Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summary of Significant Accounting Policies

1.Summary of Significant Accounting Policies

Organization

OGE Energy is a holding company with investments in energy and energy services providers offering physical delivery and related services for electricity in Oklahoma and western Arkansas. Prior to September 30, 2022, OGE Energy also held investments in Enable and Energy Transfer, which offered natural gas, crude oil and NGL services. OGE Energy reports these activities through two business segments: (i) electric company 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 consolidated financial statements. All intercompany transactions and balances are eliminated in such consolidation. For periods prior to the December 2, 2021 closing of the Enable and Energy Transfer merger, OGE Energy accounted for its investment in Enable as an equity method investment and reported it within OGE Energy's natural gas midstream operations segment. For the period of December 2, 2021 through September 30, 2022, OGE Energy accounted for its investment in the Energy Transfer units it acquired in the merger as an investment in equity securities, as further discussed below. As of the end of September 2022, OGE Energy had sold all of its Energy Transfer limited partner units, becoming primarily an electric company.

Electric Company Operations. OGE Energy's electric company 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 company in Oklahoma, and its franchised service territory includes Fort Smith, Arkansas and the surrounding communities. OG&E sold its retail natural gas business in 1928 and is no longer engaged in the natural gas distribution business.

Natural Gas Midstream Operations. For the period of December 2, 2021 to September 30, 2022, OGE Energy's natural gas midstream operations segment included OGE Energy's investment in Energy Transfer's equity securities acquired in the Enable/Energy Transfer merger. For the year ended December 31, 2022, this segment also includes legacy Enable seconded employee pension and postretirement costs. Prior to OGE Energy's sale of all Energy Transfer limited partner units, the investment in Energy Transfer's equity securities was held through wholly-owned subsidiaries and ultimately OGE Holdings. OGE Energy accounted for its investment in Energy Transfer as an investment in equity securities, as further discussed under "Investment in Equity Securities of Energy Transfer" below.

Accounting Records

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

Management's expected recovery of deferred costs and flowback of deferred credits generally results from specific decisions by regulators granting such ratemaking treatment.

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

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

December 31 (In millions)	2022		2021
REGULATORY ASSETS
Current:
Oklahoma fuel clause under recoveries	$	474.3	$	140.4
Arkansas fuel clause under recoveries		40.6		11.5
Oklahoma Energy Efficiency Rider under recoveries (A)		7.7		11.7
Other (A)		4.7		19.0
Total current regulatory assets	$	527.3	$	182.6
Non-current:
Oklahoma deferred storm expenses	$	206.3	$	172.8
Benefit obligations regulatory asset		119.7		109.2
Arkansas Winter Storm Uri costs		78.2		88.9
Pension tracker		57.2		42.9
Sooner Dry Scrubbers		18.1		18.9
Arkansas deferred pension expenses		12.3		12.1
Unamortized loss on reacquired debt		8.0		8.9
COVID-19 impacts		7.7		8.2
Frontier Plant deferred expenses		5.2		6.7
Oklahoma Winter Storm Uri costs		—		747.9
Other		11.6		14.3
Total non-current regulatory assets	$	524.3	$	1,230.8
REGULATORY LIABILITIES
Current:
SPP cost tracker over recovery (B)	$	3.0	$	—
Other (B)		2.5		2.5
Total current regulatory liabilities	$	5.5	$	2.5
Non-current:
Income taxes refundable to customers, net	$	894.7	$	930.7
Accrued removal obligations, net		250.5		296.8
Other		1.9		3.6
Total non-current regulatory liabilities	$	1,147.1	$	1,231.1

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

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

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

OG&E recovers program costs related to the Energy Efficiency Program in Oklahoma through the Energy Efficiency Rider, which operates on a three-year program cycle. The current program cycle, which runs through 2024, includes recovery of (i) energy efficiency program costs, (ii) lost revenues associated with certain achieved energy efficiency and demand savings, (iii) performance-based incentives and (iv) costs associated with research and development investments.

OG&E includes in expense any Oklahoma storm-related operation and maintenance expenses up to $2.7 million annually and defers to a regulatory asset any additional expenses incurred over $2.7 million. OG&E typically recovers the amounts deferred each year over a five to ten year period in accordance with historical practice.

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

benefit plan expenses, this could cause the benefit obligations regulatory asset balance to be reclassified to accumulated other comprehensive income.

The following table presents a summary of the components of the benefit obligations regulatory asset.

