associated with constructing this solar facility to be fully recovered in Oklahoma.

OCC Proceedings

Oklahoma Grid Enhancement Plan

In November 2020, the OCC issued a final order approving a Joint Stipulation and Settlement Agreement that allows for interim recovery of OG&E's costs associated with its grid enhancement plan. The approved agreement included the following key terms: (i) cost recovery through a rider mechanism will be limited to projects placed in service in 2020 and 2021, capped at a revenue requirement of $7.0 million annually and only include communication, automation and technology systems projects; (ii) no operation and maintenance expense will be included in the rider mechanism; (iii) the rider mechanism will terminate by the issuance of a final order in OG&E's next general rate review or October 31, 2022, whichever occurs first; (iv) the rider mechanism rate of return will be capped at OG&E's current cost of capital; and (v) all cost recovery is subject to true-up and refund in OG&E's next general rate review. The rider mechanism became effective on February 1, 2021.

OG&E reports to the OCC new projects completed each quarter, and the cost recovery factor is adjusted to include those projects after a stakeholder review. OG&E has submitted its report for projects that were placed in service through June 30, 2021. The cost recovery factors that include those projects will become effective on September 1, 2021.

Any capital investment falling outside the criteria of the rider mechanism will be included in OG&E's next general rate review for recovery.
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Pending Regulatory Matters

Various proceedings pending before state or federal regulatory agencies are described below. Unless stated otherwise, the Registrants cannot predict when the regulatory agency will act or what action the regulatory agency will take. The Registrants' financial results are dependent in part on timely and 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 through 2015 period in 2016, held that the SPP tariff provision that prohibited those charges could not be waived and ordered the SPP to develop a plan to refund the payments but not to implement the refunds until further ordered to do so. In response, in April 2019, OG&E filed a request for rehearing with the FERC, and in May 2019, OG&E filed a FERC 206 complaint against the SPP, alleging that the SPP's forced unwinding of the revenue credit payments to OG&E would violate the provisions of the Sponsored Upgrade Agreement and of the applicable tariff. OG&E's filing requested that the FERC rule that the SPP is not entitled to seek refunds or in any other way seek to unwind the revenue credit payments it had paid to OG&E pursuant to the Sponsored Upgrade Agreement. The SPP's response to OG&E's filing agreed that OG&E should be entitled to keep its Z2 payments and argued that the SPP should not be held responsible for those payments if refunds are ordered. Further, the SPP has requested the FERC to negotiate a global settlement with all impacted parties, including other project sponsors who, like OG&E, have also filed complaints at FERC contending that the payments they have received cannot properly be unwound.
In February 2020, the FERC denied OG&E's request for rehearing of its February 2019 order, denying the waiver and ruling that the SPP must seek refunds from project sponsors for Z2 payments for the 2008 through 2015 period and pay them back to transmission owners. The FERC also denied the SPP's request for a stay and for institution of settlement procedures. The FERC stated it would not institute settlement procedures unless parties on both sides of the matter requested them. The FERC did not rule on OG&E's complaint or the complaints of other project sponsors, or consider the SPP's refund plan. The FERC thus has not set any date for payment of refunds. In March 2020, OG&E petitioned the U.S. Court of Appeals for the District of Columbia Circuit for review of the FERC's order denying the waiver and requiring refunds. The appeal was argued on April 14, 2021 and is expected to be decided before the court's current term ends in August 2021.
The Registrants cannot predict the outcome of this proceeding based on currently available information, and as of June 30, 2021 and at present time, the Registrants have 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, the Registrants would be impacted by $5.0 million in expense that initially benefited the Registrants in 2016, and OG&E customers would incur a net impact of $8.0 million in expense through rider mechanisms or the FERC formula rate.

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

Incentive Adders for Transmission Rates

The FERC issued a NOPR on March 20, 2020, and issued a supplemental NOPR on April 15, 2021, proposing to update its transmission incentives policy. Among other things, the NOPR proposes (i) the current 50-basis point return on equity adder for RTO/ISO participation would be applicable only to transmitting utilities that join an RTO/ISO, and this incentive would only apply for the first three years in which the utility is an RTO/ISO member and (ii) transmitting utilities that have been members of an RTO/ISO for three years or more, such as OG&E, would be required to make a compliance filing to remove the existing return on equity adder from their rates. OG&E is currently evaluating the potential impacts of this proposed rule.

APSC Proceedings

Winter Storm Uri

In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. On April 1, 2021, OG&E filed with the APSC a Motion for Authority to Establish Special Regulatory Treatment within the Energy Cost Recovery Rider to Defer Extraordinary Fuel Costs Incurred Due to Winter Storm Uri. More specifically, OG&E's Motion sought approval to defer, amortize and recover the extraordinary fuel costs over a ten-year period with a carrying charge of OG&E's pre-tax rate of return of 6.60 percent, through a special factor within OG&E's Energy Cost Recovery Rider beginning with the first billing cycle of May 2021. On April 13, 2021, the APSC issued Order No. 18 allowing OG&E interim recovery at an interest rate equal to the customer deposit interest rate, which is currently 0.8 percent, over a period of ten years beginning with the first billing cycle of May 2021. Recovery is subject to a true-up after the APSC determines the appropriate allocation, length of recovery and carrying charge. Such determinations are expected to be made by the APSC later this year. On May 4, 2021, OG&E filed testimony further supporting its 10-year amortization period and a carrying charge of OG&E's pre-tax rate of return of 6.60 percent. As of June 30, 2021, OG&E has deferred $92.3 million to a regulatory asset, as indicated in Note 1.

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

On May 20, 2021, OG&E filed a Motion for Suspension of Procedural Schedule, which the APSC approved, to investigate and evaluate the potential securitization recovery of the Arkansas jurisdictional portion of the Winter Storm Uri costs. OG&E intends to apply for securitization in the second half of 2021 if it is deemed to strike the right balance between protecting the credit strength of OG&E and providing customer savings.

OCC Proceedings

Oklahoma Retail Electric Supplier Certified Territory Act Causes

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

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If the Oklahoma Supreme Court ultimately were to find that some or all of the customers being served are not exempted from the Oklahoma Retail Electric Supplier Certified Territory Act, OG&E would have to evaluate the recoverability of some plant investments made to serve these customers. The total amount of OG&E's plant investments made to serve the customers in all five cases is approximately $28.0 million, of which $11.7 million applies to the three cases where the OCC ruled in favor of the electric cooperatives. In addition to the evaluation of the recoverability of the investments, OG&E may also be required to reimburse certified territory suppliers for an amount of lost revenue. The amount of such lost revenue would depend on how the OCC calculates the revenue requirement but could range from approximately $22.2 million to $30.7 million for all five cases, of which $2.1 million to $3.3 million would apply to the three cases where the OCC ruled in favor of the electric cooperatives.

October 2020 Storm Examination

In October 2020, a major ice storm moved through OG&E's service territory which caused significant damage to the system. In November 2020, the Public Utility Division of the OCC initiated an examination and review of all distribution utilities and cooperatives affected by the storm into the mitigation efforts, restoration processes and proposed improvements for future related or similar events. Respondents are required to provide certain information related to the examination, and the OCC may request additional relief as the examination proceeds. No procedural schedule has been proposed currently; however, OG&E is responding to discovery requests.

Winter Storm Uri

In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. On February 24, 2021, OG&E submitted an application to the OCC outlining a two-step approach for regulatory treatment for the fuel and purchased power costs associated with Winter Storm Uri. The steps included: (i) an intra-year fuel clause increase to be effective April 1, 2021; and (ii) a request for regulatory asset treatment at OG&E's weighted average cost of capital for the remaining fuel and purchased power costs. On March 18, 2021, the OCC approved OG&E's filing to establish a regulatory asset. The approval allowed OG&E to create a regulatory asset for all deferred costs with an initial carrying charge based on the effective cost of the debt financing, until such time where the prudency of this event is evaluated, the amortization period is decided on and a long-term carry cost is established.

