0001193125-26-055414 | 10-K | XBRL Viewer

$ 17,947.9

$ 17,068.8

5,217.5

4,982.2

12,730.4

12,086.6

Public Utility, Property, Plant and Equipment [Line Items]

17,941.8

17,062.7

5,217.5

4,982.2

OG&E [Member] | Electric Generation Equipment [Member]

12,724.3

12,080.5

Public Utility, Property, Plant and Equipment [Line Items]

5,873.5

^[1]

5,518.5

^[2]

2,285.0

^[1]

2,145.9

^[2]

OG&E [Member] | Electric Transmission [Member]

3,588.5

^[1]

3,372.6

^[2]

Public Utility, Property, Plant and Equipment [Line Items]

3,524.8

^[3]

3,432.1

^[4]

781.1

^[3]

748.5

^[4]

OG&E [Member] | Finite-Lived Intangible Assets, Major Class Name [Member]

2,743.7

^[3]

2,683.6

^[4]

Public Utility, Property, Plant and Equipment [Line Items]

2.5

752.3

0.7

203.7

OG&E [Member] | Property, Plant and Equipment, Other Types [Member]

1.8

548.6

Public Utility, Property, Plant and Equipment [Line Items]

1,465.9

705.3

406.4

244.3

1,059.5

461.0

Public Utility, Property, Plant and Equipment [Line Items]

6.1

0.0

Summary of OGE Energy's Business Segments

$ 6.1

[1]	This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.
[2]	This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.
[3]	This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.
[4]	This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.

Common Equity - Common Stock Public Offering and Forward Equity Sale Agreements - Additional Information (Details) - USD ($) $ / shares in Units, $ in Millions		12 Months Ended
	Nov. 20, 2025	Dec. 31, 2025	Dec. 31, 2024
Issuance of common stock		$ 203.8	$ 17.1
Forward equity sale agreements [Member]
Number of shares issued	4,613,372
Price per share	$ 41.71
Conversion of shares		181,000
Conversion price		$ 7.9
Incremental shares		19,000
OGE Energy [Member]
Conversion of shares		4,613,372
Conversion price		$ 193.0
OGE Energy [Member] \| Forward equity sale agreements [Member]
Number of shares issued	4,613,372
IPO [Member] \| OGE Energy [Member]
Number of shares issued	8,023,256
Price per share	$ 43
Issuance of common stock	$ 345.0
Underwriters exercised an option to purchase additional shares	1,203,488
Option excercised price	$ 51.7
Underwriter [Member]
Number of shares issued	9,226,744
Underwriter [Member] \| Forward equity sale agreements [Member]
Number of shares issued	4,613,272
Issuance of common stock	$ 192.4

Report of Business Segments (Tables)

12 Months Ended

Dec. 31, 2025

Segment Reporting [Abstract]

The following tables, which include significant segment expenses, present the results of OGE Energy's business segments for the years ended December 31, 2025, 2024 and 2023.


2025	Electric Company		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	3,260.1	$	—		$	—		$	3,260.1
Fuel, purchased power and direct transmission expense		1,259.9		—			—			1,259.9
Other operation and maintenance		531.0		0.6			—			531.6
Depreciation and amortization		559.8		—			—			559.8
Taxes other than income		109.4		—			—			109.4
Operating income (loss)		800.0		(0.6	)		—			799.4
Other income		30.4		7.4			(6.4	)		31.4
Interest expense		225.5		51.2			(6.4	)		270.3
Income tax expense (benefit)		105.1		(15.3	)		—			89.8
Net income (loss)	$	499.8	$	(29.1	)	$	—		$	470.7
Total assets	$	14,277.5	$	134.1		$	(41.1	)	$	14,370.5
Capital expenditures	$	1,054.4	$	—		$	—		$	1,054.4


2024	Electric Company		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	2,985.3	$	—		$	—		$	2,985.3
Fuel, purchased power and direct transmission expense		1,076.4		—			—			1,076.4
Other operation and maintenance		514.1		0.3			—			514.4
Depreciation and amortization		539.5		—			—			539.5
Taxes other than income		109.7		—			—			109.7
Operating income (loss)		745.6		(0.3	)		—			745.3
Other income		31.9		2.4			(4.5	)		29.8
Interest expense		214.4		44.6			(4.5	)		254.5
Income tax expense (benefit)		93.2		(14.1	)		—			79.1
Net income (loss)	$	469.9	$	(28.4	)	$	—		$	441.5
Total assets	$	13,581.3	$	402.9		$	(268.2	)	$	13,716.0
Capital expenditures	$	1,090.9	$	—		$	—		$	1,090.9


2023	Electric Company		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	2,674.3	$	—		$	—		$	2,674.3
Fuel, purchased power and direct transmission expense		911.7		—			—			911.7
Other operation and maintenance		505.0		(2.4	)		—			502.6
Depreciation and amortization		506.6		—			—			506.6
Taxes other than income		99.4		3.8			—			103.2
Operating income (loss)		651.6		(1.4	)		—			650.2
Other income		43.5		8.1			(7.4	)		44.2
Interest expense		199.9		28.9			(7.4	)		221.4
Income tax expense (benefit)		68.8		(12.6	)		—			56.2
Net income (loss)	$	426.4	$	(9.6	)	$	—		$	416.8
Total assets	$	12,642.6	$	301.1		$	(153.0	)	$	12,790.7
Capital expenditures	$	1,178.2	$	—		$	—		$	1,178.2

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 470.7	$ 441.5	$ 416.8
Adjustments to reconcile net income to net cash provided from operating activities:
Depreciation and amortization	559.8	539.5	506.6
Deferred income taxes and other tax credits, net	59.5	15.6	11.6
Allowance for equity funds used during construction	(26.0)	(25.5)	(19.4)
Stock-based compensation expense	14.0	11.7	13.1
Regulatory assets	(66.9)	(52.4)	(92.1)
Regulatory liabilities	0.5	(2.8)	(12.2)
Other assets	(32.5)	(16.8)	0.0
Other liabilities	39.4	30.6	5.0
Other	(8.7)	0.0	0.0
Change in certain current assets and liabilities:
Accounts receivable and accrued unbilled revenues, net	(108.8)	(33.6)	42.8
Income taxes receivable	(37.3)	18.2	2.5
Fuel, materials and supplies inventories	81.9	25.7	(122.8)
Fuel recoveries	130.5	(123.9)	535.4
Other current assets	17.1	(30.1)	44.6
Accounts payable	34.9	(14.7)	(136.3)
Other current liabilities	9.0	29.8	36.7
Net cash provided from operating activities	1,137.1	812.8	1,232.3
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(1,054.4)	(1,090.9)	(1,178.2)
Cost of removal and other	(72.2)	(70.3)	(93.9)
Net cash used in investing activities	(1,126.6)	(1,161.2)	(1,272.1)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	344.4	706.3	788.3
Payment of long-term debt	(32.6)	(0.1)	(1,000.1)
(Decrease) increase in short-term debt	(177.3)	(29.9)	499.2
Dividends paid on common stock	(341.9)	(338.5)	(333.2)
Proceeds (costs) from issuance of common stock	203.8	17.1	0.0
Cash paid for employee equity-based compensation	(7.3)	(6.1)	(2.3)
Net cash (used in) provided from financing activities	(10.9)	348.8	(48.1)
NET CHANGE IN CASH AND CASH EQUIVALENTS	(0.4)	0.4	(87.9)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	0.6	0.2	88.1
CASH AND CASH EQUIVALENTS AT END OF YEAR	0.2	0.6	0.2
SUPPLEMENTAL CASH FLOW INFORMATION
Interest (net of interest capitalized)	268.7	251.1	202.4
Federal income taxes (net of income tax refunds)	73.9	44.0	44.0
State income taxes (net of income tax refunds)	1.2	(7.1)	(2.5)
NON-CASH INVESTING AND FINANCING ACTIVITIES
Power plant long-term service agreement	3.4	6.4	0.7
Tinker Air Force Base distribution assets purchase	0.0	2.6	0.0
OG&E [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	499.8	469.9	426.4
Adjustments to reconcile net income to net cash provided from operating activities:
Depreciation and amortization	559.8	539.5	506.6
Deferred income taxes and other tax credits, net	61.7	16.8	15.4
Allowance for equity funds used during construction	(26.0)	(25.5)	(19.4)
Stock-based compensation expense	14.0	11.7	3.1
Regulatory assets	(66.9)	(52.4)	(92.1)
Regulatory liabilities	0.5	(2.8)	(12.2)
Other assets	(37.9)	(9.8)	4.7
Other liabilities	36.8	28.0	0.3
Change in certain current assets and liabilities:
Accounts receivable and accrued unbilled revenues, net	(108.7)	(33.2)	42.1
Fuel, materials and supplies inventories	81.9	25.7	(122.8)
Fuel recoveries	130.5	(123.9)	535.4
Other current assets	11.7	(36.5)	51.1
Accounts payable	66.4	(0.3)	(131.1)
Income taxes payable - parent	(47.6)	23.8	9.4
Other current liabilities	15.2	30.8	34.6
Net cash provided from operating activities	1,191.2	861.8	1,251.5
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (less allowance for equity funds used during construction)	(1,054.4)	(1,090.9)	(1,178.2)
Cost of removal	(70.3)	(67.5)	(91.0)
Net cash used in investing activities	(1,124.7)	(1,158.4)	(1,269.2)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	344.4	350.5	788.8
Payment of long-term debt	(32.6)	(0.1)	(500.1)
Changes In advances with parent	(148.3)	(53.8)	229.2
Capital contribution from OGE Energy	150.0	0.0	0.0
Dividends paid on common stock	(380.0)	0.0	(500.0)
Net cash (used in) provided from financing activities	(66.5)	296.6	17.9
NET CHANGE IN CASH AND CASH EQUIVALENTS	0.0	0.0	0.2
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	0.2	0.2	0.0
CASH AND CASH EQUIVALENTS AT END OF YEAR	0.2	0.2	0.2
SUPPLEMENTAL CASH FLOW INFORMATION
Interest (net of interest capitalized)	216.9	206.3	180.7
Federal income taxes (net of income tax refunds)	90.7	51.9	43.5
State income taxes (net of income tax refunds)	1.2	0.1	0.7
NON-CASH INVESTING AND FINANCING ACTIVITIES
Power plant long-term service agreement	3.4	6.4	0.7
Tinker Air Force Base distribution assets purchase	$ 0.0	$ 2.6	$ 0.0

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 1.6925	$ 1.6789	$ 1.6646

Summary of Significant Accounting Policies - Schedule of Jointly Owned Utility Plants (Details) - USD ($)
$ in Millions

Dec. 31, 2025

Dec. 31, 2024

$ 17,947.9

$ 17,068.8

5,217.5

4,982.2

$ 12,730.4

$ 12,086.6

McClain Plant [Member]

Jointly Owned Utility Plant, Proportionate Ownership Share

77.00%

^[1]

77.00%

^[2]

$ 254.6

^[1]

$ 244.4

^[2]

81.6

^[1]

75.8

^[2]

$ 173.0

^[1]

$ 168.6

^[2]

Redbud Plant [Member]

Jointly Owned Utility Plant, Proportionate Ownership Share

51.00%

^[1],[3]

51.00%

^[2],[4]

$ 582.1

^[1],[3]

$ 556.7

^[2],[4]

261.1

^[1],[3]

247.7

^[2],[4]

321.0

^[1],[3]

309.0

^[2],[4]

6.1

0.0

6.1

17,941.8

17,062.7

5,217.5

4,982.2

OG&E [Member] | Electric Transmission and Distribution [Member]

12,724.3

12,080.5

7,075.1

6,654.5

1,744.3

1,639.8

OG&E [Member] | Electric Generation Equipment [Member]

5,330.8

5,014.7

5,873.5

^[5]

5,518.5

^[6]

2,285.0

^[5]

2,145.9

^[6]

OG&E [Member] | Electric Transmission [Member]

3,588.5

^[5]

3,372.6

^[6]

3,524.8

^[7]

3,432.1

^[8]

781.1

^[7]

748.5

^[8]

OG&E [Member] | Finite-Lived Intangible Assets, Major Class Name [Member]

2,743.7

^[7]

2,683.6

^[8]

2.5

752.3

0.7

203.7

OG&E [Member] | Property, Plant and Equipment, Other Types [Member]

1.8

548.6

1,465.9

705.3

406.4

244.3

$ 1,059.5

$ 461.0

[1]	Construction work in progress was $0.1 million and $25.8 million for the McClain and Redbud Plants, respectively.
[2]	Construction work in progress was $0.8 million and $5.1 million for the McClain and Redbud Plants, respectively.
[3]	This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.
[4]	This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.
[5]	This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.
[6]	This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.
[7]	This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.
[8]	This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.

Long-Term Debt (Additional Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Apr. 01, 2025
Debt Instrument [Line Items]
Percent of Principal Amount Subject to Optional Tender	100.00%
Long term debt repaid	$ 32.6	$ 0.1	$ 1,000.1
Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Oct. 01, 2039
Muskogee Industrial Authority, Janaury 1, 2025 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Jan. 01, 2025
OGE Energy [Member]
Debt Instrument [Line Items]
Long-Term Debt, Maturity, Year Two	$ 241.0
Long-term Debt, Maturities, Repayments of Principal in Year Three	500.0
Long-Term Debt, Maturity, Year Four	350.0
Long-term Debt, Maturities, Repayments of Principal in Year Five	$ 600.0
OGE Energy [Member] \| Senior Notes due April 1, 2055 [Member]
Debt Instrument [Line Items]
Long term debt				$ 350.0
OGE Energy [Member] \| Senior Notes due April 1, 2055 [Member] \| Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				5.80%
Debt instrument, maturity date	Apr. 01, 2055
OGE Energy [Member] \| Muskogee Industrial Authority, Janaury 1, 2025 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Jan. 01, 2025
Long term debt repaid	$ 32.4
OG&E [Member]
Debt Instrument [Line Items]
Long-Term Debt, Maturity, Year Two	181.0
Long-term Debt, Maturities, Repayments of Principal in Year Three	500.0
Long-term Debt, Maturities, Repayments of Principal in Year Five	600.0
Long term debt repaid	$ 32.6	$ 0.1	$ 500.1
OG&E [Member] \| Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Oct. 01, 2039
OG&E [Member] \| Muskogee Industrial Authority, Janaury 1, 2025 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Jan. 01, 2025

Retirement Plans and Postretirement Benefit Plans - Summary of Reconciliation of Postretirement Benefit Plans Investments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2025 USD ($)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Level 3 Asset Value, Beginning of Period	$ 13.6
Claims paid	(5.4)
Interest income	0.3
Realized gains	0.1
Investment fees	(0.1)
Net unrealized gains related to instruments held at the reporting date	0.2
Level 3 Asset Value, End of Period	$ 8.7

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Pension Plans [Member]
Pension Plan and Restoration of Retirement Income Plan:
Amortization of prior service cost, net of tax of $0.1, $0.1 and $0.1, respectively	$ 0.1	$ 0.1	$ 0.1
Amortization of deferred net loss, net of tax of $0.1, $0.1 and $0.2, respectively	0.1	0.1	0.2
Net (loss) gain arising during the period, net of tax of $(0.5), $0.0 and $0.0, respectively	(0.5)	0.0	1.0
Regulatory classification of certain pension costs, net of tax of $0.0, $1.2 and $0.0, respectively	0.0	1.2	0.0
Settlement cost, net of tax of $0.0, $0.0 and $0.4, respectively	0.0	0.0	0.4
Other Postretirement Benefits Plan [Member]
Postretirement plans:
Amortization of deferred net gain, net of tax of $(0.1), ($0.1) and $(0.1), respectively	(0.1)	(0.1)	(0.1)
Net gain (loss) arising during the period, net of tax of $0.4, $0.2 and $(0.2), respectively	$ 0.4	$ 0.2	$ (0.2)

Income Taxes

12 Months Ended

Dec. 31, 2025

Income Taxes [Abstract]

Income Taxes

7. Income Taxes

Income Tax Expense

The following table presents the components of income tax expense.


	OGE Energy							OG&E
Year Ended December 31 (In millions)	2025		2024		2023			2025		2024		2023
Provision for current income taxes:
Federal	$	29.3	$	62.0	$	46.1		$	39.9	$	72.7	$	48.9
State		0.3		0.8		(2.2	)		2.7		3.0		3.7
Total provision for current income taxes		29.6		62.8		43.9			42.6		75.7		52.6
Provision for deferred income taxes, net:
Federal		49.7		8.0		18.1			51.9		9.0		18.8
State		10.5		8.3		(5.8	)		10.6		8.5		(2.6	)
Total provision for deferred income taxes, net		60.2		16.3		12.3			62.5		17.5		16.2
Total income tax expense	$	89.8	$	79.1	$	56.2		$	105.1	$	93.2	$	68.8

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 2022. 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. Oklahoma investment tax credits are also earned on investments at electric generating facilities which further reduce OG&E's effective tax rate.

The following tables present a reconciliation of the statutory tax rates to the effective income tax rate.


OGE Energy
Year Ended December 31 (Dollars in millions)	2025					2024					2023
Statutory federal tax rate	$	117.7		21.0	%	$	109.3		21.0	%	$	99.3		21.0	%
State income taxes, net of federal income tax benefit (A)		8.5		1.5			7.3		1.4			(12.6	)	(2.7	)
Amortization of net unfunded deferred taxes		(32.3	)	(5.7	)		(32.6	)	(6.3	)		(33.2	)	(7.0	)
Federal tax credits		(2.6	)	(0.5	)		(2.6	)	(0.5	)		(3.6	)	(0.8	)
Uncertain tax position		—		—			—		—			6.2		1.3
Nontaxable or nondeductible items		(1.5	)	(0.3	)		(2.3	)	(0.4	)		0.1		0.1
Effective income tax rate	$	89.8		16.0	%	$	79.1		15.2	%	$	56.2		11.9	%


OG&E
Year Ended December 31 (Dollars in millions)	2025					2024					2023
Statutory federal tax rate	$	127.0		21.0	%	$	118.3		21.0	%	$	104.0		21.0	%
State income taxes, net of federal income tax benefit (A)		10.5		1.8			9.1		1.6			0.8		0.2
Amortization of net unfunded deferred taxes		(32.3	)	(5.3	)		(32.6	)	(5.8	)		(33.2	)	(6.7	)
Federal tax credits		(2.6	)	(0.5	)		(2.6	)	(0.4	)		(3.6	)	(0.8	)
Nontaxable or nondeductible items		2.5		0.4			1.0		0.2			0.8		0.2
Effective income tax rate	$	105.1		17.4	%	$	93.2		16.6	%	$	68.8		13.9	%

(A)

In 2025, state taxes in Oklahoma made up the majority (greater than 50 percent) of the tax effect in this category.

The deferred tax provisions are recognized as costs in the ratemaking process by the commissions having jurisdiction over the rates charged by OG&E. The following table presents the components of Deferred Income Taxes at December 31, 2025 and 2024.


	OGE Energy						OG&E
December 31 (In millions)	2025			2024			2025			2024
Deferred income tax liabilities, net:
Accelerated depreciation and other property related differences	$	1,907.6		$	1,809.5		$	1,907.6		$	1,809.5
Regulatory assets		66.6			65.6			66.6			65.6
Pension Plan		21.5			22.0			38.5			38.6
Corporate owned life insurance		3.1			2.8			—			—
Bond redemption-unamortized costs		1.0			1.2			1.0			1.2
State tax credits		(223.6	)		(223.8	)		(208.6	)		(208.5	)
Income taxes recoverable from customers, net		(173.6	)		(188.6	)		(173.6	)		(188.6	)
Regulatory liabilities		(59.8	)		(57.3	)		(59.8	)		(57.3	)
Asset retirement obligations		(18.8	)		(20.9	)		(18.8	)		(20.9	)
Postretirement medical and life insurance benefits		(21.5	)		(19.1	)		(15.1	)		(12.6	)
Accrued liabilities		(9.0	)		(15.7	)		(2.7	)		(9.8	)
Deferred federal investment tax credits		(2.4	)		(2.5	)		(2.4	)		(2.5	)
Accrued vacation		(1.7	)		(1.9	)		(1.7	)		(1.9	)
Uncollectible accounts		(1.0	)		(0.5	)		(1.0	)		(0.5	)
Other		0.9			0.3			1.3			(1.6	)
Total deferred income tax liabilities, net	$	1,489.3		$	1,371.1		$	1,531.3		$	1,410.7

As of December 31, 2025, the Registrants have classified $14.7 million of unrecognized tax benefits as a reduction of deferred tax assets recorded. Management is currently unaware of any issues under review that could result in significant additional payments, accruals or other material deviation from this amount.

The following table presents a reconciliation of the Registrants' total gross unrecognized tax benefits as of the years ended December 31, 2025, 2024 and 2023.


(In millions)	2025		2024		2023
Balance at January 1	$	28.6	$	28.6	$	20.7
Tax positions related to current year:
Additions		—		—		7.9
Balance at December 31	$	28.6	$	28.6	$	28.6

The Registrants recognize tax benefits from an uncertain tax position only if it is more likely than not the tax position will be sustained on examination by taxing authorities based on the technical merits of the position. The tax benefits in the financial statements from such positions are then measured based on the largest benefit that has a greater than 50 percent likelihood of being realized on settlement. In 2023, the Registrants recorded a $7.9 million reserve related to a state tax position taken associated with the sale of Energy Transfer units.

Where applicable, the Registrants classify income tax-related interest and penalties as interest expense and other expense, respectively. With regard to uncertain tax positions, there were $0.6 million in income tax-related interest and no penalties recorded during both of the years ended December 31, 2025 and 2024 and no interest or penalties recorded during the year ended December 31, 2023.

At each of December 31, 2025, 2024 and 2023, there were $22.6 million of unrecognized tax benefits that, if recognized, would affect the annual effective tax rate.

The following table presents a summary of the Registrants' tax credits carried forward as deferred tax assets. Under current law, the Registrants expect future taxable income will be sufficient to utilize all credits before they expire.


	OGE Energy				OG&E
(In millions)	Carry Forward Amount		Deferred Tax Asset		Carry Forward Amount		Deferred Tax Asset		Earliest Expiration Date
State tax credits:
Oklahoma investment tax credits	$	268.5	$	210.8	$	249.6	$	195.8	N/A
Oklahoma capital investment board credits	$	12.8	$	12.8	$	12.8	$	12.8	N/A

N/A - not applicable

The entire disclosure for income tax.

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Long-Term Debt, Unclassified [Abstract]

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Accounts Receivable, Allowance for Credit Loss	$ 4.1	$ 2.0
OG&E [Member]
Accounts Receivable, Allowance for Credit Loss	$ 4.1	$ 2.0

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Interest costs capitalized	$ 15.8	$ 14.6	$ 7.1
OG&E [Member]
Interest costs capitalized	$ 15.8	$ 14.6	$ 7.1

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2025

Schedule of Long-term Debt Instruments

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


Series			Date Due	Amount
				(In millions)
1.65%	—	4.60%	Muskogee Industrial Authority, June 1, 2027	$	56.0
1.80%	—	4.60%	Garfield Industrial Authority, October 1, 2039		47.0
Total (redeemable during next 12 months)				$	103.0

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

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Fair Value Measurements - Summary of Financial Instrument Measured at Fair Value On A Recurring Basis and Carrying Amount and Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	$ 5,369.2	$ 5,053.3
OGE Energy Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	347.6	346.9
Long-Term Debt, Fair Value	362.5	355.7
OGE Energy Term Loan [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	59.9	59.7
Long-Term Debt, Fair Value	60.0	60.0
OG&E Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	4,847.2	4,499.6
Long-Term Debt, Fair Value	4,644.7	4,174.9
OG&E Industrial Authority Bonds [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	103.0	135.4
Long-Term Debt, Fair Value	103.0	135.4
OG&E Tinker Debt [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	11.5	11.7
Long-Term Debt, Fair Value	$ 9.1	$ 9.0

Amount, after deduction of unamortized premium (discount) and debt issuance cost, of long-term debt. Excludes lease obligation.

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Rate Matters and Regulation

Rate Matters and Regulation

12 Months Ended

Dec. 31, 2025

Regulated Operations [Abstract]

14. Rate Matters and Regulation

Regulation and Rates

OG&E's retail electric tariffs are regulated by the OCC in Oklahoma and by the APSC in Arkansas. The issuance of certain securities by OG&E is also regulated by the OCC and the APSC. OG&E's transmission activities, short-term borrowing authorization and accounting practices are subject to the jurisdiction of the FERC. The Secretary of the U.S. Department of Energy has jurisdiction over some of OG&E's facilities and operations. In 2025, 88 percent of OG&E's electric revenue was subject to the jurisdiction of the OCC, seven percent to the APSC and five percent to the FERC.

The OCC and the APSC require that, among other things, (i) OGE Energy permits the OCC and the APSC access to the books and records of OGE Energy and its affiliates relating to transactions with OG&E; (ii) OGE Energy employ accounting and other procedures and controls to protect against subsidization of non-utility activities by OG&E's customers; and (iii) OGE Energy refrain from pledging OG&E assets or income for affiliate transactions. In addition, the FERC has access to the books and records of OGE Energy and its affiliates as the FERC deems relevant to costs incurred by OG&E or necessary or appropriate for the protection of utility customers with respect to the FERC jurisdictional rates.

Completed Regulatory Matters

Integrated Resource Plans

In 2025, OG&E issued its 2025 IRP to the OCC and APSC. The 2025 IRP was intended to address updated planning assumptions from OG&E’s 2024 IRP and present OG&E’s current capacity needs in light of the SPP’s planning reserve margin requirements for both summer and winter seasons as well as the SPP’s revised resource accreditation methodologies and updated load projections. The 2025 IRP identified capacity needs of 1,647 MWs by 2030. OG&E has executed contracts for over 1,000 MWs of generation capacity as a result of the 2024 request for proposal process, and regulatory approvals are currently being pursued, as further discussed below. OG&E has determined that an event of default occurred under the terms of the Black Kettle Energy Storage capacity purchase agreement and, as a result, the agreement has been terminated, effective February 3, 2026. OG&E intends to pursue all remedies available under the agreement and applicable law. Further, in January 2026, OG&E issued additional requests for proposals for resources to meet projected capacity needs while maintaining affordability and reliability for OG&E's customers. In February 2026, OG&E issued its Draft 2026 IRP to the OCC and APSC, which is intended to address OG&E's updated load forecast as well as updated SPP Resource Adequacy policies. The Draft 2026 IRP identifies capacity needs of 1,922 MWs by the 2031/2032 winter season and which is inclusive of approximately 800 MWs of capacity needs driven by changes in the SPP Resource Adequacy policies. The 2026 IRP is expected to be finalized in April 2026. OG&E intends to evaluate incremental capacity needs through future IRPs and to satisfy the needs through request for proposal processes, as needed.

SPP Proceedings

Resource Capacity Accreditation

In July 2022, the SPP Board of Directors approved a new unit accreditation methodology for conventional generation which requires submittal to and approval from the FERC prior to becoming effective. On March 2, 2023, the FERC rejected the SPP’s proposed capacity accreditation methodology for wind and solar generators. Following the FERC’s rejection, the SPP began an extensive review of both the methodology proposed for thermal resources which had not yet been submitted to the FERC, and the accreditation methodology for wind and solar generators. These methodologies were reviewed and approved by both the Regional State Committee and the SPP Board of Directors in late October 2023 and were submitted to the FERC for approval on February 23, 2024. On January 16, 2025, the FERC accepted the SPP's proposed tariff revisions for each accreditation methodology, which became effective October 1, 2025. This change has been implemented for the 2026 summer season. OG&E is evaluating the impact of the FERC's acceptance of these accreditation methods, which may contribute to OG&E’s capacity needs.

FERC Proceedings

Muskogee to Fort Smith Transmission Project

On May 15, 2025, OG&E filed an application with the FERC requesting CWIP incentive and abandoned plant incentive for a high voltage transmission line project running from OG&E's Muskogee substation in Oklahoma to its Fort Smith substation in Arkansas at a cost of approximately $250 million. On July 15, 2025, the FERC issued an order approving OG&E's request. On August 12, 2025, OG&E accepted the notice to construct from the SPP for a total of 106 miles of new, upgraded, and rebuilt high voltage transmission lines. OG&E has commenced design work on this project and expects the project to go into service in stages beginning in 2027 and be fully in service by 2029. OG&E would be allowed to seek recovery of prudently incurred costs through its formula rates should this project be abandoned for circumstances outside of OG&E's control.

OCC Proceedings

2023 Oklahoma General Rate Review

In December 2023, OG&E filed a general rate review in Oklahoma, and on June 12, 2024, OG&E entered into an uncontested settlement agreement, which was also executed by the OCC Public Utility Division Staff, the Oklahoma Attorney General, the OG&E Shareholders Association, Oklahoma Industrial Energy Consumers and other intervenors. This settlement agreement resulted in an annual revenue requirement increase of $126.7 million. OG&E had the right to implement interim rates subject to refund beginning July 1, 2024 (180 days after the filing of its application on December 29, 2023). On July 1, 2024, OG&E implemented an annual interim rate increase in line with the settlement agreement, subject to refund based on final approval by the OCC.

On November 26, 2024, the OCC issued an interim order approving the settlement agreement; as such, no refund of interim rates was deemed necessary. The key terms of the interim order were discussed in the 2024 Form 10-K. On March 27, 2025, the OCC issued a final order in this matter, which affirmed its previous order approving the settlement agreement and approved the ALJ report on the remaining one MW issue with one exception. The one exception stated that in its next general rate review, OG&E shall directly assign the costs of transmission radials to new competitive load customers that are added to the system after November 1, 2023. No other changes were made to rates implemented effective July 1, 2024 after the November 26, 2024 interim order. While the OCC’s final order has been appealed, the rates will remain in effect.

2023 Oklahoma Fuel Prudency

On June 10, 2024, the Public Utility Division Staff filed their application initiating the prudence review of the 2023 fuel adjustment clause. The OCC issued an order on April 22, 2025 finding that OG&E's 2023 fuel costs and generation operations were prudent.

2024 Oklahoma Fuel Prudency

On April 1, 2025, the Public Utility Division Staff filed their application initiating the prudence review of the 2024 fuel adjustment clause. On December 4, 2025, the OCC issued a final order finding OG&E's 2024 fuel costs, procurement decisions and operations were prudent.

Oklahoma Retail Electric Supplier Certified Territory Act Causes

As previously disclosed, several rural electric cooperative electricity suppliers filed complaints with the OCC alleging that OG&E, because it was providing service to large loads in another supplier's territory, had violated the Oklahoma Retail Electric Supplier Certified Territory Act. OG&E believes it is lawfully serving customers under specific exemptions under this act that allow it to serve customers having a load of one MW or greater. There were five complaint cases initiated at the OCC, and the OCC issued decisions on each of them. The OCC ruled in favor of the electric cooperatives in three of those cases under statutory interpretation and ruled in favor of OG&E in two of those cases based on the defense of "laches," effectively determining that the plaintiff did not raise their claims in a timely manner. All five of those cases were appealed to the Oklahoma Supreme Court, with two additional appeals consolidated with two of the original appeals, so that there were five cases in total.

On April 4, 2023, the Oklahoma Supreme Court issued its opinion which vacated the OCC's injunctions in one of the five cases and held that the Oklahoma Retail Electric Supplier Certified Territory Act does not limit the mechanism by which OG&E may provide service to large loads in another supplier's territory pursuant to the one MW exception.

On March 4, 2025, the Oklahoma Supreme Court issued a decision in a second case, finding that OG&E may not “extend service” from third-party transmission facilities and also effectively reversed its decision in the prior case addressing the same claims. This ruling was prospective in nature, which means OG&E may still serve the customers subject to the ruling, but in the future, OG&E may not extend services off of third-party transmission facilities. On September 23, 2025, this decision was reaffirmed in another case by the Oklahoma Supreme Court. OG&E can continue serving existing customers that would have otherwise been impacted by this decision.

On June 17, 2025, the Oklahoma Supreme Court ruled in favor of OG&E’s appeal in another of the cases, resolving the statutory interpretation of how a supplier calculates “connected load for initial full operation" for purposes of the exemption under the act. This will allow OG&E to continue serving one MW customers outside its certified service territory based on the ‘nameplate rating,’ of all devices connected to a distribution system.

On October 28, 2025, the Oklahoma Supreme Court affirmed the OCC’s final order in the last remaining appeal regarding the Retail Electric Supplier Certified Territory Act. The Oklahoma Supreme Court held that, consistent with prior rulings, prospectively OG&E shall not be permitted to extend its service from third-party transmission lines but shall not be enjoined from serving existing customers.

2025 Oklahoma Preapproval Case

On May 19, 2025, OG&E filed a preapproval case seeking OCC approval of three projects that will add capacity to the OG&E portfolio: (i) the Black Kettle Battery Storage capacity purchase agreement; (ii) the Kiamichi natural gas capacity purchase agreement; and (iii) construction of two additional combustion turbines at the Horseshoe Lake generating facility (Units 13 and 14). OG&E sought recovery through a rider, CWIP recovery for the Horseshoe Lake combustion turbines and a return on the Black Kettle Battery Storage and Kiamichi capacity purchase agreements. On October 6, 2025, OG&E reached a non-unanimous settlement agreement with OCC Public Utility Division Staff, the Oklahoma Attorney General and the Petroleum Alliance of Oklahoma. On November 13, 2025, the OCC issued a final order rejecting the settlement but approving the three projects with no CWIP recovery. The final order allows OG&E to recover the costs of the capacity purchase agreements with no return through the fuel clause adjustment rider and recover the revenue requirement for the Horseshoe Lake combustion turbines through a rider once the turbines are placed into service.

Pending Regulatory Matters

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

SPP Proceedings

Demand Response Accreditation

The SPP has been evaluating demand response accreditation for several years, and a proposal has evolved that would treat demand resource accreditation on a performance-based approach. This approach requires demand response resources to be market registered and dispatched based on SPP market protocols or be reliability registered and dispatched during conservative operations or energy emergency alerts within the SPP. Alternatively, demand response programs that are built into a LRE’s forecast, known as load modifiers, can be used to reduce the load and resources needed to satisfy the entity’s planning reserve margin but would include an after-the-fact look at whether the LRE’s peak forecast was below the actuals in a given year. If under forecasted, a LRE would have to pay a deficiency payment for not providing enough resources to satisfy its planning reserve margin and actual peak load. At their February 2026 meetings, both the SPP Regional State Committee and the SPP Board of Directors adopted policies to include the 2027 implementation of a LRE’s load modifier cap and full implementation in 2028. These policies are subject to FERC review and approval prior to implementation.