December 31 (In millions)	2022		2021
Pension Plan and Restoration of Retirement Income Plan:
Net loss	$	110.0	$	89.6
Postretirement Benefit Plans:
Net loss		9.7		23.2
Prior service cost		—		(3.6	)
Total	$	119.7	$	109.2

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. The OCC allowed OG&E to create a regulatory asset for the Oklahoma portion of all deferred costs, and the Oklahoma Winter Storm Uri regulatory asset was fully recovered in July 2022 through OG&E's receipt of securitization funds from the ODFA, as further discussed in Note 14. In 2021, the APSC allowed OG&E to create a regulatory asset for the Arkansas portion of all deferred costs and, as ordered in January 2023, to amortize the regulatory asset balance over 10 years using a weighted average cost of capital as a carrying charge, as further discussed in Note 14.

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 regulatory asset in the table above. As discussed in Note 14, the OCC recently approved recovery of the over/under-recovery balance of the Pension tracker over 15 years, which is a change from the previous five-year recovery period.

As approved by the OCC, OG&E deferred the non-fuel incremental operation and maintenance expenses, depreciation, debt cost associated with the capital investment and related ad valorem taxes for the Dry Scrubbers at Sooner Units 1 and 2 as a regulatory asset, and these costs are being recovered over 25 years.

Arkansas includes a certain level of pension expense in base rates. When the Pension Plan experiences a settlement, which represents an acceleration of future pension costs, OG&E defers to a regulatory asset the Arkansas jurisdictional portion of each settlement, which historically has been recovered from customers over the average life of the remaining plan participants. A portion of these settlements is being recovered in current rates, and recovery of additional amounts will be requested as additional settlements occur. For additional information related to settlements, see Note 11.

Unamortized loss on reacquired debt is comprised of unamortized debt issuance costs related to the early retirement of OG&E's long-term debt. These amounts are recorded in interest expense and are being amortized over the term of the long-term debt which replaced the previous long-term debt. The unamortized loss on reacquired debt is recovered as a part of OG&E's cost of capital.

In response to the COVID-19 pandemic, the OCC and APSC issued orders allowing OG&E to defer certain expenses related to its COVID-19 response, such as incremental expenses that were related to the suspension of or delay in disconnection of service and additional expenses associated with ensuring the continuity of electric utility service. As discussed in Note 14, the OCC approved recovery of these costs over five years in OG&E's most recent Oklahoma general rate review.

OG&E deferred to a regulatory asset the Oklahoma jurisdictional portion of costs, including non-fuel operation and maintenance expenses, depreciation, taxes other than income taxes and a return on capital, for its investment in the Frontier plant. The OCC approved recovery of these costs within base rates through the Oklahoma general rate review order received in September 2022.

OG&E recovers certain SPP costs related to base plan charges from its customers and refunds certain SPP revenues received to its customers in Oklahoma through the SPP cost tracker and in Arkansas through the transmission cost recovery rider.

Income taxes refundable to customers, net, primarily represents the reduction in accumulated deferred income taxes that resulted from the reduction in the federal income tax rate as part of the Tax Cuts and Jobs Act of 2017 as well as other state tax rate changes, partially offset by income taxes recoverable from customers primarily related to the equity component of the allowance for funds used during construction. These net liabilities will be returned to customers in varying amounts over approximately 80 years, and the assets will be amortized over the estimated remaining life of the assets to which they relate, as the temporary differences that generated the income tax benefits turn-around.

Accrued removal obligations, net represents asset retirement costs previously recovered from ratepayers for other than legal obligations.

Management continuously monitors the future recoverability of regulatory assets. When in management's judgment future recovery becomes impaired, the amount of the regulatory asset is adjusted, as appropriate. 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.

Use of Estimates

In preparing the 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 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 Registrants' financial statements. However, 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 include the determination of pension and postretirement plan assumptions, income taxes, contingency reserves, asset retirement obligations, regulatory assets and liabilities, unbilled revenues and the allowance for uncollectible accounts receivable.

Cash and Cash Equivalents

For purposes of the financial statements, the Registrants consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents. These investments are carried at cost, which approximates fair value.

Allowance for Uncollectible Accounts Receivable

Customer balances are generally written off if not collected within six months after the final billing date. The allowance for uncollectible accounts receivable for OG&E is 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. 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 balance sheets and is included in Other Operation and Maintenance Expense in the statements of income. The allowance for uncollectible accounts receivable was $1.9 million and $2.4 million at December 31, 2022 and 2021, respectively.