In April 2021, Oklahoma enacted legislation to allow for the securitization of costs incurred during Winter Storm Uri. The new statute authorizes the OCC to issue a financing order for the issuance of securitization bonds after consideration of certain factors, including but not limited to, mitigated impacts and savings for customers through the use of ratepayer-backed securitization bonds as compared to traditional utility financing. The OCC must issue a financing order within 180 days after receiving all necessary information required by the statute. Under the statute, the Oklahoma Development Finance Authority is responsible for issuing the securitization bonds within two years from the date of the financing order. Carrying costs will be included at a rate and time determined by the OCC and continue until the bonds are issued. On April 26, 2021, OG&E filed an application pursuant to the Act seeking OCC approval to securitize its costs related to Winter Storm Uri and to receive an interim carrying charge on OG&E's regulatory asset balance at its weighted-average cost of capital for the period between April 2022 and the date when the securitized bonds are issued. On June 18, 2021, OG&E filed its direct testimony which supports the prudence of the costs incurred during Winter Storm Uri and demonstrates the customer savings associated with securitization as opposed to traditional utility financing. As of June 30, 2021, OG&E has deferred $754.8 million to a regulatory asset, as indicated in Note 1. The Oklahoma jurisdictional amount requested for recovery is subject to carrying costs and any updates from the SPP settlement process.

2020 Oklahoma Fuel Prudency

On June 28, 2021, the Public Utility Division Staff filed their application initiating the review of the 2020 fuel adjustment clause and prudence review. OG&E plans to file its Minimum Filing Requirements and Supporting Testimony on August 27, 2021.

Integrated Resource Plans

On August 2, 2021, OG&E released its draft triennial IRP and provided that draft to the OCC and the APSC. This 2021 IRP identified capacity needs of 145, 183, 417 and 514 MWs in 2023, 2024, 2025 and 2026, respectively. OG&E will be conducting technical conferences for stakeholder engagement in the Oklahoma and Arkansas jurisdictions and plans to issue its final 2021 IRP in October 2021.
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Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

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

Introduction
 
OGE Energy is a holding company with investments in energy and energy services providers offering physical delivery and related services for both electricity and natural gas primarily in the south-central U.S. OGE Energy conducts these activities through two business segments: (i) electric utility and (ii) natural gas midstream operations. The accounts of OGE Energy and its wholly-owned subsidiaries, including OG&E, are included in OGE Energy's condensed consolidated financial statements. All intercompany transactions and balances are eliminated in such consolidation. OGE Energy generally uses the equity method of accounting for investments where its ownership interest is between 20 percent and 50 percent and it lacks the power to direct activities that most significantly impact economic performance.

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

Enable. OGE Energy's natural gas midstream operations segment represents OGE Energy's investment in Enable. The investment in Enable is held through wholly-owned subsidiaries and ultimately OGE Holdings. Formed in 2013, Enable is primarily engaged in the business of gathering, processing, transporting and storing natural gas. Enable's natural gas gathering and processing assets are strategically located in four states and serve natural gas production in the Anadarko, Arkoma and Ark-La-Tex Basins. Enable also owns crude oil gathering assets in the Anadarko and Williston Basins. Enable has intrastate natural gas transportation and storage assets that are located in Oklahoma as well as interstate assets that extend from western Oklahoma and the Texas Panhandle to Louisiana, from Louisiana to Illinois and from Louisiana to Alabama. Enable's general partner is equally controlled by OGE Energy and CenterPoint, who each have 50 percent management ownership. Based on the 50/50 management ownership, with neither company having control, OGE Energy accounts for its interest in Enable using the equity method of accounting. As disclosed in OGE Energy's 2020 Form 10-K, Enable is subject to a number of risks, including contract renewal risk, the reliance on the drilling and production decisions of others and the volatility of natural gas, NGLs and crude oil prices. The effects of COVID-19, including negative impacts on demand and commodity prices, could exacerbate these risks, as experienced in 2020 which, along with actions of the Organization of Petroleum Exporting Countries and other oil exporting nations, influenced OGE Energy's impairment of its investment in Enable. If any of those risks were to occur or reoccur, OGE Energy's business, financial condition, results of operations or cash flows could be materially adversely affected.

In February 2021, Enable entered into a definitive merger agreement with Energy Transfer, which is further discussed under "Recent Developments - Enable Merger Agreement with Energy Transfer" below and in Note 4 within "Item 1. Financial Statements." For a discussion of risks related to the Enable and Energy Transfer merger, see "Item 1A. Risk Factors" in OGE Energy's 2020 Form 10-K.
 
Overview
 
Strategy
 
OGE Energy's purpose is to energize life, providing life-sustaining and life-enhancing products and services, while honoring its commitment to strengthen communities. Its business model is centered around growth and sustainability for employees (internally referred to as "members"), communities and customers and the owners of OGE Energy, its shareholders.
 
OGE Energy is focused on creating long-term shareholder value by targeting the consistent growth of earnings per share of five percent at the electric utility, underscored by a strategy of investing in lower risk infrastructure projects that improve the economic vitality of the communities it serves in Oklahoma and Arkansas. OGE Energy utilizes cash distributions from its natural gas midstream operations segment to help fund its electric utility capital investments. OGE Energy's financial objectives also include maintaining investment grade credit ratings and providing a strong and reliable dividend for shareholders.

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

Recent Developments

Enable Merger Agreement with Energy Transfer

In February 2021, Enable entered into a definitive merger agreement with Energy Transfer, pursuant to which, and subject to the conditions of the merger agreement, all outstanding common units of Enable will be acquired by Energy Transfer in an all-equity transaction. Under the terms of the merger agreement, Enable's common unitholders, including OGE Energy, will receive 0.8595 of one common unit representing limited partner interests in Energy Transfer for each common unit of Enable. The transaction is subject to the receipt of the required approvals from the holders of a majority of Enable's common units. In April 2021, CenterPoint and OGE Energy, who collectively own approximately 79.2 percent of Enable's common units, delivered written consents approving the merger agreement, and those consents are sufficient to approve the merger. The transaction also is subject to the receipt of anti-trust approvals and other customary closing conditions. The transaction is anticipated to close in 2021. Assuming the transaction closes, OGE Energy will own approximately three percent of Energy Transfer's outstanding limited partner units in lieu of the 25.5 percent interest in Enable that it currently owns. OGE Energy expects to incur transaction costs for investment bankers, advisors and attorneys as part of the transaction.

Assuming the transaction closes, OGE Energy expects to receive distributions from Energy Transfer instead of the distributions currently received from Enable. Therefore, OGE Energy does not expect significant changes to its cash requirements for funding operations or capital expenditures as a result of the merger between Enable and Energy Transfer. Assuming the successful completion of the merger, OGE Energy intends to exit the midstream segment in a prudent manner.

Winter Storm Uri

In February 2021, Winter Storm Uri resulted in record winter peak demand for electricity and extremely high natural gas and purchased power prices in OG&E's service territory. Both the OCC and APSC have approved regulatory mechanisms for OG&E's recovery of the significant fuel and purchased power costs associated with Winter Storm Uri, as further discussed in Note 15 within "Item 1. Financial Statements." As of June 30, 2021, OG&E has recorded regulatory assets of $754.8 million and $92.3 million for the Oklahoma and Arkansas jurisdictional portions, respectively, of fuel and purchased power costs incurred during Winter Storm Uri.

In March 2021, OGE Energy entered into a $1.0 billion unsecured 364-day term loan agreement and borrowed the full $1.0 billion to help cover the significant fuel and purchased power costs incurred during Winter Storm Uri. In May 2021, OGE Energy and OG&E each issued $500.0 million in senior notes, and using these proceeds, OGE Energy repaid $900.0 million of the $1.0 billion term loan, as further described in Notes 10 and 11 within "Item 1. Financial Statements." The Oklahoma and Arkansas legislatures have both passed legislation that would help alleviate the immediate burden on customers and OGE Energy by securitizing the cost impacts from Winter Storm Uri. The securitization of these costs could spread out the recovery of the costs over a longer period of time at a lower finance carrying charge. On April 26, 2021, OG&E filed an application seeking OCC approval to securitize its costs related to Winter Storm Uri, and on June 18, 2021, OG&E filed its direct testimony which supports the prudence of the costs incurred during Winter Storm Uri and demonstrates the customer savings associated with securitization as opposed to traditional utility financing. Further discussion can be found in Note 15 within "Item 1. Financial Statements."