Seminole to Shreveport Transmission Line

At the end of 2025, the SPP Board of Directors adopted their 2025 Integrated Transmission Plan. This plan included a new 765kV transmission line running from Konawa, Oklahoma to Shreveport, Louisiana. OG&E will construct and own a significant portion of the line. The project is pending OG&E's receipt and acceptance of a notice to construct, which is expected later this year.

APSC Proceedings

Arkansas Prudence of Horseshoe Lake and Tinker Generation Facilities

On December 30, 2024, pursuant to orders in the generation construction notice filings, OG&E filed an application requesting a determination of prudence of action and initial contract costs for the generating units being constructed at Horseshoe Lake (Units 11 and 12) and Tinker Air Force Base. On May 19, 2025, intervenors, including the Attorney General, filed direct testimony and APSC staff recommended a finding of prudence of action and initial contract costs for both projects. The Attorney General recommended approval of the Horseshoe Lake project but raised concerns regarding certain elements of the Tinker Air Force Base project. On May 22, 2025, OG&E filed a supplemental application to serve as notice to the APSC of OG&E’s intent to recover the costs of these projects through a rider under the newly enacted Act 373. On June 16, 2025, OG&E filed rebuttal testimony to address concerns raised by the Attorney General in direct testimony. OG&E entered into a settlement agreement with APSC Staff on August 4, 2025 that agreed that the Horseshoe Lake and Tinker combustion turbines were prudent and that OG&E satisfied part of the eligibility criteria for recovery of these costs through a Strategic Investment Rider. The Arkansas Attorney General opposes the part of the settlement relating to eligibility for a Strategic Investment Rider. On August 29, 2025, the APSC issued an order seeking additional testimony that responds to several questions related to the eligibility of the Strategic Investment Rider for out of state projects. On September 12, 2025, OG&E and APSC Staff filed responsive supplemental testimony. OG&E is awaiting a final order from the APSC.

2025 Arkansas Preapproval Case

On July 25, 2025, OG&E filed an application requesting several approvals from the APSC relating to three capacity projects arising from the 2024 request for proposals for generating capacity: (i) the Black Kettle Battery Storage capacity purchase agreement; (ii) the Kiamichi natural gas capacity purchase agreement; and (iii) construction of two additional combustion turbines at the Horseshoe Lake generating facility (Units 13 and 14). OG&E sought authority to begin construction of the Horseshoe Lake units, a prudency determination of those new Horseshoe Lake units, authorization to enter into the Black Kettle Battery Storage capacity purchase agreement and other findings needed under Arkansas law, including eligibility to recover costs of the new Horseshoe Lake units through a rider under the newly enacted Act 373. On November 25, 2025, OG&E and the APSC staff filed a settlement agreement

approving OG&E’s application with some additional reporting requirements and allowing an additional return on the Black Kettle Battery Storage capacity purchase agreement at the 20-year U.S. treasury rate. On December 1, 2025, the Attorney General filed testimony in opposition to the settlement. On January 23, 2026, the APSC issued an order denying the settlement agreement and denying preapproval of Horseshoe Lake Units 13 and 14 but approving the Black Kettle Battery Storage capacity purchase agreement. The APSC also found that OG&E did not need to seek approval of the Kiamichi natural gas capacity purchase agreement since the term is shorter than five years. In the order, the APSC stated OG&E could still seek a prudence determination and cost recovery of Horseshoe Lake Units 13 and 14 after they are placed into service. On February 13, 2026, OG&E filed additional evidence pursuant to Arkansas law and requested that the APSC consider the additional evidence in finding that Horseshoe Lake Units 13 and 14 are reasonable, necessary and in the public interest.

2025 Arkansas Act 373 Tariff Filing

On December 29, 2025, OG&E filed an application for approval of an Act 373 tariff to recover return on CWIP and revenue requirement for Horseshoe Lake and Tinker generation facilities. Recovery under the Act 373 tariff is dependent on a finding of eligibility for the Horseshoe Lake Units 11 and 12 and Tinker generation facilities in the prudence case disclosed above. On January 30, 2026, the APSC Staff filed testimony suggesting minor changes to the proposed tariff, and on February 9, 2026, OG&E filed rebuttal testimony largely agreeing to APSC Staff’s suggested revisions. On February 17, 2026, OG&E and the APSC Staff entered into a settlement agreement that agreed to recommended changes to the proposed tariff.

Arkansas Frontier Energy Storage Project Preapproval Filing

On February 3, 2026, OG&E filed a preapproval case for the Frontier Energy Storage Project, which involves a purchase and sale agreement for a 300 MW battery storage facility in Oklahoma. The Frontier Energy Storage Project is the final project resulting from OG&E's 2024 request for proposals and subsequent negotiations. In this proceeding, OG&E seeks authorization to commence construction of the Frontier Energy Storage Project and to later acquire the facility pursuant to the purchase and sale agreement, a prudency determination for the project, and all other findings and approvals needed under Arkansas law.

FERC Proceedings

Order for Sponsored Transmission Upgrades within SPP

Under Attachment Z2 of the SPP Open Access Transmission Tariff, costs of participant-funded, or "sponsored," transmission upgrades may be recovered from other SPP customers who benefit from the upgrade. The FERC approved a waiver of a time limitation in the SPP tariff to allow the SPP in 2016 to bill for the 2008 through 2015 period due to information system limitations that had delayed that billing. The SPP then both billed users and credited sponsors, including OG&E, for Z2 charges during the period. OG&E refunded most of the net credits to customers through its various rate riders that include SPP activity, with the remaining amounts retained by OG&E.

Net payers of Z2 credits contested the waiver, leading the FERC to reverse its decision, deny the waiver, and instruct the SPP to refund payments made for charges from 2008 to 2015. OG&E and other net creditors challenged this reversal. However, the FERC upheld its reversal, and in August 2021 and September 2024, the U.S. Court of Appeals upheld the FERC’s decision and denied relief to OG&E and the other creditors against SPP. All appellate options have now been exhausted.

The SPP has submitted a refund process to the FERC stating some issues need the FERC's clarification before refunds can proceed. OG&E and other parties have commented on the filings, and the matter remains pending before the FERC. The SPP has submitted a refund process to the FERC stating some issues need the FERC's clarification before refunds can proceed. OG&E and other parties have commented on the filings, and the matter remains pending before the FERC. The SPP has calculated that OG&E will need to refund approximately $14 million, net of amounts paid to other utilities for upgrades, plus interest. This would shift recovery of these upgrade credits to future periods. Of the $14 million, the Registrants would be impacted by $4 million in expense that initially benefited the Registrants in 2016, and OG&E customers would incur a net impact of $10 million in expense through rider mechanisms or the FERC formula rate. As of December 31, 2025, the Registrants have reserved $14 million plus estimated interest for a potential refund.

Subsequent to the initiation of the disputes discussed above, the FERC approved 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. This elimination of the Attachment Z2 revenue crediting would only impact OG&E and its recovery of any future upgrade

costs that it may incur as a project sponsor after July 2020. All projects initiated prior to July 2020 remain eligible to receive revenue credits under Attachment Z2, which includes the $14 million related to the refunds discussed above.

OCC Proceedings

Oklahoma CWIP Filing

On December 12, 2025, OG&E filed an application for CWIP treatment for Horseshoe Lake combustion turbines Units 13 and 14, as allowed by SB 998. A motion to dismiss the case was filed by the Oklahoma Industrial Energy Consumers, as well as the Public Utility Division Staff. OG&E filed a response as well as motions to move the case and all outstanding motions to be heard en banc. These motions were heard before the OCC on January 27, 2026.

Oklahoma Frontier Energy Storage Project Preapproval Filing

On December 19, 2025, OG&E filed a preapproval case for the Frontier Energy Storage Project, which involves a purchase and sale agreement for a 300 MW battery storage facility in Oklahoma. The Frontier Energy Storage Project is the final project resulting from OG&E's 2024 request for proposals and subsequent negotiations. On January 28, 2026, the Attorney General and Petroleum Alliance of Oklahoma filed a joint motion to dismiss the case based on an interpretation that a battery energy storage system in not an electric generation facility. On February 3, 2026, OG&E filed a response in opposition to the joint motion to dismiss, and a hearing on the motion was held on February 5, 2026.

Retirement Plans and Postretirement Benefit Plans - Schedule of Expected Benefit Payments (Details) $ in Millions	Dec. 31, 2025 USD ($)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected Future Benefit Payments, Next Twelve Months	$ 59.1
Expected Future Benefit Payments, Year Two	42.2
Expected Future Benefit Payments, Year Three	33.4
Expected Future Benefit Payments, Year Four	30.6
Expected Future Benefit Payments, Year Five	29.3
Expected Future Benefit Payments, Five Fiscal Years Thereafter	120.9
OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Expected Future Benefit Payments, Next Twelve Months	52.3
Expected Future Benefit Payments, Year Two	30.1
Expected Future Benefit Payments, Year Three	29.4
Expected Future Benefit Payments, Year Four	27.5
Expected Future Benefit Payments, Year Five	25.4
Expected Future Benefit Payments, Five Fiscal Years Thereafter	$ 105.9

Revenue Recognition (Tables)

12 Months Ended

Dec. 31, 2025

Revenues from Contract with Customers [Abstract]

Disaggregation of Revenue

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 Company) Results of Operations" within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations."


	Year Ended December 31,
(In millions)	2025		2024			2023
Residential	$	1,172.1	$	1,116.4		$	1,008.6
Commercial		955.7		816.5			666.7
Industrial		260.1		248.6			235.2
Oilfield		241.5		225.7			210.0
Public authorities and street light		269.6		255.5			228.6
System sales revenues		2,899.0		2,662.7			2,349.1
Provision for rate refund and tax refund		3.0		(3.0	)		2.0
Integrated market		91.6		74.5			71.6
Transmission		159.4		152.9			143.0
Other		37.9		29.5			41.6
Revenues from contracts with customers	$	3,190.9	$	2,916.6		$	2,607.3

Credit Facilities and Short-Term Debt - Schedule of Line of Credit Facilities (Details)
$ in Millions

12 Months Ended

Dec. 31, 2025

USD ($)

Line of Credit Outstanding, Amount

Aggregate Commitment

$ 1,160.0

$ 292.4

^[1]

4.12%

Line of Credit Facility, Current Borrowing Capacity

$ 550.0

^[2]

Line of Credit Outstanding, Amount

$ 292.0

^[1],[2]

OGE Energy [Member] | Term Loan [Member]

4.12%

^[2],[3]

Maturity

Dec. 18, 2029

^[2]

Line of Credit Facility, Current Borrowing Capacity

$ 60.0

^[4]

Line of Credit Outstanding, Amount

$ 0.0

^[1],[4]

0.00%

^[3],[4]

Maturity

May 24, 2027

^[4]

Line of Credit Facility, Current Borrowing Capacity

$ 550.0

^[5],[6]

Letters of Credit Outstanding, Amount

$ 0.4

^[1],[5],[6]

Performance Units [Member] | OGE Energy and OG&E [Member]

1.20%

^[3],[5],[6]

Maturity

Dec. 18, 2029

^[5],[6]

[1]	Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at December 31, 2025
[2]	This bank facility is available to back up OGE Energy's commercial paper borrowings and to provide revolving credit borrowings. This bank facility can also be used as a letter of credit facility.
[3]	Represents the weighted-average interest rate for the outstanding borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit.
[4]	OGE Energy has a $120.0 million floating rate unsecured three-year credit agreement, of which $60.0 million is considered a revolving loan, which is included in the table above, and $60.0 million is considered a term loan. The credit agreement, under certain circumstances, may be increased to a maximum commitment limit of $155.0 million and includes a maximum leverage ratio of 0.70 to 1.0. The other covenants under this credit agreement are substantially the same as OGE Energy's existing $550.0 million revolving credit agreement.
[5]	OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $450.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of December 18, 2029. At December 31, 2025, there was $78.3 million in advances to parent, and there were no borrowings under the intercompany borrowing agreement.
[6]	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.

Document and Entity Information Document - USD ($)	12 Months Ended
Document and Entity Information Document - USD ($)	Dec. 31, 2025	Jan. 31, 2026	Jun. 30, 2025
Entity Information [Line Items]
Entity Registrant Name	OGE ENERGY CORP.
Entity Central Index Key	0001021635
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Period End Date	Dec. 31, 2025
Document Fiscal Year Focus	2025
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-1481638
Entity Address, Address Line One	321 North Harvey
Entity Address, Address Line Two	P.O. Box 321
Trading Symbol	OGE
Security Exchange Name	NYSE
Entity Interactive Data Current	Yes
City Area Code	405
Local Phone Number	553-3000
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	73101-0321
Entity File Number	1-12579
Title of 12(b) Security	Common Stock
Entity Address, City or Town	Oklahoma City
Share Price			$ 44.38
Document Transition Report	false
Document Annual Report	true
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Document Type	10-K
Entity Common Stock, Shares Outstanding		206,259,022	201,395,142
Entity Public Float			$ 8,937,916,402
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE The Proxy Statement for OGE Energy Corp.'s 2026 annual meeting of shareowners is incorporated by reference into Part III of this Form 10-K. This combined Form 10-K represents separate filings by OGE Energy Corp. and Oklahoma Gas and Electric Company. Information contained herein related to an individual registrant is filed by such registrant on its own behalf. Oklahoma Gas and Electric Company makes no representations as to the information relating to OGE Energy Corp.'s other operations. Oklahoma Gas and Electric Company meets the conditions set forth in General Instruction I(1)(a) and (b) of Form 10-K and is therefore filing this form with the reduced disclosure format permitted by General Instruction I(2).
Auditor Name	Ernst & Young LLP
Auditor Firm ID	42
Auditor Location	Oklahoma City, Oklahoma
Auditor Opinion [Text Block]	Opinion on the Financial Statements We have audited the accompanying balance sheets and statements of capitalization of Oklahoma Gas and Electric Company (the Company) as of December 31, 2025 and 2024, the related statements of income and comprehensive income, changes in stockholder's equity and cash flows for each of the three years in the period ended December 31, 2025, and the related notes and financial statement schedule listed in the Index at Item 15(a) (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2025 and 2024, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2025, in conformity with U.S. generally accepted accounting principles. We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2025, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework), and our report dated February 17, 2026, expressed an unqualified opinion thereon.
OG&E [Member]
Entity Information [Line Items]
Entity Registrant Name	OKLAHOMA GAS AND ELECTRIC COMPANY
Entity Central Index Key	0000074145
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Tax Identification Number	73-0382390
Entity Interactive Data Current	Yes
Entity File Number	1-1097
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Entity Common Stock, Shares Outstanding		40,378,745
Auditor Name	Ernst & Young LLP
Auditor Firm ID	42
Auditor Location	Oklahoma City, Oklahoma

Stock-Based Compensation - Share-based Compensation, Activity (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2025

Dec. 31, 2024

Dec. 31, 2023

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

Share-Based Compensation Arrangement by Share-Based Payment Award, Non-Option Equity Instruments, Outstanding, Number, Beginning Balance

646,192

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

^[1]

216,426

Equity Instruments Other than Options, Converted in Period

^[2]

(191,918)

Equity Instruments Other than Options, Vested in Period

(191,740)

Equity Instruments Other than Options, Forfeited in Period

(12,756)

Share-Based Compensation Arrangement by Share-Based Payment Award, Non-Option Equity Instruments, Outstanding, Number, Ending Balance

657,944

646,192

Awards Other than Options, Fully Vested

^[3]

191,740

Equity Instruments Other than Options, Converted, Aggregrate Intrinsic Value

$ 12.5

Equity Instruments Other than Options, Outstanding, Aggregrate Intrinsic Value

19.7

Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested

$ 8.2

Restricted Stock [Member]

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

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

121,056

148,345

114,926

Restricted Stock [Member] | OG&E [Member]

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

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

121,056

148,345

35,034

Restricted Stock [Member] | OGE Energy and OG&E [Member]

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

Share-Based Compensation Arrangement by Share-Based Payment Award, Non-Option Equity Instruments, Outstanding, Number, Beginning Balance

244,054

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

121,056

Equity Instruments Other than Options, Vested in Period

(100,933)

Equity Instruments Other than Options, Forfeited in Period

(9,924)

Share-Based Compensation Arrangement by Share-Based Payment Award, Non-Option Equity Instruments, Outstanding, Number, Ending Balance

254,253

244,054

Equity Instruments Other than Options, Vested, Aggregrate Intrinsic Value

$ 4.3

Equity Instruments Other than Options, Outstanding, Aggregrate Intrinsic Value

$ 10.9

[1]	For performance units, this represents the target number of performance units granted. Actual number of performance units earned, if any, is dependent upon performance and may range from zero percent to 200 percent of the target.
[2]	These amounts represent performance units that vested at December 31, 2024, which were settled in February 2025.
[3]	These amounts represent performance units that vested at December 31, 2025. Actual expected amounts to be paid out in 2026 will differ based on the percentage at which the performance metric was met and are dependent upon Compensation Committee approval.

Summary of Significant Accounting Policies - Summary of Changes to Asset Retirement Obligation (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2025

Dec. 31, 2024

Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]

Balance at January 1

$ 84.6

$ 81.3

Accretion expense

0.8

0.9

Liabilities settled

^[1]

(7.6)

(0.2)

Revisions in estimated cash flows

^[2]

0.0

2.6

Balance at December 31

$ 77.8

$ 84.6

[1]	Asset retirement obligations were settled for asbestos removal at OG&E's generating facilities.
[2]	Assumptions changed due to new removal estimates related to wind turbine removal at three of OG&E's wind farms in 2024.

Fair Value Measures and Disclosures (Policies)

12 Months Ended

Dec. 31, 2025

Fair Value Disclosures [Abstract]

Fair Value Measurement, Policy

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).

Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Pay vs Performance Disclosure
Net Income (Loss)	$ 470.7	$ 441.5	$ 416.8

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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-Name Accounting Standards Codification
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Reference 46: http://www.xbrl.org/2003/role/disclosureRef
-Topic 220
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Reference 48: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
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Reference 49: http://fasb.org/us-gaap/role/ref/legacyRef
-Topic 942
-SubTopic 220
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-04(22))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147478524/942-220-S99-1

Revenue from Contract with Customer [Abstract]

Revenue Recognition

12 Months Ended

Dec. 31, 2025

Revenue Recognition

3. Revenue Recognition


	Year Ended December 31,
(In millions)	2025		2024			2023
Residential	$	1,172.1	$	1,116.4		$	1,008.6
Commercial		955.7		816.5			666.7
Industrial		260.1		248.6			235.2
Oilfield		241.5		225.7			210.0
Public authorities and street light		269.6		255.5			228.6
System sales revenues		2,899.0		2,662.7			2,349.1
Provision for rate refund and tax refund		3.0		(3.0	)		2.0
Integrated market		91.6		74.5			71.6
Transmission		159.4		152.9			143.0
Other		37.9		29.5			41.6
Revenues from contracts with customers	$	3,190.9	$	2,916.6		$	2,607.3

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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-URI https://asc.fasb.org/1943274/2147479806/606-10-50-10

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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
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-Subparagraph (c)
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-SubTopic 10
-Name Accounting Standards Codification
-Section 50
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-Subparagraph (d)
-Publisher FASB
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
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-Subparagraph (e)
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-Topic 606
-SubTopic 10
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-Name Accounting Standards Codification
-Topic 606
-Publisher FASB
-URI https://asc.fasb.org/606/tableOfContent

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Summary of Significant Accounting Policies - Summary of Amount Reclassified Out of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2025

Dec. 31, 2024

Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent

$ (0.4)

$ (0.3)

Pension Plan [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax

^[1]

(0.4)

(0.3)

Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax

^[1]

(0.3)

Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax

(0.7)

(0.6)

Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, Tax

(0.2)

Amounts reclassified from accumulated other comprehensive income (loss)

(0.5)

(0.4)

Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax

^[1]

(0.3)

Other Postretirement Benefits Plan [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax

^[1]

0.2

Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax

0.2

Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, Tax

0.1

Amounts reclassified from accumulated other comprehensive income (loss)

$ 0.1

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

Commitments and Contingencies - Unrecorded Unconditional Purchase Obligations Disclosure (Details) $ in Millions	Dec. 31, 2025 USD ($)
Loss Contingencies [Line Items]
Purchase Obligation, Due in Next Twelve Months	$ 421.1
Unrecorded Unconditional Purchase Obligation, Due within Two Years	672.3
Unrecorded Unconditional Purchase Obligation, Due within Three Years	263.7
Unrecorded Unconditional Purchase Obligation, Due within Four Years	170.9
Unrecorded Unconditional Purchase Obligation, Due within Five Years	155.1
Unrecorded Unconditional Purchase Obligation, Total	1,683.1
OG&E minimum fuel purchase commitments [Member]
Loss Contingencies [Line Items]
Purchase Obligation, Due in Next Twelve Months	110.4
Unrecorded Unconditional Purchase Obligation, Due within Two Years	72.5
Unrecorded Unconditional Purchase Obligation, Due within Three Years	67.1
Unrecorded Unconditional Purchase Obligation, Due within Four Years	63.8
Unrecorded Unconditional Purchase Obligation, Due within Five Years	63.9
Unrecorded Unconditional Purchase Obligation, Total	377.7
OgE Wind Purchase Commitments [Member]
Loss Contingencies [Line Items]
Purchase Obligation, Due in Next Twelve Months	57.3
Unrecorded Unconditional Purchase Obligation, Due within Two Years	57.8
Unrecorded Unconditional Purchase Obligation, Due within Three Years	58.4
Unrecorded Unconditional Purchase Obligation, Due within Four Years	58.6
Unrecorded Unconditional Purchase Obligation, Due within Five Years	57.8
Unrecorded Unconditional Purchase Obligation, Total	289.9
OG&E Capacity Commitments [Member]
Loss Contingencies [Line Items]
Purchase Obligation, Due in Next Twelve Months	105.0
Unrecorded Unconditional Purchase Obligation, Due within Two Years	41.5
Unrecorded Unconditional Purchase Obligation, Due within Three Years	31.3
Unrecorded Unconditional Purchase Obligation, Due within Four Years	26.9
Unrecorded Unconditional Purchase Obligation, Due within Five Years	27.8
Unrecorded Unconditional Purchase Obligation, Total	232.5
OG&E long-term service agreement commitments [Member]
Loss Contingencies [Line Items]
Purchase Obligation, Due in Next Twelve Months	50.1
Unrecorded Unconditional Purchase Obligation, Due within Two Years	19.0
Unrecorded Unconditional Purchase Obligation, Due within Three Years	8.9
Unrecorded Unconditional Purchase Obligation, Due within Four Years	4.5
Unrecorded Unconditional Purchase Obligation, Due within Five Years	5.6
Unrecorded Unconditional Purchase Obligation, Total	88.1
OG&E Generation Capacity Construction Commitments [Member]
Loss Contingencies [Line Items]
Purchase Obligation, Due in Next Twelve Months	98.3
Unrecorded Unconditional Purchase Obligation, Due within Two Years	481.5
Unrecorded Unconditional Purchase Obligation, Due within Three Years	98.0
Unrecorded Unconditional Purchase Obligation, Due within Four Years	17.1
Unrecorded Unconditional Purchase Obligation, Due within Five Years	0.0
Unrecorded Unconditional Purchase Obligation, Total	$ 694.9

Stock-Based Compensation - Schedule of Nonvested Share Activity (Details) - $ / shares

12 Months Ended

Dec. 31, 2025

Dec. 31, 2024

Dec. 31, 2023

Performance Units [Member] | OGE Energy and OG&E [Member]

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

Equity Instruments Other than Options, Nonvested, Number, Beginning Balance

454,274

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

^[1]

216,426

Equity Instruments Other than Options, Vested in Period

(191,740)

Equity Instruments Other than Options, Forfeited in Period

(12,756)

Equity Instruments Other than Options, Nonvested, Number, Ending Balance

466,204

454,274

Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Beginning Balance

$ 39.28

Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value

55.43

Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value

43.74

Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value

42.49

Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Ending Balance

$ 44.86

$ 39.28

Restricted Stock [Member]

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

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

121,056

148,345

114,926

Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value

$ 43.69

$ 32.74

$ 37.52

Restricted Stock [Member] | Og and E [Member]

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

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

121,056

148,345

35,034

Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value

$ 43.69

$ 32.74

$ 37.52

Restricted Stock [Member] | OGE Energy and OG&E [Member]

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

Equity Instruments Other than Options, Nonvested, Number, Beginning Balance

244,054

Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted

121,056

Equity Instruments Other than Options, Vested in Period

(100,933)

Equity Instruments Other than Options, Forfeited in Period

(9,924)

Equity Instruments Other than Options, Nonvested, Number, Ending Balance

254,253

244,054

Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Beginning Balance

$ 34.81

Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value

43.69

Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value

42.79

Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value

36.73

Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Ending Balance

$ 37.88

$ 34.81

[1]	For performance units, this represents the target number of performance units granted. Actual number of performance units earned, if any, is dependent upon performance and may range from zero percent to 200 percent of the target.

Common Equity - Dividends Restriction (Additional Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Class of Stock [Line Items]
Preferred Stock, Shares Outstanding	0
Stock Issued During Period, Shares, New Issues	234,476	255,578	82,321
OGE Energy [Member]
Class of Stock [Line Items]
Retained Earnings, Restricted	$ 1,000.0
Retained Earnings, Unrestricted	$ 2,600.0
OGE Energy [Member] \| Maximum [Member]
Class of Stock [Line Items]
Ratio of Consolidated Debt to Consolidated Capitalization	70.00%
Og and E [Member]
Class of Stock [Line Items]
Ratio of Consolidated Debt to Consolidated Capitalization	65.00%
Retained Earnings, Restricted	$ 918.9
Retained Earnings, Unrestricted	$ 3,100.0
Stock Issued During Period, Shares, New Issues	0	0	0

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Reference 3: http://www.xbrl.org/2009/role/commonPracticeRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 5: http://www.xbrl.org/2003/role/exampleRef
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Reference 6: http://www.xbrl.org/2003/role/recommendedDisclosureRef
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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Reference 8: http://www.xbrl.org/2009/role/commonPracticeRef
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
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Reference 10: http://www.xbrl.org/2003/role/disclosureRef
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Reference 11: http://www.xbrl.org/2003/role/disclosureRef
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Reference 12: http://www.xbrl.org/2003/role/disclosureRef
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Reference 13: http://www.xbrl.org/2003/role/disclosureRef
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Reference 14: http://www.xbrl.org/2003/role/disclosureRef
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Reference 15: http://www.xbrl.org/2003/role/disclosureRef
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Reference 16: http://www.xbrl.org/2003/role/disclosureRef
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Reference 17: http://www.xbrl.org/2003/role/disclosureRef
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Reference 18: http://www.xbrl.org/2003/role/disclosureRef
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Reference 19: http://www.xbrl.org/2003/role/disclosureRef
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Reference 20: http://www.xbrl.org/2003/role/disclosureRef
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Reference 21: http://www.xbrl.org/2003/role/disclosureRef
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Schedule of Line of Credit Facilities

Credit Facilities and Short-Term Debt (Tables)

12 Months Ended

Dec. 31, 2025

Short-Term Debt [Abstract]

The following table presents information regarding the Registrants' revolving credit agreements at December 31, 2025.


Entity	Aggregate Commitment		Amount Outstanding (A)		Weighted-Average Interest Rate				Expiration
	(In millions)
OGE Energy (B)	$	550.0	$	292.0		4.12	%	(F)	December 18, 2029
OGE Energy (C)		60.0		—		—		(F)	May 24, 2027
OG&E (D)(E)		550.0		0.4		1.20	%	(F)	December 18, 2029
Total	$	1,160.0	$	292.4		4.12	%

(A)

Includes direct borrowings under the revolving credit agreements, commercial paper borrowings and letters of credit at December 31, 2025. Typically, OGE Energy issues commercial paper to address consolidated operational activity, and OG&E will borrow from OGE Energy under the intercompany borrowing agreement as discussed below in footnote (E).

(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)

OGE Energy has a $120.0 million floating rate unsecured three-year credit agreement, of which $60.0 million is considered a revolving loan, which is included in the table above, and $60.0 million is considered a term loan. The credit agreement, under certain circumstances, may be increased to a maximum commitment limit of $155.0 million and includes a maximum leverage ratio of 0.70 to 1.0. The other covenants under this credit agreement are substantially the same as OGE Energy's existing $550.0 million revolving credit agreement.

(D)

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.

(E)

OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $450.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of December 18, 2029. At December 31, 2025, there was $78.3 million in advances to parent, and there were no borrowings under the intercompany borrowing agreement.

(F)

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

Commitments and Contingencies

12 Months Ended

Dec. 31, 2025

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

13. Commitments and Contingencies

Purchase Obligations and Commitments

The following table presents the Registrants' future purchase obligations and commitments estimated for the next five years.


(In millions)	2026		2027		2028		2029		2030		Total
Purchase obligations and commitments:
Minimum purchase commitments	$	110.4	$	72.5	$	67.1	$	63.8	$	63.9	$	377.7
Wind purchase commitments		57.3		57.8		58.4		58.6		57.8		289.9
Capacity commitments		105.0		41.5		31.3		26.9		27.8		232.5
Long-term service agreement commitments		50.1		19.0		8.9		4.5		5.6		88.1
Generation capacity construction commitments		98.3		481.5		98.0		17.1		—		694.9
Total purchase obligations and commitments	$	421.1	$	672.3	$	263.7	$	170.9	$	155.1	$	1,683.1

OG&E Minimum Purchase Commitments

OG&E has coal contracts for purchases through December 31, 2027. OG&E may also purchase coal through spot purchases on an as-needed basis. As a participant in the SPP Integrated Marketplace, OG&E purchases its natural gas supply through short-term agreements. OG&E relies on a combination of natural gas base load agreements and call agreements, whereby OG&E has the right but not the obligation to purchase a defined quantity of natural gas, combined with day and intra-day purchases to meet the demands of the SPP Integrated Marketplace.

OG&E has natural gas transportation service contracts with Energy Transfer, ONEOK, Inc. and Southern Star, which grant these companies the responsibility of delivering natural gas to OG&E's generating facilities. The contracts with Energy Transfer end in December 2034, December 2038 and September 2045; the contracts with ONEOK, Inc. end in August 2037 and December 2045; and the contract with Southern Star ends in December 2034. OG&E also has natural gas storage agreements with ONEOK, Inc. for firm storage which ends in December 2045, and the Energy Transfer agreement for park and loan service ends in April 2027.

OG&E Estimated Wind Power Purchase Commitments

The following table presents OG&E's wind purchased power contracts.


Company	Location	Original Term of Contract	Expiration of Contract	MWs
CPV Keenan	Woodward County, OK	20 years	2030		152.0
Edison Mission Energy	Dewey County, OK	20 years	2031		130.0
NextEra Energy	Blackwell, OK	20 years	2032		60.0

The following table presents a summary of OG&E's wind power purchases for the years ended December 31, 2025, 2024 and 2023.


Year Ended December 31 (In millions)	2025		2024		2023
CPV Keenan	$	28.3	$	25.4	$	23.0
Edison Mission Energy		21.9		23.3		20.5
NextEra Energy		4.6		5.6		5.3
Total wind power purchased	$	54.8	$	54.3	$	48.8

OG&E Capacity Commitments

The SPP requires its members, including OG&E, to maintain a generation planning reserve margin. Due to near-term generation requirements, OG&E entered into short-term power purchase agreements to meet its incremental capacity needs in each of the years through 2030 to address the planning reserve margin requirements.

OG&E Long-Term Service Agreement Commitments

OG&E has a long-term parts and service maintenance contract for the upkeep of the McClain Plant that is expected to run for the earlier of 128,000 factored-fired hours or 4,800 factored-fired starts. Based on historical usage and current expectations for future usage, this contract is expected to run until 2035. The contract requires payments based on both a fixed and variable cost component, depending on how much the McClain Plant is used.

OG&E has a long-term parts and service maintenance contract for the upkeep of the Redbud Plant for a maximum of the earlier of 144,000 factored-fired hours or 4,500 factored-fired starts. Based on historical usage and current expectations for future usage, this contract is expected to run until 2032. The contract requires payments based on both a fixed and variable cost component, depending on how much the Redbud Plant is used.

OG&E has a long-term parts and service maintenance contract for the upkeep of the Horseshoe Lake Plant Units 11 and 12 for a maximum of the earlier of 64,000 factored-fired hours or 2,500 factored-fired starts for each unit. Based on historical usage and current expectations for future usage, this contract is expected to run until 2044. The contract requires payments based on both a fixed and variable cost component, depending on how much the Horseshoe Lake Plant is used.

OG&E Generation Capacity Construction Commitments

OG&E has generation capacity construction projects at its existing Horseshoe Lake generating facility and Tinker Air Force Base. At Horseshoe Lake, OG&E is installing four combustion turbines with a total capacity of 896 MWs, of which 448 MWs (Units 11 and 12) is expected to be placed into service by late 2026 and the remaining 448 MWs (Units 13 and 14) is expected to be placed into service during 2029. At Tinker Air Force Base, OG&E is installing two combustion turbines with a combined capacity of 96 MWs which are expected to be placed into service in early 2026. OG&E also has a commitment related to the Frontier Energy Storage Project, which involves a purchase and sale agreement for a 300 MW battery storage facility in Oklahoma.

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 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 financial statements. If the assessment indicates that a potential loss is not probable but reasonably possible, the nature of the contingent matter, together with an estimate of the range of possible loss, if determinable and material, would be disclosed. At the present time, based on currently available information, except as discussed below, 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 financial statements and would not have a material adverse effect on their financial position, results of operations or cash flows.

In July 2023, OG&E was named, along with its contractor, as a defendant in a lawsuit filed by an apartment owner and its insurance companies seeking in excess of $60.0 million in damages related to a fire at an apartment building under construction in Oklahoma City. Several additional defendants have also been named. OG&E disputes the claims in the lawsuit and intends to vigorously defend this action. If OG&E is ultimately deemed liable for damages in connection with this incident, OG&E believes its existing insurance policies will cover its costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have. Due to the uncertain and developing nature of this litigation, the outcome cannot be predicted, and OG&E is unable to provide a range of possible loss in this matter.

Long-Term Debt

12 Months Ended

Dec. 31, 2025

Long-Term Debt, Unclassified [Abstract]

Long-Term Debt

9. Long-Term Debt

A summary of the Registrants' long-term debt is included in the statements of capitalization. At December 31, 2025, the Registrants were in compliance with all of their debt agreements.

