# EDGAR Filing Document

**Accession Number:** 0001021635
**File Stem:** 0001193125-26-055414
**Filing Date:** 2026-2
**Character Count:** 533455
**Document Hash:** f8737adbbcc707c2fe2bbca5b3ed7248
**Contains OCR:** False
**Source Format:** 

## Filing Content

## Filing Summary
**0001193125-26-055414.hdr.sgml**: 20260218

**ACCESSION NUMBER**: 0001193125-26-055414

**CONFORMED SUBMISSION TYPE**: 10-K

**PUBLIC DOCUMENT COUNT**: 130

**CONFORMED PERIOD OF REPORT**: 20251231

**FILED AS OF DATE**: 20260218

**DATE AS OF CHANGE**: 20260217

**FILER**: 

**COMPANY DATA:**
- **COMPANY CONFORMED NAME:** OGE ENERGY CORP.
- **CENTRAL INDEX KEY:** 0001021635
- **STANDARD INDUSTRIAL CLASSIFICATION:** ELECTRIC SERVICES [4911]
- **ORGANIZATION NAME:** 01 Energy & Transportation
- **EIN:** 731481638
- **STATE OF INCORPORATION:** OK
- **FISCAL YEAR END:** 1231

**FILING VALUES:**
- **FORM TYPE:** 10-K
- **SEC ACT:** 1934 Act
- **SEC FILE NUMBER:** 001-12579
- **FILM NUMBER:** 26644478

**BUSINESS ADDRESS:**
- **STREET 1:** 321 N HARVEY
- **STREET 2:** P.O. BOX 321
- **CITY:** OKLAHOMA CITY
- **STATE:** OK
- **ZIP:** 73101-0321
- **BUSINESS PHONE:** 4055533000

**MAIL ADDRESS:**
- **STREET 1:** 321 N HARVEY
- **STREET 2:** P.O. BOX 321
- **CITY:** OKLAHOMA CITY
- **STATE:** OK
- **ZIP:** 73101-0321

**FORMER COMPANY:**
- **FORMER CONFORMED NAME:** OGE ENERGY CORP
- **DATE OF NAME CHANGE:** 19960827
**FILER**: 

**COMPANY DATA:**
- **COMPANY CONFORMED NAME:** OKLAHOMA GAS & ELECTRIC CO
- **CENTRAL INDEX KEY:** 0000074145
- **STANDARD INDUSTRIAL CLASSIFICATION:** ELECTRIC SERVICES [4911]
- **ORGANIZATION NAME:** 01 Energy & Transportation
- **EIN:** 730382390
- **STATE OF INCORPORATION:** OK
- **FISCAL YEAR END:** 1231

**FILING VALUES:**
- **FORM TYPE:** 10-K
- **SEC ACT:** 1934 Act
- **SEC FILE NUMBER:** 001-01097
- **FILM NUMBER:** 26644479

**BUSINESS ADDRESS:**
- **STREET 1:** 321 NORTH HARVEY
- **STREET 2:** PO BOX 321
- **CITY:** OKLAHOMA CITY
- **STATE:** OK
- **ZIP:** 73101-0321
- **BUSINESS PHONE:** 4055533000

**MAIL ADDRESS:**
- **STREET 1:** 321 N HARVEY
- **STREET 2:** P O BOX 321
- **CITY:** OKLAHOMA CITY
- **STATE:** OK
- **ZIP:** 73101

?xml version='1.0' encoding='ASCII'? 10-K

**UNITED STATES**

**SECURITIES AND EXCHANGE COMMISSION**

Washington, D.C. 20549

**FORM** 10-K

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

For the fiscal year ended December 31, 2025

**OR**

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

For the transition period from _____to_____

---

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

---

321 North Harvey

P.O. Box 321

Oklahoma City**,** Oklahoma 73101-0321

405**-**553-3000

**State or other jurisdiction of incorporation or organization:** Oklahoma

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

---

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

---

**Securities registered pursuant to Section 12(g) of the Act: None**

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

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

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Act.

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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

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

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

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

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

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

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

Indicate by check mark whether the registrant has filed a report on and attestation to its management's assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.

OGE Energy Corp. ☑ Oklahoma Gas and Electric Company ☑

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. ☐

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant's executive oﬃcers during the relevant recovery period pursuant to §240.10D-1(b). ☐

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

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

At June 30, 2025, the last business day of OGE Energy Corp.'s most recently completed second fiscal quarter, the aggregate market value of shares of common stock held by non-affiliates was $8,937,916,402 based on the number of shares held by non-affiliates (201,395,142) and the reported closing market price of the common stock on the New York Stock Exchange on such date of $44.38.

At June 30, 2025, there was no voting or non-voting common equity of Oklahoma Gas and Electric Company held by non-affiliates.

At January 31, 2026, there were 206,259,022 shares of OGE Energy Corp.'s common stock, par value $0.01 per share, outstanding.

At January 31, 2026, there were 40,378,745 shares of Oklahoma Gas and Electric Company's common stock, par value $2.50 per share, outstanding, all of which were held by OGE Energy Corp. There were no other shares of capital stock of the registrant outstanding at such date.