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 enacted various measures, including orders to close or place restrictions on businesses not deemed "essential," enact "shelter in place" restrictions on residents and practice social distancing when engaging in essential activities. Since May 2020, there have been no Oklahoma City-wide or Oklahoma state-wide "shelter in place" restrictions. Currently, COVID-19 vaccines are available to all Oklahoma and Arkansas residents, depending upon the age requirements of the particular vaccine, and the Registrants have provided on-site access to COVID-19 vaccines to their members. The Registrants' top priority is to protect their employees and their families, as well as their customers. The Registrants are taking precautionary measures as directed by health authorities and local and national governments and continue to monitor COVID-19 cases and whether any occupancy reductions or closures are necessary to help ensure the health and safety of their employees and customers. The OCC and the APSC both issued accounting orders allowing the Registrants to defer for recovery the incremental costs incurred for
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pandemic-related safety measures and the incremental bad debt resulting from COVID-19. These orders are further discussed in Note 15 within "Item 1. Financial Statements" and in the Registrants' 2020 Form 10-K.

OG&E's Regulatory Matters

Completed regulatory matters affecting current period results are discussed in Note 15 within "Item 1. Financial Statements."

Summary of OGE Energy Operating Results

Three Months Ended June 30, 2021 as compared to the Three Months Ended June 30, 2020

OGE Energy's net income was $112.9 million, or $0.56 per diluted share, during the three months ended June 30, 2021 as compared to $85.9 million, or $0.43 per diluted share, during the same period in 2020. The increase in net income of $27.0 million, or $0.13 per diluted share, is further discussed below.

An increase in net income at OGE Holdings of $13.2 million, or $0.06 per diluted share of OGE Energy's common stock, was primarily due to an increase in equity in earnings of Enable, which was driven by increased net income from Enable's gathering and processing business resulting from higher average market prices for NGL products and increased crude oil and condensate gathered volumes, and a decrease in income tax expense, which was driven by the Oklahoma state tax rate impact on deferred taxes.
An increase in net income at OG&E of $6.2 million, or $0.03 per diluted share of OGE Energy's common stock, was primarily due to higher utility margin (despite mild weather), partially offset by higher depreciation and amortization expense due to additional assets being placed into service.
A decrease in net loss of other operations (holding company) of $7.6 million, or $0.04 per diluted share of OGE Energy's common stock, was primarily due to lower income tax expense in 2021. In March 2020, OGE Energy recorded an impairment of its investment in Enable which had a corresponding income tax benefit due to a consolidating income tax adjustment related to the interim period that was eliminated in the ordinary course of business over the remainder of 2020.

Six Months Ended June 30, 2021 as compared to the Six Months Ended June 30, 2020

OGE Energy's net income was $165.6 million, or $0.83 per diluted share, during the six months ended June 30, 2021 as compared to a net loss of $405.9 million, or $2.03 per diluted share, during the same period in 2020. The increase in net income of $571.5 million, or $2.86 per diluted share, is further discussed below.

Net income at OGE Holdings was $70.1 million, or $0.35 per diluted share of OGE Energy's common stock, during the six months ended June 30, 2021 compared to a net loss of $549.0 million, or $2.74 per diluted share of OGE Energy's common stock, during the six months ended June 30, 2020. The increase was primarily due to the 2020 impact of lower equity in earnings of Enable related to the impairment of OGE Energy's investment in Enable, partially offset by a decrease in income tax benefit related to this impairment charge. The increase in equity in earnings of Enable was also impacted by increased net income from Enable's transportation and storage business resulting from higher average natural gas sales prices.
A decrease in net income at OG&E of $2.5 million, or $0.01 per diluted share of OGE Energy's common stock, was primarily due to higher depreciation and amortization expense due to additional assets being placed into service and lower utility margin driven by losses from the guaranteed flat bill program during Winter Storm Uri, partially offset by lower other operation and maintenance expense.
A decrease in net income of other operations (holding company) of $45.1 million, or $0.22 per diluted share of OGE Energy's common stock, was primarily due to a lower income tax benefit driven by the 2020 impairment of OGE Energy's investment in Enable. The income tax benefit impact was due to a consolidating income tax adjustment related to the interim period that was eliminated in the ordinary course of business over the remainder of 2020.

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2021 Outlook

OG&E's 2021 earnings guidance remains unchanged and is between $352 million to $373 million, or $1.76 to $1.86 per average diluted share. Based on results for the first half of 2021, including the impacts of Winter Storm Uri and strong mitigation efforts, OG&E's full year earnings are currently projected to be in the lower half of this range. The guidance assumes, among other things, approximately 200 million average diluted shares outstanding and normal weather for the year. As indicated in its 2020 Form 10-K, OGE Energy is not issuing 2021 consolidated earnings guidance due to Enable not issuing an earnings outlook due to the announced merger between Enable and Energy Transfer. See OGE Energy's 2020 Form 10-K for other key factors and assumptions underlying its 2021 guidance.

Non-GAAP Financial Measures

OG&E

Utility margin is defined by OG&E as Operating Revenues less Fuel, Purchased Power and Direct Transmission Expense. Fuel, Purchased Power and Direct Transmission Expense, as reflected on the income statement, includes fuel used in electric generation, purchased power and certain transmission expenses. Utility margin is a non-GAAP financial measure because it excludes operating expenses such as depreciation and amortization. Expenses for fuel, purchased power and direct transmission are recovered through fuel adjustment clauses or other regulatory mechanisms, and as a result, changes in these expenses are offset in operating revenues with no impact on operating income except for the portion of fuel, purchased power and direct transmission costs related to customers under the guaranteed flat bill program. OG&E believes utility margin provides a more meaningful basis for evaluating its operations across periods than operating revenues because utility margin excludes the revenue effect of fluctuations in these expenses. Utility margin is used internally to measure performance against budget and in reports for management and the Board of Directors. OG&E's definition of utility margin may be different from similar terms used by other companies. Further, utility margin is not intended to replace operating income as determined in accordance with GAAP as an indicator of operating performance. The below table presents a reconciliation of utility margin to operating income, which is the most directly comparable financial measure calculated and presented in accordance with GAAP, for the three and six months ended June 30, 2021 and 2020.

Three Months EndedSix Months Ended
June 30,June 30,
(In millions)2021202020212020
Operating income$131.2 $126.1 $180.3 $183.1 
Operating revenues$577.4 $503.5 $2,208.0 $934.8 
Fuel, purchased power and direct transmission expense(200.0)(137.4)(1,546.8)(272.4)
Utility margin377.4 366.1 661.2 662.4 
Other operation and maintenance(118.3)(117.7)(228.6)(238.7)
Depreciation and amortization(102.9)(97.3)(201.6)(191.7)
Taxes other than income(25.0)(25.0)(50.7)(48.9)
Operating income$131.2 $126.1 $180.3 $183.1 

Enable

Enable margin is defined as total revenues minus costs of natural gas and NGLs, excluding depreciation and amortization. Total revenues consist of the fees that Enable charges its customers and the sales price of natural gas, NGLs, crude oil and condensate that Enable sells. The cost of natural gas and NGLs consists of the purchase price of natural gas and NGLs that Enable purchases. Enable deducts the cost of natural gas and NGLs from total revenues to arrive at a measure of the core profitability of their mix of fee-based and commodity-based customer arrangements. Enable margin allows for meaningful comparison of the operating results between Enable's fee-based revenues and Enable's commodity-based contracts which involve the purchase or sale of natural gas, NGLs and/or crude oil. In addition, OGE Energy believes Enable margin allows for a meaningful comparison of the results of Enable's commodity-based activities across different commodity price environments because it measures the spread between the product sales price and cost of products sold. The Enable margin definition used by OGE Energy may be different from similar terms used by other companies. Further, Enable margin is not intended to replace operating income as determined in accordance with GAAP as an indicator of operating performance. The below table presents a
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reconciliation of Enable margin to operating income, which is the most directly comparable financial measure calculated and presented in accordance with GAAP, for the three and six months ended June 30, 2021 and 2020.