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

Fuel Inventories

Fuel inventories for the generation of electricity consist of coal, natural gas, oil and alternative fuel. OG&E uses the weighted-average cost method of accounting for inventory that is physically added to or withdrawn from storage or stockpiles. The amount of fuel inventory was $108.8 million and $40.6 million at December 31, 2022 and 2021, respectively.

Property, Plant and Equipment

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

The following tables present OG&E's ownership interest in the jointly-owned McClain Plant and the jointly-owned Redbud Plant, and, as disclosed below, only OG&E's ownership interest is reflected in the property, plant and equipment and accumulated depreciation balances in these tables. The owners of the remaining interests in the McClain Plant and the Redbud Plant are responsible for providing their own financing of capital expenditures. Also, only OG&E's proportionate interests of any direct expenses of the

McClain Plant and the Redbud Plant, such as fuel, maintenance expense and other operating expenses, are included in the applicable financial statement captions in the statements of income.

December 31, 2022 (In millions)	Percentage Ownership			Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)		77	%	$	261.9	$	119.4	$	142.5
Redbud Plant (A)(B)		51	%	$	542.1	$	225.2	$	316.9

(A)Construction work in progress was $0.7 million and $1.5 million for the McClain and Redbud Plants, respectively.

(B)This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $78.2 million.

December 31, 2021 (In millions)	Percentage Ownership			Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)		77	%	$	258.5	$	109.0	$	149.5
Redbud Plant (A)(B)		51	%	$	538.2	$	203.4	$	334.8

(A)Construction work in progress was $0.2 million and $0.2 million for the McClain and Redbud Plants, respectively.

(B)This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $72.8 million.

The following tables present the Registrants' major classes of property, plant and equipment and related accumulated depreciation.

December 31, 2022 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
OG&E:
Distribution assets	$	5,781.3	$	1,527.1	$	4,254.2
Electric generation assets (A)		5,188.1		1,982.7		3,205.4
Transmission assets (B)		3,180.5		667.9		2,512.6
Intangible plant		384.0		193.6		190.4
Other property and equipment		591.3		213.2		378.1
OG&E property, plant and equipment		15,125.2		4,584.5		10,540.7
Non-OG&E property, plant and equipment		6.1		—		6.1
Total OGE Energy property, plant and equipment	$	15,131.3	$	4,584.5	$	10,546.8

(A)This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $78.3 million.

(B)This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.0 million.

Depreciation and Amortization

The provision for depreciation, which was 2.7 percent and 2.6 percent of the average depreciable utility plant for 2022 and 2021, respectively, is calculated using the straight-line method over the estimated service life of the utility assets. Depreciation is provided at the unit level for production plant and at the account or sub-account level for all other plant and is based on the average life group method. In 2023, the provision for depreciation is projected to be 2.7 percent of the average depreciable utility plant.

Amortization of intangible assets is calculated using the straight-line method. Of the remaining amortizable intangible plant balance at December 31, 2022, 43.1 percent will be amortized over 6.7 years, 56.3 percent will be amortized over 13.8 years and the remaining 0.6 percent will be amortized over 22.4 years.

Amortization of plant acquisition adjustments is provided on a straight-line basis over the estimated remaining service life of the acquired assets. Plant acquisition adjustments include $148.3 million for the Redbud Plant, which is being amortized over a 27- year life, and $3.3 million for certain transmission substation facilities in OG&E's service territory, which is being amortized over a 37 to 59-year period.

Asset Retirement Obligations

OG&E has asset retirement obligations primarily associated with the removal of company-owned wind turbines on leased land, as well as the removal of asbestos from certain power generating stations. OG&E has recorded asset retirement obligations that are being accreted over their respective lives ranging from five to 68 years. Asset retirement obligations are included in Other Deferred Credits in the Registrants' balance sheets.

The following table presents changes to OG&E's asset retirement obligations during the years ended December 31, 2022 and 2021.