Maturities of OGE Energy's consolidated long-term debt during the next five years consist of $241.0 million in 2027, $500.0 million in 2028, $350.0 million in 2029 and $600.0 million in 2030. Maturities of OG&E's long-term debt during the next five years consist of $181.0 million in 2027, $500.0 million in 2028 and $600.0 million in 2030. All other long-term debt of the Registrants matures after 2032.

The Registrants have previously incurred costs related to debt refinancing. Unamortized loss on reacquired debt is classified as a Non-Current Regulatory Asset in the balance sheets. Unamortized debt expense and unamortized premium and discount on long-term debt are classified as Long-Term Debt in the balance sheets and are being amortized over the life of the respective debt.

OG&E Industrial Authority Bonds

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


Series			Date Due	Amount
				(In millions)
1.65%	—	4.60%	Muskogee Industrial Authority, June 1, 2027	$	56.0
1.80%	—	4.60%	Garfield Industrial Authority, October 1, 2039		47.0
Total (redeemable during next 12 months)				$	103.0

OG&E repaid $32.4 million of Muskogee Industrial Authority bonds that matured on January 1, 2025.

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 remarketing of bonds does not result in short-term debt classification in the balance sheets. OG&E believes that it has sufficient liquidity to meet these obligations.

Issuance of Long-Term Debt

On April 1, 2025, OG&E issued $350.0 million of 5.80 percent senior notes due April 1, 2055. The proceeds from this issuance were added to OG&E's general funds and used for the repayment of short-term debt and borrowings under its revolving credit facility, and to fund OG&E's capital investment program and working capital needs.

Credit Facilities and Short-Term Debt - Schedule of Line of Credit Facilities (Parenthetical) (Details)

12 Months Ended

Dec. 31, 2025

USD ($)

Dec. 31, 2024

USD ($)

Outstanding Intercompany Borrowings

$ 0

Line of Credit Facility, Maximum Borrowing Capacity

1,160,000,000

Intercompany Borrowing Agreement - Maximum Borrowing Capacity

$ 450,000,000

Credit facility termination date

^[1],[2]

Dec. 18, 2029

Line of Credit Facility, Current Borrowing Capacity

^[1],[2]

$ 550,000,000

Advances from parent

$ 247,600,000

Advances to parent

$ 78,300,000

Credit facility termination date

^[3]

Dec. 18, 2029

Line of Credit Facility, Current Borrowing Capacity

^[3]

$ 550,000,000

OGE Energy [Member] | Series Due May 24, 2027 [Member]

OGE Energy [Member] | Series due August 15, 2028 [Member]

Long term debt

120,000,000

Line of Credit Facility, Maximum Borrowing Capacity

$ 155,000,000

Debt Instrument Maximum Leverage Ratio

0.7

Credit Facility [Member] | OGE Energy [Member] | Series Due May 24, 2027 [Member]

Term Loan [Member] | OGE Energy [Member]

Long term debt

$ 60,000,000

Credit facility termination date

^[4]

May 24, 2027

Line of Credit Facility, Current Borrowing Capacity

^[4]

$ 60,000,000

Term Loan [Member] | OGE Energy [Member] | Series Due May 24, 2027 [Member]

Long term debt

$ 60,000,000

[1]	OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $450.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of December 18, 2029. At December 31, 2025, there was $78.3 million in advances to parent, and there were no borrowings under the intercompany borrowing agreement.
[2]	This bank facility is available to back up OG&E's commercial paper borrowings and to provide revolving credit borrowings. This bank facility can also be used as a letter of credit facility.
[3]	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.
[4]	OGE Energy has a $120.0 million floating rate unsecured three-year credit agreement, of which $60.0 million is considered a revolving loan, which is included in the table above, and $60.0 million is considered a term loan. The credit agreement, under certain circumstances, may be increased to a maximum commitment limit of $155.0 million and includes a maximum leverage ratio of 0.70 to 1.0. The other covenants under this credit agreement are substantially the same as OGE Energy's existing $550.0 million revolving credit agreement.

Rate Matters and Regulation - Additional Information (Details) $ in Millions			12 Months Ended	72 Months Ended	84 Months Ended
	May 15, 2025 USD ($)	Jun. 12, 2024 USD ($)	Dec. 31, 2025 USD ($) Megawattsday kV MWd	Dec. 31, 2030 Megawattsday	Dec. 31, 2031 Megawattsday
Rate Matters and Regulation [Line Items]
Construction Work In Progress Incentive and Abandonment Incentive Cost	$ 250.0
Estimated Refund to SPP			$ 14.0
Oklahoma [Member]
Rate Matters and Regulation [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 126.7
Energy generation capacity \| MWd			300
Integrated Transmission Plan [Member]
Rate Matters and Regulation [Line Items]
Energy generation capacity \| kV			765
Oklahoma Corporation Commission [Member]
Rate Matters and Regulation [Line Items]
OG&E's Jurisdictional Revenues			88.00%
Arkansas Public Service Commission [Member]
Rate Matters and Regulation [Line Items]
OG&E's Jurisdictional Revenues			7.00%
Federal Energy Regulatory Commission [Member]
Rate Matters and Regulation [Line Items]
OG&E's Jurisdictional Revenues			5.00%
Arkansas 2024 Generation Construction Notice Filing \| Forecast [Member]
Rate Matters and Regulation [Line Items]
Energy generation capacity \| Megawattsday				1,647
Arkansas 2026 Generation Construction Notice Filing \| Forecast [Member]
Rate Matters and Regulation [Line Items]
Energy generation capacity \| Megawattsday					1,922
Minimum [Member] \| Arkansas 2025 Generation Construction Notice Filing
Rate Matters and Regulation [Line Items]
Energy generation capacity \| Megawattsday			1,000
Impact to Company [Member]
Rate Matters and Regulation [Line Items]
Estimated Refund to SPP			$ 4.0
Customer Impact [Member]
Rate Matters and Regulation [Line Items]
Estimated Refund to SPP			$ 10.0
SPP Resource Adequacy [Member] \| Arkansas 2026 Generation Construction Notice Filing \| Forecast [Member]
Rate Matters and Regulation [Line Items]
Energy generation capacity \| Megawattsday					800

Retirement Plans and Postretirement Benefit Plans - Schedule of Allocation of Plan Assets (Details) - Other Postretirement Benefits Plan [Member] - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	$ 28.4	$ 30.0	$ 32.7
OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	26.2	27.2	$ 29.6
Group Retiree Medical Insurance Contract [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	8.7	13.6
Mutual fund [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	19.7	16.4
Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	19.7	16.4
Fair Value, Inputs, Level 1 [Member] \| Group Retiree Medical Insurance Contract [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0.0	0.0
Fair Value, Inputs, Level 1 [Member] \| Mutual fund [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	19.7	16.4
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	8.7	13.6
Fair Value, Inputs, Level 3 [Member] \| Group Retiree Medical Insurance Contract [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	8.7	13.6
Fair Value, Inputs, Level 3 [Member] \| Mutual fund [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0.0	0.0
Fair Value, Inputs, Level 1, 2 and 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	28.4	30.0
Fair Value, Inputs, Level 1, 2 and 3 [Member] \| OGE Energy [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	(2.2)	(2.8)
Fair Value, Inputs, Level 1, 2 and 3 [Member] \| OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	$ 26.2	$ 27.2

Common Equity - Schedule of Earnings Per Share Basic and Diluted (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Net income	$ 470.7	$ 441.5	$ 416.8
Basic average common shares outstanding	201.9	200.8	200.3
Contingently issuable shares (performance and restricted stock units)	0.6	0.5	0.6
Forward equity sale agreements	0.0	0.0	0.0
Diluted average common shares outstanding	202.5	201.3	200.9
Basic earnings per average common share	$ 2.33	$ 2.20	$ 2.08
Diluted earnings per average common share	$ 2.32	$ 2.19	$ 2.07
Anti-dilutive shares excluded from earnings per share calculation	0.0	0.0	0.0
Retained Earnings [Member]
Net income	$ 470.7	$ 441.5	$ 416.8

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

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Fair Value, by Balance Sheet Grouping

Retirement Plans and Postretirement Benefit Plans - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer expected contribution	$ 15,000,000
Employer contributions	$ 13,500,000	$ 10,000,000
Ultimate Health Care Cost Trend Rate	4.00%
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	200.00%
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay	5.00%
Defined Contribution Plan, Cost	$ 21,900,000	21,400,000	$ 19,600,000
Maximum [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Percentage of increase in annual medical inflation cost	5.00%
OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Cost	$ 21,900,000	21,400,000	16,000,000
Other Postretirement Benefits Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer contributions	$ 6,000,000	6,300,000
Health Care Cost Trend Rate Assumed for Next Fiscal Year	8.00%
Fair Value of Plan Assets	$ 28,400,000	30,000,000	32,700,000
Other Postretirement Benefits Plan [Member] \| Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0	0
Other Postretirement Benefits Plan [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	8,700,000	13,600,000
Other Postretirement Benefits Plan [Member] \| OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer contributions	4,600,000	4,900,000
Fair Value of Plan Assets	26,200,000	27,200,000	29,600,000
Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer contributions	13,500,000	10,000,000
Fair Value of Plan Assets	262,200,000	246,900,000	243,700,000
Pension Plan [Member] \| Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Fair Value of Plan Assets	0	0
Pension Plan [Member] \| OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Employer contributions	13,500,000	10,000,000
Fair Value of Plan Assets	$ 226,200,000	$ 211,600,000	$ 191,400,000

CONSOLIDATED STATEMENTS OF CAPITALIZATION (Parenthetical) - $ / shares shares in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024
Schedule of Capitalization, Long-Term Debt [Line Items]
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Stock, Shares Authorized	450.0	450.0
Common Stock, Shares, Outstanding	206.1	201.0
Common Stock, Shares, Issued	206.1	201.0
OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Common Stock, Par or Stated Value Per Share	$ 2.5	$ 2.5
Common Stock, Shares Authorized	100.0	100.0
Common Stock, Shares, Outstanding	40.4	40.4
Muskogee Industrial Authority Bond Due 2025 [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Maturity Date	Jan. 01, 2025
Muskogee Industrial Authority Bond Due 2025 [Member] \| OGE Energy [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Maturity Date	Jan. 01, 2025
Muskogee Industrial Authority Bond Due 2025 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Maturity Date	Jan. 01, 2025
Muskogee Industrial Authority Bond Due 2027 [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Maturity Date	Jun. 01, 2027
Muskogee Industrial Authority Bond Due 2027 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Maturity Date	Jun. 01, 2027
Garfield Industrial Authority Bond [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Maturity Date	Oct. 01, 2039
Garfield Industrial Authority Bond [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Maturity Date	Oct. 01, 2039
Senior Notes [Member] \| Series Due May 15 2029 [Member] \| OGE Energy [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.45%
Debt Instrument, Maturity Date	May 15, 2029
Senior Notes [Member] \| Series Due July 15, 2027 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.65%
Debt Instrument, Maturity Date	Jul. 15, 2027
Senior Notes [Member] \| Series Due April 15, 2028 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Debt Instrument, Maturity Date	Apr. 15, 2028
Senior Notes [Member] \| Series due August 15, 2028 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.80%
Debt Instrument, Maturity Date	Aug. 15, 2028
Senior Notes [Member] \| Series Due March 15, 2030 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.30%
Debt Instrument, Maturity Date	Mar. 15, 2030
Senior Notes [Member] \| Series Due April 1, 2030 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.25%
Debt Instrument, Maturity Date	Apr. 01, 2030
Senior Notes [Member] \| Series Due January 15, 2033 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.40%
Debt Instrument, Maturity Date	Jan. 15, 2033
Senior Notes [Member] \| Series Due January 15, 2036 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.75%
Debt Instrument, Maturity Date	Jan. 15, 2036
Senior Notes [Member] \| Series Due February 1, 2038 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.45%
Debt Instrument, Maturity Date	Feb. 01, 2038
Senior Notes [Member] \| Series Due June 1, 2040 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.85%
Debt Instrument, Maturity Date	Jun. 01, 2040
Senior Notes [Member] \| Series Due May 15, 2041 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.25%
Debt Instrument, Maturity Date	May 15, 2041
Senior Notes [Member] \| Series due May 1, 2043 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.90%
Debt Instrument, Maturity Date	May 01, 2043
Senior Notes [Member] \| Series due March 15, 2044 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.55%
Debt Instrument, Maturity Date	Mar. 15, 2044
Senior Notes [Member] \| Series due December 15, 2044 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.00%
Debt Instrument, Maturity Date	Dec. 15, 2044
Senior Notes [Member] \| Series due April 1, 2047 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.15%
Debt Instrument, Maturity Date	Apr. 01, 2047
Senior Notes [Member] \| Series due August 15, 2047 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.85%
Debt Instrument, Maturity Date	Aug. 15, 2047
Senior Notes [Member] \| Series Due April 1, 2053 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.60%
Debt Instrument, Maturity Date	Apr. 01, 2053
Senior Notes [Member] \| Series Due April 1, 2055 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.80%
Debt Instrument, Maturity Date	Apr. 01, 2055
Term Loan [Member] \| Due May 24, 2027 \| OGE Energy [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Maturity Date	May 24, 2027
Term Loan [Member] \| Due May 24, 2027 \| OGE Energy [Member] \| Minimum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.89%
Term Loan [Member] \| Due May 24, 2027 \| OGE Energy [Member] \| Maximum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.53%
Long-term Debt [Member] \| Due August 31, 2062 [Member] \| OG&E [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.00%
Debt Instrument, Maturity Date	Aug. 31, 2062
Debentures Subject to Mandatory Redemption [Member] \| Muskogee Industrial Authority Bond Due 2027 [Member] \| Minimum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.65%
Debentures Subject to Mandatory Redemption [Member] \| Muskogee Industrial Authority Bond Due 2027 [Member] \| Maximum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.60%
Debentures Subject to Mandatory Redemption [Member] \| Muskogee Industrial Authority Bond Due 2027 [Member] \| OG&E [Member] \| Minimum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.65%
Debentures Subject to Mandatory Redemption [Member] \| Muskogee Industrial Authority Bond Due 2027 [Member] \| OG&E [Member] \| Maximum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.60%
Debentures Subject to Mandatory Redemption [Member] \| Garfield Industrial Authority Bond [Member] \| Minimum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.80%
Debentures Subject to Mandatory Redemption [Member] \| Garfield Industrial Authority Bond [Member] \| Maximum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.60%
Debentures Subject to Mandatory Redemption [Member] \| Garfield Industrial Authority Bond [Member] \| OG&E [Member] \| Minimum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.80%
Debentures Subject to Mandatory Redemption [Member] \| Garfield Industrial Authority Bond [Member] \| OG&E [Member] \| Maximum [Member]
Schedule of Capitalization, Long-Term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.60%

Insider Trading Policies and Procedures	12 Months Ended
Insider Trading Policies and Procedures	Dec. 31, 2025
Insider Trading Policies and Procedures [Line Items]
Insider Trading Policies and Procedures Adopted	true

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2025

Fair Value Disclosures [Abstract]

The following table presents the carrying amount and fair value of the Registrants' financial instruments at December 31, 2025 and 2024, as well as the classification level within the fair value hierarchy.


	2025				2024
December 31 (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	$	347.6	$	362.5	$	346.9	$	355.7	Level 2
OGE Energy Term Loan	$	59.9	$	60.0	$	59.7	$	60.0	Level 2
OG&E Senior Notes	$	4,847.2	$	4,644.7	$	4,499.6	$	4,174.9	Level 2
OG&E Industrial Authority Bonds	$	103.0	$	103.0	$	135.4	$	135.4	Level 2
OG&E Tinker Debt	$	11.5	$	9.1	$	11.7	$	9.0	Level 3

Stock-Based Compensation - Schedule of Nonvested Share Activity (Parenthetical) (Details)	12 Months Ended
	Dec. 31, 2025
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Minimum payout range	0.00%
Maximum payout range	200.00%

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

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-Section 50
-Paragraph 2
-Subparagraph (c)(2)(i)
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-URI https://asc.fasb.org/1943274/2147480429/718-10-50-2

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-URI https://asc.fasb.org/1943274/2147480429/718-10-50-2

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-Section 50
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Reference 29: http://www.xbrl.org/2003/role/disclosureRef
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-Section 50
-Paragraph 2
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Reference 30: http://www.xbrl.org/2003/role/disclosureRef
-Topic 718
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (e)(2)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480429/718-10-50-2

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Fair Value Measurements - Additional Information (Details) - USD ($)	Dec. 31, 2025	Dec. 31, 2024
Recurring [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Financial instruments measured at fair value	$ 0	$ 0

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2025

Summary of Significant Accounting Policies

1. Summary of Significant Accounting Policies

Organization

OGE Energy is a holding company whose primary investment provides electricity in Oklahoma and western Arkansas. OGE Energy's electric company operations are conducted through its wholly-owned subsidiary, OG&E, which generates, transmits, distributes and sells electric energy in Oklahoma and western Arkansas and are reported through OGE Energy's electric company business segment. 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 the largest electric company in Oklahoma, with a franchised service territory that 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.

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.

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 electric company, 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)	2025		2024
REGULATORY ASSETS
Current:
SPP cost tracker under recoveries (A)	$	7.1	$	—
Oklahoma fuel clause under recoveries		—		112.7
Oklahoma Energy Efficiency Rider under recoveries (A)		—		7.0
Other (A)		4.3		3.8
Total current regulatory assets	$	11.4	$	123.5
Non-current:
Oklahoma deferred storm expenses	$	224.7	$	244.3
Pension tracker		88.7		94.7
Benefit obligations regulatory asset		85.6		90.8
Arkansas Winter Storm Uri costs		54.2		63.0
Oklahoma SB 998 deferred costs, net		22.9		—
Oklahoma SAP S/4 HANA deferred expenses		16.5		14.3
Sooner Dry Scrubbers		15.5		16.4
Oklahoma vegetation management program deferred costs		13.9		6.4
Arkansas deferred pension expenses		9.3		11.0
Arkansas capacity power purchase agreements		6.7		3.5
Unamortized loss on reacquired debt		5.5		6.3
COVID-19 impacts		4.1		5.4
Other		9.6		12.0
Total non-current regulatory assets	$	557.2	$	568.1
REGULATORY LIABILITIES
Current:
Oklahoma fuel clause over recoveries	$	15.7	$	—
Arkansas fuel clause over recoveries		11.4		9.3
Oklahoma Energy Efficiency Rider over recoveries (B)		5.8		—
Oklahoma Investment Tax Credit over recoveries (B)		2.0		6.1
Other (B)		—		4.9
Total current regulatory liabilities	$	34.9	$	20.3
Non-current:
Income taxes refundable to customers, net	$	718.9	$	780.8
Accrued removal obligations, net		234.7		231.9
Other		3.5		3.7
Total non-current regulatory liabilities	$	957.1	$	1,016.4

(A)

Included in Other Current Assets in the balance sheets.

(B)

Included in Other Current Liabilities in the balance sheets.

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.

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.

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 and are being recovered over a 15-year period.

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)	2025		2024
Pension Plan and Restoration of Retirement Income Plan:
Net loss	$	74.0	$	76.5
Postretirement Benefit Plans:
Net loss		11.6		14.3
Total	$	85.6	$	90.8

As approved by the APSC, OG&E is amortizing the deferred costs related to Winter Storm Uri over 10 years using a weighted average cost of capital as a carrying charge.

As discussed below, SB 998 became effective August 29, 2025. This legislation allows OG&E to establish a regulatory asset to defer 90 percent of depreciation expense and debt return associated with qualified plant investments, that are not classified as transmission or new generation, for recovery over an allowed 20-year period in a future rate filing. OG&E began deferring costs for qualified plant investments in September 2025.

As approved by the OCC, OG&E established a regulatory asset to defer the Oklahoma jurisdictional portion of operation and maintenance costs associated with OG&E's SAP S/4 HANA enterprise resource planning system project. As approved in the most recent Oklahoma general rate review, a portion of these costs is being recovered over five years with the remaining portion being included for consideration in a future rate proceeding.

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.

As approved in the most recent Oklahoma general rate review, OG&E includes in expense any Oklahoma vegetation management operation and maintenance expenses up to $38.2 million annually and defers to a regulatory asset up to $7.5 million annually in additional expenses. These costs will be included for consideration in a future rate proceeding.

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.

As approved by the APSC, OG&E defers to a regulatory asset the Arkansas jurisdictional portion of capacity costs associated with short-term power purchase agreements entered into to meet capacity needs in each of the years between 2023 and 2027.

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 approved by the OCC, OG&E is recovering the Oklahoma jurisdictional portion of these costs over five years.

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 five-year program cycle. The current program cycle, which runs through 2029, 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 refunds state investment tax credits to its Oklahoma customers through the Oklahoma investment tax credit 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 removal costs previously recovered from ratepayers.

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, and regulatory assets and liabilities.

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 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 $4.1 million and $2.0 million at December 31, 2025 and 2024, 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 or when certain requirements are met. 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. OG&E held $112.0 million and $148.3 million of fuel inventory at December 31, 2025 and 2024, 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, 2025 (In millions)	Percentage Ownership			Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)		77	%	$	254.6	$	81.6	$	173.0
Redbud Plant (A)(B)		51	%	$	582.1	$	261.1	$	321.0

(A)

Construction work in progress was $0.1 million and $25.8 million for the McClain and Redbud Plants, respectively.

(B)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.


December 31, 2024 (In millions)	Percentage Ownership			Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)		77	%	$	244.4	$	75.8	$	168.6
Redbud Plant (A)(B)		51	%	$	556.7	$	247.7	$	309.0

(A)

Construction work in progress was $0.8 million and $5.1 million for the McClain and Redbud Plants, respectively.

(B)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.

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


December 31, 2025 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
OG&E:
Distribution assets	$	7,075.1	$	1,744.3	$	5,330.8
Electric generation assets (A)		5,873.5		2,285.0		3,588.5
Transmission assets (B)		3,524.8		781.1		2,743.7
Intangible plant		2.5		0.7		1.8
Other property and equipment		1,465.9		406.4		1,059.5
OG&E property, plant and equipment		17,941.8		5,217.5		12,724.3
Non-OG&E property, plant and equipment		6.1		—		6.1
Total OGE Energy property, plant and equipment	$	17,947.9	$	5,217.5	$	12,730.4

(A)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.

(B)

This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.


December 31, 2024 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
OG&E:
Distribution assets	$	6,654.5	$	1,639.8	$	5,014.7
Electric generation assets (A)		5,518.5		2,145.9		3,372.6
Transmission assets (B)		3,432.1		748.5		2,683.6
Intangible plant		752.3		203.7		548.6
Other property and equipment		705.3		244.3		461.0
OG&E property, plant and equipment		17,062.7		4,982.2		12,080.5
Non-OG&E property, plant and equipment		6.1		—		6.1
Total OGE Energy property, plant and equipment	$	17,068.8	$	4,982.2	$	12,086.6

(A)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.

(B)

This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.

OG&E's unamortized computer software costs were $631.7 million and $280.9 million at December 31, 2025 and 2024, respectively. OG&E's amortization expense for computer software costs was $44.4 million, $32.7 million and $33.4 million for the years ended December 31, 2025, 2024 and 2023, respectively. At December 31, 2025, and in such table above, unamortized software costs are included within the various functional areas to which the software relates, with the majority of the costs categorized within other property and equipment. At December 31, 2024, and in such table above, unamortized computer software costs are included in intangible plant. The increase in unamortized computer software costs was primarily due to a new enterprise resource planning system implementation in 2025.

Depreciation and Amortization

Depreciation expense was $442.5 million, $436.6 million and $421.6 million for the years ended December 31, 2025, 2024 and 2023, respectively. The provision for depreciation, which was 2.7 percent, 2.8 percent and 2.8 percent of the average depreciable utility plant for 2025, 2024 and 2023, respectively, is calculated using the straight-line method over the estimated service life of the associated 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 2026, the provision for depreciation is projected to be 2.7 percent of the average depreciable utility plant.

Amortization of intangible and software assets is calculated using the straight-line method. Of the remaining related amortizable plant balance at December 31, 2025, 36.81 percent will be amortized over 13.1 years, 62.90 percent will be amortized over 19.5 years, and the remaining 0.29 percent will be amortized over 23.4 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 three to 68 years. Asset retirement obligations are included in Other Deferred Credits and Other Liabilities in the Registrants' balance sheets.

The following table presents changes to OG&E's asset retirement obligations during the years ended December 31, 2025 and 2024.


(In millions)	2025			2024
Balance at January 1	$	84.6		$	81.3
Accretion expense		0.8			0.9
Liabilities settled (A)		(7.6	)		(0.2	)
Revisions in estimated cash flows (B)		—			2.6
Balance at December 31	$	77.8		$	84.6

(A)

Asset retirement obligations were settled for asbestos removal at OG&E's generating facilities.

(B)

Assumptions changed due to new removal estimates related to wind turbine removal at three of OG&E's wind farms in 2024.

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 $21.8 million and $30.2 million in accrued environmental liabilities at December 31, 2025 and 2024, 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 7.1 percent, 7.1 percent and 7.0 percent for the years ended December 31, 2025, 2024 and 2023, 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 and believes this method provides a reasonable basis for allocating common expenses.

OGE Energy charged operating costs to OG&E of $148.3 million during the year ended December 31, 2023. As a result of OGE Energy's exit of its former midstream business and becoming primarily an electric company, all employees are directly employed by OG&E beginning in 2024. In 2025, 2024 and 2023, OG&E declared $250.0 million, $130.0 million and $500.0 million of dividends, respectively, to OGE Energy.

Accumulated Other Comprehensive Income (Loss)

The following table presents changes in the components of accumulated other comprehensive income (loss) attributable to OGE Energy during 2025 and 2024. 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)			Total
Balance at December 31, 2023	$	(12.1	)	$	(0.8	)	$	5.7		$	(7.2	)
Other comprehensive income (loss) before reclassifications		(0.2	)		—			0.5			0.3
Amounts reclassified from accumulated other comprehensive income (loss)		0.2			0.2			(0.1	)		0.3
Regulatory classification of certain pension costs		3.9			—			—			3.9
Net current period other comprehensive income (loss)		3.9			0.2			0.4			4.5
Balance at December 31, 2024		(8.2	)		(0.6	)		6.1			(2.7	)
Other comprehensive income (loss) before reclassifications		(1.7	)		—			1.4			(0.3	)
Amounts reclassified from accumulated other comprehensive income (loss)		0.3			0.2			(0.1	)		0.4
Net current period other comprehensive income (loss)		(1.4	)		0.2			1.3			0.1
Balance at December 31, 2025	$	(9.6	)	$	(0.4	)	$	7.4		$	(2.6	)

The following table presents significant amounts reclassified out of accumulated other comprehensive income (loss) attributable to OGE Energy by the respective line items in net income during the years ended December 31, 2025 and 2024.


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)	2025			2024
Amortization of Pension Plan and Restoration of Retirement Income Plan items:
Actuarial losses	$	(0.4	)	$	(0.3	)	(A)
Prior service cost		(0.3	)		(0.3	)	(A)
		(0.7	)		(0.6	)	Income Before Taxes
		(0.2	)		(0.2	)	Income Tax Expense
	$	(0.5	)	$	(0.4	)	Net Income

Amortization of postretirement benefit plans items:
Actuarial gains	$	0.2		$	0.2		(A)
		0.2			0.2		Income Before Taxes
		0.1			0.1		Income Tax Expense
	$	0.1		$	0.1		Net Income

Total reclassifications for the period, net of tax	$	(0.4	)	$	(0.3	)	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).

Legislative Matters

Oklahoma

In May 2025, SB 998 was passed into law and became effective August 29, 2025. This legislation allows rate-regulated retail electric service providers, such as OG&E, to receive CWIP recovery of new natural gas generation capacity, if those proposed generation sources are approved by the OCC under existing statutory review procedures, and sets specific timelines for the OCC to review proposed projects. SB 998 also allows utilities to establish a regulatory asset to defer 90 percent of depreciation expense and return associated with qualified plant investments, that are not classified as transmission or new generation, for recovery over an allowed 20-year period in a future rate review filing.

Arkansas

In March 2025, Act 373 was signed into law by the Governor of Arkansas. Act 373 enables rate-regulated retail electric providers, such as OG&E, to receive CWIP recovery of "strategic investments," including (i) new electric generating facilities, including transportation and storage facilities for associated fuel, (ii) upgrades, expansions, or fuel conversions of electric generating facilities, including transportation and storage facilities for associated fuel, and (iii) new or upgraded electric transmission facilities, including substations. All projects are subject to review and approval by the APSC. Act 373 further authorizes use of a rider to recover approved strategic investments that are not being recovered through previously approved rates, upon approval of the project by the APSC.

Schedule II (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2025

Dec. 31, 2024

Dec. 31, 2023

SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]

Valuation Allowances and Reserves, Beginning Balance

$ 2.0

$ 2.2

$ 1.9

Valuation Allowances and Reserves, Charged to Cost and Expense

7.5

4.0

5.7

SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction

^[1]

5.4

4.2

5.4

Valuation Allowances and Reserves, Ending Balance

$ 4.1

$ 2.0

$ 2.2

[1]	Uncollectible accounts receivable written off, net of recoveries.

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Name Regulation S-X (SX)
-Number 210
-Section 12
-Subsection 09
-Paragraph Column E
-Publisher SEC

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Name Regulation S-X (SX)
-Number 210
-Section 12
-Subsection 09
-Paragraph Column D
-Publisher SEC

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Name Regulation S-X (SX)
-Number 210
-Section 12
-Subsection 09
-Paragraph Column C
-Subparagraph (1)
-Publisher SEC

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Name Regulation S-X (SX)
-Number 210
-Section 12
-Subsection 09
-Paragraph Column C
-Subparagraph (2)
-Publisher SEC

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Name Regulation S-X (SX)
-Number 210
-Section 12
-Subsection 09
-Paragraph Column B
-Publisher SEC

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S50
-Paragraph 5
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480738/235-10-S50-5

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 4
-Subparagraph (SX 210.12-09(Column C)(2))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480678/235-10-S99-4

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 4
-Subparagraph (SX 210.12-09(Column C)(1))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480678/235-10-S99-4

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 4
-Subparagraph (SX 210.12-09(Column B))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480678/235-10-S99-4

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 4
-Subparagraph (SX 210.12-09(Column E))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480678/235-10-S99-4

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 4
-Subparagraph (SX 210.12-09(Column D))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480678/235-10-S99-4

Retirement Plans and Postretirement Benefit Plans [Abstract]

Retirement Plans and Postretirement Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2025

Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets

The details of the funded status of OGE Energy's Pension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans and the amounts included in the balance sheets for 2025 and 2024 are included in the following tables. These amounts have been recorded in Accrued Benefit Obligations with the offset in Accumulated Other Comprehensive Loss (except OG&E's portion, which is recorded as a regulatory asset as discussed in Note 1) in the balance sheets. The amounts in Accumulated Other Comprehensive Loss and those recorded as a regulatory asset represent a net periodic benefit cost to be recognized in the statements of income in future periods. The benefit obligation for OGE Energy's Pension Plan and the Restoration of Retirement Income Plan represents the projected benefit obligation, while the benefit obligation for the postretirement benefit plans represents the accumulated postretirement benefit obligation. The accumulated postretirement benefit obligation for OGE Energy's Pension Plan and Restoration of Retirement Income Plan differs from the projected benefit obligation in that the former includes no assumption about future compensation levels.


	OGE Energy												OG&E
	Pension Plan						Restoration of Retirement Income Plan						Pension Plan						Restoration of Retirement Income Plan
December 31 (In millions)	2025			2024			2025			2024			2025			2024			2025			2024
Change in benefit obligation
Beginning obligations	$	303.1		$	303.7		$	7.0		$	5.5		$	263.9		$	238.6		$	1.4		$	—
Service cost		5.4			5.3			1.0			1.0			5.4			5.3			0.1			0.1
Interest cost		16.2			15.6			0.4			0.3			14.1			13.4			0.1			0.1
Regulatory classification of certain pension costs		—			—			—			—			—			23.9			—			1.1
Special termination benefits		0.5			—			—			—			0.5			—			—			—
Actuarial losses (gains)		11.5			(2.9	)		0.9			0.2			8.9			(2.2	)		0.3			0.1
Benefits paid		(21.5	)		(18.6	)		—			—			(18.9	)		(15.1	)		—			—
Ending obligations	$	315.2		$	303.1		$	9.3		$	7.0		$	273.9		$	263.9		$	1.9		$	1.4

Change in plans' assets
Beginning fair value	$	246.9		$	243.7		$	—		$	—		$	211.6		$	191.4		$	—		$	—
Actual return on plans' assets		23.3			11.8			—			—			20.0			10.1			—			—
Employer contributions		13.5			10.0			—			—			13.5			10.0			—			—
Regulatory classification of certain pension costs		—			—			—			—			—			15.2			—			—
Benefits paid		(21.5	)		(18.6	)		—			—			(18.9	)		(15.1	)		—			—
Ending fair value	$	262.2		$	246.9		$	—		$	—		$	226.2		$	211.6		$	—		$	—
Funded status at end of year	$	(53.0	)	$	(56.2	)	$	(9.3	)	$	(7.0	)	$	(47.7	)	$	(52.3	)	$	(1.9	)	$	(1.4	)
Accumulated postretirement benefit obligation	$	305.6		$	289.4		$	8.9		$	6.8		$	264.3		$	250.2		$	1.7		$	1.4

For the year ended December 31, 2025, Pension Plan actuarial losses were primarily due to an updated experience study and a decreased discount rate. For the year ended December 31, 2024, Pension Plan actuarial gains were primarily due to an increased discount rate, partially offset by an increased interest crediting rate.


	OGE Energy						OG&E
	Postretirement Benefit Plans						Postretirement Benefit Plans
December 31 (In millions)	2025			2024			2025			2024
Change in benefit obligation
Beginning obligations	$	98.1		$	103.3		$	74.7		$	77.3
Service cost		0.1			0.1			0.1			0.1
Interest cost		5.4			5.2			4.1			3.9
Participants' contributions		2.5			3.5			1.8			2.4
Actuarial gains		(3.8	)		(3.1	)		(1.9	)		(2.1	)
Regulatory classification of certain pension costs		—			—			—			1.4
Benefits paid		(11.9	)		(10.9	)		(9.1	)		(8.3	)
Ending obligations	$	90.4		$	98.1		$	69.7		$	74.7

Change in plans' assets
Beginning fair value	$	30.0		$	32.7		$	27.2		$	29.6
Actual return on plans' assets		1.8			(1.6	)		1.7			(1.4	)
Employer contributions		6.0			6.3			4.6			4.9
Participants' contributions		2.5			3.5			1.8			2.4
Benefits paid		(11.9	)		(10.9	)		(9.1	)		(8.3	)
Ending fair value	$	28.4		$	30.0		$	26.2		$	27.2
Funded status at end of year	$	(62.0	)	$	(68.1	)	$	(43.5	)	$	(47.5	)

Schedule of Defined Benefit Plans Disclosures

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 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 Income (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 Income (Expense) in the statements of income.