Three Months EndedSix Months Ended
June 30,June 30,
(In millions)2021202020212020
Operating income$124 $80 $330 $226 
Total revenues$787 $515 $1,757 $1,163 
Cost of natural gas and NGLs (excluding depreciation and amortization shown separately)(426)(177)(945)(403)
Enable margin361 338 812 760 
Operation and maintenance(91)(115)(175)(217)
General and administrative(25)(21)(62)(45)
Depreciation and amortization(103)(105)(209)(209)
Impairments of property, plant and equipment and goodwill —  (28)
Taxes other than income tax(18)(17)(36)(35)
Operating income$124 $80 $330 $226 

Results of Operations
 
The following discussion and analysis presents factors that affected the Registrants' results of operations for the three and six months ended June 30, 2021 as compared to the same periods in 2020 and the Registrants' financial position at June 30, 2021. Due to seasonal fluctuations and other factors, the Registrants' operating results for the three and six months ended June 30, 2021 are not necessarily indicative of the results that may be expected for the year ending December 31, 2021 or for any future period. The following information should be read in conjunction with the condensed financial statements and notes thereto. Known trends and contingencies of a material nature are discussed to the extent considered relevant.  
Three Months EndedSix Months Ended
OGE EnergyJune 30,June 30,
(In millions except per share data)2021202020212020
Net income (loss)$112.9 $85.9 $165.6 $(405.9)
Basic average common shares outstanding200.2 200.2 200.1 200.2 
Diluted average common shares outstanding200.4 200.5 200.2 200.2 
Basic earnings (loss) per average common share$0.56 $0.43 $0.83 $(2.03)
Diluted earnings (loss) per average common share$0.56 $0.43 $0.83 $(2.03)
Dividends declared per common share$0.40250 $0.38750 $0.80500 $0.77500 

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Results by Business Segment
Three Months EndedSix Months Ended
June 30,June 30,
(In millions)2021202020212020
Net income (loss):
OG&E (Electric Utility)$85.1 $78.9 $96.3 $98.8 
OGE Holdings (Natural Gas Midstream Operations) (A)32.2 19.0 70.1 (549.0)
Other operations (A)(B)(4.4)(12.0)(0.8)44.3 
OGE Energy net income (loss)$112.9 $85.9 $165.6 $(405.9)
(A)In 2020, OGE Energy recorded a $780.0 million impairment ($589.6 million after tax) on its investment in Enable, as further discussed in Note 4 within "Item 1. Financial Statements." Other operations' results for the three and six months ended June 30, 2020 included $16.4 million tax expense and $36.4 million tax benefit impacts, respectively, due to a consolidating tax adjustment related to the interim period that eliminated in the ordinary course of business over the remainder of the year.
(B)Other operations primarily includes the operations of the holding company and consolidating eliminations.

The following discussion of results of operations by business segment includes intercompany transactions that are eliminated in OGE Energy's condensed consolidated financial statements. 
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OG&E (Electric Utility)
Three Months EndedSix Months Ended
June 30,June 30,
(Dollars in millions)2021202020212020
Operating revenues$577.4 $503.5 $2,208.0 $934.8 
Fuel, purchased power and direct transmission expense200.0 137.4 1,546.8 272.4 
Other operation and maintenance118.3 117.7 228.6 238.7 
Depreciation and amortization102.9 97.3 201.6 191.7 
Taxes other than income25.0 25.0 50.7 48.9 
Operating income131.2 126.1 180.3 183.1 
Allowance for equity funds used during construction1.6 1.3 2.9 2.6 
Other net periodic benefit expense1.2 1.0 2.1 1.5 
Other income1.1 1.1 2.8 2.6 
Other expense0.3 0.9 0.7 1.4 
Interest expense37.9 39.3 76.3 76.2 
Income tax expense9.4 8.4 10.6 10.4 
Net income$85.1 $78.9 $96.3 $98.8 
Operating revenues by classification:
Residential$184.2 $208.4 $757.5 $380.7 
Commercial112.2 116.1 421.9 210.2 
Industrial38.7 45.7 186.4 88.3 
Oilfield29.6 39.1 190.9 78.1 
Public authorities and street light38.1 41.6 162.0 77.2 
Sales for resale0.1 0.1 0.1 — 
System sales revenues402.9 451.0 1,718.8 834.5 
Provision for rate refund (1.0) (1.6)
Integrated market128.3 8.5 430.4 15.7 
Transmission36.7 39.8 73.0 74.0 
Other9.5 5.2 (14.2)12.2 
Total operating revenues$577.4 $503.5 $2,208.0 $934.8 
MWh sales by classification (In millions)
Residential2.0 2.2 4.5 4.4 
Commercial1.7 1.5 3.2 3.0 
Industrial1.0 0.9 2.0 2.0 
Oilfield1.0 1.0 2.0 2.1 
Public authorities and street light0.8 0.7 1.4 1.3 
System sales6.5 6.3 13.1 12.8 
Integrated market0.4 0.5 0.7 0.8 
Total sales6.9 6.8 13.8 13.6 
Number of customers874,713 863,234 874,713 863,234 
Weighted-average cost of energy per kilowatt-hour (In cents)
Natural gas2.919 1.907 20.973 1.784 
Coal1.897 1.976 1.835 1.962 
Total fuel2.346 1.760 11.634 1.655 
Total fuel and purchased power2.722 1.919 10.547 1.902 
Degree days (A)
Heating - Actual291 302 2,357 1,951 
Heating - Normal220 204 2,020 2,004 
Cooling - Actual460 559 466 582 
Cooling - Normal569 626 582 639 
(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 $6.2 million, or 7.9 percent, and decreased $2.5 million, or 2.5 percent, during the three and six months ended June 30, 2021, respectively, as compared to the same periods in 2020. The following section discusses the primary drivers for the changes in net income during the three and six months ended June 30, 2021, as compared to the same periods in 2020.
Operating revenues increased $73.9 million, or 14.7 percent, and increased $1,273.2 million during the three and six months ended June 30, 2021, respectively, primarily due to increased fuel, purchased power and direct transmission expenses which are typically recovered from customers. Operating revenues for the six months ended June 30, 2021 were significantly impacted by Winter Storm Uri.
Utility margin increased $11.3 million, or 3.1 percent, and decreased $1.2 million, or 0.2 percent, during the three and six months ended June 30, 2021, respectively, primarily driven by the below factors.
$ Change
(In millions)Three Months EndedSix Months Ended
Price variance$9.2 $17.4 
Guaranteed flat bill program (A)3.9 (27.7)
Non-residential demand and related revenues2.5 3.6 
Industrial and oilfield sales2.0 0.6 
New customer growth1.7 3.5 
Other(3.1)(1.5)
Quantity impacts (primarily weather) (B)(4.9)2.9 
Change in utility margin$11.3 $(1.2)
(A)Increased during the three months ended June 30, 2021 primarily due to SPP purchased power resettlements related to Winter Storm Uri. Decreased during the six months ended June 30, 2021 primarily due to the loss from the guaranteed flat bill program related to Winter Storm Uri. The guaranteed flat bill program allows qualifying customers the opportunity to purchase their electricity needs at a set monthly price for an entire year, which resulted in those customers not being allocated incremental fuel and purchased power costs incurred during Winter Storm Uri.
(B)Decreased during the three months ended June 30, 2021 primarily due to a 17.7 percent decrease in cooling degree days. Increased during the six months ended June 30, 2021 primarily due to a 20.8 percent increase in heating degree days, partially offset by a 19.9 percent decrease in cooling degree days.