(In millions)	2022			2021
Balance at January 1	$	80.2		$	79.6
Accretion expense		0.6			0.6
Liabilities settled		(2.5	)		—
Balance at December 31	$	78.3		$	80.2

Accruals for environmental costs are recognized when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated. Costs are charged to expense or deferred as a regulatory asset based on expected recovery from customers in future rates, if they relate to the remediation of conditions caused by past operations or if they are not expected to mitigate or prevent contamination from future operations. Where environmental expenditures relate to facilities currently in use, such as pollution control equipment, the costs may be capitalized and depreciated over the future service periods. Estimated remediation costs are recorded at undiscounted amounts, independent of any insurance or rate recovery, based on prior experience, assessments and current technology. Accrued obligations are regularly adjusted as environmental assessments and estimates are revised and remediation efforts proceed. For sites where OG&E has been designated as one of several potentially responsible parties, the amount accrued represents OG&E's

estimated share of the cost. OG&E had $24.2 million and $25.8 million in accrued environmental liabilities at December 31, 2022 and 2021, respectively, which are included in OG&E's asset retirement obligations.

Allowance for Funds Used During Construction

Allowance for funds used during construction, a non-cash item, is reflected as an increase to Net Other Income and a reduction to Interest Expense in the statements of income and as an increase to Construction Work in Progress in the balance sheets. Allowance for funds used during construction is calculated according to the FERC requirements for the imputed cost of equity and borrowed funds. Allowance for funds used during construction rates, compounded semi-annually, were 4.8 percent, 7.4 percent and 7.3 percent for the years ended December 31, 2022, 2021 and 2020, respectively.

Collection of Sales Tax

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

Revenue Recognition

General

OG&E recognizes revenue from electric sales when power is delivered to customers. The performance obligation to deliver electricity is generally created and satisfied simultaneously, and the provisions of the regulatory-approved tariff determine the charges OG&E may bill the customer, payment due date and other pertinent rights and obligations of both parties. OG&E measures its customers' metered usage and sends bills to its customers throughout each month. As a result, there is a significant amount of customers' electricity consumption that has not been billed at the end of each month. OG&E accrues an estimate of the revenues for electric sales delivered since the latest billings. Unbilled revenue is presented in Accrued Unbilled Revenues in the balance sheets and in Revenues from Contracts with Customers in the statements of income based on estimates of usage and prices during the period. The estimates that management uses in this calculation could vary from the actual amounts to be paid by customers.

Integrated Market and Transmission

OG&E currently owns and operates transmission and generation facilities as part of a vertically integrated utility. OG&E is a member of the SPP regional transmission organization and has transferred operational authority, but not ownership, of OG&E's transmission facilities to the SPP. The SPP has implemented FERC-approved regional day-ahead and real-time markets for energy and operating services, as well as associated transmission congestion rights. Collectively, the three markets operate together under the global name, SPP Integrated Marketplace. OG&E represents owned and contracted generation assets and customer load in the SPP Integrated Marketplace for the sole benefit of its customers. OG&E has not participated in the SPP Integrated Marketplace for any speculative trading activities.

OG&E records the SPP Integrated Marketplace transactions as sales or purchases per FERC Order 668, which requires that purchases and sales be recorded on a net basis for each settlement period of the SPP Integrated Marketplace. Purchases and sales are based on the fixed transaction price determined by the market at the time of the purchase or sale and the MWh quantity purchased or sold. These results are reported as Revenues from Contracts with Customers or Fuel, Purchased Power and Direct Transmission Expense in the statements of income. OG&E's revenues, expenses, assets and liabilities may be adversely affected by changes in the organization, operating and regulation by the FERC or the SPP.

OG&E's transmission revenues are generated by the use of OG&E's transmission network by the SPP, which operates the network, on behalf of other transmission owners. OG&E recognizes revenue on the sale of transmission service to its customers over time as the service is provided in the amount OG&E has a right to invoice. Transmission service to the SPP is billed monthly based on a fixed transaction price determined by OG&E's FERC-approved formula transmission rates along with other SPP-specific charges and the megawatt quantity reserved.

Other Revenues

Other Revenues in the statements of income is comprised of certain rider revenue that includes alternative revenue measures as defined in ASC 980, "Regulated Operations," which details two types of alternative revenue programs. The first type adjusts billings for the effects of weather abnormalities or broad external factors or to compensate OG&E for demand-side management initiatives (i.e., no-growth plans and similar conservation efforts). The second type provides for additional billings (i.e., incentive awards) for the achievement of certain objectives, such as reducing costs, reaching specified milestones or demonstratively improving customer service. Once the specific events permitting billing of the additional revenues under either program type have been completed, OG&E recognizes the additional revenues if (i) the program is established by an order from OG&E's regulatory commission that allows for automatic

adjustment of future rates; (ii) the amount of additional revenues for the period is objectively determinable and is probable of recovery; and (iii) the additional revenues will be collected within 24 months following the end of the annual period in which they are recognized.