OGE Energy	Pension Plan									Restoration of Retirement Income Plan
Year Ended December 31 (In millions)	2025			2024			2023			2025		2024		2023
Service cost	$	5.4		$	5.3		$	5.4		$	1.0	$	1.0	$	1.0
Interest cost		16.2			15.6			15.9			0.4		0.3		0.3
Expected return on plan assets		(16.5	)		(16.5	)		(16.2	)		—		—		—
Amortization of net loss		6.2			6.5			8.0			0.1		—		—
Special termination benefits		0.5			—			—			—		—		—
Amortization of unrecognized prior service cost (A)		—			—			—			0.3		0.3		0.3
Settlement cost		—			—			21.8			—		—		0.5
Net periodic benefit cost	$	11.8		$	10.9		$	34.9		$	1.8	$	1.6	$	2.1

(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.


OG&E	Pension Plan									Restoration of Retirement Income Plan
Year Ended December 31 (In millions)	2025			2024			2023			2025		2024		2023
Service cost	$	5.4		$	5.3		$	4.4		$	0.1	$	0.1	$	—
Interest cost		14.1			13.4			12.6			0.1		0.1		—
Expected return on plan assets		(14.2	)		(14.0	)		(12.9	)		—		—		—
Amortization of net loss		5.9			6.2			6.9			—		—		—
Special termination benefits		0.5			—			—			—		—		—
Settlement cost		—			—			20.4			—		—		0.4
Total net periodic benefit cost		11.7			10.9			31.4			0.2		0.2		0.4
Plus: Amount allocated from OGE Energy		—			—			3.0			1.6		1.4		1.7
Net periodic benefit cost	$	11.7		$	10.9		$	34.4		$	1.8	$	1.6	$	2.1

In addition to the net periodic benefit cost amounts recognized, as presented in the table above, for the Pension and Restoration of Retirement Income Plans in 2025, 2024 and 2023, the Registrants recognized the following:


Year Ended December 31 (In millions)	2025			2024		2023
Change in pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	(0.4	)	$	5.8	$	33.3
Deferral of pension expense related to pension settlement and special termination benefits charges included in the above line item:
Oklahoma jurisdiction (A)	$	0.5		$	—	$	20.1
Arkansas jurisdiction (A)	$	—		$	—	$	1.9

(A)

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


	OGE Energy									OG&E
	Postretirement Benefit Plans									Postretirement Benefit Plans
Year Ended December 31 (In millions)	2025			2024			2023			2025			2024			2023
Service cost	$	0.1		$	0.1		$	0.1		$	0.1		$	0.1		$	0.1
Interest cost		5.4			5.2			5.2			4.1			3.9			3.9
Expected return on plan assets		(1.7	)		(1.6	)		(1.7	)		(1.5	)		(1.4	)		(1.6	)
Amortization of net loss (gain)		0.4			(0.2	)		(0.2	)		0.6			—			—
Total net periodic benefit cost		4.2			3.5			3.4			3.3			2.6			2.4
Plus: Amount allocated from OGE Energy											0.4			0.5			0.5
Net periodic benefit cost	$	4.2		$	3.5		$	3.4		$	3.7		$	3.1		$	2.9

In addition to the net periodic benefit cost or income amounts recognized, as presented in the table above, for the postretirement benefit plans in 2025, 2024 and 2023, the Registrants recognized the following:


Year Ended December 31 (In millions)	2025		2024		2023
Change in postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	0.6	$	2.3	$	4.4

(A)

Included in the pension regulatory asset, as indicated in the regulatory assets and liabilities table in Note 1.

Schedule of Capitalized Pension and Postretirement Cost

The following table presents the amount of net periodic benefit cost capitalized and attributable to each of the Registrants for OGE Energy's Pension Plan and postretirement benefit plans in 2025, 2024 and 2023.


	OGE Energy						OG&E
(In millions)	2025		2024		2023		2025		2024		2023
Capitalized portion of net periodic pension benefit cost	$	2.4	$	2.2	$	2.2	$	2.4	$	2.2	$	1.9
Capitalized portion of net periodic postretirement benefit cost	$	—	$	0.1	$	0.1	$	—	$	0.1	$	0.1

Schedule of Assumptions Used

Rate Assumptions


	Pension Plan and Restoration of Retirement Income Plan									Postretirement Benefit Plans
Year Ended December 31	2025			2024			2023			2025			2024			2023
Assumptions to determine benefit obligations:
Discount rate		5.45	%		5.70	%		5.40	%		5.45	%		5.70	%		5.35	%
Rate of compensation increase		4.20	%		4.20	%		4.20	%	N/A			N/A			N/A
Interest crediting rate		4.25	%		4.25	%		3.50	%	N/A			N/A			N/A
Assumptions to determine net periodic benefit cost:
Discount rate		5.70	%		5.40	%		5.45	%		5.70	%		5.35	%		5.40	%
Expected return on plan assets		7.00	%		7.00	%		7.00	%		4.50	%		4.00	%		4.00	%
Rate of compensation increase		4.20	%		4.20	%		4.20	%	N/A			N/A			N/A
Interest crediting rate		4.25	%		3.50	%		3.50	%	N/A			N/A			N/A

N/A - not applicable

Projected Benefit Obligation Funded Status Thresholds

The Pension Plan assets are held in a trust which follows an investment policy and strategy designed to reduce the funded status volatility of the Plan by utilizing liability driven investing. The purpose of liability-driven investing is to structure the asset portfolio to more closely resemble the pension liability and thereby more effectively hedge against changes in the liability. The investment policy follows a glide path approach that shifts a higher portfolio weighting to fixed income as the Plan's funded status increases. The following table presents the targeted fixed income and equity allocations at different funded status levels.


Projected Benefit Obligation Funded Status Thresholds	<90%	95%	100%	105%	110%	115%	120%
Fixed income	50%	58%	65%	73%	80%	85%	90%
Equity	50%	42%	35%	27%	20%	15%	10%
Total	100%	100%	100%	100%	100%	100%	100%

Pension Plan Equity Asset Allocation Table

Within the portfolio's overall allocation to equities, the funds are allocated according to the guidelines in the following table.


Asset Class	Target Allocation	Minimum	Maximum
Domestic Large Cap Equity	40%	35%	60%
Domestic Mid-Cap Equity	15%	5%	25%
Domestic Small-Cap Equity	25%	5%	30%
International Equity	20%	10%	30%

Schedule of Allocation of Plan Assets

The following tables present the postretirement benefit plans' investments that are measured at fair value on a recurring basis at December 31, 2025 and 2024. There were no Level 2 investments held by the postretirement benefit plans at December 31, 2025 and 2024.


(In millions)	December 31, 2025			Level 1		Level 3
Group retiree medical insurance contract	$	8.7		$	—	$	8.7
Mutual funds		19.7			19.7		—
Total OGE Energy plan investments	$	28.4		$	19.7	$	8.7
Plan investments attributable to affiliates		(2.2	)
Total OG&E plan investments	$	26.2


(In millions)	December 31, 2024			Level 1		Level 3
Group retiree medical insurance contract	$	13.6		$	—	$	13.6
Mutual funds		16.4			16.4		—
Total OGE Energy plan investments	$	30.0		$	16.4	$	13.6
Plan investments attributable to affiliates		(2.8	)
Total OG&E plan investments	$	27.2

Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets

The following table presents a reconciliation of the postretirement benefit plans' investments that are measured at fair value on a recurring basis using significant unobservable inputs (Level 3).


Year Ended December 31 (In millions)	2025
Group retiree medical insurance contract:
Beginning balance	$	13.6
Claims paid		(5.4	)
Interest income		0.3
Realized gains		0.1
Investment fees		(0.1	)
Net unrealized gains related to instruments held at the reporting date		0.2
Ending balance	$	8.7

Schedule of Expected Benefit Payments

The following table presents the benefit payments the Registrants expect to pay related to the Pension Plan and Restoration of Retirement Income Plan. These expected benefits are based on the same assumptions used to measure the Registrants' benefit obligation at the end of the year and include benefits attributable to estimated future employee service.


(In millions)	OGE Energy		OG&E
2026	$	59.1	$	52.3
2027	$	42.2	$	30.1
2028	$	33.4	$	29.4
2029	$	30.6	$	27.5
2030	$	29.3	$	25.4
2031-2035	$	120.9	$	105.9

The Medicare Prescription Drug, Improvement and Modernization Act of 2003 expanded coverage for prescription drugs. The following table presents the gross benefit payments the Registrants expect to pay related to the postretirement benefit plans, including prescription drug benefits.


(In millions)	OGE Energy		OG&E
2026	$	12.1	$	9.1
2027	$	9.6	$	7.2
2028	$	8.9	$	6.8
2029	$	8.3	$	6.5
2030	$	7.9	$	6.1
2031-2035	$	33.3	$	26.0

Defined Benefit Plan, Plan Assets, Category

The following tables present the Pension Plan's investments that are measured at fair value on a recurring basis at December 31, 2025 and 2024. There were no Level 3 investments held by the Pension Plan at December 31, 2025 and 2024.


(In millions)	December 31, 2025			Level 1		Level 2		Net Asset Value (A)
Common stocks	$	38.0		$	38.0	$	—	$	—
U.S. Treasury notes and bonds (B)		41.3			41.3		—		—
Mortgage- and asset-backed securities		22.3			—		22.3		—
Corporate fixed income and other securities		51.9			—		51.9		—
Commingled fund (C)		18.7			—		—		18.7
Foreign government bonds		0.1			—		0.1		—
U.S. municipal bonds		0.1			—		0.1		—
Money market fund		10.6			—		—		10.6
Mutual funds		83.0			83.0		—		—
U.S. Treasury futures:
Cash collateral		0.9			0.9		—		—
Forward contracts:
Receivable (foreign currency)		0.1			—		0.1		—
Total Pension Plan investments		267.0		$	163.2	$	74.5	$	29.3
Interest and dividends receivable		1.4
Receivable from broker for securities sold		9.0
Payable to broker for securities purchased		(15.2	)
Total OGE Energy Pension Plan assets	$	262.2
Pension Plan investments attributable to affiliates		(36.0	)
Total OG&E Pension Plan assets	$	226.2


(In millions)	December 31, 2024			Level 1		Level 2		Net Asset Value (A)
Common stocks	$	55.7		$	55.7	$	—	$	—
U.S. Treasury notes and bonds (B)		49.3			49.3		—		—
Mortgage- and asset-backed securities		23.9			—		23.9		—
Corporate fixed income and other securities		50.3			—		50.3		—
Commingled fund (C)		13.4			—		—		13.4
Foreign government bonds		0.3			—		0.3		—
U.S. municipal bonds		0.1			—		0.1		—
Money market fund		0.9			—		—		0.9
Mutual funds		62.0			62.0		—		—
Preferred stocks		0.5			0.5		—		—
U.S. Treasury futures:
Cash collateral		0.1			0.1		—		—
Forward contracts:
Receivable (foreign currency)		0.1			—		0.1		—
Total Pension Plan investments		256.6		$	167.6	$	74.7	$	14.3
Interest and dividends receivable		1.5
Receivable from broker for securities sold		9.1
Payable to broker for securities purchased		(20.3	)
Total OGE Energy Pension Plan assets	$	246.9
Pension Plan investments attributable to affiliates		(35.3	)
Total OG&E Pension Plan assets	$	211.6

(A)

GAAP allows the measurement of certain investments that do not have a readily determinable fair value at the net asset value. These investments do not consider the observability of inputs; therefore, they are not included within the fair value hierarchy.

(B)

This category represents U.S. Treasury notes and bonds with a Moody's Investors Service rating of Aaa and Government Agency Bonds with a Moody's Investors Service rating of A1 or higher.

(C)

This category represents units of participation in a commingled fund that primarily invested in stocks of international companies and emerging markets.

CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Revenues from contracts with customers	$ 3,190.9	$ 2,916.6	$ 2,607.3
Other revenues	69.2	68.7	67.0
Operating revenues	3,260.1	2,985.3	2,674.3
FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE	1,259.9	1,076.4	911.7
OPERATING EXPENSES
Other operation and maintenance	531.6	514.4	502.6
Depreciation and amortization	559.8	539.5	506.6
Taxes other than income	109.4	109.7	103.2
Operating expenses	1,200.8	1,163.6	1,112.4
OPERATING INCOME	799.4	745.3	650.2
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction	26.0	25.5	19.4
Other net periodic benefit (expense) income	(11.0)	(2.2)	5.6
Other income	39.4	30.6	48.2
Other expense	(23.0)	(24.1)	(29.0)
Net other income	31.4	29.8	44.2
INTEREST EXPENSE
Interest on long-term debt	261.0	228.3	205.0
Allowance for borrowed funds used during construction	(15.8)	(14.6)	(7.1)
Interest on short-term debt and other interest charges	25.1	40.8	23.5
Interest expense	270.3	254.5	221.4
INCOME BEFORE TAXES	560.5	520.6	473.0
INCOME TAX EXPENSE	89.8	79.1	56.2
NET INCOME	$ 470.7	$ 441.5	$ 416.8
BASIC AVERAGE COMMON SHARES OUTSTANDING	201.9	200.8	200.3
DILUTED AVERAGE COMMON SHARES OUTSTANDING	202.5	201.3	200.9
BASIC EARNINGS PER AVERAGE COMMON SHARE	$ 2.33	$ 2.20	$ 2.08
DILUTED EARNINGS PER AVERAGE COMMON SHARE	$ 2.32	$ 2.19	$ 2.07
Other comprehensive income, net of tax	$ 0.1	$ 4.5	$ 4.7
Comprehensive income	470.8	446.0	421.5
OG&E [Member]
Revenues from contracts with customers	3,190.9	2,916.6	2,607.3
Other revenues	69.2	68.7	67.0
Operating revenues	3,260.1	2,985.3	2,674.3
FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE	1,259.9	1,076.4	911.7
OPERATING EXPENSES
Other operation and maintenance	531.0	514.1	505.0
Depreciation and amortization	559.8	539.5	506.6
Taxes other than income	109.4	109.7	99.4
Operating expenses	1,200.2	1,163.3	1,111.0
OPERATING INCOME	800.0	745.6	651.6
OTHER INCOME (EXPENSE)
Allowance for equity funds used during construction	26.0	25.5	19.4
Other net periodic benefit (expense) income	(10.3)	(1.6)	6.5
Other income	17.3	12.5	23.9
Other expense	(2.6)	(4.5)	(6.3)
Net other income	30.4	31.9	43.5
INTEREST EXPENSE
Interest on long-term debt	237.8	212.0	200.4
Allowance for borrowed funds used during construction	(15.8)	(14.6)	(7.1)
Interest on short-term debt and other interest charges	3.5	17.0	6.6
Interest expense	225.5	214.4	199.9
INCOME BEFORE TAXES	604.9	563.1	495.2
INCOME TAX EXPENSE	105.1	93.2	68.8
NET INCOME	499.8	469.9	426.4
Other comprehensive income, net of tax	0.0	0.0	0.0
Comprehensive income	$ 499.8	$ 469.9	$ 426.4

Leases

12 Months Ended

Dec. 31, 2025

Leases [Abstract]

Leases

4. Leases

Based on their evaluation of all contracts under ASC 842, as described in Note 1, the Registrants concluded they have operating lease obligations as described below.

OG&E Railcar Lease Agreement

Effective February 1, 2024, OG&E renewed its railcar lease agreement for 770 rotary gondola railcars to transport coal from Wyoming to OG&E's coal-fired generation units. Rental payments are charged to fuel expense and are recoverable through OG&E's fuel adjustment clauses. On February 1, 2029, OG&E has the option to either purchase the railcars at a stipulated fair market value or renew the lease. If OG&E chooses not to purchase the railcars or renew the lease agreement, it would be responsible for the difference between the actual fair value of the railcars and the stipulated fair market value, up to a maximum of $3.2 million. OG&E held an additional railcar lease agreement for 135 rotary gondola railcars to transport coal with a term of October 1, 2022 to December 31, 2025, which was not renewed.

OG&E Wind Farm Land Lease Agreements

OG&E has operating leases related to land for OG&E's Centennial, OU Spirit and Crossroads wind farms with terms of seven to 11 years remaining, depending on the lease. The Centennial lease has rent escalations which increase annually based on the Consumer Price Index. While lease liabilities are not remeasured as a result of changes to the Consumer Price Index, changes to the Consumer Price Index are treated as variable lease payments and recognized in the period in which the obligation for those payments was incurred. The OU Spirit and Crossroads leases each have rent escalations which increase after five and ten years. Although the leases are cancellable, OG&E is required to make annual lease payments as long as the wind turbines are located on the land. OG&E does not expect to terminate the leases until the wind turbines reach the end of their useful life.

Financial Statement Information and Maturity Analysis of Lease Liabilities

The following tables present amounts recognized for operating leases in the Registrants' statements of income, statements of cash flows and balance sheets and supplemental information related to those amounts recognized.


OGE Energy and OG&E	Year Ended December 31,
(In millions)	2025		2024		2023
Operating lease cost	$	5.2	$	4.7	$	6.4
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases	$	4.9	$	4.5	$	5.2
Right-of-use assets obtained in exchange for new operating lease liabilities	$	—	$	5.7	$	—


OGE Energy and OG&E
(Dollars in millions)	December 31, 2025			December 31, 2024
Right-of-use assets at period end (A)	$	25.0		$	28.3
Operating lease liabilities at period end (B)	$	29.2		$	32.7
Operating lease weighted-average remaining lease term (in years)		9.0			9.7
Operating lease weighted-average discount rate		4.1	%		4.2	%

(A)

Included in Property, Plant and Equipment in the Registrants' balance sheets.

(B)

Included in Other Deferred Credits and Other Liabilities in the Registrants' balance sheets.

The following table presents a maturity analysis of the Registrants' operating lease liabilities.


OGE Energy and OG&E
Future minimum operating lease payments as of December 31:
(In millions)
2026	$	4.3
2027		4.3
2028		4.3
2029		3.2
2030		3.5
Thereafter		16.1
Total future minimum lease payments		35.7
Less: Imputed interest		6.5
Present value of net minimum lease payments	$	29.2

Credit Facilities and Short-Term Debt

12 Months Ended

Dec. 31, 2025

Short-Term Debt [Abstract]

Credit Facilities and Short-Term Debt

10. Credit Facilities and Short-Term Debt

The Registrants borrow, as necessary, by the issuance of commercial paper and by borrowings under their revolving credit agreements.

The following table presents information regarding the Registrants' revolving credit agreements at December 31, 2025.


Entity	Aggregate Commitment		Amount Outstanding (A)		Weighted-Average Interest Rate				Expiration
	(In millions)
OGE Energy (B)	$	550.0	$	292.0		4.12	%	(F)	December 18, 2029
OGE Energy (C)		60.0		—		—		(F)	May 24, 2027
OG&E (D)(E)		550.0		0.4		1.20	%	(F)	December 18, 2029
Total	$	1,160.0	$	292.4		4.12	%

(A)

(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)

(D)

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.

(E)

(F)

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

OGE Energy's credit facility has a financial covenant requiring that OGE Energy maintains a maximum debt to capitalization ratio of 70 percent, as defined in such facility. OG&E's credit facility has a financial covenant requiring that OG&E maintains a maximum debt to capitalization ratio of 65 percent, as defined in such facility. The Registrants' facilities each also contain covenants which restrict the respective borrower and certain of its subsidiaries in respect of, among other things, mergers and consolidations, sales of all or substantially all assets, incurrence of liens and transactions with affiliates. The Registrants' facilities are each subject to acceleration upon the occurrence of any default, including, among others, payment defaults on such facilities, breach of representations, warranties and covenants, acceleration of indebtedness (other than intercompany and non-recourse indebtedness) of $100.0 million or more in the aggregate, change of control (as defined in each such facility), nonpayment of uninsured judgments in excess of $100.0 million and the occurrence of certain Employee Retirement Income Security Act and bankruptcy events, subject where applicable to specified cure periods.

The Registrants' ability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions. Pricing grids associated with the Registrants' credit facilities could cause annual fees and borrowing rates

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

OG&E must obtain regulatory approval from the FERC in order to borrow on a short-term basis. OG&E has the necessary regulatory approvals to incur up to $1.0 billion in short-term borrowings at any one time for a two-year period beginning January 1, 2025 and ending December 31, 2026.

Common Equity - Automatic Dividend Reinvestment and Stock Purchase Plan - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Class of Stock [Line Items]
Stock Issued During Period, Shares, New Issues	234,476	255,578	82,321
Proceeds from issuance of common stock	$ 203.8	$ 17.1	$ 0.0
Automatic Dividend Reinvestment and Stock Purchase Plan [Member]
Class of Stock [Line Items]
Stock Issued During Period, Shares, New Issues	269,387
Proceeds from issuance of common stock	$ 11.9
Shares Held in Reserve Related to Dividend Reinvestment Plan and Stock Purchase Plan	4,053,120

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Credit Facilities and Short-Term Debt - Additional Information (Details) - USD ($)

Dec. 31, 2025

Dec. 31, 2024

Acceleration of Indebtedness of Credit Facility

Short-term debt

$ 292,000,000

$ 469,300,000

100,000,000

Nonpayment of Uninsured Judgments

100,000,000

Outstanding Intercompany Borrowings

Line of Credit Facility, Current Borrowing Capacity

^[1]

$ 550,000,000

OGE Energy [Member] | Maximum [Member]

Ratio of Consolidated Debt to Consolidated Capitalization

70.00%

Line of Credit Facility, Current Borrowing Capacity

^[2],[3]

$ 550,000,000

Short Term Borrowing Capacity That Has Regulatory Approval

$ 1,000,000,000

Ratio of Consolidated Debt to Consolidated Capitalization

65.00%

[1]	This bank facility is available to back up OGE Energy's commercial paper borrowings and to provide revolving credit borrowings. This bank facility can also be used as a letter of credit facility.
[2]	OG&E has an intercompany borrowing agreement with OGE Energy whereby OG&E has access to up to $450.0 million of OGE Energy's revolving credit amount. This agreement has a termination date of December 18, 2029. At December 31, 2025, there was $78.3 million in advances to parent, and there were no borrowings under the intercompany borrowing agreement.
[3]	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.

Income Taxes - Schedule of Effective Income Tax Rate Reconciliation (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2025

Dec. 31, 2024

Dec. 31, 2023

Income Taxes [Line Items]

Statutory federal tax rate, amount

$ 117.7

$ 109.3

$ 99.3

Tax Jurisdiction of Domicile [Extensible Enumeration]

us-gaap:DomesticCountryMember

Statutory federal tax rate

21.00%

State income taxes, net of federal income tax benefit, amount

^[1]

$ 8.5

$ 7.3

$ (12.6)

State income taxes, net of federal income tax benefit

^[1]

1.50%

1.40%

(2.70%)

Amortization of net unfunded deferred taxes, amount

$ (32.3)

$ (32.6)

$ (33.2)

Amortization of net unfunded deferred taxes

(5.70%)

(6.30%)

(7.00%)

Federal tax credits, amount

$ (2.6)

$ (3.6)

Federal tax credits

(0.50%)

(0.80%)

Uncertain tax position, amount

$ 0.0

$ 6.2

Uncertain tax position

0.00%

1.30%

Nontaxable or nondeductible items, amount

$ (1.5)

$ (2.3)

$ 0.1

Nontaxable or nondeductible items

(0.30%)

(0.40%)

0.10%

Effective income tax rate, amount

$ 89.8

$ 79.1

$ 56.2

Effective income tax rate

16.00%

15.20%

11.90%

Statutory federal tax rate, amount

Income Taxes [Line Items]

$ 127.0

$ 118.3

$ 104.0

Statutory federal tax rate

21.00%

State income taxes, net of federal income tax benefit, amount

^[1]

$ 10.5

$ 9.1

$ 0.8

State income taxes, net of federal income tax benefit

^[1]

1.80%

1.60%

0.20%

Amortization of net unfunded deferred taxes, amount

$ (32.3)

$ (32.6)

$ (33.2)

Amortization of net unfunded deferred taxes

(5.30%)

(5.80%)

(6.70%)

Federal tax credits, amount

$ (2.6)

$ (3.6)

Federal tax credits

(0.50%)

(0.40%)

(0.80%)

Nontaxable or nondeductible items, amount

$ 2.5

$ 1.0

$ 0.8

Nontaxable or nondeductible items

0.40%

0.20%

Effective income tax rate, amount

$ 105.1

$ 93.2

$ 68.8

Effective income tax rate

17.40%

16.60%

13.90%

[1]	In 2025, state taxes in Oklahoma made up the majority (greater than 50 percent) of the tax effect in this category.

Stock Based Compensation (Tables)

12 Months Ended

Dec. 31, 2025

Stock-Based Compensation [Abstract]

Schedule of Pre-tax Compensation Expense and Related Income Tax Benefit

The following table presents the Registrants' pre-tax compensation expense and related income tax benefit for the years ended December 31, 2025, 2024 and 2023 related to performance units and restricted stock units for the Registrants' employees.


	OGE Energy						OG&E
Year Ended December 31 (In millions)	2025		2024		2023		2025		2024		2023
Performance units	$	9.6	$	7.9	$	9.3	$	9.6	$	7.9	$	2.2
Restricted stock units		4.4		3.8		3.8		4.4		3.8		0.9
Total compensation expense	$	14.0	$	11.7	$	13.1	$	14.0	$	11.7	$	3.1
Income tax benefit	$	3.4	$	2.8	$	3.2	$	3.4	$	2.8	$	0.7

Schedule of Performance Units Granted and Assumptions Used to Calculate Grant Date Fair Value of Performance Units

The following table presents the number of performance units granted and the assumptions used to calculate the grant date fair value of the performance units.


	OGE Energy									OG&E
	2025			2024			2023			2025			2024			2023
Number of units granted		216,426			275,499			213,442			216,426			275,499			65,069
Fair value of units granted	$	55.43		$	35.86		$	43.74		$	55.43		$	35.86		$	43.74
Expected dividend yield		3.8	%		5.1	%		4.2	%		3.8	%		5.1	%		4.2	%
Expected price volatility		20.0	%		19.9	%		31.0	%		20.0	%		19.9	%		31.0	%
Risk-free interest rate		4.28	%		4.41	%		4.47	%		4.28	%		4.41	%		4.47	%
Expected life of units (in years)		2.87			2.86			2.85			2.87			2.86			2.85

Schedule of Restricted Stock Units Granted and Grant Date Fair Value

The following table presents the number of restricted stock units granted and the grant date fair value.


	OGE Energy						OG&E
	2025		2024		2023		2025		2024		2023
Restricted stock units granted		121,056		148,345		114,926		121,056		148,345		35,034
Fair value of restricted stock units granted	$	43.69	$	32.74	$	37.52	$	43.69	$	32.74	$	37.52

Schedule of Activity for Performance Units and Restricted Stock Units

The following table presents a summary of the activity for the Registrants' performance units and restricted stock units for the year ended December 31, 2025.


OGE Energy and OG&E	Performance Units						Restricted Stock Units
(Dollars in millions)	Number of Units				Aggregate Intrinsic Value		Number of Shares			Aggregate Intrinsic Value
Units/shares outstanding at 12/31/24		646,192						244,054
Granted		216,426		(A)				121,056
Converted		(191,918	)	(B)	$	12.5	N/A
Vested	N/A							(100,933	)	$	4.3
Forfeited		(12,756	)					(9,924	)
Units/shares outstanding at 12/31/25		657,944			$	19.7		254,253		$	10.9
Units/shares fully vested at 12/31/25		191,740		(C)	$	8.2	N/A			N/A

(A)

For performance units, this represents the target number of performance units granted. Actual number of performance units earned, if any, is dependent upon performance and may range from zero percent to 200 percent of the target.

(B)

These amounts represent performance units that vested at December 31, 2024, which were settled in February 2025.

(C)

These amounts represent performance units that vested at December 31, 2025. Actual expected amounts to be paid out in 2026 will differ based on the percentage at which the performance metric was met and are dependent upon Compensation Committee approval.

Summary of Activity for Non-vested Performance Units and Restricted Stock Units

The following table presents a summary of the activity for the Registrants' non-vested performance units and restricted stock units for the year ended December 31, 2025.


OGE Energy and OG&E	Performance Units						Restricted Stock Units
	Number of Units				Weighted-Average Grant Date Fair Value		Number of Shares			Weighted-Average Grant Date Fair Value
Units/shares non-vested at 12/31/24		454,274			$	39.28		244,054		$	34.81
Granted		216,426		(A)	$	55.43		121,056		$	43.69
Vested		(191,740	)		$	43.74		(100,933	)	$	42.79
Forfeited		(12,756	)		$	42.49		(9,924	)	$	36.73
Units/shares non-vested at 12/31/25		466,204			$	44.86		254,253		$	37.88

(A)

Summary of Fair Value for Vested Performance Units and Restricted Stock Units

The following table presents a summary of the Registrants' fair value for vested performance units and restricted stock units.


	OGE Energy						OG&E
Year Ended December 31 (In millions)	2025		2024		2023		2025		2024		2023
Performance units	$	8.4	$	7.9	$	9.0	$	8.4	$	7.9	$	2.4
Restricted stock units	$	3.8	$	3.6	$	2.4	$	3.8	$	3.6	$	0.6

Summary of Unrecognized Compensation Cost and Weighted-average Periods Over which Compensation Cost is Expected to be Recognized

The following table presents a summary of the Registrants' unrecognized compensation cost for non-vested performance units and restricted stock units and the weighted-average periods over which the compensation cost is expected to be recognized.


OGE Energy and OG&E December 31, 2025	Unrecognized Compensation Cost (In millions)		Weighted Average to be Recognized (In years)
Performance units	$	10.3		1.72
Restricted stock units		4.6		1.77
Total unrecognized compensation cost	$	14.9

Income Taxes - Schedule of Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Income Taxes [Line Items]
Current Federal Tax Expense	$ 29.3	$ 62.0	$ 46.1
Current State and Local Tax Expense	0.3	0.8	(2.2)
Current Income Tax Expense	29.6	62.8	43.9
Deferred Federal Income Tax Expense	49.7	8.0	18.1
Deferred State and Local Income Tax Expense	10.5	8.3	(5.8)
Deferred Income Tax Expense	60.2	16.3	12.3
Income Tax Expense	89.8	79.1	56.2
OG&E [Member]
Income Taxes [Line Items]
Current Federal Tax Expense	39.9	72.7	48.9
Current State and Local Tax Expense	2.7	3.0	3.7
Current Income Tax Expense	42.6	75.7	52.6
Deferred Federal Income Tax Expense	51.9	9.0	18.8
Deferred State and Local Income Tax Expense	10.6	8.5	(2.6)
Deferred Income Tax Expense	62.5	17.5	16.2
Income Tax Expense	$ 105.1	$ 93.2	$ 68.8

Amount of current income tax expense (benefit) and deferred income tax expense (benefit) pertaining to continuing operations.

Reference 1: http://www.xbrl.org/2003/role/exampleRef
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Reference 3: http://www.xbrl.org/2003/role/exampleRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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Reference 10: http://www.xbrl.org/2003/role/disclosureRef
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Investment in Unconsolidated Affiliate (Details)	Jun. 30, 2025 $ / shares
Schedule of Equity Method Investments [Line Items]
Share Price	$ 44.38

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References + Details

Stock-Based Compensation - Performance Units Total Shareholder Return Valuation Assumptions (Details) - Total Shareholder Return [Member] - $ / shares	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	216,426	275,499	213,442
Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 55.43	$ 35.86	$ 43.74
Expected Dividend Rate	3.80%	5.10%	4.20%
Expected Volatility Rate	20.00%	19.90%	31.00%
Risk Free Interest Rate	4.28%	4.41%	4.47%
Expected Term	2 years 10 months 13 days	2 years 10 months 9 days	2 years 10 months 6 days
Og and E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	216,426	275,499	65,069
Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 55.43	$ 35.86	$ 43.74
Expected Dividend Rate	3.80%	5.10%	4.20%
Expected Volatility Rate	20.00%	19.90%	31.00%
Risk Free Interest Rate	4.28%	4.41%	4.47%
Expected Term	2 years 10 months 13 days	2 years 10 months 9 days	2 years 10 months 6 days

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Schedule of Financial Statement Information of Lease Liabilities

Leases (Tables)

12 Months Ended

Dec. 31, 2025

Leases [Abstract]


OGE Energy and OG&E	Year Ended December 31,
(In millions)	2025		2024		2023
Operating lease cost	$	5.2	$	4.7	$	6.4
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows for operating leases	$	4.9	$	4.5	$	5.2
Right-of-use assets obtained in exchange for new operating lease liabilities	$	—	$	5.7	$	—


OGE Energy and OG&E
(Dollars in millions)	December 31, 2025			December 31, 2024
Right-of-use assets at period end (A)	$	25.0		$	28.3
Operating lease liabilities at period end (B)	$	29.2		$	32.7
Operating lease weighted-average remaining lease term (in years)		9.0			9.7
Operating lease weighted-average discount rate		4.1	%		4.2	%

(A)

Included in Property, Plant and Equipment in the Registrants' balance sheets.

(B)

Included in Other Deferred Credits and Other Liabilities in the Registrants' balance sheets.

Schedule of Maturity Analysis of Operating Lease Liabilities

The following table presents a maturity analysis of the Registrants' operating lease liabilities.


OGE Energy and OG&E
Future minimum operating lease payments as of December 31:
(In millions)
2026	$	4.3
2027		4.3
2028		4.3
2029		3.2
2030		3.5
Thereafter		16.1
Total future minimum lease payments		35.7
Less: Imputed interest		6.5
Present value of net minimum lease payments	$	29.2

Stock Based Compensation

12 Months Ended

Dec. 31, 2025

Stock-Based Compensation [Abstract]

Stock-Based Compensation

6. Stock-Based Compensation

In 2022, OGE Energy adopted, and its shareholders approved, the 2022 Stock Incentive Plan. The 2022 Stock Incentive Plan replaced the 2013 Stock Incentive Plan, and no further awards will be granted under the 2013 Stock Incentive Plan; however, as noted below, outstanding awards under the 2013 Stock Incentive Plan were settled in 2023, 2024 and 2025. Under the 2022 Stock Incentive Plan, restricted stock, restricted stock units, stock options, stock appreciation rights and performance units may be granted to officers, directors and other key employees of OGE Energy and its subsidiaries, including OG&E. OGE Energy has authorized the issuance of up to 8,417,755 shares under the 2022 Stock Incentive Plan.