Fuel, purchased power and direct transmission expense 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 fuel, purchased power and direct transmission expense increased $62.6 million, or 45.6 percent, and increased $1,274.4 million during the three and six months ended June 30, 2021, respectively, primarily driven by the below factors.
$ Change% Change
(In millions)Three Months EndedSix Months EndedThree Months EndedSix Months Ended
Fuel expense (A)$9.8 $681.9 13.5 %*
Purchased power costs:
Purchases from SPP (B)53.7 591.3 **
Wind(1.8)(3.0)(10.7)%(9.7)%
Other(0.2)3.0 (12.7)%*
Transmission expense1.1 1.2 5.8 %3.2 %
Change in fuel, purchased power and direct transmission expense$62.6 $1,274.4 
*Change is greater than 100 percent variance.
(A)Increased primarily due to higher fuel costs related to Winter Storm Uri.
(B)Increased primarily due to higher market prices as a result of impacts from Winter Storm Uri.
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Other operation and maintenance expense increased $0.6 million, or 0.5 percent, and decreased $10.1 million, or 4.2 percent, during the three and six months ended June 30, 2021, respectively, primarily driven by the below factors.
$ Change% Change
(In millions)Three Months EndedSix Months EndedThree Months EndedSix Months Ended
Corporate overheads and allocations$(3.6)$(8.6)(11.0)%(12.7)%
Capitalized labor(2.7)(6.1)(10.1)%(11.0)%
Payroll and benefits(1.8)(4.9)(2.8)%(3.8)%
Contract technical and construction services (A)4.4 7.7 38.1 %35.8 %
Other4.3 1.8 11.1 %2.4 %
Change in other operation and maintenance expense (B)$0.6 $(10.1)
(A) Increased primarily due to intentional cost reduction and the delay of certain projects due to COVID-19 in 2020.
(B) OG&E has been focused on reducing other operation and maintenance activities in light of COVID-19.

Depreciation and amortization expense increased $5.6 million, or 5.8 percent, and increased $9.9 million, or 5.2 percent, during the three and six months ended June 30, 2021, respectively, primarily due to additional assets being placed into service.
Income tax expense increased $1.0 million, or 11.9 percent, primarily due to higher pretax income during the three months ended June 30, 2021.

OGE Holdings (Natural Gas Midstream Operations)
Three Months Ended June 30,Six Months Ended June 30,
(In millions)2021202020212020
Operating revenues$ $— $ $— 
Fuel, purchased power and direct transmission expense —  — 
Other operation and maintenance1.6 0.3 2.0 0.9 
Taxes other than income0.1 0.1 0.2 0.2 
Operating loss(1.7)(0.4)(2.2)(1.1)
Equity in earnings (losses) of unconsolidated affiliates (A)33.5 26.9 86.7 (719.6)
Other expense0.2 — 0.7 — 
Income (loss) before taxes31.6 26.5 83.8 (720.7)
Income tax expense (benefit)(0.6)7.5 13.7 (171.7)
Net income (loss) attributable to OGE Holdings$32.2 $19.0 $70.1 $(549.0)
(A)In March 2020, OGE Energy recorded a $780.0 million impairment on its investment in Enable, as further discussed in Note 4 within "Item 1. Financial Statements."

Reconciliation of Equity in Earnings (Losses) of Unconsolidated Affiliates

See Note 4 within "Item 1. Financial Statements" for the reconciliation of Enable's net income to OGE Energy's equity in earnings (losses) of unconsolidated affiliates and the reconciliation of the difference between OGE Energy's investment in Enable and its underlying equity in the net assets of Enable (basis difference).

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Enable Results of Operations and Operating Data

The following section presents summarized financial information of Enable for the three and six months ended June 30, 2021 and 2020 and related discussion of the primary drivers for the changes during the periods.
Three Months EndedSix Months Ended
June 30,June 30,
(In millions)2021202020212020
Total revenues$787 $515 $1,757 $1,163 
Cost of natural gas and NGLs (excluding depreciation and amortization)$426 $177 $945 $403 
Operating income$124 $80 $330 $226 
Net income$79 $35 $234 $138 
Three Months EndedSix Months Ended
June 30,June 30,
2021202020212020
Natural gas gathered volumes - TBtu/d4.39 4.14 4.24 4.33 
Natural gas processed volumes - TBtu/d (A)2.20 2.04 2.13 2.24 
NGLs sold - MBbl/d (B)147.62 122.99 133.82 122.15 
Crude oil and condensate gathered volumes - MBbl/d110.98 84.68 112.17 112.97 
Transported volumes - TBtu/d5.44 5.40 5.77 5.98 
(A)Includes volumes under third-party processing arrangements.
(B)Excludes condensate. NGLs sold includes volumes of NGLs withdrawn from inventory or purchased for system balancing purposes.

OGE Holdings' net income increased $13.2 million, or 69.5 percent, during the three months ended June 30, 2021 as compared to the same period in 2020. This increase was primarily due to an increase in equity in earnings of Enable, which was driven by an increase in Enable's net income, and a decrease in income tax expense. OGE Holdings' net income was $70.1 million compared to a net loss of $549.0 million during the six months ended June 30, 2021 and 2020, respectively. This change was primarily due to the 2020 impact of the impairment of OGE Energy's investment in Enable, as discussed in Note 4 within "Item 1. Financial Statements."

The following table presents summarized information regarding Enable's income statement changes for the three and six months ended June 30, 2021, as compared to the same periods in 2020, and the corresponding impact those changes had on OGE Energy's equity in earnings of Enable. See Note 4 within "Item 1. Financial Statements" for further discussion of OGE Energy's equity investment in Enable. The increases in Enable's net income were primarily driven by the below factors.
Three Months EndedSix Months Ended
(In millions)Income Statement Change at EnableImpact to OGE Energy's Equity in EarningsIncome Statement Change at EnableImpact to OGE Energy's Equity in Earnings
Enable margin (A)$23.0 $5.9 $52.0 $13.3 
Impairments of property, plant and equipment and goodwill (B)$— $— $(28.0)$4.4 
Operation and maintenance, General and administrative$(20.0)$5.1 $(25.0)$6.4 
Depreciation and amortization$(2.0)$0.5 $— $— 
(A)Enable margin is a non-GAAP measure and is defined and reconciled to its most directly comparable financial measure as calculated and presented within "Non-GAAP Financial Measures - Enable" above.
(B)Included in the $28.0 million of impairments recorded by Enable in 2020 is a $12.0 million goodwill impairment and a $16.0 million impairment for certain long-lived assets in their gathering and processing business segment. OGE Energy recorded a $4.4 million pre-tax charge for its share of Enable's goodwill and long-lived asset impairments, as adjusted for basis differences.

Enable's gathering and processing business segment reported an increase in operating income of $40.0 million and $30.0 million for the three and six months ended June 30, 2021, respectively, as compared to the same periods in 2020. The following table presents summarized information regarding Enable's gathering and processing business segment income
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statement changes for the three and six months ended June 30, 2021, as compared to the same periods in 2020, and the corresponding impact those changes had on OGE Energy's equity in earnings of Enable. The increases in Enable's gathering and processing business segment operating income were primarily driven by the below factors.
Three Months EndedSix Months Ended
(In millions)Income Statement Change at EnableImpact to OGE Energy's Equity in EarningsIncome Statement Change at EnableImpact to OGE Energy's Equity in Earnings
Enable margin (A)$21.0 $5.4 $(19.0)$(4.8)
Impairments of property, plant and equipment and goodwill (B)$— $— $(28.0)$4.4 
Operating and maintenance, General and administrative$(19.0)$4.8 $(21.0)$5.4 
(A)Enable margin is a non-GAAP measure and is defined and reconciled to its most directly comparable financial measure as calculated and presented within "Non-GAAP Financial Measures - Enable" above.
(B)Included in the $28.0 million of impairments recorded by Enable in 2020 is a $12.0 million goodwill impairment and a $16.0 million impairment for certain long-lived assets in their gathering and processing business segment. OGE Energy recorded a $4.4 million pre-tax charge for its share of Enable's goodwill and long-lived asset impairments, as adjusted for basis differences.