Fuel Adjustment Clauses

The actual cost of fuel used in electric generation and certain purchased power costs are generally recoverable from OG&E's customers through fuel adjustment clauses. The fuel adjustment clauses are subject to periodic review by the OCC and the APSC.

Leases

The Registrants evaluate all contracts under ASC 842 to determine if the contract is or contains a lease and to determine classification as an operating or finance lease. If a lease is identified, the Registrants recognize a right-of-use asset and a lease liability in their balance sheets. The Registrants recognize and measure a lease liability when they conclude the contract contains an identified asset that the Registrants control through having the right to obtain substantially all of the economic benefits and the right to direct the use of the identified asset. The liability is equal to the present value of lease payments, and the asset is based on the liability, subject to adjustment, such as for initial direct costs. Further, the Registrants utilize an incremental borrowing rate for purposes of measuring lease liabilities, if the discount rate is not implicit in the lease. To calculate the incremental borrowing rate, the Registrants start with a current pricing report for their senior unsecured notes, which indicates rates for periods reflective of the lease term, and adjust for the effects of collateral to arrive at the secured incremental borrowing rate. As permitted by ASC 842, the Registrants made an accounting policy election to not apply the balance sheet recognition requirements to short-term leases and to not separate lease components from non-lease components when recognizing and measuring lease liabilities. For income statement purposes, the Registrants record operating lease expense on a straight-line basis.

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 tax return of OGE Energy. 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 company property have been deferred and will be amortized to income over the life of the related property. The Registrants use the asset and liability method of accounting for income taxes. Under this method, a deferred tax asset or liability is recognized for the estimated future tax effects attributable to temporary differences between the financial statement basis and the tax basis of assets and liabilities as well as tax credit carry forwards and net operating loss carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period of the change. The Registrants recognize interest related to unrecognized tax benefits in Interest Expense and recognize penalties in Other Expense in the statements of income. Deferred tax assets are evaluated for future realization and reduced by a valuation allowance to the extent the Registrants believe they will not be realized.

Accrued Vacation

The Registrants accrue vacation pay monthly by establishing a liability for vacation earned. Vacation may be taken as earned and is charged against the liability. At the end of each year, the liability represents the amount of vacation earned but not taken.

Related Party Transactions

OGE Energy charges operating costs to OG&E based on several factors, and operating costs directly related to OG&E are assigned as such. Operating costs incurred for the benefit of OG&E are allocated either as overhead based primarily on labor costs or using the "Distrigas" method, which is a three-factor formula that uses an equal weighting of payroll, net operating revenues and gross property, plant and equipment. OGE Energy adopted this method as a result of a recommendation by the OCC Staff. OGE Energy believes this method provides a reasonable basis for allocating common expenses.

OGE Energy charged operating costs to OG&E of $135.5 million, $139.3 million and $140.6 million during the years ended December 31, 2022, 2021 and 2020, respectively. In 2022, no dividends were declared from OG&E to OGE Energy. In 2021 and 2020, OG&E declared dividends to OGE Energy of $265.0 million and $325.0 million, respectively.

Accumulated Other Comprehensive Income (Loss)

The following table presents changes in the components of accumulated other comprehensive income (loss) attributable to OGE Energy during 2022 and 2021. All amounts below are presented net of tax.

	Pension Plan and Restoration of Retirement Income Plan						Postretirement Benefit Plans
(In millions)	Net Gain (Loss)			Prior Service Cost (Credit)			Net Gain (Loss)			Prior Service Cost (Credit)			Other Comprehensive Gain (Loss) from Unconsolidated Affiliates			Total
Balance at December 31, 2020	$	(33.9	)	$	(0.2	)	$	1.7		$	1.6		$	(1.3	)	$	(32.1	)
Other comprehensive income (loss) before reclassifications		1.4			(1.1	)		(0.7	)		—			1.3			0.9
Amounts reclassified from accumulated other comprehensive income (loss)		1.6			0.1			0.1			(1.4	)		—			0.4
Settlement cost		6.0			—			—			—			—			6.0
Net current period other comprehensive income (loss)		9.0			(1.0	)		(0.6	)		(1.4	)		1.3			7.3
Balance at December 31, 2021		(24.9	)		(1.2	)		1.1			0.2			—			(24.8	)
Other comprehensive income (loss) before reclassifications		(7.6	)		—			5.5			—			—			(2.1	)
Amounts reclassified from accumulated other comprehensive income (loss)		1.4			0.2			—			(0.2	)		—			1.4
Settlement cost		13.6			—			—			—			—			13.6
Net current period other comprehensive income (loss)		7.4			0.2			5.5			(0.2	)		—			12.9
Balance at December 31, 2022	$	(17.5	)	$	(1.0	)	$	6.6		$	—		$	—		$	(11.9	)

The following table presents significant amounts reclassified out of accumulated other comprehensive income (loss) by the respective line items in net income during the years ended December 31, 2022 and 2021.