The tables designated as "OGE Energy" within this Note 6 include the OG&E standalone activity, as OGE Energy represents consolidated results. As a result of OGE Energy's exit of its former midstream business and becoming primarily an electric company, all employees are directly employed by OG&E beginning in 2024.


	OGE Energy						OG&E
Year Ended December 31 (In millions)	2025		2024		2023		2025		2024		2023
Performance units	$	9.6	$	7.9	$	9.3	$	9.6	$	7.9	$	2.2
Restricted stock units		4.4		3.8		3.8		4.4		3.8		0.9
Total compensation expense	$	14.0	$	11.7	$	13.1	$	14.0	$	11.7	$	3.1
Income tax benefit	$	3.4	$	2.8	$	3.2	$	3.4	$	2.8	$	0.7

During the year ended December 31, 2023, OGE Energy issued 82,321 shares of new common stock pursuant to OGE Energy's 2013 Stock Incentive Plan and issued 2,371 shares of treasury stock to satisfy payouts of earned performance units and restricted stock unit grants to the Registrants' employees.

During the year ended December 31, 2024, OGE Energy issued 255,578 shares of new common stock pursuant to OGE Energy's 2013 Stock Incentive Plan to satisfy payouts of earned performance units and restricted stock unit grants to the Registrants' employees.

During the year ended December 31, 2025, OGE Energy issued 234,476 shares of new common stock pursuant to OGE Energy's 2013 Stock Incentive Plan and 252 shares of new common stock pursuant to OGE Energy's 2022 Stock Incentive Plan to satisfy payouts of earned performance units and restricted stock unit grants to the Registrants' employees.

Performance Units

Under the Stock Incentive Plan, OGE Energy has issued performance units which represent the value of one share of OGE Energy's common stock. The performance units provide for accelerated vesting if there is a change in control (as defined in the Stock Incentive Plan). Each performance unit is subject to forfeiture if the recipient terminates employment with OGE Energy or a subsidiary prior to the end of the primarily three-year award cycle for any reason other than death, disability or retirement. In the event of death, disability or retirement, a participant will receive a prorated payment based on such participant's number of full months of service during the award cycle, further adjusted based on the achievement of the performance goals during the award cycle. The Registrants estimate expected forfeitures in accounting for performance unit compensation expense.

The performance units granted are contingently awarded and will be payable in shares of OGE Energy's common stock subject to the condition that the number of performance units, if any, earned by the employees upon the expiration of a primarily three-year award cycle (i.e., three-year cliff vesting period) is dependent on OGE Energy's total shareholder return ranking relative to a peer group of companies. These performance units are classified as equity in the balance sheets. If there is no or only a partial payout for the performance units at the end of the award cycle, the unearned performance units are cancelled. Payout requires approval of the Compensation Committee of OGE Energy's Board of Directors. Payouts, if any, are all made in common stock and are considered made when the payout is approved by the Compensation Committee.

The fair value of the performance units was estimated on the grant date using a lattice-based valuation model that factors in information, including the expected dividend yield, expected price volatility, risk-free interest rate and the probable outcome of the market condition, over the expected life of the performance units. Compensation expense for the performance units is a fixed amount determined at the grant date fair value and is recognized over the primarily three-year award cycle regardless of whether performance units are awarded at the end of the award cycle. Dividends are accrued on a quarterly basis pending achievement of payout criteria and are included in the fair value calculations. Expected price volatility is based on the historical volatility of OGE Energy's common stock for the past three years and is simulated using the Geometric Brownian Motion process. The risk-free interest rate for the performance unit grants is based on the three-year U.S. Treasury yield curve in effect at the time of the grant. The expected life of the units is based on the non-vested period since inception of the award cycle. There are no post-vesting restrictions related to OGE Energy's performance units. The following table presents the number of performance units granted and the assumptions used to calculate the grant date fair value of the performance units.


	OGE Energy									OG&E
	2025			2024			2023			2025			2024			2023
Number of units granted		216,426			275,499			213,442			216,426			275,499			65,069
Fair value of units granted	$	55.43		$	35.86		$	43.74		$	55.43		$	35.86		$	43.74
Expected dividend yield		3.8	%		5.1	%		4.2	%		3.8	%		5.1	%		4.2	%
Expected price volatility		20.0	%		19.9	%		31.0	%		20.0	%		19.9	%		31.0	%
Risk-free interest rate		4.28	%		4.41	%		4.47	%		4.28	%		4.41	%		4.47	%
Expected life of units (in years)		2.87			2.86			2.85			2.87			2.86			2.85

Restricted Stock Units

Under the Stock Incentive Plan, OGE Energy has issued restricted stock units to certain existing non-officer employees as well as other executives upon hire to attract and retain individuals to be competitive in the marketplace. The restricted stock units vest primarily in a three-year award cycle (i.e., three-year cliff vesting period). Prior to vesting, each restricted stock unit is subject to forfeiture if the recipient ceases to render substantial services to OGE Energy or a subsidiary. These restricted stock units may not be sold, assigned, transferred or pledged and are subject to a risk of forfeiture.

The fair value of the restricted stock units was based on the closing market price of OGE Energy's common stock on the grant date. Compensation expense for the restricted stock units is a fixed amount determined at the grant date fair value and is recognized as services are rendered by employees over a primarily three-year vesting period. Also, for those restricted stock units that vest in one-third annual increments over a three-year cycle, OGE Energy treats its restricted stock units as multiple separate awards by recording compensation expense separately for each tranche whereby a substantial portion of the expense is recognized in the earlier years in the requisite service period.

Dividends will only be paid on restricted stock unit awards that vest; therefore, only the present value of dividends expected to vest are included in the fair value calculations. The expected life of the restricted stock units is based on the non-vested period since inception of the primarily three-year award cycle. There are no post-vesting restrictions related to OGE Energy's restricted stock units. The following table presents the number of restricted stock units granted and the grant date fair value.


	OGE Energy						OG&E
	2025		2024		2023		2025		2024		2023
Restricted stock units granted		121,056		148,345		114,926		121,056		148,345		35,034
Fair value of restricted stock units granted	$	43.69	$	32.74	$	37.52	$	43.69	$	32.74	$	37.52

Performance Units and Restricted Stock Units Activity

The following table presents a summary of the activity for the Registrants' performance units and restricted stock units for the year ended December 31, 2025.


OGE Energy and OG&E	Performance Units						Restricted Stock Units
(Dollars in millions)	Number of Units				Aggregate Intrinsic Value		Number of Shares			Aggregate Intrinsic Value
Units/shares outstanding at 12/31/24		646,192						244,054
Granted		216,426		(A)				121,056
Converted		(191,918	)	(B)	$	12.5	N/A
Vested	N/A							(100,933	)	$	4.3
Forfeited		(12,756	)					(9,924	)
Units/shares outstanding at 12/31/25		657,944			$	19.7		254,253		$	10.9
Units/shares fully vested at 12/31/25		191,740		(C)	$	8.2	N/A			N/A

(A)

(B)

These amounts represent performance units that vested at December 31, 2024, which were settled in February 2025.

(C)

The following table presents a summary of the activity for the Registrants' non-vested performance units and restricted stock units for the year ended December 31, 2025.


OGE Energy and OG&E	Performance Units						Restricted Stock Units
	Number of Units				Weighted-Average Grant Date Fair Value		Number of Shares			Weighted-Average Grant Date Fair Value
Units/shares non-vested at 12/31/24		454,274			$	39.28		244,054		$	34.81
Granted		216,426		(A)	$	55.43		121,056		$	43.69
Vested		(191,740	)		$	43.74		(100,933	)	$	42.79
Forfeited		(12,756	)		$	42.49		(9,924	)	$	36.73
Units/shares non-vested at 12/31/25		466,204			$	44.86		254,253		$	37.88

(A)

Fair Value of Vested Performance Units and Restricted Stock Units

The following table presents a summary of the Registrants' fair value for vested performance units and restricted stock units.


	OGE Energy						OG&E
Year Ended December 31 (In millions)	2025		2024		2023		2025		2024		2023
Performance units	$	8.4	$	7.9	$	9.0	$	8.4	$	7.9	$	2.4
Restricted stock units	$	3.8	$	3.6	$	2.4	$	3.8	$	3.6	$	0.6

Unrecognized Compensation Cost


OGE Energy and OG&E December 31, 2025	Unrecognized Compensation Cost (In millions)		Weighted Average to be Recognized (In years)
Performance units	$	10.3		1.72
Restricted stock units		4.6		1.77
Total unrecognized compensation cost	$	14.9

Summary of Significant Accounting Policies - Schedule of Regulatory Assets and Liabilities (Details) - USD ($)
$ in Millions

Dec. 31, 2025

Dec. 31, 2024

Schedule of Regulatory Assets and Liabilities [Line Items]

Fuel clause under recoveries

$ 0.0

$ 112.7

11.4

123.5

557.2

568.1

34.9

20.3

Schedule of Regulatory Assets and Liabilities [Line Items]

957.1

1,016.4

Oklahoma [Member]

Fuel clause under recoveries

0.0

112.7

Arkansas fuel clause over recoveries [Member]

15.7

0.0

Schedule of Regulatory Assets and Liabilities [Line Items]

Investment Tax Credit Over Recoveries [Member]

11.4

9.3

Schedule of Regulatory Assets and Liabilities [Line Items]

Income taxes recoverable from customers, net [Member]

^[1]

2.0

6.1

Schedule of Regulatory Assets and Liabilities [Line Items]

Accrued removal obligations [Member]

718.9

780.8

Schedule of Regulatory Assets and Liabilities [Line Items]

Oklahoma Energy Efficiency Rider Under Recovery [Member]

234.7

231.9

Schedule of Regulatory Assets and Liabilities [Line Items]

Schedule of Regulatory Assets and Liabilities [Line Items]

^[1]

5.8

0.0

Pension tracker [Member]

Other Regulatory Liabilities [Member]

88.7

94.7

Schedule of Regulatory Assets and Liabilities [Line Items]

^[1]

0.0

4.9

Oklahoma Energy Efficiency Rider Under Recovery [Member]

3.5

3.7

Schedule of Regulatory Assets and Liabilities [Line Items]

Benefit obligations regulatory asset [Member]

^[2]

0.0

7.0

Schedule of Regulatory Assets and Liabilities [Line Items]

Winter Storm Uri costs [Member] | ARKANSAS [Member]

85.6

90.8

Schedule of Regulatory Assets and Liabilities [Line Items]

Deferred storm expenses [Member]

54.2

63.0

Schedule of Regulatory Assets and Liabilities [Line Items]

Unamortized loss on reacquired debt [Member]

224.7

244.3

Schedule of Regulatory Assets and Liabilities [Line Items]

Dry Scrubber Regulatory Asset [Member]

5.5

6.3

Schedule of Regulatory Assets and Liabilities [Line Items]

SAP S/4 HANA Deferred Expenses [Member]

15.5

16.4

Schedule of Regulatory Assets and Liabilities [Line Items]

Deferred Pension Expenses [Member]

16.5

14.3

Schedule of Regulatory Assets and Liabilities [Line Items]

SB 998 Deferred Costs, Net [Member]

9.3

11.0

Schedule of Regulatory Assets and Liabilities [Line Items]

Vegetation Management Program Deferred Costs [Member]

22.9

0.0

Schedule of Regulatory Assets and Liabilities [Line Items]

Other Regulatory Assets [Member]

13.9

6.4

Schedule of Regulatory Assets and Liabilities [Line Items]

^[2]

4.3

3.8

SPP cost tracker under recovery [Member]

9.6

12.0

Schedule of Regulatory Assets and Liabilities [Line Items]

COVID-19 Deferred Expenses [Member]

^[2]

7.1

0.0

Schedule of Regulatory Assets and Liabilities [Line Items]

Capacity Power Purchase Agreements [Member]

4.1

5.4

Schedule of Regulatory Assets and Liabilities [Line Items]

Organization, Consolidation and Presentation of Financial Statements [Abstract]

$ 6.7

$ 3.5

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

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2025

Schedule of Regulatory Assets and Liabilities

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


December 31 (In millions)	2025		2024
REGULATORY ASSETS
Current:
SPP cost tracker under recoveries (A)	$	7.1	$	—
Oklahoma fuel clause under recoveries		—		112.7
Oklahoma Energy Efficiency Rider under recoveries (A)		—		7.0
Other (A)		4.3		3.8
Total current regulatory assets	$	11.4	$	123.5
Non-current:
Oklahoma deferred storm expenses	$	224.7	$	244.3
Pension tracker		88.7		94.7
Benefit obligations regulatory asset		85.6		90.8
Arkansas Winter Storm Uri costs		54.2		63.0
Oklahoma SB 998 deferred costs, net		22.9		—
Oklahoma SAP S/4 HANA deferred expenses		16.5		14.3
Sooner Dry Scrubbers		15.5		16.4
Oklahoma vegetation management program deferred costs		13.9		6.4
Arkansas deferred pension expenses		9.3		11.0
Arkansas capacity power purchase agreements		6.7		3.5
Unamortized loss on reacquired debt		5.5		6.3
COVID-19 impacts		4.1		5.4
Other		9.6		12.0
Total non-current regulatory assets	$	557.2	$	568.1
REGULATORY LIABILITIES
Current:
Oklahoma fuel clause over recoveries	$	15.7	$	—
Arkansas fuel clause over recoveries		11.4		9.3
Oklahoma Energy Efficiency Rider over recoveries (B)		5.8		—
Oklahoma Investment Tax Credit over recoveries (B)		2.0		6.1
Other (B)		—		4.9
Total current regulatory liabilities	$	34.9	$	20.3
Non-current:
Income taxes refundable to customers, net	$	718.9	$	780.8
Accrued removal obligations, net		234.7		231.9
Other		3.5		3.7
Total non-current regulatory liabilities	$	957.1	$	1,016.4

(A)

Included in Other Current Assets in the balance sheets.

Included in Other Current Liabilities in the balance sheets.

Summary of Components of Benefit Obligation

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


December 31 (In millions)	2025		2024
Pension Plan and Restoration of Retirement Income Plan:
Net loss	$	74.0	$	76.5
Postretirement Benefit Plans:
Net loss		11.6		14.3
Total	$	85.6	$	90.8

Schedule of Jointly Owned Utility Plants


December 31, 2025 (In millions)	Percentage Ownership			Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)		77	%	$	254.6	$	81.6	$	173.0
Redbud Plant (A)(B)		51	%	$	582.1	$	261.1	$	321.0

(A)

Construction work in progress was $0.1 million and $25.8 million for the McClain and Redbud Plants, respectively.

(B)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.


December 31, 2024 (In millions)	Percentage Ownership			Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)		77	%	$	244.4	$	75.8	$	168.6
Redbud Plant (A)(B)		51	%	$	556.7	$	247.7	$	309.0

(A)

Construction work in progress was $0.8 million and $5.1 million for the McClain and Redbud Plants, respectively.

(B)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.

Summary of Property Plant and Equipment

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


December 31, 2025 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
OG&E:
Distribution assets	$	7,075.1	$	1,744.3	$	5,330.8
Electric generation assets (A)		5,873.5		2,285.0		3,588.5
Transmission assets (B)		3,524.8		781.1		2,743.7
Intangible plant		2.5		0.7		1.8
Other property and equipment		1,465.9		406.4		1,059.5
OG&E property, plant and equipment		17,941.8		5,217.5		12,724.3
Non-OG&E property, plant and equipment		6.1		—		6.1
Total OGE Energy property, plant and equipment	$	17,947.9	$	5,217.5	$	12,730.4

(A)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.

(B)

This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.


December 31, 2024 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
OG&E:
Distribution assets	$	6,654.5	$	1,639.8	$	5,014.7
Electric generation assets (A)		5,518.5		2,145.9		3,372.6
Transmission assets (B)		3,432.1		748.5		2,683.6
Intangible plant		752.3		203.7		548.6
Other property and equipment		705.3		244.3		461.0
OG&E property, plant and equipment		17,062.7		4,982.2		12,080.5
Non-OG&E property, plant and equipment		6.1		—		6.1
Total OGE Energy property, plant and equipment	$	17,068.8	$	4,982.2	$	12,086.6

(A)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.

(B)

This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.

Schedule of Change in Asset Retirement Obligation

The following table presents changes to OG&E's asset retirement obligations during the years ended December 31, 2025 and 2024.


(In millions)	2025			2024
Balance at January 1	$	84.6		$	81.3
Accretion expense		0.8			0.9
Liabilities settled (A)		(7.6	)		(0.2	)
Revisions in estimated cash flows (B)		—			2.6
Balance at December 31	$	77.8		$	84.6

(A)

Asset retirement obligations were settled for asbestos removal at OG&E's generating facilities.

(B)

Assumptions changed due to new removal estimates related to wind turbine removal at three of OG&E's wind farms in 2024.

Summary of Accumulated Other Comprehensive Income (Loss) (Details)

The following table presents changes in the components of accumulated other comprehensive income (loss) attributable to OGE Energy during 2025 and 2024. 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)			Total
Balance at December 31, 2023	$	(12.1	)	$	(0.8	)	$	5.7		$	(7.2	)
Other comprehensive income (loss) before reclassifications		(0.2	)		—			0.5			0.3
Amounts reclassified from accumulated other comprehensive income (loss)		0.2			0.2			(0.1	)		0.3
Regulatory classification of certain pension costs		3.9			—			—			3.9
Net current period other comprehensive income (loss)		3.9			0.2			0.4			4.5
Balance at December 31, 2024		(8.2	)		(0.6	)		6.1			(2.7	)
Other comprehensive income (loss) before reclassifications		(1.7	)		—			1.4			(0.3	)
Amounts reclassified from accumulated other comprehensive income (loss)		0.3			0.2			(0.1	)		0.4
Net current period other comprehensive income (loss)		(1.4	)		0.2			1.3			0.1
Balance at December 31, 2025	$	(9.6	)	$	(0.4	)	$	7.4		$	(2.6	)

Reclassified Out of Accumulated Other Comprehensive Income (Loss)


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)	2025			2024
Amortization of Pension Plan and Restoration of Retirement Income Plan items:
Actuarial losses	$	(0.4	)	$	(0.3	)	(A)
Prior service cost		(0.3	)		(0.3	)	(A)
		(0.7	)		(0.6	)	Income Before Taxes
		(0.2	)		(0.2	)	Income Tax Expense
	$	(0.5	)	$	(0.4	)	Net Income

Amortization of postretirement benefit plans items:
Actuarial gains	$	0.2		$	0.2		(A)
		0.2			0.2		Income Before Taxes
		0.1			0.1		Income Tax Expense
	$	0.1		$	0.1		Net Income

Total reclassifications for the period, net of tax	$	(0.4	)	$	(0.3	)	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).

Long-Term Debt - Schedule of Long-term Debt Instruments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024
Debt Instrument [Line Items]
Long-term Debt	$ 5,369.2	$ 5,053.3
Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Jan. 01, 2025
Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Jun. 01, 2027
Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Oct. 01, 2039
Redeemable during the next 12 months
Debt Instrument [Line Items]
Long-term Debt		103.0
OG&E [Member]
Debt Instrument [Line Items]
Long-term Debt	$ 4,961.7	4,646.7
OG&E [Member] \| Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Jan. 01, 2025
OG&E [Member] \| Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Jun. 01, 2027
OG&E [Member] \| Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	Oct. 01, 2039
OG&E [Member] \| Redeemable during the next 12 months \| Muskogee Industrial Authority Bond Due 2025 [Member]
Debt Instrument [Line Items]
Long term debt	$ 0.0	32.4
OG&E [Member] \| Redeemable during the next 12 months \| Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Long term debt	56.0	56.0
OG&E [Member] \| Redeemable during the next 12 months \| Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Long term debt	$ 47.0	$ 47.0
Minimum [Member] \| Redeemable during the next 12 months \| Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.65%
Minimum [Member] \| Redeemable during the next 12 months \| Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.80%
Minimum [Member] \| OG&E [Member] \| Redeemable during the next 12 months \| Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.65%
Minimum [Member] \| OG&E [Member] \| Redeemable during the next 12 months \| Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.80%
Maximum [Member] \| Redeemable during the next 12 months \| Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.60%
Maximum [Member] \| Redeemable during the next 12 months \| Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.60%
Maximum [Member] \| OG&E [Member] \| Redeemable during the next 12 months \| Muskogee Industrial Authority Bond Due 2027 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.60%
Maximum [Member] \| OG&E [Member] \| Redeemable during the next 12 months \| Garfield Industrial Authority Bond [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.60%

Retirement Plans and Postretirement Benefit Plans - Projected Benefit Obligation Funded Status Thresholds (Details)	12 Months Ended
	Dec. 31, 2025
Less Than 90% [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	50.00%
Projected Benefit Obligation Funded Status Thresholds Equity	50.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
95% [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	58.00%
Projected Benefit Obligation Funded Status Thresholds Equity	42.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
100% [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	65.00%
Projected Benefit Obligation Funded Status Thresholds Equity	35.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
105% [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	73.00%
Projected Benefit Obligation Funded Status Thresholds Equity	27.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
110% [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	80.00%
Projected Benefit Obligation Funded Status Thresholds Equity	20.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
115% [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	85.00%
Projected Benefit Obligation Funded Status Thresholds Equity	15.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
120% [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation Funded Status Thresholds Fixed Income	90.00%
Projected Benefit Obligation Funded Status Thresholds Equity	10.00%
Projected Benefit Obligation Funded Status Thresholds	100.00%
Domestic All-Cap/Large Cap Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	40.00%
Domestic All-Cap/Large Cap Equity [Member] \| Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	35.00%
Domestic All-Cap/Large Cap Equity [Member] \| Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	60.00%
Domestic Mid-Cap Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	15.00%
Domestic Mid-Cap Equity [Member] \| Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	5.00%
Domestic Mid-Cap Equity [Member] \| Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	25.00%
Domestic Small-Cap Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	25.00%
Domestic Small-Cap Equity [Member] \| Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	5.00%
Domestic Small-Cap Equity [Member] \| Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	30.00%
International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	20.00%
International Equity [Member] \| Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	10.00%
International Equity [Member] \| Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	30.00%

Report of Business Segments - Additional Information (Details)	12 Months Ended
	Dec. 31, 2025 Segment
Segment Reporting [Abstract]
Number of reporting segments	1
Number of Operating Segments	1
Segment Reporting, CODM, Individual Title and Position or Group Name [Extensible Enumeration]	srt:ChiefExecutiveOfficerMember
Segment Reporting, CODM, Profit (Loss) Measure, How Used, Description	The Chief Executive Officer uses net income as the measure of reportable segment profit or loss to make operating decisions, allocate resources, and assess performance.

Stock-Based Compensation - Share-based Compensation, Activity (Parenthetical) (Details)	12 Months Ended
	Dec. 31, 2025
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Minimum payout range	0.00%
Maximum payout range	200.00%

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Schedule of Components of Income Tax Expense

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2025

Income Taxes [Abstract]

The following table presents the components of income tax expense.


	OGE Energy							OG&E
Year Ended December 31 (In millions)	2025		2024		2023			2025		2024		2023
Provision for current income taxes:
Federal	$	29.3	$	62.0	$	46.1		$	39.9	$	72.7	$	48.9
State		0.3		0.8		(2.2	)		2.7		3.0		3.7
Total provision for current income taxes		29.6		62.8		43.9			42.6		75.7		52.6
Provision for deferred income taxes, net:
Federal		49.7		8.0		18.1			51.9		9.0		18.8
State		10.5		8.3		(5.8	)		10.6		8.5		(2.6	)
Total provision for deferred income taxes, net		60.2		16.3		12.3			62.5		17.5		16.2
Total income tax expense	$	89.8	$	79.1	$	56.2		$	105.1	$	93.2	$	68.8

Schedule of Effective Income Tax Rate Reconciliation

The following tables present a reconciliation of the statutory tax rates to the effective income tax rate.


OGE Energy
Year Ended December 31 (Dollars in millions)	2025					2024					2023
Statutory federal tax rate	$	117.7		21.0	%	$	109.3		21.0	%	$	99.3		21.0	%
State income taxes, net of federal income tax benefit (A)		8.5		1.5			7.3		1.4			(12.6	)	(2.7	)
Amortization of net unfunded deferred taxes		(32.3	)	(5.7	)		(32.6	)	(6.3	)		(33.2	)	(7.0	)
Federal tax credits		(2.6	)	(0.5	)		(2.6	)	(0.5	)		(3.6	)	(0.8	)
Uncertain tax position		—		—			—		—			6.2		1.3
Nontaxable or nondeductible items		(1.5	)	(0.3	)		(2.3	)	(0.4	)		0.1		0.1
Effective income tax rate	$	89.8		16.0	%	$	79.1		15.2	%	$	56.2		11.9	%


OG&E
Year Ended December 31 (Dollars in millions)	2025					2024					2023
Statutory federal tax rate	$	127.0		21.0	%	$	118.3		21.0	%	$	104.0		21.0	%
State income taxes, net of federal income tax benefit (A)		10.5		1.8			9.1		1.6			0.8		0.2
Amortization of net unfunded deferred taxes		(32.3	)	(5.3	)		(32.6	)	(5.8	)		(33.2	)	(6.7	)
Federal tax credits		(2.6	)	(0.5	)		(2.6	)	(0.4	)		(3.6	)	(0.8	)
Nontaxable or nondeductible items		2.5		0.4			1.0		0.2			0.8		0.2
Effective income tax rate	$	105.1		17.4	%	$	93.2		16.6	%	$	68.8		13.9	%

(A)

In 2025, state taxes in Oklahoma made up the majority (greater than 50 percent) of the tax effect in this category.

Schedule of Deferred Tax Assets and Liabilities

The following table presents the components of Deferred Income Taxes at December 31, 2025 and 2024.


	OGE Energy						OG&E
December 31 (In millions)	2025			2024			2025			2024
Deferred income tax liabilities, net:
Accelerated depreciation and other property related differences	$	1,907.6		$	1,809.5		$	1,907.6		$	1,809.5
Regulatory assets		66.6			65.6			66.6			65.6
Pension Plan		21.5			22.0			38.5			38.6
Corporate owned life insurance		3.1			2.8			—			—
Bond redemption-unamortized costs		1.0			1.2			1.0			1.2
State tax credits		(223.6	)		(223.8	)		(208.6	)		(208.5	)
Income taxes recoverable from customers, net		(173.6	)		(188.6	)		(173.6	)		(188.6	)
Regulatory liabilities		(59.8	)		(57.3	)		(59.8	)		(57.3	)
Asset retirement obligations		(18.8	)		(20.9	)		(18.8	)		(20.9	)
Postretirement medical and life insurance benefits		(21.5	)		(19.1	)		(15.1	)		(12.6	)
Accrued liabilities		(9.0	)		(15.7	)		(2.7	)		(9.8	)
Deferred federal investment tax credits		(2.4	)		(2.5	)		(2.4	)		(2.5	)
Accrued vacation		(1.7	)		(1.9	)		(1.7	)		(1.9	)
Uncollectible accounts		(1.0	)		(0.5	)		(1.0	)		(0.5	)
Other		0.9			0.3			1.3			(1.6	)
Total deferred income tax liabilities, net	$	1,489.3		$	1,371.1		$	1,531.3		$	1,410.7

Schedule of Unrecognized Tax Benefits Roll Forward

The following table presents a reconciliation of the Registrants' total gross unrecognized tax benefits as of the years ended December 31, 2025, 2024 and 2023.


(In millions)	2025		2024		2023
Balance at January 1	$	28.6	$	28.6	$	20.7
Tax positions related to current year:
Additions		—		—		7.9
Balance at December 31	$	28.6	$	28.6	$	28.6

Summary of Tax Credit Carryforwards


	OGE Energy				OG&E
(In millions)	Carry Forward Amount		Deferred Tax Asset		Carry Forward Amount		Deferred Tax Asset		Earliest Expiration Date
State tax credits:
Oklahoma investment tax credits	$	268.5	$	210.8	$	249.6	$	195.8	N/A
Oklahoma capital investment board credits	$	12.8	$	12.8	$	12.8	$	12.8	N/A

N/A - not applicable

Report of Business Segments - Summary of OGE Energy's Business Segments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Segment Reporting Information [Line Items]
Operating revenues	$ 3,260.1	$ 2,985.3	$ 2,674.3
Fuel, purchased power and direct transmission expense	1,259.9	1,076.4	911.7
Other operation and maintenance	531.6	514.4	502.6
Depreciation and amortization	559.8	539.5	506.6
Taxes other than income	109.4	109.7	103.2
OPERATING INCOME	799.4	745.3	650.2
Other income	31.4	29.8	44.2
Interest expense	270.3	254.5	221.4
Income tax expense (benefit)	89.8	79.1	56.2
Net income (loss)	470.7	441.5	416.8
Total assets	14,370.5	13,716.0	12,790.7
Capital expenditures	1,054.4	1,090.9	1,178.2
Operating Segments [Member] \| Electric Company [Member]
Segment Reporting Information [Line Items]
Operating revenues	3,260.1	2,985.3	2,674.3
Fuel, purchased power and direct transmission expense	1,259.9	1,076.4	911.7
Other operation and maintenance	531.0	514.1	505.0
Depreciation and amortization	559.8	539.5	506.6
Taxes other than income	109.4	109.7	99.4
OPERATING INCOME	800.0	745.6	651.6
Other income	30.4	31.9	43.5
Interest expense	225.5	214.4	199.9
Income tax expense (benefit)	105.1	93.2	68.8
Net income (loss)	499.8	469.9	426.4
Total assets	14,277.5	13,581.3	12,642.6
Capital expenditures	1,054.4	1,090.9	1,178.2
Operating Segments [Member] \| Other Operations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0.0	0.0	0.0
Fuel, purchased power and direct transmission expense	0.0	0.0	0.0
Other operation and maintenance	0.6	0.3	(2.4)
Depreciation and amortization	0.0	0.0	0.0
Taxes other than income	0.0	0.0	3.8
OPERATING INCOME	(0.6)	(0.3)	(1.4)
Other income	7.4	2.4	8.1
Interest expense	51.2	44.6	28.9
Income tax expense (benefit)	(15.3)	(14.1)	(12.6)
Net income (loss)	(29.1)	(28.4)	(9.6)
Total assets	134.1	402.9	301.1
Capital expenditures	0.0	0.0	0.0
Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	0.0	0.0	0.0
Fuel, purchased power and direct transmission expense	0.0	0.0	0.0
Other operation and maintenance	0.0	0.0	0.0
Depreciation and amortization	0.0	0.0	0.0
Taxes other than income	0.0	0.0	0.0
OPERATING INCOME	0.0	0.0	0.0
Other income	(6.4)	(4.5)	(7.4)
Interest expense	(6.4)	(4.5)	(7.4)
Income tax expense (benefit)	0.0	0.0	0.0
Net income (loss)	0.0	0.0	0.0
Total assets	(41.1)	(268.2)	(153.0)
Capital expenditures	$ 0.0	$ 0.0	$ 0.0

Commitments and Contingencies - Additional Information (Details) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2023 USD ($)	Dec. 31, 2025 USD ($) Megawattsday Turbine MWd Segment	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts \| $		$ 54.8	$ 54.3	$ 48.8
Damages sought, description	In July 2023, OG&E was named, along with its contractor, as a defendant in a lawsuit filed by an apartment owner and its insurance companies seeking in excess of $60.0 million in damages related to a fire at an apartment building under construction in Oklahoma City. Several additional defendants have also been named. OG&E disputes the claims in the lawsuit and intends to vigorously defend this action. If OG&E is ultimately deemed liable for damages in connection with this incident, OG&E believes its existing insurance policies will cover its costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have. Due to the uncertain and developing nature of this litigation, the outcome cannot be predicted, and OG&E is unable to provide a range of possible loss in this matter.
Damage from Fire [Member]
Loss Contingencies [Line Items]
Damages sought \| $	$ 60.0
Oklahoma [Member]
Loss Contingencies [Line Items]
Current energy generation capacity \| MWd		300
CPV Keenan [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts \| $		$ 28.3	25.4	23.0
Edison Mission Energy [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts \| $		21.9	23.3	20.5
NextEra Energy [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts \| $		$ 4.6	$ 5.6	$ 5.3
OG&E long-term service agreement commitments [Member] \| McClain Plant [Member]
Loss Contingencies [Line Items]
Factored-Fired Hours		128,000
Factored-Fired Starts		4,800
OG&E long-term service agreement commitments [Member] \| Redbud Plant [Member]
Loss Contingencies [Line Items]
Factored-Fired Hours		144,000
Factored-Fired Starts		4,500
OG&E long-term service agreement commitments [Member] \| Horseshoe Lake Plant [Member]
Loss Contingencies [Line Items]
Factored-Fired Hours		64,000
Factored-Fired Starts		2,500
OG&E Generation Capacity Construction Commitments [Member] \| Horseshoe Lake [Member]
Loss Contingencies [Line Items]
Number of hydrogen capable combustion turbines \| Turbine		4
Current energy generation capacity \| Megawattsday		896
OG&E Generation Capacity Construction Commitments [Member] \| Horseshoe Lake [Member] \| 2026 [Member]
Loss Contingencies [Line Items]
Current energy generation capacity \| Megawattsday		448
OG&E Generation Capacity Construction Commitments [Member] \| Horseshoe Lake [Member] \| 2029 [Member]
Loss Contingencies [Line Items]
Current energy generation capacity \| Megawattsday		448
OG&E Generation Capacity Construction Commitments [Member] \| Tinker Air Force Base [Member]
Loss Contingencies [Line Items]
Number of hydrogen capable combustion turbines \| Turbine		2
Current energy generation capacity \| Megawattsday		96

Summary of Significant Accounting Policies Property - Summary of OG&E's Ownership Interest in Jointly-owned Plant (Parenthetical) (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
McClain Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	$ 0.1	$ 0.8
Redbud Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant, Ownership Amount of Construction Work in Progress	25.8	5.1
Amount of Acquisition Adjustments	148.3	148.3
Public Utilities, Property, Plant and Equipment, Amount of Acquisition Adjustments, Related Accumulated Depreciation	$ 94.7	$ 89.3