Gathering and processing Enable margin increased for the three months ended June 30, 2021 primarily due to:

an increase in revenues from NGL sales less the cost of NGLs primarily due to an increase in the average realized sales price from higher average market prices for NGL products combined with higher recoveries of ethane and higher processed volumes;
an increase in processing service fees due to higher consideration received from percent-of-proceeds, percent-of-liquids and keep-whole processing arrangements due to higher average market prices, partially offset by lower processed volumes under fee-based arrangements and a decrease in the recognition of certain annual minimum processing fees; and
an increase in crude oil, condensate and produced water gathering revenues primarily due to an increase in gathered crude oil and condensate volumes; partially offset by
a decrease in revenues from natural gas sales less the cost of natural gas due to higher natural gas purchase costs;
an increase in realized losses on natural gas, condensate and NGL derivatives;
a decrease in changes in the fair value of natural gas, condensate and NGL derivatives; and
a decrease in natural gas gathering fees due to lower volumes gathered under fee-based arrangements.

Gathering and processing Enable margin decreased for the six months ended June 30, 2021 primarily due to:

an increase in realized losses on natural gas, condensate and NGL derivatives;
a decrease in revenues from natural gas sales less the cost of natural gas due to higher natural gas purchase costs, inclusive of purchase costs related to Winter Storm Uri;
a decrease in changes in the fair value of natural gas, condensate and NGL derivatives; and
a decrease in natural gas gathering fees due to lower gathered volumes, inclusive of volume curtailments and production freeze-offs related to Winter Storm Uri, partially offset by higher assessed producer imbalance penalties; partially offset by
an increase in revenues from NGL sales less the cost of NGLs primarily due to an increase in the average realized sales price from higher average market prices for NGL products combined with higher recoveries of ethane, partially offset by lower processed volumes;
an increase in processing service fees due to higher consideration received from percent-of-proceeds, percent-of-liquids and keep-whole processing arrangements due to higher average market prices, partially offset by lower processed volumes under fee-based arrangements and a decrease in the recognition of certain annual minimum processing fees; and
an increase in crude oil, condensate and produced water gathering revenues primarily due to an increase in gathered crude oil volumes in the Williston Basin, partially offset by a decrease in gathered crude oil and condensate volumes in the Anadarko Basin.

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Enable's transportation and storage business segment reported an increase in operating income of $3.0 million and $73.0 million for the three and six months ended June 30, 2021, respectively, as compared to the same periods in 2020. The following table presents summarized information regarding Enable's transportation and storage business segment income statement changes for the three and six months ended June 30, 2021, as compared to the same periods in 2020, and the corresponding impact those changes had on OGE Energy's equity in earnings of Enable. The increases in Enable's transportation and storage business segment operating income were primarily driven by the below factors.
Three Months EndedSix Months Ended
(In millions)Income Statement Change at EnableImpact to OGE Energy's Equity in EarningsIncome Statement Change at EnableImpact to OGE Energy's Equity in Earnings
Enable margin (A)$1.0 $0.3 $70.0 $17.9 
Operation and maintenance, General and administrative$(1.0)$0.3 $(4.0)$1.0 
Depreciation and amortization$(2.0)$0.5 $— $— 
(A)Enable margin is a non-GAAP measure and is defined and reconciled to its most directly comparable financial measure as calculated and presented within "Non-GAAP Financial Measures - Enable" above.

Transportation and storage Enable margin increased for the three months ended June 30, 2021 primarily due to:

an increase in system management activities primarily due to higher average natural gas sales prices, less the cost of natural gas;
an increase in revenues from NGL sales, less the cost of NGLs due to an increase in average NGL prices; and
a reduction in lower of cost or net realizable value adjustments related to natural gas storage inventories; partially offset by
a decrease in firm transportation and storage services primarily due to interstate contract extensions at lower rates and terminations of certain intrastate firm transportation agreements;
higher realized losses on natural gas derivatives; and
a decrease in changes in the fair value of natural gas derivatives.

Transportation and storage Enable margin increased for the six months ended June 30, 2021 primarily due to:

an increase in system management activities primarily due to higher average natural gas sales prices, less the cost of natural gas;
an increase in volume-dependent transportation and storage revenues due to an increase in assessed shipper imbalance penalties, partially offset by lower off-system intrastate transported volumes, inclusive of disruptions in natural gas supply associated with Winter Storm Uri and the recognition in 2020 of revenue upon the settlement of a certain rate case with no comparable item in 2021;
a reduction in lower of cost or net realizable value adjustments related to natural gas storage inventories; and
an increase in revenues from NGL sales, less the cost of NGLs due to an increase in average NGL prices, partially offset by lower volumes; partially offset by
a decrease in firm transportation and storage services due to the recognition in 2020 of previously reserved revenue upon the settlement of a certain rate case with no comparable item in 2021 combined with interstate contract extensions at lower rates and terminations of certain intrastate firm transportation agreements;
a decrease in changes in the fair value of natural gas derivatives; and
higher realized losses on natural gas derivatives.

OGE Holdings' income tax expense decreased $8.1 million during the three months ended June 30, 2021, as compared to the same period in 2020, primarily due to state deferred tax adjustments related to OGE Energy's investment in Enable primarily driven by the decrease in the Oklahoma corporate tax rate, partially offset by higher pretax income. OGE Holdings' income tax expense was $13.7 million during the six months ended June 30, 2021, as compared to an income tax benefit of $171.7 million during the same period in 2020. The change is primarily due to a tax benefit of $190.4 million related to the impairment recorded in 2020 on OGE Energy's investment in Enable and higher pretax income in 2021, partially offset by state deferred tax adjustments related to OGE Energy's investment in Enable primarily driven by the decrease in the Oklahoma corporate tax rate.

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Off-Balance Sheet Arrangements
 
There have been no significant changes in OGE Energy's off-balance sheet arrangements from those discussed in its 2020 Form 10-K. OGE Energy has no off-balance sheet arrangements with equity method investments that would affect its liquidity.

Liquidity and Capital Resources

Cash Flows

OGE Energy
Six Months Ended
June 30,2021 vs. 2020
(Dollars in millions)20212020$ Change% Change
Net cash (used in) provided from operating activities (A)$(767.8)$263.3 $(1,031.1)*
Net cash used in investing activities (B)$(356.8)$(282.3)$(74.5)26.4 %
Net cash provided from financing activities (C)$1,123.5 $86.5 $1,037.0 *
* Change is greater than 100 percent variance.
(A)Decreased primarily due to an increase in vendor payments, including payments for fuel and purchased power costs related to Winter Storm Uri.
(B)Changed due to increased spend on grid modernization projects at OG&E as well as timing of plant outages.
(C)Increased primarily due to increases in long- and short-term debt to provide additional liquidity for the increased fuel and purchased power costs incurred by OG&E related to Winter Storm Uri.

Working Capital

Working capital is defined as the difference in current assets and current liabilities. OGE Energy's working capital requirements are driven generally by changes in accounts receivable, accounts payable, commodity prices, credit extended to and the timing of collections from OG&E's customers, the level and timing of spending for maintenance and expansion activity, inventory levels and fuel recoveries. The following discussion addresses changes in OGE Energy's working capital balances at June 30, 2021 compared to December 31, 2020.

Accounts Receivable and Accrued Unbilled Revenues increased $42.5 million, or 18.9 percent, primarily due to an increase in billings to OG&E's retail customers reflecting higher seasonal usage in June 2021 as compared to December 2020.

Income Taxes Receivable decreased $4.0 million, or 49.4 percent, primarily due to current year tax expense accruals in excess of the prior accrued receivable.

Fuel Inventories increased $9.6 million, or 26.3 percent, primarily due to increased coal inventory.

Other Current Assets increased $5.9 million, or 14.3 percent, primarily due to an increase in SPP deposits, prepayments associated with software expense and under-recovered riders, partially offset by a decrease in the SPP transmission formula rate true-up and prepaid insurance.

Short-term Debt increased $289.5 million, primarily due to borrowings under OGE Energy's revolving credit and term loan agreements to provide additional liquidity for the increased fuel and purchased power costs incurred as a result of Winter Storm Uri. OGE Energy borrows on a short-term basis, as necessary, by the issuance of commercial paper and borrowings under its revolving credit agreements and term credit agreements.