Details about Accumulated Other Comprehensive Income (Loss) Components	Amount Reclassified from Accumulated Other Comprehensive Income (Loss)						Affected Line Item in OGE Energy's Statements of Income
	Year Ended December 31,
(In millions)	2022			2021
Amortization of Pension Plan and Restoration of Retirement Income Plan items:
Actuarial losses	$	(1.6	)	$	(2.5	)	(A)
Prior service cost		(0.3	)		(0.1	)	(A)
Settlement cost		(17.9	)		(8.7	)	(A)
		(19.8	)		(11.3	)	Income Before Taxes
		(4.6	)		(3.6	)	Income Tax Expense
	$	(15.2	)	$	(7.7	)	Net Income
Amortization of postretirement benefit plans items:
Prior service credit	$	0.3		$	1.8		(A)
Actuarial losses		—			(0.1	)	(A)
		0.3			1.7		Income Before Taxes
		0.1			0.4		Income Tax Expense
	$	0.2		$	1.3		Net Income
Total reclassifications for the period, net of tax	$	(15.0	)	$	(6.4	)	Net Income

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

Investment in Unconsolidated Affiliates and Related Party Transactions (Enable)

On December 2, 2021, Energy Transfer completed its acquisition of Enable, and all of the 110,982,805 common units of Enable owned by OGE Energy were exchanged for 95,389,721 common units of Energy Transfer. As part of the transaction, Energy Transfer also acquired the general partner interests of Enable from OGE Energy and CenterPoint for cash consideration. OGE Energy accounted for its investment in Enable as an equity method investment until the merger with Energy Transfer closed on December 2, 2021. As a result of the transaction, OGE Energy recorded a pre-tax gain of $344.4 million, which contemplates the December 2, 2021 fair value of the Energy Transfer securities, the December 2, 2021 balance of OGE Energy's equity method investment in Enable, the $35.0 million cash payment received as part of the transaction ($5.0 million from Energy Transfer and $30.0 million from CenterPoint), the accumulated other comprehensive loss impact of OGE Energy's share of Enable's interest rate derivative losses and OGE Energy's transaction costs of $8.6 million. Further discussion of the transaction can be found in OGE Energy's 2021 Form 10-K.

Under the equity method, the investment was adjusted each period for contributions made, distributions received and OGE Energy's share of the investee's comprehensive income as adjusted for basis differences.

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

In this Form 10-K, Enable activity is included for the relevant portion of OGE Energy's 2021 information presented through December 2, 2021. The below information is provided for prior year context.

The following tables present summarized unaudited financial information for 100 percent of Enable as of December 2, 2021 and for the period of January 1, 2021 through December 2, 2021 and the year ended December 31, 2020.

Balance Sheet	December 2, 2021
(In millions)
Current assets	$	594
Non-current assets	$	11,227
Current liabilities	$	1,254
Non-current liabilities	$	3,281

	Period of
Income Statement	January 1, 2021 through December 2, 2021		Year Ended December 31, 2020
(In millions)
Total revenues	$	3,466	$	2,463
Cost of natural gas and NGLs (excluding depreciation and amortization)	$	1,959	$	965
Operating income	$	634	$	465
Net income	$	461	$	52

The following table presents a reconciliation of OGE Energy's equity in earnings (losses) of unconsolidated affiliates for the period of January 1, 2021 through December 2, 2021 and the year ended December 31, 2020.