Revenue Recognition (Details) - USD ($) $ in Millions	12 Months Ended
Revenue Recognition (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 3,190.9	$ 2,916.6	$ 2,607.3
Provision for Rate Refund and Tax Refund
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3.0	(3.0)	2.0
Integrated Market
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	91.6	74.5	71.6
Transmission
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	159.4	152.9	143.0
Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	37.9	29.5	41.6
Residential
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,172.1	1,116.4	1,008.6
Commercial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	955.7	816.5	666.7
Industrial
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	260.1	248.6	235.2
Oilfield
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	241.5	225.7	210.0
Public Authority and Street Light
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	269.6	255.5	228.6
System Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,899.0	$ 2,662.7	$ 2,349.1

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Dec. 31, 2025
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Summary of Significant Accounting Policies - Summary of Components of Benefit Obligation (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Regulatory Asset, Noncurrent	$ 557.2	$ 568.1
Pension Plan [Member] \| Defined Benefit Plans Income Loss [Member]
Components of Benefit Obligation Regulatory Asset	74.0	76.5
Other Postretirement Benefits Plan [Member] \| Defined Benefit Plans Income Loss [Member]
Components of Benefit Obligation Regulatory Asset	11.6	14.3
Benefit obligations regulatory asset [Member]
Regulatory Asset, Noncurrent	$ 85.6	$ 90.8

Stock-Based Compensation - Fair Value of Vested Performance Units and Restricted Stock (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair Value of Vested Performance Units and Restricted Stock	$ 8.4	$ 7.9	$ 9.0
Performance Units [Member] \| Og and E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair Value of Vested Performance Units and Restricted Stock	8.4	7.9	2.4
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair Value of Vested Performance Units and Restricted Stock	3.8	3.6	2.4
Restricted Stock [Member] \| Og and E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair Value of Vested Performance Units and Restricted Stock	$ 3.8	$ 3.6	$ 0.6

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

U.S. common stocks [Member]

Retirement Plans and Postretirement Benefit Plans - Defined Benefit Plan, Plan Assets, Category (Details) - USD ($)
$ in Millions

Dec. 31, 2025

Dec. 31, 2024

U.S. treasury notes and bonds [Member]

$ 38.0

$ 55.7

Mortgage-backed securities

^[1]

41.3

49.3

Corporate fixed income and other securities [Member]

22.3

23.9

51.9

50.3

Commingled fund [Member]

Foreign government bonds [Member]

^[2]

18.7

13.4

0.1

0.3

Municipal Bonds [Member]

Money Market Funds [Member]

0.1

Interest and dividends receivable [Member]

10.6

0.9

Payable to broker for securities purchased [Member]

1.4

1.5

(15.2)

(20.3)

Mutual Funds [Member]

83.0

62.0

Preferred Stock [Member]

0.5

Cash Collateral [Member]

Receivable (foreign currency) [Member]

0.9

0.1

Receivable from broker for securities sold [Member]

0.1

Total Plan investments [Member]

9.0

9.1

Plan Assets Attributable to Affiliates

267.0

256.6

Total Plan assets [Member]

(36.0)

(35.3)

Total Plan assets [Member] | OG&E [Member]

262.2

246.9

Fair Value, Inputs, Level 1 [Member] | U.S. common stocks [Member]

226.2

211.6

Fair Value, Inputs, Level 1 [Member] | U.S. treasury notes and bonds [Member]

38.0

55.7

Fair Value, Inputs, Level 1 [Member] | Mortgage-backed securities

^[1]

41.3

49.3

Fair Value, Inputs, Level 1 [Member] | Corporate fixed income and other securities [Member]

0.0

Fair Value, Inputs, Level 1 [Member] | Commingled fund [Member]

0.0

Fair Value, Inputs, Level 1 [Member] | Foreign government bonds [Member]

^[2]

0.0

Fair Value, Inputs, Level 1 [Member] | Municipal Bonds [Member]

0.0

Fair Value, Inputs, Level 1 [Member] | Money Market Funds [Member]

0.0

Fair Value, Inputs, Level 1 [Member] | Mutual Funds [Member]

0.0

Fair Value, Inputs, Level 1 [Member] | Preferred Stock [Member]

83.0

62.0

Fair Value, Inputs, Level 1 [Member] | Cash Collateral [Member]

0.5

Fair Value, Inputs, Level 1 [Member] | Receivable (foreign currency) [Member]

0.9

0.1

Fair Value, Inputs, Level 1 [Member] | Total Plan investments [Member]

0.0

Fair Value, Inputs, Level 2 [Member] | U.S. common stocks [Member]

163.2

167.6

Fair Value, Inputs, Level 2 [Member] | U.S. treasury notes and bonds [Member]

0.0

Fair Value, Inputs, Level 2 [Member] | Mortgage-backed securities

^[1]

0.0

Fair Value, Inputs, Level 2 [Member] | Corporate fixed income and other securities [Member]

22.3

23.9

Fair Value, Inputs, Level 2 [Member] | Commingled fund [Member]

51.9

50.3

Fair Value, Inputs, Level 2 [Member] | Foreign government bonds [Member]

^[2]

0.0

Fair Value, Inputs, Level 2 [Member] | Municipal Bonds [Member]

0.1

0.3

Fair Value, Inputs, Level 2 [Member] | Money Market Funds [Member]

0.1

Fair Value, Inputs, Level 2 [Member] | Mutual Funds [Member]

0.0

Fair Value, Inputs, Level 2 [Member] | Preferred Stock [Member]

0.0

Fair Value, Inputs, Level 2 [Member] | Cash Collateral [Member]

0.0

Fair Value, Inputs, Level 2 [Member] | Receivable (foreign currency) [Member]

0.0

Fair Value, Inputs, Level 2 [Member] | Total Plan investments [Member]

0.1

Net Asset Value [Member] | U.S. common stocks [Member]

74.5

74.7

Net Asset Value [Member] | U.S. treasury notes and bonds [Member]

^[3]

0.0

Net Asset Value [Member] | Mortgage-backed securities

^[1],[3]

0.0

Net Asset Value [Member] | Corporate fixed income and other securities [Member]

^[3]

0.0

Net Asset Value [Member] | Commingled fund [Member]

^[3]

0.0

Net Asset Value [Member] | Foreign government bonds [Member]

^[2],[3]

18.7

13.4

Net Asset Value [Member] | Municipal Bonds [Member]

^[3]

0.0

Net Asset Value [Member] | Money Market Funds [Member]

^[3]

0.0

Net Asset Value [Member] | Mutual Funds [Member]

^[3]

10.6

0.9

Net Asset Value [Member] | Preferred Stock [Member]

^[3]

0.0

Net Asset Value [Member] | Cash Collateral [Member]

^[3]

0.0

Net Asset Value [Member] | Receivable (foreign currency) [Member]

^[3]

0.0

Net Asset Value [Member] | Total Plan investments [Member]

^[3]

0.0

Accounting Pronouncements

^[3]

$ 29.3

$ 14.3

[1]	This category represents U.S. Treasury notes and bonds with a Moody's Investors Service rating of Aaa and Government Agency Bonds with a Moody's Investors Service rating of A1 or higher.
[2]	This category represents units of participation in a commingled fund that primarily invested in stocks of international companies and emerging markets.
[3]	GAAP allows the measurement of certain investments that do not have a readily determinable fair value at the net asset value. These investments do not consider the observability of inputs; therefore, they are not included within the fair value hierarchy.

Retirement Plans and Postretirement Benefit Plans - Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Employer contributions	$ 13.5	$ 10.0
Pension Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	303.1	303.7
Service cost	5.4	5.3	$ 5.4
Interest cost	16.2	15.6	15.9
Regulatory classification of certain pension costs	0.0	0.0
Special termination benefits	0.5	0.0
Actuarial losses (gains)	11.5	(2.9)
Benefits paid	(21.5)	(18.6)
Benefit Obligation, Ending	315.2	303.1	303.7
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	246.9	243.7
Actual return on plans' assets	23.3	11.8
Employer contributions	13.5	10.0
Regulatory classification of certain pension costs	0.0	0.0
Benefits paid	(21.5)	(18.6)
Fair Value of Plan Assets, Ending	262.2	246.9	243.7
Funded status at end of year	(53.0)	(56.2)
Accumulated Benefit Obligation	(305.6)	(289.4)
Pension Plan [Member] \| OG&E [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	263.9	238.6
Service cost	5.4	5.3	4.4
Interest cost	14.1	13.4	12.6
Regulatory classification of certain pension costs	0.0	23.9
Special termination benefits	0.5	0.0
Actuarial losses (gains)	8.9	(2.2)
Benefits paid	(18.9)	(15.1)
Benefit Obligation, Ending	273.9	263.9	238.6
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	211.6	191.4
Actual return on plans' assets	20.0	10.1
Employer contributions	13.5	10.0
Regulatory classification of certain pension costs	0.0	15.2
Benefits paid	(18.9)	(15.1)
Fair Value of Plan Assets, Ending	226.2	211.6	191.4
Funded status at end of year	(47.7)	(52.3)
Accumulated Benefit Obligation	(264.3)	(250.2)
Restoration of Retirement Income Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	7.0	5.5
Service cost	1.0	1.0	1.0
Interest cost	0.4	0.3	0.3
Regulatory classification of certain pension costs	0.0	0.0
Special termination benefits	0.0	0.0
Actuarial losses (gains)	0.9	0.2
Benefits paid	0.0	0.0
Benefit Obligation, Ending	9.3	7.0	5.5
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	0.0	0.0
Actual return on plans' assets	0.0	0.0
Employer contributions	0.0	0.0
Regulatory classification of certain pension costs	0.0	0.0
Benefits paid	0.0	0.0
Fair Value of Plan Assets, Ending	0.0	0.0	0.0
Funded status at end of year	(9.3)	(7.0)
Accumulated Benefit Obligation	(8.9)	(6.8)
Restoration of Retirement Income Plan [Member] \| OG&E [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	1.4	0.0
Service cost	0.1	0.1	0.0
Interest cost	0.1	0.1	0.0
Regulatory classification of certain pension costs	0.0	1.1
Special termination benefits	0.0	0.0
Actuarial losses (gains)	0.3	0.1
Benefits paid	0.0	0.0
Benefit Obligation, Ending	1.9	1.4	0.0
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	0.0	0.0
Actual return on plans' assets	0.0	0.0
Employer contributions	0.0	0.0
Regulatory classification of certain pension costs	0.0	0.0
Benefits paid	0.0	0.0
Fair Value of Plan Assets, Ending	0.0	0.0	0.0
Funded status at end of year	(1.9)	(1.4)
Accumulated Benefit Obligation	(1.7)	(1.4)
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	98.1	103.3
Service cost	0.1	0.1	0.1
Interest cost	5.4	5.2	5.2
Regulatory classification of certain pension costs	0.0	0.0
Participants' contributions	2.5	3.5
Actuarial losses (gains)	(3.8)	(3.1)
Benefits paid	(11.9)	(10.9)
Benefit Obligation, Ending	90.4	98.1	103.3
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	30.0	32.7
Actual return on plans' assets	1.8	(1.6)
Employer contributions	6.0	6.3
Participants' contributions	2.5	3.5
Benefits paid	(11.9)	(10.9)
Fair Value of Plan Assets, Ending	28.4	30.0	32.7
Accumulated Benefit Obligation	(62.0)	(68.1)
Other Postretirement Benefits Plan [Member] \| OG&E [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation, Beginning	74.7	77.3
Service cost	0.1	0.1	0.1
Interest cost	4.1	3.9	3.9
Regulatory classification of certain pension costs	0.0	1.4
Participants' contributions	1.8	2.4
Actuarial losses (gains)	(1.9)	(2.1)
Benefits paid	(9.1)	(8.3)
Benefit Obligation, Ending	69.7	74.7	77.3
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Fair Value of Plan Assets, Beginning	27.2	29.6
Actual return on plans' assets	1.7	(1.4)
Employer contributions	4.6	4.9
Participants' contributions	1.8	2.4
Benefits paid	(9.1)	(8.3)
Fair Value of Plan Assets, Ending	26.2	27.2	$ 29.6
Accumulated Benefit Obligation	$ (43.5)	$ (47.5)

Retirement Plans and Postretirement Benefit Plans - Summary of Gross Benefit Payments Registrants Expect to Pay (Details) $ in Millions	Dec. 31, 2025 USD ($)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Postretirement Plan, Expected Future Benefit Payments, Next Twelve Months	$ 12.1
Postretirement Plan, Expected Future Benefit Payments, Year Two	9.6
Postretirement Plan, Expected Future Benefit Payments, Year Three	8.9
Postretirement Plan, Expected Future Benefit Payments in Year Four	8.3
Postretirement Plan, Expected Future Benefit Payments, Year Five	7.9
Postretirement Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	33.3
OG&E [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Postretirement Plan, Expected Future Benefit Payments, Next Twelve Months	9.1
Postretirement Plan, Expected Future Benefit Payments, Year Two	7.2
Postretirement Plan, Expected Future Benefit Payments, Year Three	6.8
Postretirement Plan, Expected Future Benefit Payments in Year Four	6.5
Postretirement Plan, Expected Future Benefit Payments, Year Five	6.1
Postretirement Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	$ 26.0

Accounting Pronouncements

12 Months Ended

Dec. 31, 2025

Accounting Pronouncement [Abstract]

2. Accounting Pronouncements

In December 2023, the Financial Accounting Standards Board issued ASU 2023-09, "Income Taxes (Topic 740) Improvements to Income Tax Disclosures." The amendments in this update require public entities on an annual basis to (i) disclose specific categories in the rate reconciliation and (ii) provide additional information for reconciling items that meet a quantitative threshold. Further, the amendments require entities to disclose on an annual basis income taxes paid (net of refunds received) disaggregated by federal (national), state and foreign taxes and to disaggregate the information by jurisdiction based on a quantitative threshold. The Registrants adopted this standard effective January 1, 2025. The presentation of certain prior year information in the supplemental cash flow statement information and within Note 7 have been adjusted to align with current year disclosure changes resulting from the Registrants' adoption of ASU 2023-09.

In November 2024, the Financial Accounting Standards Board issued ASU 2024-03, "Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures." The amendments in this update improve financial reporting by requiring disclosure of additional information about specific expense categories in the notes to financial statements on an annual and interim basis. This standard is effective for fiscal years beginning after December 15, 2026 and interim periods beginning after December 15, 2027. Early adoption is permitted. The Registrants are evaluating the impact of this standard and do not believe it will have a material impact on their financial statement disclosures.

In September 2025, the Financial Accounting Standards Board issued ASU 2025-06, "Intangibles - Goodwill and Other - Internal-Use Software." The targeted improvements in this update aim to better align current software development processes when considering capitalization of internal-use software costs. This standard is effective for fiscal years beginning after December 15, 2027 and interim periods within that period. Early adoption is permitted. The Registrants are evaluating the impact of this standard on their financial statements.

The Registrants believe that other 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.

The entire disclosure for change in accounting principle. Includes, but is not limited to, nature, reason, and method of adopting amendment to accounting standards or other change in accounting principle.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 5: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
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Reference 21: http://www.xbrl.org/2003/role/disclosureRef
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Reference 22: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483443/250-10-50-1

Reference 23: http://www.xbrl.org/2003/role/disclosureRef
-Topic 326
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 4
-Subparagraph (e)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479654/326-10-65-4

Reference 24: http://www.xbrl.org/2003/role/disclosureRef
-Topic 326
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 4
-Subparagraph (e)(2)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479654/326-10-65-4

Reference 25: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 6
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480530/250-10-S99-6

Reference 26: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
-SubTopic 20
-Name Accounting Standards Codification
-Section 65
-Paragraph 4
-Subparagraph (f)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481538/470-20-65-4

Reference 27: http://www.xbrl.org/2003/role/disclosureRef
-Topic 470
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-Name Accounting Standards Codification
-Section 65
-Paragraph 4
-Subparagraph (e)
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Reference 28: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (b)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483443/250-10-50-1

Reference 29: http://www.xbrl.org/2003/role/disclosureRef
-Name Accounting Standards Codification
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Reference 30: http://www.xbrl.org/2003/role/disclosureRef
-Topic 815
-SubTopic 40
-Name Accounting Standards Codification
-Section 65
-Paragraph 1
-Subparagraph (e)(1)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480175/815-40-65-1

SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]

Schedule II (Tables)

12 Months Ended

Dec. 31, 2025

Schedule II Valuation and Qualifying Accounts


			Additions
Description	Balance at Beginning of Period		Charged to Costs and Expenses		Deductions (A)		Balance at End of Period
	(In millions)
Balance at December 31, 2023
Reserve for Uncollectible Accounts	$	1.9	$	5.7	$	5.4	$	2.2
Balance at December 31, 2024
Reserve for Uncollectible Accounts	$	2.2	$	4.0	$	4.2	$	2.0
Balance at December 31, 2025
Reserve for Uncollectible Accounts	$	2.0	$	7.5	$	5.4	$	4.1

(A)

Uncollectible accounts receivable written off, net of recoveries.

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Income Taxes [Line Items]
Accelerated depreciation and other property related differences	$ 1,907.6	$ 1,809.5
Regulatory assets	66.6	65.6
Pension Plan	21.5	22.0
Corporate owned life insurance	3.1	2.8
Bond redemption-unamortized costs	1.0	1.2
State tax credits	(223.6)	(223.8)
Income taxes recoverable from customers, net	(173.6)	(188.6)
Regulatory liabilities	(59.8)	(57.3)
Asset retirement obligations	(18.8)	(20.9)
Postretirement medical and life insurance benefits	(21.5)	(19.1)
Accrued liabilities	(9.0)	(15.7)
Deferred federal investment tax credits	(2.4)	(2.5)
Accrued vacation	(1.7)	(1.9)
Uncollectible accounts	(1.0)	(0.5)
Other	0.9	0.3
Deferred Income Tax Liabilities, Net, Total	1,489.3	1,371.1
OG&E [Member]
Income Taxes [Line Items]
Accelerated depreciation and other property related differences	1,907.6	1,809.5
Regulatory assets	66.6	65.6
Pension Plan	38.5	38.6
Corporate owned life insurance	0.0	0.0
Bond redemption-unamortized costs	1.0	1.2
State tax credits	(208.6)	(208.5)
Income taxes recoverable from customers, net	(173.6)	(188.6)
Regulatory liabilities	(59.8)	(57.3)
Asset retirement obligations	(18.8)	(20.9)
Postretirement medical and life insurance benefits	(15.1)	(12.6)
Accrued liabilities	(2.7)	(9.8)
Deferred federal investment tax credits	(2.4)	(2.5)
Accrued vacation	(1.7)	(1.9)
Uncollectible accounts	(1.0)	(0.5)
Other	1.3	(1.6)
Deferred Income Tax Liabilities, Net, Total	$ 1,531.3	$ 1,410.7

Stock-Based Compensation - Schedule of Unrecognized Compensation Cost, Nonvested Awards (Details) $ in Millions	12 Months Ended
	Dec. 31, 2025 USD ($)
OGE Energy and OG&E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Compensation Cost Not yet Recognized	$ 14.9
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	1 year 8 months 19 days
Performance Units [Member] \| OGE Energy and OG&E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Compensation Cost Not yet Recognized	$ 10.3
Restricted Stock [Member] \| OGE Energy and OG&E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total Compensation Cost Not yet Recognized	$ 4.6
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition	1 year 9 months 7 days

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2025

Organization

Accounting Records

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


December 31 (In millions)	2025		2024
REGULATORY ASSETS
Current:
SPP cost tracker under recoveries (A)	$	7.1	$	—
Oklahoma fuel clause under recoveries		—		112.7
Oklahoma Energy Efficiency Rider under recoveries (A)		—		7.0
Other (A)		4.3		3.8
Total current regulatory assets	$	11.4	$	123.5
Non-current:
Oklahoma deferred storm expenses	$	224.7	$	244.3
Pension tracker		88.7		94.7
Benefit obligations regulatory asset		85.6		90.8
Arkansas Winter Storm Uri costs		54.2		63.0
Oklahoma SB 998 deferred costs, net		22.9		—
Oklahoma SAP S/4 HANA deferred expenses		16.5		14.3
Sooner Dry Scrubbers		15.5		16.4
Oklahoma vegetation management program deferred costs		13.9		6.4
Arkansas deferred pension expenses		9.3		11.0
Arkansas capacity power purchase agreements		6.7		3.5
Unamortized loss on reacquired debt		5.5		6.3
COVID-19 impacts		4.1		5.4
Other		9.6		12.0
Total non-current regulatory assets	$	557.2	$	568.1
REGULATORY LIABILITIES
Current:
Oklahoma fuel clause over recoveries	$	15.7	$	—
Arkansas fuel clause over recoveries		11.4		9.3
Oklahoma Energy Efficiency Rider over recoveries (B)		5.8		—
Oklahoma Investment Tax Credit over recoveries (B)		2.0		6.1
Other (B)		—		4.9
Total current regulatory liabilities	$	34.9	$	20.3
Non-current:
Income taxes refundable to customers, net	$	718.9	$	780.8
Accrued removal obligations, net		234.7		231.9
Other		3.5		3.7
Total non-current regulatory liabilities	$	957.1	$	1,016.4

(A)

Included in Other Current Assets in the balance sheets.

(B)

Included in Other Current Liabilities in the balance sheets.

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


December 31 (In millions)	2025		2024
Pension Plan and Restoration of Retirement Income Plan:
Net loss	$	74.0	$	76.5
Postretirement Benefit Plans:
Net loss		11.6		14.3
Total	$	85.6	$	90.8

As approved by the APSC, OG&E is amortizing the deferred costs related to Winter Storm Uri over 10 years using a weighted average cost of capital as a carrying charge.

OG&E refunds state investment tax credits to its Oklahoma customers through the Oklahoma investment tax credit rider.

Accrued removal obligations, net represents asset removal costs previously recovered from ratepayers.

Use of Estimates

Cash and Cash Equivalents

Allowance for Uncollectible Accounts Receivable

Fuel Inventories

Property, Plant and Equipment


December 31, 2025 (In millions)	Percentage Ownership			Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)		77	%	$	254.6	$	81.6	$	173.0
Redbud Plant (A)(B)		51	%	$	582.1	$	261.1	$	321.0

(A)

Construction work in progress was $0.1 million and $25.8 million for the McClain and Redbud Plants, respectively.

(B)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.


December 31, 2024 (In millions)	Percentage Ownership			Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
McClain Plant (A)		77	%	$	244.4	$	75.8	$	168.6
Redbud Plant (A)(B)		51	%	$	556.7	$	247.7	$	309.0

(A)

Construction work in progress was $0.8 million and $5.1 million for the McClain and Redbud Plants, respectively.

(B)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.

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


December 31, 2025 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
OG&E:
Distribution assets	$	7,075.1	$	1,744.3	$	5,330.8
Electric generation assets (A)		5,873.5		2,285.0		3,588.5
Transmission assets (B)		3,524.8		781.1		2,743.7
Intangible plant		2.5		0.7		1.8
Other property and equipment		1,465.9		406.4		1,059.5
OG&E property, plant and equipment		17,941.8		5,217.5		12,724.3
Non-OG&E property, plant and equipment		6.1		—		6.1
Total OGE Energy property, plant and equipment	$	17,947.9	$	5,217.5	$	12,730.4

(A)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $94.7 million.

(B)

This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.


December 31, 2024 (In millions)	Total Property, Plant and Equipment		Accumulated Depreciation		Net Property, Plant and Equipment
OG&E:
Distribution assets	$	6,654.5	$	1,639.8	$	5,014.7
Electric generation assets (A)		5,518.5		2,145.9		3,372.6
Transmission assets (B)		3,432.1		748.5		2,683.6
Intangible plant		752.3		203.7		548.6
Other property and equipment		705.3		244.3		461.0
OG&E property, plant and equipment		17,062.7		4,982.2		12,080.5
Non-OG&E property, plant and equipment		6.1		—		6.1
Total OGE Energy property, plant and equipment	$	17,068.8	$	4,982.2	$	12,086.6

(A)

This amount includes a plant acquisition adjustment of $148.3 million and accumulated amortization of $89.3 million.

(B)

This amount includes a plant acquisition adjustment of $3.3 million and accumulated amortization of $1.2 million.

Depreciation and Amortization

Asset Retirement Obligations

The following table presents changes to OG&E's asset retirement obligations during the years ended December 31, 2025 and 2024.


(In millions)	2025			2024
Balance at January 1	$	84.6		$	81.3
Accretion expense		0.8			0.9
Liabilities settled (A)		(7.6	)		(0.2	)
Revisions in estimated cash flows (B)		—			2.6
Balance at December 31	$	77.8		$	84.6

(A)

Asset retirement obligations were settled for asbestos removal at OG&E's generating facilities.

(B)

Assumptions changed due to new removal estimates related to wind turbine removal at three of OG&E's wind farms in 2024.

Environmental Costs

Allowance for Funds Used During Construction

Collection of Sales Tax

Revenue Recognition

General

Integrated Market and Transmission

Other Revenues

Fuel Adjustment Clauses

Leases

Income Taxes

Accrued Vacation

Related Party Transactions

Accumulated Other Comprehensive Income (Loss)

The following table presents changes in the components of accumulated other comprehensive income (loss) attributable to OGE Energy during 2025 and 2024. 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)			Total
Balance at December 31, 2023	$	(12.1	)	$	(0.8	)	$	5.7		$	(7.2	)
Other comprehensive income (loss) before reclassifications		(0.2	)		—			0.5			0.3
Amounts reclassified from accumulated other comprehensive income (loss)		0.2			0.2			(0.1	)		0.3
Regulatory classification of certain pension costs		3.9			—			—			3.9
Net current period other comprehensive income (loss)		3.9			0.2			0.4			4.5
Balance at December 31, 2024		(8.2	)		(0.6	)		6.1			(2.7	)
Other comprehensive income (loss) before reclassifications		(1.7	)		—			1.4			(0.3	)
Amounts reclassified from accumulated other comprehensive income (loss)		0.3			0.2			(0.1	)		0.4
Net current period other comprehensive income (loss)		(1.4	)		0.2			1.3			0.1
Balance at December 31, 2025	$	(9.6	)	$	(0.4	)	$	7.4		$	(2.6	)


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)	2025			2024
Amortization of Pension Plan and Restoration of Retirement Income Plan items:
Actuarial losses	$	(0.4	)	$	(0.3	)	(A)
Prior service cost		(0.3	)		(0.3	)	(A)
		(0.7	)		(0.6	)	Income Before Taxes
		(0.2	)		(0.2	)	Income Tax Expense
	$	(0.5	)	$	(0.4	)	Net Income

Amortization of postretirement benefit plans items:
Actuarial gains	$	0.2		$	0.2		(A)
		0.2			0.2		Income Before Taxes
		0.1			0.1		Income Tax Expense
	$	0.1		$	0.1		Net Income

Total reclassifications for the period, net of tax	$	(0.4	)	$	(0.3	)	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).

Legislative Matters

Oklahoma

Arkansas

Income Taxes - Schedule of Unrecognized Tax Benefits Roll Forward (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Income Taxes [Line Items]
Unrecognized Tax Benefits, Beginning Balance	$ 28.6	$ 28.6	$ 20.7
Additions	0.0	0.0	7.9
Unrecognized Tax Benefits, Ending Balance	$ 28.6	$ 28.6	$ 28.6

Common Equity (Tables)

12 Months Ended

Dec. 31, 2023

Equity [Abstract]

Schedule of Earnings Per Share Basic and Diluted

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


(In millions except per share data)	2025		2024		2023
Net income	$	470.7	$	441.5	$	416.8
Average common shares outstanding:
Basic average common shares outstanding		201.9		200.8		200.3
Effect of dilutive securities:
Contingently issuable shares (performance and restricted stock units)		0.6		0.5		0.6
Forward equity sale agreements		—		—		—
Diluted average common shares outstanding		202.5		201.3		200.9
Basic earnings per average common share	$	2.33	$	2.20	$	2.08
Diluted earnings per average common share	$	2.32	$	2.19	$	2.07
Anti-dilutive shares excluded from earnings per share calculation		—		—		—

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
CURRENT ASSETS
Cash and cash equivalents	$ 0.2	$ 0.6
Accounts receivable	347.8	240.6
Accrued unbilled revenues	76.2	74.6
Income taxes receivable	37.3	0.0
Fuel inventories	112.0	148.3
Materials and supplies, at average cost	212.7	229.4
Fuel clause under recoveries	0.0	112.7
Other	71.7	88.9
Total current assets	857.9	895.1
OTHER PROPERTY AND INVESTMENTS
Other	129.4	124.2
Total other property and investments	129.4	124.2
PROPERTY, PLANT AND EQUIPMENT
In service	17,203.0	16,254.6
Construction work in progress	744.9	814.2
Total property, plant and equipment	17,947.9	17,068.8
Less: accumulated depreciation	5,217.5	4,982.2
Net property, plant and equipment	12,730.4	12,086.6
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	557.2	568.1
Other	95.6	42.0
Total deferred charges and other assets	652.8	610.1
TOTAL ASSETS	14,370.5	13,716.0
CURRENT LIABILITIES
Short-term debt	292.0	469.3
Accounts payable	350.6	305.7
Dividends payable	87.6	84.7
Customer deposits	127.2	111.1
Accrued taxes	53.0	58.8
Accrued interest	68.8	63.8
Accrued compensation	54.3	53.0
Long-term debt due within one year	0.0	32.4
Fuel clause over recoveries	27.1	9.3
Other	33.5	41.7
Total current liabilities	1,094.1	1,229.8
LONG-TERM DEBT	5,369.2	5,020.9
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	164.4	170.9
Deferred income taxes	1,489.3	1,371.1
Deferred investment tax credits	9.8	10.6
Regulatory liabilities	957.1	1,016.4
Other	309.3	255.4
Total deferred credits and other liabilities	2,929.9	2,824.4
Total liabilities	9,393.2	9,075.1
COMMITMENTS AND CONTINGENCIES (NOTE 13)
STOCKHOLDER'S EQUITY
Common stockholder's equity	1,378.4	1,167.9
Retained earnings	3,601.5	3,475.7
Accumulated other comprehensive loss, net of tax	(2.6)	(2.7)
Total stockholder's equity	4,977.3	4,640.9
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY	14,370.5	13,716.0
OG&E [Member]
CURRENT ASSETS
Cash and cash equivalents	0.2	0.2
Accounts receivable	347.2	240.1
Accrued unbilled revenues	76.2	74.6
Advances to parent	78.3
Fuel inventories	112.0	148.3
Materials and supplies, at average cost	212.7	229.4
Fuel clause under recoveries	0.0	112.7
Other	71.5	83.2
Total current assets	898.1	888.5
OTHER PROPERTY AND INVESTMENTS
Total other property and investments	4.1	4.5
PROPERTY, PLANT AND EQUIPMENT
In service	17,196.9	16,248.5
Construction work in progress	744.9	814.2
Total property, plant and equipment	17,941.8	17,062.7
Less: accumulated depreciation	5,217.5	4,982.2
Net property, plant and equipment	12,724.3	12,080.5
DEFERRED CHARGES AND OTHER ASSETS
Regulatory assets	557.2	568.1
Other	93.8	39.7
Total deferred charges and other assets	651.0	607.8
TOTAL ASSETS	14,277.5	13,581.3
CURRENT LIABILITIES
Accounts payable	348.7	272.2
Advances from parent	0.0	247.6
Customer deposits	127.2	111.1
Accrued taxes	52.3	51.4
Accrued interest	66.4	61.4
Accrued compensation	54.3	53.0
Long-term debt due within one year	0.0	32.4
Fuel clause over recoveries	27.1	9.3
Other	33.5	41.8
Total current liabilities	709.5	880.2
LONG-TERM DEBT	4,961.7	4,614.3
DEFERRED CREDITS AND OTHER LIABILITIES
Accrued benefit obligations	93.2	102.2
Deferred income taxes	1,531.3	1,410.7
Deferred investment tax credits	9.8	10.6
Regulatory liabilities	957.1	1,016.4
Other	274.7	220.5
Total deferred credits and other liabilities	2,866.1	2,760.4
Total liabilities	8,537.3	8,254.9
COMMITMENTS AND CONTINGENCIES (NOTE 13)
STOCKHOLDER'S EQUITY
Common stockholder's equity	1,753.5	1,589.5
Retained earnings	3,986.7	3,736.9
Total stockholder's equity	5,740.2	5,326.4
TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY	$ 14,277.5	$ 13,581.3

CONSOLIDATED STATEMENTS OF CAPITALIZATION - USD ($) $ in Millions	Dec. 31, 2025	Dec. 31, 2024
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	$ 4,977.3	$ 4,640.9
Retained earnings	3,601.5	3,475.7
Accumulated other comprehensive loss, net of tax	(2.6)	(2.7)
Total stockholder's equity	4,977.3	4,640.9
Unamortized debt expense	(33.4)	(32.9)
Unamortized discount	(6.9)	(5.9)
Total long-term debt	5,369.2	5,053.3
Less: long-term debt due within one year	0.0	(32.4)
Total long-term debt (excluding long-term debt due within one year)	5,369.2	5,020.9
Total capitalization (including long-term debt due within one year)	10,346.5	9,694.2
Common Stock
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	2.1	2.0
Premium on Common Stock
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	1,376.3	1,165.9
Retained Earnings
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	3,601.5	3,475.7
Accumulated Other Comprehensive (Loss) Income
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	(2.6)	(2.7)
Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	5,740.2	5,326.4
Retained earnings	3,986.7	3,736.9
Total stockholder's equity	5,740.2	5,326.4
Unamortized debt expense	(31.2)	(29.9)
Unamortized discount	(6.6)	(5.5)
Total long-term debt	4,961.7	4,646.7
Less: long-term debt due within one year	0.0	(32.4)
Total long-term debt (excluding long-term debt due within one year)	4,961.7	4,614.3
Total capitalization (including long-term debt due within one year)	10,701.9	9,973.1
Og and E [Member] \| Common Stock
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	100.9	100.9
Og and E [Member] \| Premium on Common Stock
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	1,652.6	1,488.6
Og and E [Member] \| Retained Earnings
Schedule of Capitalization, Long-term Debt [Line Items]
Stockholder's equity	3,986.7	3,736.9
Senior Notes [Member] \| Series Due May 15, 2029 [Member] \| OGE Energy [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	350.0	350.0
Senior Notes [Member] \| Series Due July 15, 2027 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	125.0	125.0
Senior Notes [Member] \| Series Due April 15, 2028 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	100.0	100.0
Senior Notes [Member] \| Series Due August 15, 2028 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	400.0	400.0
Senior Notes [Member] \| Series Due March 15, 2030 \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	300.0	300.0
Senior Notes [Member] \| Series Due April 1, 2030 \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	300.0	300.0
Senior Notes [Member] \| Series Due January 15, 2033 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	450.0	450.0
Senior Notes [Member] \| Series Due January 15, 2036 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	110.0	110.0
Senior Notes [Member] \| Series Due February 1, 2038 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	200.0	200.0
Senior Notes [Member] \| Series Due June 1, 2040 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	250.0	250.0
Senior Notes [Member] \| Series Due May 15, 2041 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	250.0	250.0
Senior Notes [Member] \| Series Due May 1, 2043 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	250.0	250.0
Senior Notes [Member] \| Series Due March 15, 2044 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	250.0	250.0
Senior Notes [Member] \| Series Due December 15, 2044 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	250.0	250.0
Senior Notes [Member] \| Series due April 1, 2047 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	300.0	300.0
Senior Notes [Member] \| Series due August 15, 2047 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	300.0	300.0
Senior Notes [Member] \| Series Due April 1, 2053 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	700.0	700.0
Senior Notes [Member] \| Series Due April 1, 2055 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	350.0	0.0
Term Loan [Member] \| Due May 24, 2027 \| OGE Energy [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	60.0	60.0
Long-term Debt [Member] \| Due August 31, 2062 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	11.5	11.7
Debentures Subject to Mandatory Redemption [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Total long-term debt		103.0
Debentures Subject to Mandatory Redemption [Member] \| Muskogee Industrial Authority Bond Due 2025 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	0.0	32.4
Debentures Subject to Mandatory Redemption [Member] \| Muskogee Industrial Authority Bond Due 2027 [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	56.0	56.0
Debentures Subject to Mandatory Redemption [Member] \| Garfield Industrial Authority Bond [Member] \| Og and E [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Long-term Debt, Gross	$ 47.0	$ 47.0

Retirement Plans and Postretirement Benefit Plans - Schedule of Capitalized Pension and Postretirement Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Capitalized Portion of Net Periodic Benefit Cost	$ 2.4	$ 2.2	$ 2.2
Pension Plan [Member] \| OG&E [Member]
Defined Benefit Plan Disclosure [Line Items]
Capitalized Portion of Net Periodic Benefit Cost	2.4	2.2	1.9
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Capitalized Portion of Net Periodic Benefit Cost	0.0	0.1	0.1
Other Postretirement Benefits Plan [Member] \| OG&E [Member]
Defined Benefit Plan Disclosure [Line Items]
Capitalized Portion of Net Periodic Benefit Cost	$ 0.0	$ 0.1	$ 0.1

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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Operating Leased Assets [Line Items]

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Statement of Comprehensive Income [Abstract]
Net income	$ 470.7	$ 441.5	$ 416.8
Pension Plan and Restoration of Retirement Income Plan:
Amortization of prior service cost, net of tax of $0.1, $0.1 and $0.1, respectively	0.2	0.2	0.2
Amortization of deferred net loss, net of tax of $0.1, $0.1 and $0.2, respectively	0.3	0.2	0.9
Net (loss) gain arising during the period, net of tax of $(0.5), $0.0 and $1.0, respectively	(1.7)	(0.2)	3.3
Regulatory classification of certain pension costs, net of tax of $0.0, $1.2 and $0.0, respectively	0.0	3.9	0.0
Settlement cost, net of tax of $0.0, $0.0 and $0.4, respectively	0.0	0.0	1.2
Postretirement benefit plans:
Amortization of deferred net gain, net of tax of $(0.1), $(0.1) and $(0.1), respectively	(0.1)	(0.1)	(0.1)
Net gain (loss) arising during the period, net of tax of $0.4, $0.2 and $(0.2), respectively	1.4	0.5	(0.8)
Other comprehensive income, net of tax	0.1	4.5	4.7
Comprehensive income	$ 470.8	$ 446.0	$ 421.5

Retirement Plans and Postretirement Benefit Plans - Schedule of Assumptions Used (Details)	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Pension Plan [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Assumptions Used Calculating Benefit Obligation, Discount Rate	5.45%	5.70%	5.40%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	4.20%	4.20%	4.20%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Weighted-Average Interest Crediting Rate	4.25%	4.25%	3.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	5.70%	5.40%	5.45%
Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	7.00%	7.00%	7.00%
Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	4.20%	4.20%	4.20%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Weighted-Average Interest Crediting Rate	4.25%	3.50%	3.50%
Postretirement Benefit Plans [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Assumptions Used Calculating Benefit Obligation, Discount Rate	5.45%	5.70%	5.35%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	5.70%	5.35%	5.40%
Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	4.50%	4.00%	4.00%

Leases - Schedule of Maturity Analysis of Operating Lease Liabilities (Details) - OGE Energy And OG&E [Member] - USD ($)
$ in Millions

Dec. 31, 2025

Dec. 31, 2024

$ 4.3

4.3

4.3

3.2

3.5

16.1

Total future minimum lease payments

35.7

Less: Imputed interest

6.5

Present value of net minimum lease payments

^[1]

$ 29.2

$ 32.7

[1]	Included in Other Deferred Credits and Other Liabilities in the Registrants' balance sheets.