Accounts Payable decreased $61.7 million, or 24.5 percent, primarily due to the timing of vendor payments and lower fuel and purchased power accruals as a result of timing differences and SPP purchased power resettlements related to Winter Storm Uri.

Accrued Compensation increased $4.9 million, or 15.8 percent, primarily due to increased 2021 labor accruals as a result of pay period timing differences, partially offset by 2020 incentive compensation payouts that occurred in the first quarter of 2021.

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Fuel Clause Over Recoveries decreased $23.9 million, or 83.6 percent, primarily due to both higher fuel costs and decreased collections from customers.

Future Capital Requirements

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

Capital Expenditures
 
OGE Energy's estimates of capital expenditures, which represent base maintenance capital expenditures plus capital expenditures for known and committed projects, for the years 2021 through 2025 are presented in the following table. Estimated capital expenditures for Enable are not included. Additional capital expenditures beyond those identified below, including additional incremental growth opportunities, will be evaluated based upon the requirements of OG&E's power supply, transmission and distribution operational teams and the resultant customer benefits as well as their impact upon achieving OGE Energy's financial objectives.
(In millions)20212022202320242025Total
Transmission$150 $110 $115 $105 $125 $605 
Oklahoma distribution275 290 265 300 300 1,430 
Arkansas distribution25 20 20 20 20 105 
Generation105 85 125 125 130 570 
Oklahoma Grid Advancement215 180 185 185 185 950 
Subscription Solar Plan15 20 20 20 20 95 
Other65 80 80 80 80 385 
Total$850 $785 $810 $835 $860 $4,140 

Financing Activities and Future Sources of Financing

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

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

OGE Energy has unsecured five-year revolving credit facilities totaling $900.0 million ($450.0 million for OGE Energy and $450.0 million for OG&E), which can also be used as letter of credit facilities. The following table presents information about OGE Energy's revolving credit agreements at June 30, 2021.
(Dollars in millions)
June 30, 2021
Balance of outstanding supporting letters of credit$0.4 
Weighted-average interest rate of outstanding supporting letters of credit1.15 %
Net available liquidity under revolving credit agreements$615.1 
Balance of cash and cash equivalents$— 

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The following table presents information about OGE Energy's total short-term debt activity for the three and six months ended June 30, 2021.
(Dollars in millions)Three Months Ended June 30, 2021Six Months Ended June 30, 2021
Average balance of short-term debt$1,037.3 $733.1 
Weighted-average interest rate of average balance of short-term debt0.65 %0.60 %
Maximum month-end balance of short-term debt$1,443.4 $1,443.4 

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

In March 2021, OGE Energy entered into a $1.0 billion unsecured 364-day term loan agreement to provide additional liquidity to help cover the increased fuel and purchased power costs incurred by OG&E during Winter Storm Uri. In May 2021, $900.0 million of the $1.0 billion term loan was repaid using the proceeds from the senior notes issued by both OGE Energy and OG&E, as further described below. See Note 11 within "Item 1. Financial Statements" for further discussion of the Registrants' short-term debt activity.

Issuance of Long-Term Debt

In May 2021, OGE Energy issued $500.0 million of 0.703 percent senior notes, and OG&E issued $500.0 million of 0.553 percent senior notes. Each series is due May 26, 2023 but may be redeemed by OGE Energy or OG&E on or after November 26, 2021 at a price equal to 100 percent of the principal amount of the senior notes being redeemed, plus any accrued and unpaid interest. The proceeds from these issuances were used to repay $900.0 million of the $1.0 billion term loan OGE Energy entered into in March 2021 to help cover the fuel and purchased power costs incurred by OG&E during Winter Storm Uri.

Security Ratings 

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

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

On March 1, 2021, Moody's Investors Service revised their ratings outlook on both OGE Energy and OG&E from stable to negative. Moody's Investors Service indicated that the negative outlook on OGE Energy's rating is consistent with OG&E's and reflects the increased regulatory uncertainty related to the recovery timeline of the cost incurred to procure fuel and purchased power during Winter Storm Uri.

On March 3, 2021, S&P's Global Ratings revised their ratings outlook on both OGE Energy and OG&E from stable to negative. S&P's Global Ratings indicated that the revised outlooks reflect their expectation for weaker financial measures directly associated with the significant increase in fuel and purchased power costs as a result of Winter Storm Uri, the uncertainty regarding timely recovery of those costs and the associated refinancing risk related to the 364-day $1.0 billion term loan. For OGE Energy, S&P's Global Ratings indicated the revised outlook also reflects their expectation of execution risk associated with the closing of Energy Transfer's acquisition of Enable.

Distributions by Enable

Pursuant to the Enable Limited Partnership Agreement, during the three and six months ended June 30, 2021, Enable made distributions of $18.4 million and $36.7 million to OGE Energy, respectively.

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

In management's opinion, the areas where the most significant judgment is exercised for the Registrants include the determination of Pension Plan assumptions, income taxes, contingency reserves, asset retirement obligations, regulatory assets and liabilities, unbilled revenues and the allowance for uncollectible accounts receivable. For OGE Energy, significant judgment is also exercised in the determination of any impairment of equity method investments. The selection, application and disclosure of the critical accounting estimates have been discussed with the Audit Committee of OGE Energy's Board of Directors and are discussed in detail within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Registrants' 2020 Form 10-K.

Commitments and Contingencies
 
In the normal course of business, the Registrants are confronted with issues or events that may result in a contingent liability. These generally relate to lawsuits or claims made by third parties, including governmental agencies. When appropriate, management consults with legal counsel and other experts to assess the claim. If, in management's opinion, the Registrants have incurred a probable loss as set forth by GAAP, an estimate is made of the loss, and the appropriate accounting entries are reflected in the condensed financial statements. At the present time, based on available information, the Registrants believe that any reasonably possible losses in excess of accrued amounts arising out of pending or threatened lawsuits or claims would not be quantitatively material to their condensed financial statements and would not have a material adverse effect on their financial position, results of operations or cash flows. See Notes 14 and 15 within "Item 1. Financial Statements" for further discussion of the Registrants' commitments and contingencies.

Environmental Laws and Regulations
 
The activities of OG&E are subject to numerous, stringent and complex federal, state and local laws and regulations governing environmental protection. These laws and regulations can change, restrict or otherwise impact OG&E's business activities in many ways, including the handling or disposal of waste material, planning for future construction activities to avoid or mitigate harm to threatened or endangered species and requiring the installation and operation of emissions or pollution control equipment. Failure to comply with these laws and regulations could result in the assessment of administrative, civil and criminal penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations. Management believes that all of the Registrants' operations are in substantial compliance with current federal, state and local environmental standards.

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

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

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
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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 update applies to ozone-season NOx emissions from power plants in 22 eastern states (including Oklahoma). The rule utilizes a cap and trade program for NOx emissions and went into effect on May 1, 2017 in Oklahoma. The update 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 partially remanded the Cross-State Air Pollution Rule update and also deferred a decision on OG&E's challenges to the rule pending an EPA review and decision on a separate administrative petition that OG&E filed. Subsequently, all of OG&E's judicial challenges were voluntarily dismissed, but the administrative petitions for reconsideration remain pending at the EPA. On October 30, 2020, the EPA published a proposed rule to revise the 2016 update rule and address the 2019 remand. The EPA published a final version of the remanded rule in the Federal Register on May 17, 2021. Consistent with the proposal, the EPA does not require additional reductions in the emissions budget for Oklahoma based on a determination that the state does not cause or contribute to nonattainment of the ambient air quality standards in the relevant downwind areas.

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

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. Petitions for judicial review of the final May 2020 rule have been filed at the D.C. Circuit Court. The consolidated challenges are being held in abeyance pending the EPA's review of the 2020 rule.

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 June 30, 2021, no areas of Oklahoma had been designated as non-attainment for pollutants that are likely to affect OG&E's operations.