	Period of
(In millions)	January 1, 2021 through December 2, 2021			Year Ended December 31, 2020
Enable net income	$	461.0		$	52.0
Differences due to timing of OGE Energy and Enable accounting close		9.0			—
Enable net income used to calculate OGE Energy's equity in earnings	$	470.0		$	52.0
OGE Energy's percent ownership at period end		25.5	%		25.5	%
OGE Energy's portion of Enable net income	$	119.8		$	13.2
Amortization of basis difference and dilution recognition (A)		50.0			98.8
Impairment of OGE Energy's equity method investment in Enable (B)		—			(780.0	)
Equity in earnings (losses) of unconsolidated affiliates (C)	$	169.8		$	(668.0	)

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

(B)During the year ended December 31, 2020, OGE Energy recorded a $780.0 million impairment on its investment in Enable as, effective March 31, 2020, OGE estimated the fair value of its investment in Enable was below the book value and concluded the decline in value was not temporary.

(C)For the year ended December 31, 2020, Enable recorded a $225.0 million impairment on an equity method investment, which ran through OGE Energy's portion of Enable net income and was offset by basis differences that flow through the amortization of basis difference and dilution recognition line item above.

Distributions received from Enable were $73.4 million and $91.7 million during the years ended December 31, 2021 and 2020, respectively.

Related Party Transactions - OGE Energy and Enable

Prior to December 2, 2021, OGE Energy charged operating costs to Enable based on several factors, and operating costs directly related to Enable were assigned as such.

Further, OGE Energy and Enable were parties to several agreements whereby OGE Energy provided specified support services to Enable, such as certain information technology, payroll and benefits administration. Under these agreements, OGE Energy charged operating costs to Enable of $0.3 million and $0.4 million for the period of January 1, 2021 through December 2, 2021 and the year ended December 31, 2020, respectively.

OGE Energy also provided retirement benefits and retiree health care benefits to employees previously seconded to Enable. OGE Energy billed Enable for reimbursement of $12.2 million and $17.3 million in 2021 and 2020, respectively, under the former seconding agreement for employment costs. As of a result of the merger between Enable and Energy Transfer, the seconding agreement was terminated, and those employees are no longer employed by OGE Energy. If lump sum payments were made to those employees previously seconded to Enable, OGE Energy would recognize a settlement or curtailment of the pension/retiree health care charges, which would increase expense at OGE Energy by $5.1 million. Settlement and curtailment charges associated with the employees previously seconded to Enable are not reimbursable to OGE Energy.

OGE Energy had accounts receivable from Enable for amounts billed for support services, including the cost of seconded employees, of $0.3 million as of December 31, 2021, which is included in Accounts Receivable in OGE Energy's balance sheets.

Related Party Transactions - OG&E and Enable

Enable provided gas transportation services to OG&E pursuant to agreements that granted Enable the responsibility of delivering natural gas to OG&E's generating facilities and performing an imbalance service. Upon the closing of the merger between Enable and Energy Transfer, these contracts were assumed by Energy Transfer. The following table presents summarized related party transactions between OG&E and Enable during the period of January 1, 2021 through December 2, 2021 and the year ended December 31, 2020.

	Period of
(In millions)	January 1, 2021 through December 2, 2021			Year Ended December 31, 2020
Operating revenues:
Electricity to power electric compression assets	$	13.3		$	15.1
Fuel, purchased power and direct transmission expense:
Natural gas transportation services	$	32.7		$	32.8
Natural gas purchases (sales)	$	(33.5	)	$	2.7

Investment in Equity Securities of Energy Transfer

For the period of December 2, 2021 through September 30, 2022, OGE Energy accounted for its investment in Energy Transfer's equity securities as an equity investment with a readily determinable fair value under ASC 321, "Investments – Equity Securities." As of the end of September 2022, OGE Energy had sold all of its 95.4 million Energy Transfer limited partner units, resulting in pre-tax net proceeds of $1,067.2 million. Prior to exiting its Energy Transfer investment, OGE Energy presented the Energy Transfer equity securities at fair value in its balance sheet. OGE Energy presents realized gains and losses of the equity securities, as well as dividend income from the investment, within the Other Income (Expense) section in its statement of income, as appropriate. During the year ended December 31, 2022, OGE Energy recognized a gain of $282.1 million related to its investment in Energy Transfer's equity securities. Due to OGE Energy's sale of all Energy Transfer limited partner units, at December 31, 2022, there is no unrecognized gain or loss related to the investment. For the period between December 2, 2021 and December 31, 2021, OGE Energy had an unrealized loss of $8.6 million related to its investment in Energy Transfer's equity securities. During the year ended December 31, 2022, OGE Energy received distributions of $34.0 million from Energy Transfer, which are presented within Other Income in OGE Energy's 2022 consolidated income statement.