Commitments and Contingencies - Schedule of Wind Purchased Power (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts	$ 54.8	$ 54.3	$ 48.8
CPV Keenan [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts	28.3	25.4	23.0
Edison Mission Energy [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts	21.9	23.3	20.5
NextEra Energy [Member]
Loss Contingencies [Line Items]
Utilities Operating Expense, Purchased Power under Long-term Contracts	$ 4.6	$ 5.6	$ 5.3

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 275
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
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Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef
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Reference 3: http://www.xbrl.org/2009/role/commonPracticeRef
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
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-Section 50
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
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-Name Accounting Standards Codification
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-URI https://asc.fasb.org/1943274/2147483076/450-20-50-1

Fair Value Measurements

12 Months Ended

Dec. 31, 2025

Fair Value Disclosures [Abstract]

Fair Value Measurements

5. Fair Value Measurements

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

The Registrants had no financial instruments measured at fair value on a recurring basis at December 31, 2025 and 2024. The following table presents the carrying amount and fair value of the Registrants' financial instruments at December 31, 2025 and 2024, as well as the classification level within the fair value hierarchy.


	2025				2024
December 31 (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	$	347.6	$	362.5	$	346.9	$	355.7	Level 2
OGE Energy Term Loan	$	59.9	$	60.0	$	59.7	$	60.0	Level 2
OG&E Senior Notes	$	4,847.2	$	4,644.7	$	4,499.6	$	4,174.9	Level 2
OG&E Industrial Authority Bonds	$	103.0	$	103.0	$	135.4	$	135.4	Level 2
OG&E Tinker Debt	$	11.5	$	9.1	$	11.7	$	9.0	Level 3

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 820
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Reference 3: http://www.xbrl.org/2003/role/exampleRef
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-Topic 940
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Summary of Significant Accounting Policies - Additional Information (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	May 31, 2025	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Summary of Significant Accounting Policies [Line Items]
Deferred Storm and Property Reserve Deficiency, Current		$ 2.7
Allowance for Doubtful Accounts Receivable		$ 4.1	$ 2.0
Provision for Depreciation Rate		2.70%	2.80%	2.80%
Depreciation expense		$ 442.5	$ 436.6	$ 421.6
Projected provision for depreciation in next fiscal year		2.70%
Percent Of Intangible Plant Balance Amortizable		36.81%
Percent of Intangible Plant Balance Amortizable		62.90%
Amortization of intangible assets, period		13 years 1 month 6 days
Amortization of Intangible Assets, Period		19 years 6 months
Amortization of Intangible Assets, Period		23 years 4 months 24 days
Percent of Intangible Plant Balance Amortizable Thereafter		0.29%
Accrued Environmental Loss Contingencies, Noncurrent		$ 21.8	$ 30.2
Environmental Loss Contingency, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Other Liabilities, Noncurrent
Public Utilities, Allowance for Funds Used During Construction, Rate		7.10%	7.10%	7.00%
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party				$ 148.3
Maximum [Member]
Summary of Significant Accounting Policies [Line Items]
Vegetation management operation and maintenance expenses		$ 38.2
Regulatory asset		7.5
Gas Transmission Equipment [Member]
Summary of Significant Accounting Policies [Line Items]
Amount of Acquisition Adjustments		$ 3.3
Gas Transmission Equipment [Member] \| Minimum [Member]
Summary of Significant Accounting Policies [Line Items]
Amortization of intangible assets, period		37 years
Gas Transmission Equipment [Member] \| Maximum [Member]
Summary of Significant Accounting Policies [Line Items]
Amortization of intangible assets, period		59 years
Redbud Plant [Member]
Summary of Significant Accounting Policies [Line Items]
Amortization of intangible assets, period		27 years
Amount of Acquisition Adjustments		$ 148.3	$ 148.3
Oklahoma [Member]
Summary of Significant Accounting Policies [Line Items]
Regulatory asset percent of deferred cost	90.00%	90.00%
Amortization period of regulatory asset	20 years
OG&E [Member]
Summary of Significant Accounting Policies [Line Items]
Allowance for Doubtful Accounts Receivable		$ 4.1	2.0
Capitalized Computer Software, Gross		631.7	280.9
Capitalized Computer Software, Amortization		$ 44.4	32.7	33.4
OG&E [Member] \| Minimum [Member]
Summary of Significant Accounting Policies [Line Items]
Asset Retirement Obligations Accreted, Period		3 years
OG&E [Member] \| Maximum [Member]
Summary of Significant Accounting Policies [Line Items]
Asset Retirement Obligations Accreted, Period		68 years
OGE Energy [Member] \| Retained Earnings [Member]
Summary of Significant Accounting Policies [Line Items]
Dividends, Common Stock		$ 250.0	130.0	$ 500.0
Public Utilities, Inventory, Fuel [Member]
Summary of Significant Accounting Policies [Line Items]
Fuel inventories		$ 112.0	$ 148.3

Stock-Based Compensation - Schedule of Pre-tax Compensation Expense and Related Income Tax Benefit (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 14.0	$ 11.7	$ 13.1
Income tax benefit	3.4	2.8	3.2
OG&E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	14.0	11.7	3.1
Income tax benefit	3.4	2.8	0.7
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	9.6	7.9	9.3
Performance Units [Member] \| OG&E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	9.6	7.9	2.2
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	4.4	3.8	3.8
Restricted Stock Units (RSUs) [Member] \| OG&E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total compensation expense	$ 4.4	$ 3.8	$ 0.9

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

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

Common Equity

12 Months Ended

Dec. 31, 2025

Equity [Abstract]

Common Equity

8. Common Equity

OGE Energy

Automatic Dividend Reinvestment and Stock Purchase Plan

OGE Energy issued 269,387 new shares of common stock under its Automatic Dividend Reinvestment and Stock Purchase Plan in 2025 and received proceeds of $11.9 million. OGE Energy may, from time to time, issue additional shares under its Automatic Dividend Reinvestment and Stock Purchase Plan to fund capital requirements or working capital needs or have shares purchased on the open market. At December 31, 2025, there were 4,053,120 shares of unissued common stock reserved for issuance under OGE Energy's Automatic Dividend Reinvestment and Stock Purchase Plan.

Common Stock Public Offering and Forward Equity Sale Agreements

On November 20, 2025, OGE Energy announced a registered public offering of 8,023,256 shares of its common stock at a public offering price of $43.00 per share, for an aggregate amount of $345.0 million. In conjunction with this offering, underwriters exercised an option to purchase 1,203,488 additional shares at an aggregate public offering price of $51.7 million. Of the 9,226,744 shares offered, half, or 4,613,372 shares, were issued and sold by OGE Energy to the underwriters in November 2025 for $192.4 million (after underwriting discounts), and 4,613,272 shares are subject to FSAs. The 4,613,372 shares that are subject to the FSAs provide for settlement on a settlement date or dates to be specified at OGE Energy’s discretion on or prior to May 27, 2027. The forward sale

price was initially $41.71 per share and is subject to adjustment based on a floating interest rate factor equal to the overnight bank funding rate less a spread and less expected dividends on OGE Energy's common stock during the period the instruments are outstanding.

The FSAs will be physically settled with common shares issued by OGE Energy, unless OGE Energy elects to settle the agreements in net cash or net shares, subject to certain conditions. On a settlement date or dates, if OGE Energy elects to physically settle the FSAs, OGE Energy will issue shares of common stock to the various counterparties at the then-applicable forward sale price and receive issuance proceeds at that time.

At December 31, 2025, OGE Energy could have settled the FSAs with physical delivery of 4,613,372 shares of common stock to the counterparties in exchange for cash of $193.0 million. The FSAs could have also been settled at December 31, 2025, with delivery of $7.9 million of cash or approximately 181,000 shares of common stock to the counterparties, if OGE Energy had elected to net cash or net share settle, respectively. The FSAs have been classified as an equity transaction because they are indexed to OGE Energy’s common stock and the other requirements necessary for equity classification are met. As a result of the equity classification, no gain or loss will be recognized within earnings due to subsequent changes in the fair value of the FSAs.

Prior to settlement, the potentially issuable shares pursuant to the FSAs will be reflected in OGE Energy's diluted earnings per share calculations using the treasury stock method. Under this method, the number of shares of OGE Energy's common stock used in calculating diluted earnings per share for a reporting period would be increased by the number of shares, if any, that would be issued upon physical settlement of the FSAs, less the number of shares that could be purchased by OGE Energy in the market with the proceeds received from issuance (based on the average market price during that reporting period). Share dilution occurs when the average market price of OGE Energy's stock during the reporting period is higher than the then-applicable forward sale price as of the end of the reporting period. For the year ended December 31, 2025, approximately 19,000 incremental shares were included in the calculation of diluted earnings per share related to the securities under the FSAs.

Earnings Per Share

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

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


(In millions except per share data)	2025		2024		2023
Net income	$	470.7	$	441.5	$	416.8
Average common shares outstanding:
Basic average common shares outstanding		201.9		200.8		200.3
Effect of dilutive securities:
Contingently issuable shares (performance and restricted stock units)		0.6		0.5		0.6
Forward equity sale agreements		—		—		—
Diluted average common shares outstanding		202.5		201.3		200.9
Basic earnings per average common share	$	2.33	$	2.20	$	2.08
Diluted earnings per average common share	$	2.32	$	2.19	$	2.07
Anti-dilutive shares excluded from earnings per share calculation		—		—		—

Dividend Restrictions

OGE Energy's Certificate of Incorporation places restrictions on the amount of common stock dividends it can pay when preferred stock is outstanding. Before OGE Energy can pay any dividends on its common stock, the holders of any of its preferred stock that may be outstanding are entitled to receive their dividends at the respective rates as may be provided for the shares of their series. As there is no preferred stock outstanding, that restriction did not place any effective limit on OGE Energy's ability to pay dividends to its shareholders. OGE Energy utilizes dividends from OG&E to pay dividends to its shareholders.

Pursuant to the leverage restriction in OGE Energy's revolving credit agreement, OGE Energy must maintain a percentage of debt to total capitalization at a level that does not exceed 70 percent. The payment of cash dividends indirectly results in an increase in the percentage of debt to total capitalization, which results in the restriction of approximately $1.0 billion of OGE Energy's retained earnings from being paid out in dividends. Accordingly, approximately $2.6 billion of OGE Energy's retained earnings as of December 31, 2025 are unrestricted for the payment of dividends.

OG&E

There were no new shares of OG&E common stock issued in 2025, 2024 or 2023.

Dividend Restrictions

Pursuant to the Federal Power Act, OG&E is restricted from paying dividends from its capital accounts. Dividends are paid from retained earnings. Pursuant to the leverage restriction in OG&E's revolving credit agreement, OG&E must maintain a percentage of debt to total capitalization at a level that does not exceed 65 percent. The payment of cash dividends indirectly results in an increase in the percentage of debt to total capitalization, which results in the restriction of approximately $918.9 million of OG&E's retained earnings from being paid out in dividends. Accordingly, approximately $3.1 billion of OG&E's retained earnings as of December 31, 2025 are unrestricted for the payment of dividends.

Retirement Plans and Postretirement Benefit Plans

12 Months Ended

Dec. 31, 2025

Retirement Plans and Postretirement Benefit Plans

11. Retirement Plans and Postretirement Benefit Plans

OGE Energy sponsors defined benefit pension plans, 401(k) savings plans and other postretirement plans covering certain employees of the Registrants. The columns and table designated as "OGE Energy" within this Note 11 include the OG&E standalone activity, as OGE Energy represents consolidated results.

Pension Plan and Restoration of Retirement Income Plan

OGE Energy periodically makes contributions to the Pension Plan considering information such as net periodic pension expense and funded status from OGE Energy's actuarial consultants. Such contributions are intended to provide not only for benefits attributed to service to date but also for those expected to be earned in the future. OGE Energy made Pension Plan contributions of $13.5 million and $10.0 million in 2025 and 2024, respectively. OGE Energy expects to contribute $15.0 million to its Pension Plan in 2026. OGE Energy could be required to make additional contributions if the value of its pension trust and postretirement benefit plan trust assets are adversely impacted by a major market disruption in the future.

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 2023, the Registrants experienced an increase in both the number of employees electing to retire and the amount of lump sum payments paid to such employees upon retirement, which resulted in the Registrants recording pension plan settlement charges as presented in the Pension Plan net periodic benefit cost tables below. The pension settlement charges did not require a cash outlay by the Registrants and did not increase total pension expense over time, as the charges were an acceleration of costs that otherwise would be recognized as pension expense in future periods.

OGE Energy provides a Restoration of Retirement Income Plan to those participants in OGE Energy's Pension Plan whose benefits are subject to certain limitations of the Code. Participants in the Restoration of Retirement Income Plan receive the same benefits that they would have received under OGE Energy's Pension Plan in the absence of limitations imposed by the federal tax laws. The Restoration of Retirement Income Plan is intended to be an unfunded plan.

OG&E's employees participate in OGE Energy's Pension Plan and Restoration of Retirement Income Plan.

Obligations and Funded Status


	OGE Energy												OG&E
	Pension Plan						Restoration of Retirement Income Plan						Pension Plan						Restoration of Retirement Income Plan
December 31 (In millions)	2025			2024			2025			2024			2025			2024			2025			2024
Change in benefit obligation
Beginning obligations	$	303.1		$	303.7		$	7.0		$	5.5		$	263.9		$	238.6		$	1.4		$	—
Service cost		5.4			5.3			1.0			1.0			5.4			5.3			0.1			0.1
Interest cost		16.2			15.6			0.4			0.3			14.1			13.4			0.1			0.1
Regulatory classification of certain pension costs		—			—			—			—			—			23.9			—			1.1
Special termination benefits		0.5			—			—			—			0.5			—			—			—
Actuarial losses (gains)		11.5			(2.9	)		0.9			0.2			8.9			(2.2	)		0.3			0.1
Benefits paid		(21.5	)		(18.6	)		—			—			(18.9	)		(15.1	)		—			—
Ending obligations	$	315.2		$	303.1		$	9.3		$	7.0		$	273.9		$	263.9		$	1.9		$	1.4

Change in plans' assets
Beginning fair value	$	246.9		$	243.7		$	—		$	—		$	211.6		$	191.4		$	—		$	—
Actual return on plans' assets		23.3			11.8			—			—			20.0			10.1			—			—
Employer contributions		13.5			10.0			—			—			13.5			10.0			—			—
Regulatory classification of certain pension costs		—			—			—			—			—			15.2			—			—
Benefits paid		(21.5	)		(18.6	)		—			—			(18.9	)		(15.1	)		—			—
Ending fair value	$	262.2		$	246.9		$	—		$	—		$	226.2		$	211.6		$	—		$	—
Funded status at end of year	$	(53.0	)	$	(56.2	)	$	(9.3	)	$	(7.0	)	$	(47.7	)	$	(52.3	)	$	(1.9	)	$	(1.4	)
Accumulated postretirement benefit obligation	$	305.6		$	289.4		$	8.9		$	6.8		$	264.3		$	250.2		$	1.7		$	1.4


	OGE Energy						OG&E
	Postretirement Benefit Plans						Postretirement Benefit Plans
December 31 (In millions)	2025			2024			2025			2024
Change in benefit obligation
Beginning obligations	$	98.1		$	103.3		$	74.7		$	77.3
Service cost		0.1			0.1			0.1			0.1
Interest cost		5.4			5.2			4.1			3.9
Participants' contributions		2.5			3.5			1.8			2.4
Actuarial gains		(3.8	)		(3.1	)		(1.9	)		(2.1	)
Regulatory classification of certain pension costs		—			—			—			1.4
Benefits paid		(11.9	)		(10.9	)		(9.1	)		(8.3	)
Ending obligations	$	90.4		$	98.1		$	69.7		$	74.7

Change in plans' assets
Beginning fair value	$	30.0		$	32.7		$	27.2		$	29.6
Actual return on plans' assets		1.8			(1.6	)		1.7			(1.4	)
Employer contributions		6.0			6.3			4.6			4.9
Participants' contributions		2.5			3.5			1.8			2.4
Benefits paid		(11.9	)		(10.9	)		(9.1	)		(8.3	)
Ending fair value	$	28.4		$	30.0		$	26.2		$	27.2
Funded status at end of year	$	(62.0	)	$	(68.1	)	$	(43.5	)	$	(47.5	)

Net Periodic Benefit Cost


OGE Energy	Pension Plan									Restoration of Retirement Income Plan
Year Ended December 31 (In millions)	2025			2024			2023			2025		2024		2023
Service cost	$	5.4		$	5.3		$	5.4		$	1.0	$	1.0	$	1.0
Interest cost		16.2			15.6			15.9			0.4		0.3		0.3
Expected return on plan assets		(16.5	)		(16.5	)		(16.2	)		—		—		—
Amortization of net loss		6.2			6.5			8.0			0.1		—		—
Special termination benefits		0.5			—			—			—		—		—
Amortization of unrecognized prior service cost (A)		—			—			—			0.3		0.3		0.3
Settlement cost		—			—			21.8			—		—		0.5
Net periodic benefit cost	$	11.8		$	10.9		$	34.9		$	1.8	$	1.6	$	2.1

(A)


OG&E	Pension Plan									Restoration of Retirement Income Plan
Year Ended December 31 (In millions)	2025			2024			2023			2025		2024		2023
Service cost	$	5.4		$	5.3		$	4.4		$	0.1	$	0.1	$	—
Interest cost		14.1			13.4			12.6			0.1		0.1		—
Expected return on plan assets		(14.2	)		(14.0	)		(12.9	)		—		—		—
Amortization of net loss		5.9			6.2			6.9			—		—		—
Special termination benefits		0.5			—			—			—		—		—
Settlement cost		—			—			20.4			—		—		0.4
Total net periodic benefit cost		11.7			10.9			31.4			0.2		0.2		0.4
Plus: Amount allocated from OGE Energy		—			—			3.0			1.6		1.4		1.7
Net periodic benefit cost	$	11.7		$	10.9		$	34.4		$	1.8	$	1.6	$	2.1


Year Ended December 31 (In millions)	2025			2024		2023
Change in pension expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	(0.4	)	$	5.8	$	33.3
Deferral of pension expense related to pension settlement and special termination benefits charges included in the above line item:
Oklahoma jurisdiction (A)	$	0.5		$	—	$	20.1
Arkansas jurisdiction (A)	$	—		$	—	$	1.9

(A)

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


	OGE Energy									OG&E
	Postretirement Benefit Plans									Postretirement Benefit Plans
Year Ended December 31 (In millions)	2025			2024			2023			2025			2024			2023
Service cost	$	0.1		$	0.1		$	0.1		$	0.1		$	0.1		$	0.1
Interest cost		5.4			5.2			5.2			4.1			3.9			3.9
Expected return on plan assets		(1.7	)		(1.6	)		(1.7	)		(1.5	)		(1.4	)		(1.6	)
Amortization of net loss (gain)		0.4			(0.2	)		(0.2	)		0.6			—			—
Total net periodic benefit cost		4.2			3.5			3.4			3.3			2.6			2.4
Plus: Amount allocated from OGE Energy											0.4			0.5			0.5
Net periodic benefit cost	$	4.2		$	3.5		$	3.4		$	3.7		$	3.1		$	2.9


Year Ended December 31 (In millions)	2025		2024		2023
Change in postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)	$	0.6	$	2.3	$	4.4

(A)

Included in the pension regulatory asset, as indicated in the regulatory assets and liabilities table in Note 1.


	OGE Energy						OG&E
(In millions)	2025		2024		2023		2025		2024		2023
Capitalized portion of net periodic pension benefit cost	$	2.4	$	2.2	$	2.2	$	2.4	$	2.2	$	1.9
Capitalized portion of net periodic postretirement benefit cost	$	—	$	0.1	$	0.1	$	—	$	0.1	$	0.1

Rate Assumptions


	Pension Plan and Restoration of Retirement Income Plan									Postretirement Benefit Plans
Year Ended December 31	2025			2024			2023			2025			2024			2023
Assumptions to determine benefit obligations:
Discount rate		5.45	%		5.70	%		5.40	%		5.45	%		5.70	%		5.35	%
Rate of compensation increase		4.20	%		4.20	%		4.20	%	N/A			N/A			N/A
Interest crediting rate		4.25	%		4.25	%		3.50	%	N/A			N/A			N/A
Assumptions to determine net periodic benefit cost:
Discount rate		5.70	%		5.40	%		5.45	%		5.70	%		5.35	%		5.40	%
Expected return on plan assets		7.00	%		7.00	%		7.00	%		4.50	%		4.00	%		4.00	%
Rate of compensation increase		4.20	%		4.20	%		4.20	%	N/A			N/A			N/A
Interest crediting rate		4.25	%		3.50	%		3.50	%	N/A			N/A			N/A

N/A - not applicable

The discount rate used to compute the present value of plan liabilities is based generally on rates of high-grade corporate bonds with maturities similar to the average period over which benefits will be paid. The discount rate used to determine net benefit cost for the current year is the same discount rate used to determine the benefit obligation as of the previous year's balance sheet date, unless a plan settlement occurs during the current year that requires an updated discount rate for net periodic cost measurement. For 2025 and 2024, the Pension Plan discount rates used to determine net periodic benefit cost are disclosed on a weighted-average basis.

The overall expected rate of return on plan assets assumption is used in determining net periodic benefit cost. The rate of return on plan assets assumption is the average long-term rate of earnings expected on the funds currently invested and to be invested for the purpose of providing benefits specified by the Pension Plan or postretirement benefit plans. This assumption is reexamined at least annually and updated as necessary. The rate of return on plan assets assumption reflects a combination of historical return analysis, forward-looking return expectations and the plans' current and expected asset allocation.

The assumed health care cost trend rates have a significant effect on the amounts reported for postretirement medical benefit plans. Future health care cost trend rates are assumed to be 8.0 percent in 2026 with the rates trending downward to 4.0 percent by 2034.

Pension Plan

Pension Plan Investments, Policies and Strategies


Projected Benefit Obligation Funded Status Thresholds	<90%	95%	100%	105%	110%	115%	120%
Fixed income	50%	58%	65%	73%	80%	85%	90%
Equity	50%	42%	35%	27%	20%	15%	10%
Total	100%	100%	100%	100%	100%	100%	100%

Within the portfolio's overall allocation to equities, the funds are allocated according to the guidelines in the following table.


Asset Class	Target Allocation	Minimum	Maximum
Domestic Large Cap Equity	40%	35%	60%
Domestic Mid-Cap Equity	15%	5%	25%
Domestic Small-Cap Equity	25%	5%	30%
International Equity	20%	10%	30%

OGE Energy has retained an investment consultant responsible for the general investment oversight, analysis, monitoring investment guideline compliance and providing quarterly reports to certain of the Registrants' members and OGE Energy's Investment Committee. The various investment managers used by the trust operate within the general operating objectives as established in the investment policy and within the specific guidelines established for each investment manager's respective portfolio.

The portfolio is rebalanced at least on an annual basis to bring the asset allocations of various managers in line with the target asset allocation listed above. More frequent rebalancing may occur if there are dramatic price movements in the financial markets which may cause the trust's exposure to any asset class to exceed or fall below the established allowable guidelines.

To evaluate the progress of the portfolio, investment performance is reviewed quarterly. It is, however, expected that performance goals will be met over a full market cycle, normally defined as a three- to five-year period. Analysis of performance is within the context of the prevailing investment environment and the advisors' investment style. The goal of the trust is to provide a rate of return consistently from three percent to five percent over the rate of inflation (as measured by the national Consumer Price Index) on a fee adjusted basis over a typical market cycle of no less than three years and no more than five years. Each investment manager is expected to outperform its respective benchmark.

The following table presents a list of each asset class utilized with appropriate comparative benchmark(s) each manager is evaluated against and the focus of the asset class.


Asset Class	Comparative Benchmark(s)	Focus of Asset Class
Active Duration Fixed Income (A)(B)	Bloomberg Barclays Aggregate	- Maximize risk-adjusted performance while providing long bond exposure managed according to the manager's forecast on interest rates. - All invested assets must reach at or above Baa3 or BBB- investment grade. - Limited five percent exposure to any single issuer, except the U.S. Government or affiliates.
Long Duration Fixed Income (A)(B)	Duration blended Barclays Long Government/Credit & Barclays Universal	- Maximize risk-adjusted performance. - At least 75 percent of invested assets must reach at or above Baaa3 or BBB- investment grade. - Limited five percent exposure to any single issuer, except the U.S. Government or affiliates. - May invest up to 10 percent of the market value in convertible bonds as long as quality guidelines are met. - May invest up to 15 percent of the market value in private placement, including 144A securities with or without registration rights and allow for futures to be traded in the portfolio.
Equity Index (B)(C)	Standard & Poor's 500 Index	- Focus on replicating the performance of the S&P 500 Index.
Mid-Cap Equity (B)(C) Small-Cap Equity (B)(C)	Russell Midcap Index Russell Midcap Value Index Russell 2000 Index Russell 2000 Value Index	- Focus on undervalued stocks expected to earn average return and pay out higher than average dividends. - Invest in companies with market capitalizations lower than average company on public exchanges: - Price/earnings ratio at or near referenced - Small dividend yield and return on equity at or near referenced index; and - Earnings per share growth rate at or near referenced index.
International Equity (D)	Morgan Stanley Capital International ACWI ex-U.S.	- Invest in non-dollar denominated equity securities. - Diversify the overall trust investments.

(A)

Investment grades are by Moody's Investors Service, S&P Global Ratings or Fitch Ratings.

(B)

The purchase of any of OGE Energy's equity, debt or other securities is prohibited.

(C)

No more than five percent can be invested in any one stock at the time of purchase and no more than 10 percent after accounting for price appreciation. Options or financial futures may not be purchased unless prior approval from OGE Energy's Investment Committee is received. The purchase of securities on margin, securities lending, private placement purchases and venture capital purchases are prohibited. The aggregate positions in any company may not exceed one percent of the fair market value of its outstanding stock.

(D)

The manager of this asset class is required to operate under certain restrictions including regional constraints, diversification requirements and percentage of U.S. securities. All securities are freely traded on a recognized stock exchange, and there are no over-the-counter derivatives. The following investment categories are excluded: options (other than traded currency options), commodities, futures (other than currency futures or currency hedging), short sales/margin purchases, private placements, unlisted securities and real estate (but not real estate shares).

Pension Plan Investments


(In millions)	December 31, 2025			Level 1		Level 2		Net Asset Value (A)
Common stocks	$	38.0		$	38.0	$	—	$	—
U.S. Treasury notes and bonds (B)		41.3			41.3		—		—
Mortgage- and asset-backed securities		22.3			—		22.3		—
Corporate fixed income and other securities		51.9			—		51.9		—
Commingled fund (C)		18.7			—		—		18.7
Foreign government bonds		0.1			—		0.1		—
U.S. municipal bonds		0.1			—		0.1		—
Money market fund		10.6			—		—		10.6
Mutual funds		83.0			83.0		—		—
U.S. Treasury futures:
Cash collateral		0.9			0.9		—		—
Forward contracts:
Receivable (foreign currency)		0.1			—		0.1		—
Total Pension Plan investments		267.0		$	163.2	$	74.5	$	29.3
Interest and dividends receivable		1.4
Receivable from broker for securities sold		9.0
Payable to broker for securities purchased		(15.2	)
Total OGE Energy Pension Plan assets	$	262.2
Pension Plan investments attributable to affiliates		(36.0	)
Total OG&E Pension Plan assets	$	226.2


(In millions)	December 31, 2024			Level 1		Level 2		Net Asset Value (A)
Common stocks	$	55.7		$	55.7	$	—	$	—
U.S. Treasury notes and bonds (B)		49.3			49.3		—		—
Mortgage- and asset-backed securities		23.9			—		23.9		—
Corporate fixed income and other securities		50.3			—		50.3		—
Commingled fund (C)		13.4			—		—		13.4
Foreign government bonds		0.3			—		0.3		—
U.S. municipal bonds		0.1			—		0.1		—
Money market fund		0.9			—		—		0.9
Mutual funds		62.0			62.0		—		—
Preferred stocks		0.5			0.5		—		—
U.S. Treasury futures:
Cash collateral		0.1			0.1		—		—
Forward contracts:
Receivable (foreign currency)		0.1			—		0.1		—
Total Pension Plan investments		256.6		$	167.6	$	74.7	$	14.3
Interest and dividends receivable		1.5
Receivable from broker for securities sold		9.1
Payable to broker for securities purchased		(20.3	)
Total OGE Energy Pension Plan assets	$	246.9
Pension Plan investments attributable to affiliates		(35.3	)
Total OG&E Pension Plan assets	$	211.6

(A)

(B)

This category represents U.S. Treasury notes and bonds with a Moody's Investors Service rating of Aaa and Government Agency Bonds with a Moody's Investors Service rating of A1 or higher.

(C)

This category represents units of participation in a commingled fund that primarily invested in stocks of international companies and emerging markets.

As defined in the fair value hierarchy, Level 1 inputs are quoted prices in active markets for identical unrestricted assets or liabilities that are accessible by the Pension Plan 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 Plan's own assumptions about the assumptions that market participants would use in pricing the asset or liability (including assumptions about risk).

Expected Benefit Payments


(In millions)	OGE Energy		OG&E
2026	$	59.1	$	52.3
2027	$	42.2	$	30.1
2028	$	33.4	$	29.4
2029	$	30.6	$	27.5
2030	$	29.3	$	25.4
2031-2035	$	120.9	$	105.9

Postretirement Benefit Plans

In addition to providing pension benefits, OGE Energy provides certain medical and life insurance benefits for eligible retired members. Regular, full-time, active employees hired prior to February 1, 2000 whose age and years of credited service total or exceed 80 or have attained at least age 55 with 10 or more years of service at the time of retirement are entitled to postretirement medical benefits, while employees hired on or after February 1, 2000 are not entitled to postretirement medical benefits. Eligible retirees must contribute such amount as OGE Energy specifies from time to time toward the cost of coverage for postretirement benefits. The benefits are subject to deductibles, co-payment provisions and other limitations. OG&E charges postretirement benefit costs to expense and includes an annual amount as a component of the cost-of-service in future ratemaking proceedings.