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 CO2, sulfur hexafluoride and methane, and whether these emissions are contributing to the warming of the earth's atmosphere. On April 22, 2021, President Biden announced a target for the U.S. in association with the United Nations' "Paris Agreement" on climate change. The target consists of a 50 to 52 percent reduction from 2005 levels in economy-wide net greenhouse gas emissions in 2030. President Biden also has stated that a goal of his administration is to see the electric power industry fully decarbonized by 2035. The details surrounding the implementation of these targets are not finalized and the impact to OG&E, if any, is currently unknown. Such initiatives may result in future additional greenhouse gas emissions reductions in the U.S.; however, it is not possible to determine what the
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U.S. standards for greenhouse gas emissions will be in the future or 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 NOx 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 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.
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 SIP deadline 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, which has not commenced. 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. On July 8, 2021, the EPA issued a memorandum providing further information on the development of SIPs for the Regional Haze second implementation period.

On July 1, 2020, the ODEQ notified OG&E that the Horseshoe Lake generating units are to be included in the state's evaluation of visibility impairment impacts to the Wichita Mountains. OG&E conducted an analysis of all potential control measures for NOx on these units and submitted it to the ODEQ on September 15, 2020. The ODEQ will identify any cost-effective control measures in a Regional Haze SIP, to be submitted to the EPA for approval by July 31, 2021. It is unknown at this time what the outcome, or any potential material impacts, will be from the evaluations by OG&E, the ODEQ and the EPA.

Endangered Species

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

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

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Vegetation Management

On July 10, 2020, the U.S. Department of Agriculture – Forest Service published a final rule which updates procedures for creating operating plans and agreements for powerline facility maintenance and vegetation management within and abutting the linear boundary of a special use authorization for a powerline facility within Forest Service lands. This rule codifies the memorandum of understanding between utilities such as OG&E and the Forest Service regarding vegetation management best practices. All companies will be required to have an approved operating plan or agreement with the Forest Service. OG&E will be required to submit a draft operating plan to the Forest Service by August 10, 2023 for ongoing maintenance and vegetation management activities located within the Ozark National Forest in Arkansas.

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, which was decided upon in the EPA's favor on April 15, 2020 and has subsequently been appealed.

Over 95 percent of the ash from OG&E's Muskogee and Sooner facilities was recovered and sold to the concrete and cement industries in the last two years, and in 2021, River Valley became OG&E's third power plant to enter an agreement to have its fly ash reused. Using ash in this way also helps cement manufacturers minimize their impact on the environment by avoiding the need to extract and process other natural resources. Based on estimates from the American Coal Ash Association, OG&E fly ash reuse helped avoid over three million tons of CO2 emissions in the last 13 years.

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

Water

OG&E's operations are subject to the Federal Clean Water Act and comparable state laws and regulations. These laws and regulations impose detailed requirements and strict controls regarding the discharge of pollutants into state and federal waters.
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 ODEQ 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 October 13, 2020, the EPA published a final rule to revise the technology-based effluent limitations for flue gas desulfurization waste water and bottom ash transport water. 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.
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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 a rule to define the scope of federal jurisdiction over wetlands. This final rule replaces the repealed definition of waters of the U.S. from 2015. The rule became effective on June 22, 2020, and OG&E has not experienced, and does not expect to experience, any material impacts as a result.

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

Site Remediation

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

For further discussion regarding contingencies relating to environmental laws and regulations, see Note 14 within "Item 1. Financial Statements."

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.
 
There have been no significant changes in the market risks affecting the Registrants from those discussed in the Registrants' 2020 Form 10-K.

Item 4. Controls and Procedures.
 
The Registrants maintain a set of disclosure controls and procedures designed to ensure that information required to be disclosed by the Registrants in reports that they file or submit under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission rules and forms. In addition, the disclosure controls and procedures ensure that information required to be disclosed is accumulated and communicated to management, including the chief executive officer and chief financial officer, allowing timely decisions regarding required disclosure. As of the end of the period covered by this report, based on an evaluation carried out under the supervision and with the participation of the Registrants' management, including the chief executive officer and chief financial officer, of the effectiveness of the Registrants' disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15(d)-15(e) under the Securities Exchange Act of 1934), the chief executive officer and chief financial officer have concluded that the Registrants' disclosure controls and procedures are effective.
 
No change in the Registrants' internal control over financial reporting has occurred during the most recently completed fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Registrants' internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934).

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PART II. OTHER INFORMATION

Item 1. Legal Proceedings.
 
Reference is made to Item 3 of Part I of the Registrants' 2020 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 the Registrants, and there have been no material changes in the previously reported proceedings.

Item 1A. Risk Factors.

There have been no significant changes in the Registrants' risk factors from those discussed in the Registrants' 2020 Form 10-K, which are incorporated herein by reference.

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

None.

Item 5. Other Information.

On August 2, 2021, following a mid-year market-data review, the Compensation Committee of the Board of Directors approved adjustments to the annual base salaries of W. Bryan Buckler, Chief Financial Officer, and Donnie O. Jones, Vice President – Utility Operations of OG&E. Mr. Buckler's 2021 base salary increased 10 percent from $400,000 to an annual rate of $440,000, and Mr. Jones's 2021 base salary increased 10 percent from $323,000 to an annual rate of $355,000. No other compensation changes were made for Messrs. Buckler and Jones; however, as the target amount of annual incentive is expressed as a percentage of salary, the increases will have the effect of potentially increasing the annual incentive amounts earned.

Also, on August 3, 2021, the Board of Directors amended and restated the OGE Energy Corp. Supplemental Executive Retirement Plan ("SERP"), to increase the benefit amount payable under the SERP. The SERP, which originally was adopted in 1993 and most recently amended in 2019, provides a supplemental executive retirement plan in order to attract and retain lateral hires or other executives designated by the Compensation Committee who may not otherwise qualify for a sufficient level of benefits under OGE Energy's Pension Plan and Restoration of Retirement Income Plan. The SERP is an unfunded supplemental executive retirement plan that is not subject to the benefit limits imposed by the Internal Revenue Code. Sean Trauschke, Chairman, President and Chief Executive Officer of OGE Energy, was designated as a participant in the SERP in 2019 and currently is the only employee of OGE Energy that participates in the SERP.

Prior to the amendment in August 2021, the SERP provided to designated participants a retirement benefit at or after age 60 equal to the actuarial equivalent of 1.32 percent of the participant's average compensation (equal to base salary, plus target amount of annual incentive award in effect) during his or her final 36 months of employment, multiplied by his or her years of service (or portions thereof). For this purpose, years of service commence upon the later to occur of the participant's commencement of employment with OGE Energy or January 1, 2019. SERP payments will be made in a lump sum after becoming eligible for benefits and following termination, as provided in the SERP, in an amount equal to the actuarial equivalent of the monthly annuity.

The SERP, as amended, will increase the retirement benefit from the actuarial equivalent of 1.32 percent of the participant's average compensation during his or her final 36 months of employment to the actuarial equivalent of 2.90 percent of the participant's average compensation during his or her final 36 months of employment, in each case, multiplied by his or her years of service (or portions thereof).

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Item 6. Exhibits.
Exhibit No. DescriptionOGE EnergyOG&E
4.01X
4.02X
10.01*+X
31.01+X
31.02+X
32.01+X
32.02+X
101.INSInline 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.XX
101.SCHInline XBRL Taxonomy Schema Document.XX
101.PREInline XBRL Taxonomy Presentation Linkbase Document.XX
101.LABInline XBRL Taxonomy Label Linkbase Document.XX
101.CALInline XBRL Taxonomy Calculation Linkbase Document.XX
101.DEFInline XBRL Definition Linkbase Document.XX
104Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document (included in Exhibit 101).XX
  * Represents executive compensation plans and arrangements.
 + Represents exhibits filed herewith. All exhibits not so designated are incorporated by reference to a prior filing, as indicated.


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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.
 OGE ENERGY CORP.
OKLAHOMA GAS AND ELECTRIC COMPANY
 (Registrant)
  
By:/s/ Sarah R. Stafford
 Sarah R. Stafford
 Controller and Chief Accounting Officer
(On behalf of the Registrants and in her capacity as Chief Accounting Officer)

August 4, 2021

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