OGE Energy's contribution to the medical costs for pre-65 aged eligible retirees are fixed at the 2011 level, and OGE Energy covers future annual medical inflationary cost increases up to five percent. Increases in excess of five percent annually are covered by the pre-65 aged retiree in the form of premium increases. OGE Energy provides Medicare-eligible retirees and their Medicare-eligible spouses an annual fixed contribution to an OGE Energy-sponsored health reimbursement arrangement. Medicare-eligible retirees are able to purchase individual insurance policies supplemental to Medicare through a third-party administrator and use their health reimbursement arrangement funds for reimbursement of medical premiums and other eligible medical expenses.

Postretirement Plans Investments


(In millions)	December 31, 2025			Level 1		Level 3
Group retiree medical insurance contract	$	8.7		$	—	$	8.7
Mutual funds		19.7			19.7		—
Total OGE Energy plan investments	$	28.4		$	19.7	$	8.7
Plan investments attributable to affiliates		(2.2	)
Total OG&E plan investments	$	26.2


(In millions)	December 31, 2024			Level 1		Level 3
Group retiree medical insurance contract	$	13.6		$	—	$	13.6
Mutual funds		16.4			16.4		—
Total OGE Energy plan investments	$	30.0		$	16.4	$	13.6
Plan investments attributable to affiliates		(2.8	)
Total OG&E plan investments	$	27.2

The group retiree medical insurance contract invests in a pool of common stocks, bonds and money market accounts, of which a significant portion is comprised of mortgage-backed securities. The unobservable input included in the valuation of the contract includes the approach for determining the allocation of the postretirement benefit plans' pro-rata share of the total assets in the contract.

The following table presents a reconciliation of the postretirement benefit plans' investments that are measured at fair value on a recurring basis using significant unobservable inputs (Level 3).


Year Ended December 31 (In millions)	2025
Group retiree medical insurance contract:
Beginning balance	$	13.6
Claims paid		(5.4	)
Interest income		0.3
Realized gains		0.1
Investment fees		(0.1	)
Net unrealized gains related to instruments held at the reporting date		0.2
Ending balance	$	8.7

Medicare Prescription Drug, Improvement and Modernization Act of 2003


(In millions)	OGE Energy		OG&E
2026	$	12.1	$	9.1
2027	$	9.6	$	7.2
2028	$	8.9	$	6.8
2029	$	8.3	$	6.5
2030	$	7.9	$	6.1
2031-2035	$	33.3	$	26.0

401(k) Plan

OGE Energy provides a 401(k) Plan, and each regular full-time employee of OGE Energy or a participating affiliate is eligible to participate in the 401(k) Plan immediately upon hire. All other employees of OGE Energy or a participating affiliate are eligible to become participants in the 401(k) Plan after completing one year of service as defined in the 401(k) Plan. Participants may contribute each pay period any whole percentage between two percent and 75 percent of their compensation, as defined in the 401(k) Plan, for that pay period. Participants who have reached age 50 before the close of a year are allowed to make additional contributions referred to as "Catch-Up Contributions," subject to certain limitations of the Code. Participants may designate, at their discretion, all or any portion of their contributions as: (i) a before-tax contribution under Section 401(k) of the Code subject to the limitations thereof, (ii) a contribution made on a non-Roth after-tax basis or (iii) a Roth contribution. The 401(k) Plan also includes an eligible automatic contribution arrangement and provides for a qualified default investment alternative consistent with the U.S. Department of Labor regulations. Participants may elect, in accordance with the 401(k) Plan procedures, to have their future salary deferral rate to be automatically increased annually on a date and in an amount as specified by the participant in such election. For employees hired or rehired on or after December 1, 2009, OGE Energy contributes to the 401(k) Plan, on behalf of each participant, 200 percent of the participant's contributions up to five percent of compensation.

No OGE Energy contributions are made with respect to a participant's rollover contributions or with respect to a participant's contributions based on overtime payments, pay-in-lieu of overtime for exempt personnel, special lump-sum recognition awards and lump-sum merit awards included in compensation for determining the amount of participant contributions. Once made, OGE Energy's contribution may be directed to any available investment option in the 401(k) Plan. OGE Energy match contributions vest over a three-year period. After two years of service, participants become 20 percent vested in their OGE Energy contribution account and become fully vested on completing three years of service. In addition, participants fully vest when they are eligible for normal or early retirement under the Pension Plan requirements, in the event of their termination due to death or permanent disability or upon attainment of age 65 while employed by OGE Energy or its affiliates. OGE Energy contributed $21.9 million, $21.4 million and $19.6 million in 2025, 2024 and 2023, respectively, to the 401(k) Plan, of which $21.9 million, $21.4 million and $16.0 million, respectively, related to OG&E.

Deferred Compensation Plan

OGE Energy provides a nonqualified deferred compensation plan which is intended to be an unfunded plan. The plan's primary purpose is to provide a tax-deferred capital accumulation vehicle for a select group of management, highly compensated employees and non-employee members of OGE Energy's Board of Directors and to supplement such employees' 401(k) Plan contributions as well as offering this plan to be competitive in the marketplace.

Eligible employees who enroll in the plan have the following deferral options: (i) eligible employees may elect to defer up to a maximum of 70 percent of base salary and 100 percent of annual bonus awards or (ii) eligible employees may elect a deferral percentage of base salary and bonus awards based on the deferral percentage elected for a year under the 401(k) Plan with such deferrals to start when maximum deferrals to the qualified 401(k) Plan have been made because of limitations in that plan. Eligible directors who enroll in the plan may elect to defer up to a maximum of 100 percent of directors' meeting fees and annual retainers. OGE Energy matches employee (but not non-employee director) deferrals to make up for any match lost in the 401(k) Plan because of deferrals to the deferred compensation plan and to allow for a match that would have been made under the 401(k) Plan on that portion of either the first six percent of total compensation or the first five percent of total compensation, depending on prior participant elections, deferred that exceeds the limits allowed in the 401(k) Plan. Matching credits vest based on years of service, with full vesting after three years or, if earlier, on retirement, disability, death, a change in control of OGE Energy or termination of the plan. Deferrals, plus any OGE Energy match, are credited to a recordkeeping account in the participant's name. Earnings on the deferrals are indexed to the assumed investment funds selected by the participant. In 2025, those investment options included an OGE Energy Common Stock fund, whose value was determined based on the stock price of OGE Energy's Common Stock. OGE Energy accounts for the contributions related to its executive officers in this plan as Accrued Benefit Obligations and accounts for the contributions related to OGE Energy's directors in this plan as Other Deferred Credits and Other Liabilities in the balance sheets. The investment associated with these contributions is accounted for as Other Property and Investments in the balance sheets. The appreciation of these investments is accounted for as Other Income, and the increase in the liability under the plan is accounted for as Other Expense in the statements of income.

Supplemental Executive Retirement Plan

OGE Energy provides a supplemental executive retirement plan in order to attract and retain lateral hires or other executives designated by the Compensation Committee of OGE Energy's Board of Directors who may not otherwise qualify for a sufficient level of benefits under OGE Energy's Pension Plan and Restoration of Retirement Income Plan. The supplemental executive retirement plan is intended to be an unfunded plan and not subject to the benefit limitations of the Code. For the actuarial equivalence calculations, the supplemental executive retirement plan provides that (i) mortality rates shall be based on the unisex mortality table issued under Internal Revenue Service Notice 2018-02 for purposes of determining the minimum present value under Code Section 417(e)(3) for distributions with annuity starting dates that occur during stability periods beginning in the 2019 calendar year and (ii) the interest rate shall be five percent.

The entire disclosure for retirement benefits.

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Summary of Significant Accounting Policies Property - Schedule of Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Related Party Transaction [Line Items]
Operating revenues	$ 3,260.1	$ 2,985.3	$ 2,674.3
Og and E [Member]
Related Party Transaction [Line Items]
Operating revenues	$ 3,260.1	$ 2,985.3	$ 2,674.3

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

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Amount of revenue recognized from goods sold, services rendered, insurance premiums, or other activities that constitute an earning process. Includes, but is not limited to, investment and interest income before deduction of interest expense when recognized as a component of revenue, and sales and trading gain (loss).

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Stock Based Compensation - Additional Information (Details) - shares	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Number of Shares Authorized	8,417,755
Number of treasury stock used			2,371
New common stock shares issued	234,476	255,578	82,321
2022 Stock Incentive Plan
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
New common stock shares issued	252

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Stock-Based Compensation - Restricted Stock Valuation Assumptions (Details) - Restricted Stock [Member] - $ / shares	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	121,056	148,345	114,926
Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 43.69	$ 32.74	$ 37.52
Og and E [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted	121,056	148,345	35,034
Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 43.69	$ 32.74	$ 37.52

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2025

Unrecorded Unconditional Purchase Obligations Disclosure

The following table presents the Registrants' future purchase obligations and commitments estimated for the next five years.


(In millions)	2026		2027		2028		2029		2030		Total
Purchase obligations and commitments:
Minimum purchase commitments	$	110.4	$	72.5	$	67.1	$	63.8	$	63.9	$	377.7
Wind purchase commitments		57.3		57.8		58.4		58.6		57.8		289.9
Capacity commitments		105.0		41.5		31.3		26.9		27.8		232.5
Long-term service agreement commitments		50.1		19.0		8.9		4.5		5.6		88.1
Generation capacity construction commitments		98.3		481.5		98.0		17.1		—		694.9
Total purchase obligations and commitments	$	421.1	$	672.3	$	263.7	$	170.9	$	155.1	$	1,683.1

Schedule of Wind Purchased Power

The following table presents OG&E's wind purchased power contracts.


Company	Location	Original Term of Contract	Expiration of Contract	MWs
CPV Keenan	Woodward County, OK	20 years	2030		152.0
Edison Mission Energy	Dewey County, OK	20 years	2031		130.0
NextEra Energy	Blackwell, OK	20 years	2032		60.0

The following table presents a summary of OG&E's wind power purchases for the years ended December 31, 2025, 2024 and 2023.


Year Ended December 31 (In millions)	2025		2024		2023
CPV Keenan	$	28.3	$	25.4	$	23.0
Edison Mission Energy		21.9		23.3		20.5
NextEra Energy		4.6		5.6		5.3
Total wind power purchased	$	54.8	$	54.3	$	48.8

Report of Business Segments

12 Months Ended

Dec. 31, 2025

Segment Reporting [Abstract]

Report of Business Segments

12. Report of Business Segments

OGE Energy reports its operations primarily through a single segment, captioned "electric company," which is engaged in the generation, transmission, distribution and sale of electric energy. The "other operations" caption primarily includes the operations of the holding company and other energy-related investments. Intersegment revenues are recorded at prices comparable to those of unaffiliated customers and are affected by regulatory considerations. In accordance with ASC Topic 280, “Segment Reporting,” the Registrants have identified their Chief Executive Officer as the “chief operating decision maker.” The Chief Executive Officer uses net income as the measure of reportable segment profit or loss to make operating decisions, allocate resources, and assess performance. The following tables, which include significant segment expenses, present the results of OGE Energy's business segments for the years ended December 31, 2025, 2024 and 2023.


2025	Electric Company		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	3,260.1	$	—		$	—		$	3,260.1
Fuel, purchased power and direct transmission expense		1,259.9		—			—			1,259.9
Other operation and maintenance		531.0		0.6			—			531.6
Depreciation and amortization		559.8		—			—			559.8
Taxes other than income		109.4		—			—			109.4
Operating income (loss)		800.0		(0.6	)		—			799.4
Other income		30.4		7.4			(6.4	)		31.4
Interest expense		225.5		51.2			(6.4	)		270.3
Income tax expense (benefit)		105.1		(15.3	)		—			89.8
Net income (loss)	$	499.8	$	(29.1	)	$	—		$	470.7
Total assets	$	14,277.5	$	134.1		$	(41.1	)	$	14,370.5
Capital expenditures	$	1,054.4	$	—		$	—		$	1,054.4


2024	Electric Company		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	2,985.3	$	—		$	—		$	2,985.3
Fuel, purchased power and direct transmission expense		1,076.4		—			—			1,076.4
Other operation and maintenance		514.1		0.3			—			514.4
Depreciation and amortization		539.5		—			—			539.5
Taxes other than income		109.7		—			—			109.7
Operating income (loss)		745.6		(0.3	)		—			745.3
Other income		31.9		2.4			(4.5	)		29.8
Interest expense		214.4		44.6			(4.5	)		254.5
Income tax expense (benefit)		93.2		(14.1	)		—			79.1
Net income (loss)	$	469.9	$	(28.4	)	$	—		$	441.5
Total assets	$	13,581.3	$	402.9		$	(268.2	)	$	13,716.0
Capital expenditures	$	1,090.9	$	—		$	—		$	1,090.9


2023	Electric Company		Other Operations			Eliminations			Total
(In millions)
Operating revenues	$	2,674.3	$	—		$	—		$	2,674.3
Fuel, purchased power and direct transmission expense		911.7		—			—			911.7
Other operation and maintenance		505.0		(2.4	)		—			502.6
Depreciation and amortization		506.6		—			—			506.6
Taxes other than income		99.4		3.8			—			103.2
Operating income (loss)		651.6		(1.4	)		—			650.2
Other income		43.5		8.1			(7.4	)		44.2
Interest expense		199.9		28.9			(7.4	)		221.4
Income tax expense (benefit)		68.8		(12.6	)		—			56.2
Net income (loss)	$	426.4	$	(9.6	)	$	—		$	416.8
Total assets	$	12,642.6	$	301.1		$	(153.0	)	$	12,790.7
Capital expenditures	$	1,178.2	$	—		$	—		$	1,178.2

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

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Summary of Significant Accounting Policies - Summary of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Balance	$ 4,640.9	$ 4,511.6	$ 4,413.4
Other comprehensive income (loss) before reclassifications	(0.3)	0.3
Amounts reclassified from accumulated other comprehensive income (loss)	0.4	0.3
Regulatory classification of certain pension costs	0.0	3.9	0.0
Settlement cost	0.0	0.0	1.2
Net current period other comprehensive income (loss)	0.1	4.5	4.7
Balance	4,977.3	4,640.9	4,511.6
Accumulated other comprehensive loss, net of tax	(2.6)	(2.7)
Net current period other comprehensive income (loss)	0.1	4.5	4.7
Defined Benefit Plans Income Loss [Member] \| Pension Plans, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Balance	(8.2)	(12.1)
Other comprehensive income (loss) before reclassifications	(1.7)	(0.2)
Amounts reclassified from accumulated other comprehensive income (loss)	0.3	0.2
Regulatory classification of certain pension costs		3.9
Net current period other comprehensive income (loss)	(1.4)	3.9
Balance	(9.6)	(8.2)	(12.1)
Defined Benefit Plans Income Loss [Member] \| Other Postretirement Benefits Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Balance	6.1	5.7
Other comprehensive income (loss) before reclassifications	1.4	0.5
Amounts reclassified from accumulated other comprehensive income (loss)	(0.1)	(0.1)
Regulatory classification of certain pension costs		0.0
Net current period other comprehensive income (loss)	1.3	0.4
Balance	7.4	6.1	5.7
Defined Benefit Plan Prior Service Cost [Member] \| Pension Plans, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Balance	(0.6)	(0.8)
Other comprehensive income (loss) before reclassifications	0.0	0.0
Amounts reclassified from accumulated other comprehensive income (loss)	0.2	0.2
Regulatory classification of certain pension costs		0.0
Net current period other comprehensive income (loss)	0.2	0.2
Balance	(0.4)	(0.6)	(0.8)
Accumulated Other Comprehensive Income (Loss) [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Balance	(2.7)	(7.2)	(11.9)
Net current period other comprehensive income (loss)	0.1	4.5	4.7
Balance	$ (2.6)	$ (2.7)	$ (7.2)

Summary of Significant Accounting Policies - Reconciliation of Equity in Earnings (Losses) of Unconsolidated Affiliates (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Schedule of Equity Method Investments [Line Items]
Net income (loss)	$ 470.7	$ 441.5	$ 416.8

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

Operating Leased Assets [Line Items]

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References + Details

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY - USD ($) $ in Millions	Total	OG&E [Member]	Common Stock	Common Stock OG&E [Member]	Treasury Stock	Premium on Common Stock	Premium on Common Stock OG&E [Member]	Retained Earnings	Retained Earnings OG&E [Member]	Accumulated Other Comprehensive (Loss) Income
Balance at Dec. 31, 2022	$ 4,413.4	$ 5,045.2	$ 2.0	$ 100.9	$ (0.1)	$ 1,132.5	$ 1,473.7	$ 3,290.9	$ 3,470.6	$ (11.9)
Common Stock, Shares, Outstanding at Dec. 31, 2022			200,200,000	40,400,000
Treasury Stock, Common, Shares at Dec. 31, 2022					0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	416.8	426.4	$ 0.0	$ 0.0	$ 0.0	0.0	0.0	416.8	426.4	0.0
Net income, Number of Shares			0	0	0
Other comprehensive income, net of tax, Number of Shares			0		0
Other comprehensive income, net of tax	4.7	0.0	$ 0.0		$ 0.0	0.0		0.0		4.7
Dividends declared on common stock, Number of Shares			0	0	0
Dividends declared on common stock	$ (334.0)	$ (500.0)	$ 0.0	$ 0.0	$ 0.0	0.0	0.0	(334.0)	(500.0)	0.0
Issuance of common stock, Number of Shares	82,321	0
Stock-based compensation, Number of Shares			100,000	0	0
Stock-based compensation	$ 10.7	$ 3.1	$ 0.0	$ 0.0	$ 0.1	10.6	3.1	0.0	0.0	0.0
Balance at Dec. 31, 2023	4,511.6	4,974.7	$ 2.0	$ 100.9	$ 0.0	1,143.1	1,476.8	3,373.7	3,397.0	(7.2)
Common Stock, Shares, Outstanding at Dec. 31, 2023			200,300,000	40,400,000
Treasury Stock, Common, Shares at Dec. 31, 2023					0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	441.5	469.9	$ 0.0	$ 0.0	$ 0.0	0.0	0.0	441.5	469.9	0.0
Net income, Number of Shares			0	0	0
Other comprehensive income, net of tax, Number of Shares			0		0
Other comprehensive income, net of tax	4.5	0.0	$ 0.0		$ 0.0	0.0		0.0		4.5
Dividends declared on common stock, Number of Shares			0	0	0
Dividends declared on common stock	(339.5)	$ (130.0)	$ 0.0	$ 0.0	$ 0.0	0.0	0.0	(339.5)	(130.0)	0.0
Issuance of common stock	$ 17.1		$ 0.0		$ 0.0	17.1		0.0		0.0
Issuance of common stock, Number of Shares	255,578	0	500,000		0
Stock-based compensation, Number of Shares			200,000	0	0
Stock-based compensation	$ 5.7	$ 11.8	$ 0.0	$ 0.0	$ 0.0	5.7	11.8	0.0	0.0	0.0
Balance at Dec. 31, 2024	$ 4,640.9	$ 5,326.4	$ 2.0	$ 100.9	$ 0.0	1,165.9	1,488.6	3,475.7	3,736.9	(2.7)
Common Stock, Shares, Outstanding at Dec. 31, 2024	201,000,000	40,400,000	201,000,000	40,400,000
Treasury Stock, Common, Shares at Dec. 31, 2024					0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	$ 470.7	$ 499.8	$ 0.0	$ 0.0	$ 0.0	0.0	0.0	470.7	499.8	0.0
Net income, Number of Shares			0	0	0
Other comprehensive income, net of tax, Number of Shares			0		0
Other comprehensive income, net of tax	0.1	0.0	$ 0.0		$ 0.0	0.0		0.0		0.1
Dividends declared on common stock, Number of Shares			0	0	0
Dividends declared on common stock	(344.9)	$ (250.0)	$ 0.0	$ 0.0	$ 0.0		0.0	(344.9)	(250.0)	0.0
Issuance of common stock	$ 203.8		$ 0.1		$ 0.0	203.7		0.0		0.0
Issuance of common stock, Number of Shares	234,476	0	4.9		0
Capital contribution from OGE Energy		$ 150.0		$ 0.0			150.0		0.0
Capital contribution from OGE Energy, Number of Shares				0
Stock-based compensation, Number of Shares			200,000	0	0
Stock-based compensation	$ 6.7	14.0	$ 0.0	$ 0.0	$ 0.0	6.7	14.0	0.0	0.0	0.0
Balance at Dec. 31, 2025	$ 4,977.3	$ 5,740.2	$ 2.1	$ 100.9	$ (0.0)	$ 1,376.3	$ 1,652.6	$ 3,601.5	$ 3,986.7	$ (2.6)
Common Stock, Shares, Outstanding at Dec. 31, 2025	206,100,000	40,400,000	206,100,000	40,400,000
Treasury Stock, Common, Shares at Dec. 31, 2025					0

Leases - Schedule of Financial Statement Information of Lease Liabilities (Details) - OGE Energy And OG&E [Member] - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2025

Dec. 31, 2024

Dec. 31, 2023

Operating lease cost

$ 5.2

$ 4.7

$ 6.4

Operating cash flows for operating leases

4.9

4.5

5.2

Right-of-use assets obtained in exchange for new operating lease liabilities

0.0

5.7

$ 0.0

Right-of-use assets at period end

^[1]

$ 25.0

$ 28.3

Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]

Property, Plant and Equipment, Net

Operating lease liabilities at period end

^[2]

$ 29.2

$ 32.7

Operating Lease, Liability, Statement of Financial Position [Extensible Enumeration]

Liabilities, Other than Long-Term Debt, Noncurrent

Operating lease weighted-average remaining lease term (in years)

9 years

9 years 8 months 12 days

Operating lease weighted-average discount rate

4.10%

4.20%

[1]	Included in Property, Plant and Equipment in the Registrants' balance sheets.
[2]	Included in Other Deferred Credits and Other Liabilities in the Registrants' balance sheets.

Cybersecurity Risk Management, Strategy and Governance	12 Months Ended
Cybersecurity Risk Management, Strategy and Governance	Dec. 31, 2025
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	Item 1C. Cybersecurity. Risk Management and Strategy In the regular course of business, the Registrants handle a range of sensitive security and customer information. The Registrants are subject to numerous laws and rules concerning safeguarding and maintaining the confidentiality of this information. The Registrants utilize a risk-based, comprehensive, systematic and layered approach to cybersecurity risk, which helps them to continually assess, identify and manage enterprise-wide material cybersecurity risks. This comprehensive approach to protecting the Registrants’ assets, employees, and data - including customer information - utilizes a defense-in-depth approach, which enables the Registrants to continually evaluate enterprise-wide cyber and physical security risks. The Registrants’ defense-in-depth methodology is based on leading cybersecurity frameworks, including: • U.S. Department of Energy’s Cybersecurity Capability Maturity Model standard, • National Institute of Standards and Technology Cybersecurity Framework, and, particularly for the bulk electric system, • North American Electric Reliability Corporation’s Critical Infrastructure Protection Standards. In addition, the Registrants’ cybersecurity team regularly coordinates with industry peers, the Edison Electric Institute, and state and federal agencies to improve threat intelligence, situational awareness, and security practices. The Registrants have a comprehensive cybersecurity threat detection and monitoring program for their technology and network infrastructure, which leverages various systems, processes and operational measures to monitor, detect and respond to cyber incidents. The Registrants have established a security incident response plan, a business resiliency and event management framework, as well as disaster recovery mechanisms, which are tested and updated to prepare the Registrants to respond to material cybersecurity threats. The Registrants’ cybersecurity processes, including their threat detection, monitoring and response protocols, are subject to periodic internal audits. The Registrants’ Enterprise Security team partners with Internal Audit and third-party experts to conduct periodic penetration tests and assessments of the Registrants' cybersecurity processes. Cybersecurity risks are integrated into the Registrants’ Enterprise Risk Management process. The Enterprise Risk Management process engages internal stakeholders, helps identify key internal and external business risks, including cybersecurity risks, and then supports evaluations of those risks, providing consistent assessment. Key risks are then assessed using a methodology that includes a quantification of potential financial and operational impacts. Priority cybersecurity risks are assigned internal risk owners which report to the Chief Information Officer, who is responsible for the Registrants’ Enterprise Security including, among other responsibilities, developing and updating risk management plans. The Enterprise Security team utilizes third-party consultants to regularly conduct a review of the Registrants’ cybersecurity program that includes assessing their (i) ability to detect and respond to malicious behavior, (ii) configuration of security tools and (iii) security roadmap, training and staffing plans. The Enterprise Security team also utilizes multiple sources of threat intelligence information from real time feeds that come from government, industry and private sources to help stay abreast of emerging threats that could impact the Registrants. The Registrants have third-party vendor risk management processes to oversee and identify risks from cybersecurity threats associated with their use of third-party service providers. Enterprise Security works cross-functionally across the companies to review new vendors and their proposed solutions as they are engaged by the Registrants. The Enterprise Security team’s monitoring and assessment of third-party cybersecurity practices is continuous and ongoing throughout the Registrants’ relationship with the third party. Based on this process, the Enterprise Security team may require specific security controls on the third-party application, system, hardware or software being deployed. Enterprise Security monitors vendors for disclosed vulnerabilities and change in scores from external risk scoring agencies. The Registrants and their third-party vendors have been subject to, and will likely continue to be subject to, attempts to gain unauthorized access to systems, or confidential data, or to disrupt operations. None of these attempts has individually or in aggregate resulted in a security incident with a material impact on the Registrants financial condition or results of operations. Although prior incidents have not materially affected the Registrants, any future incidents related to the Registrants' information systems due to theft, ransomware, viruses, increased use of artificial intelligence technologies, denial of service, hacking, acts of war or terrorism, or inappropriate release of certain types of information, including confidential customer information or system operating information, could have a materially adverse impact on the Registrants, and affect their business strategy, results of operations or its financial condition. See “Item 1A. Risk Factors” for further discussion. Governance The Board of Directors is responsible for reviewing and overseeing the long-term strategic plans and principal issues facing the Registrants and includes the oversight of the major risk exposures and the risk management activities of the Registrants. As part of its risk oversight role, the Board delegates specific roles to its committees to help ensure risks, mitigations and opportunities are appropriately monitored and managed. The Audit Committee has overall oversight responsibility over the Registrants’ major financial risks, while the Nominating, Corporate Governance and Stewardship Committee oversees the Registrants’ cybersecurity risk exposure and management. These Committees and the full Board of Directors are updated regularly by the Chief Information Officer and the Director of Enterprise Security on cybersecurity risks and related matters, including results from audits and assessments of the Registrants’ cybersecurity practices and systems, as well as the results of their incident response and business resiliency exercises. The Chief Information Officer leads an information security team responsible for management of cybersecurity risk. The Chief Information Officer has decades of experience relevant to risk management, information systems and enterprise security. The Chief Information Officer serves on the Corporate Risk Oversight Committee where cyber risks are regularly discussed and addressed. The Registrants’ Corporate Risk Oversight Committee includes corporate officers and members of management and is responsible for the overall development, implementation and enforcement of strategies and policies for all significant risk management activities of the Registrants. The Registrants’ contingency plans, including its security incident response plan and event management framework, set forth the processes through which cybersecurity incidents are managed, including how management is informed of cybersecurity incidents. As part of these plans, incidents are evaluated, classified and elevated, as necessary, to an executive team which includes the Chief Information Officer and other executives on the Registrants’ Corporate Risk Oversight Committee. Once elevated, these executives are ultimately responsible for the management, mitigation and remediation of incidents.
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	Cybersecurity risks are integrated into the Registrants’ Enterprise Risk Management process. The Enterprise Risk Management process engages internal stakeholders, helps identify key internal and external business risks, including cybersecurity risks, and then supports evaluations of those risks, providing consistent assessment. Key risks are then assessed using a methodology that includes a quantification of potential financial and operational impacts. Priority cybersecurity risks are assigned internal risk owners which report to the Chief Information Officer, who is responsible for the Registrants’ Enterprise Security including, among other responsibilities, developing and updating risk management plans.
Cybersecurity Risk Management Third Party Engaged [Flag]	true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag]	true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag]	false
Cybersecurity Risk Board of Directors Oversight [Text Block]	The Board of Directors is responsible for reviewing and overseeing the long-term strategic plans and principal issues facing the Registrants and includes the oversight of the major risk exposures and the risk management activities of the Registrants. As part of its risk oversight role, the Board delegates specific roles to its committees to help ensure risks, mitigations and opportunities are appropriately monitored and managed. The Audit Committee has overall oversight responsibility over the Registrants’ major financial risks, while the Nominating, Corporate Governance and Stewardship Committee oversees the Registrants’ cybersecurity risk exposure and management. These Committees and the full Board of Directors are updated regularly by the Chief Information Officer and the Director of Enterprise Security on cybersecurity risks and related matters, including results from audits and assessments of the Registrants’ cybersecurity practices and systems, as well as the results of their incident response and business resiliency exercises.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]	Board delegates specific roles to its committees to help ensure risks, mitigations and opportunities are appropriately monitored and managed. The Audit Committee has overall oversight responsibility over the Registrants’ major financial risks, while the Nominating, Corporate Governance and Stewardship Committee oversees the Registrants’ cybersecurity risk exposure and management.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block]	These Committees and the full Board of Directors are updated regularly by the Chief Information Officer and the Director of Enterprise Security on cybersecurity risks and related matters, including results from audits and assessments of the Registrants’ cybersecurity practices and systems, as well as the results of their incident response and business resiliency exercises.
Cybersecurity Risk Role of Management [Text Block]	The Chief Information Officer leads an information security team responsible for management of cybersecurity risk. The Chief Information Officer has decades of experience relevant to risk management, information systems and enterprise security. The Chief Information Officer serves on the Corporate Risk Oversight Committee where cyber risks are regularly discussed and addressed. The Registrants’ Corporate Risk Oversight Committee includes corporate officers and members of management and is responsible for the overall development, implementation and enforcement of strategies and policies for all significant risk management activities of the Registrants. The Registrants’ contingency plans, including its security incident response plan and event management framework, set forth the processes through which cybersecurity incidents are managed, including how management is informed of cybersecurity incidents. As part of these plans, incidents are evaluated, classified and elevated, as necessary, to an executive team which includes the Chief Information Officer and other executives on the Registrants’ Corporate Risk Oversight Committee. Once elevated, these executives are ultimately responsible for the management, mitigation and remediation of incidents.
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]	The Chief Information Officer serves on the Corporate Risk Oversight Committee where cyber risks are regularly discussed and addressed. The Registrants’ Corporate Risk Oversight Committee includes corporate officers and members of management and is responsible for the overall development, implementation and enforcement of strategies and policies for all significant risk management activities of the Registrants.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block]	The Chief Information Officer has decades of experience relevant to risk management, information systems and enterprise security.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]	The Registrants’ contingency plans, including its security incident response plan and event management framework, set forth the processes through which cybersecurity incidents are managed, including how management is informed of cybersecurity incidents. As part of these plans, incidents are evaluated, classified and elevated, as necessary, to an executive team which includes the Chief Information Officer and other executives on the Registrants’ Corporate Risk Oversight Committee.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

Retirement Plans and Postretirement Benefit Plans (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2025

Dec. 31, 2024

Dec. 31, 2023

Pension Plan [Member]

Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]

$ 5.4

$ 5.3

$ 5.4

Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Interest Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 16.2

$ 15.6

$ 15.9

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Defined Benefit Plan, Net Periodic Benefit (Cost) Credit, Expected Return (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]

$ (16.5)

$ (16.2)

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Defined Benefit Plan, Net Periodic Benefit (Cost) Credit, Amortization of Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 6.2

$ 6.5

$ 8.0

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Amortization of unrecognized prior service cost

$ 0.5

$ 0.0

^[1]

0.0

0.0

21.8

Other Pension Plan [Member]

11.8

10.9

34.9

Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]

1.0

Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Interest Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 0.4

$ 0.3

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Defined Benefit Plan, Net Periodic Benefit (Cost) Credit, Expected Return (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 0.0

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Defined Benefit Plan, Net Periodic Benefit (Cost) Credit, Amortization of Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 0.1

$ (0.0)

$ 0.0

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Amortization of unrecognized prior service cost

$ 0.0

^[1]

0.3

0.0

0.5

Other Postretirement Benefits Plan [Member]

1.8

1.6

2.1

Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]

0.1

5.4

5.2

(1.7)

(1.6)

(1.7)

0.4

(0.2)

4.2

3.5

3.4

OG&E [Member] | Pension Plan [Member]

4.2

3.5

3.4

Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]

5.4

5.3

4.4

Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Interest Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 14.1

$ 13.4

$ 12.6

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Defined Benefit Plan, Net Periodic Benefit (Cost) Credit, Expected Return (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]

$ (14.2)

$ (14.0)

$ (12.9)

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Defined Benefit Plan, Net Periodic Benefit (Cost) Credit, Amortization of Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 5.9

$ 6.2

$ 6.9

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

$ 0.5

$ 0.0

0.0

20.4

Plus: Amount allocated from OGE Energy

11.7

10.9

31.4

0.0

3.0

OG&E [Member] | Other Pension Plan [Member]

11.7

10.9

34.4

Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]

0.1

0.0

Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Interest Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 0.1

$ 0.0

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Defined Benefit Plan, Net Periodic Benefit (Cost) Credit, Expected Return (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 0.0

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

Defined Benefit Plan, Net Periodic Benefit (Cost) Credit, Amortization of Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]

$ 0.0

Pension and Other Postretirement Benefits Cost (Reversal of Cost)

$ 0.0

0.0

0.4

Plus: Amount allocated from OGE Energy

0.2

0.4

1.6

1.4

1.7

OG&E [Member] | Other Postretirement Benefits Plan [Member]

1.8

1.6

2.1

Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]

0.1

4.1

3.9

(1.5)

(1.4)

(1.6)

0.6

0.0

Plus: Amount allocated from OGE Energy

3.3

2.6

2.4

0.4

0.5

Oklahoma Jurisdiction | Pension Plan [Member]

3.7

3.1

2.9

Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]

Change in postretirement expense to maintain allowed recoverable amount in Oklahoma jurisdiction (A)

^[2]

0.5

0.0

20.1

^[2]

(0.4)

5.8

33.3

Arkansas Jurisdiction | Pension Plan [Member]

Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]