**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).

------

**FORM 10-K**

**FOR THE YEAR ENDED DECEMBER 31, 2025**

**TABLE OF CONTENTS**

---

| | |
|:---|:---|
|  | &nbsp;&nbsp;**<u>Page</u>** |
| &nbsp;&nbsp;[<u>GLOSSARY OF TERMS</u>](#section3) | &nbsp;&nbsp;3 |
| &nbsp;&nbsp;[<u>FILING FORMAT AND FORWARD-LOOKING STATEMENTS</u>](#section4) | &nbsp;&nbsp;4 |
| &nbsp;&nbsp;[**<u>Part I</u>**](#part_i) |  |
| &nbsp;&nbsp;[<u>Item 1. Business</u>](#item_1_business) | &nbsp;&nbsp;6 |
| &nbsp;&nbsp;[<u>Item 1A. Risk Factors</u>](#section22) | &nbsp;&nbsp;15 |
| &nbsp;&nbsp;[<u>Item 1B. Unresolved Staff Comments</u>](#section59) | &nbsp;&nbsp;24 |
| &nbsp;&nbsp;[<u>Item 1C. Cybersecurity</u>](#cybersecurity) | &nbsp;&nbsp;25 |
| &nbsp;&nbsp;[<u>Item 2. Properties</u>](#section60) | &nbsp;&nbsp;27 |
| &nbsp;&nbsp;[<u>Item 3. Legal Proceedings</u>](#section62) | &nbsp;&nbsp;28 |
| &nbsp;&nbsp;[<u>Item 4. Mine Safety Disclosures</u>](#section63) | &nbsp;&nbsp;28 |
| &nbsp;&nbsp;[**<u>Part II</u>**](#part_ii) |  |
| &nbsp;&nbsp;[<u>Item 5. Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities</u>](#item_5_market_for_registrant) | &nbsp;&nbsp;29 |
| &nbsp;&nbsp;[<u>Item 6. \[Reserved\]</u>](#section67) | &nbsp;&nbsp;29 |
| &nbsp;&nbsp;[<u>Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations</u>](#section68) | &nbsp;&nbsp;30 |
| &nbsp;&nbsp;[<u>Item 7A. Quantitative and Qualitative Disclosures About Market Risk</u>](#section107) | &nbsp;&nbsp;45 |
| &nbsp;&nbsp;[<u>Item 8. Financial Statements and Supplementary Data</u>](#section108) | &nbsp;&nbsp;47 |
| &nbsp;&nbsp;[<u>Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure</u>](#section163) | &nbsp;&nbsp;106 |
| &nbsp;&nbsp;[<u>Item 9A. Controls and Procedures</u>](#section164) | &nbsp;&nbsp;106 |
| &nbsp;&nbsp;[<u>Item 9B. Other Information</u>](#section168) | &nbsp;&nbsp;109 |
| &nbsp;&nbsp;[<u>Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections</u>](#section169) | &nbsp;&nbsp;109 |
| &nbsp;&nbsp;[**<u>Part III</u>**](#part_iii) |  |
| &nbsp;&nbsp;[<u>Item 10. Directors, Executive Officers and Corporate Governance</u>](#item_10_directors) | &nbsp;&nbsp;110 |
| &nbsp;&nbsp;[<u>Item 11. Executive Compensation</u>](#section172) | &nbsp;&nbsp;110 |
| &nbsp;&nbsp;[<u>Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters</u>](#item_12_benowners) | &nbsp;&nbsp;110 |
| &nbsp;&nbsp;[<u>Item 13. Certain Relationships and Related Transactions, and Director Independence</u>](#item_13_directorindependence) | &nbsp;&nbsp;110 |
| &nbsp;&nbsp;[<u>Item 14. Principal Accountant Fees and Services</u>](#item_14_auditorfees) | &nbsp;&nbsp;111 |
| &nbsp;&nbsp;[**<u>Part IV</u>**](#part_iv) |  |
| &nbsp;&nbsp;[<u>Item 15. Exhibit and Financial Statement Schedules</u>](#exhibit_and_financial) | &nbsp;&nbsp;112 |
| &nbsp;&nbsp;[<u>Item 16. Form 10-K Summary</u>](#section179) | &nbsp;&nbsp;118 |
| &nbsp;&nbsp;[<u>Signatures</u>](#signatures) | &nbsp;&nbsp;119 |

---

------

**GLOSSARY OF TERMS**

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

---

| | |
|:---|:---|
| **Abbreviation** | **Definition** |
| 2024 Form 10-K | Annual Report on Form 10-K for the year ended December 31, 2024 |
| 401(k) Plan | Qualified defined contribution retirement plan |
| Act 373 | Arkansas Act 373, also known as the Generating Arkansas Jobs Act of 2025 |
| ALJ | Administrative Law Judge |
| APSC | Arkansas Public Service Commission |
| ASC | Financial Accounting Standards Board Accounting Standards Codification |
| ASU | Financial Accounting Standards Board Accounting Standards Update |
| CO2 | Carbon dioxide |
| Code | Internal Revenue Code of 1986 |
| COVID-19 | Novel Coronavirus disease |
| CWIP | Construction work in progress |
| Dry Scrubber | Dry flue gas desulfurization unit with spray dryer absorber |
| Energy Transfer | Energy Transfer LP, a Delaware limited partnership, collectively with its subsidiaries |
| EPA | U.S. Environmental Protection Agency |
| Federal Clean Water Act | Federal Water Pollution Control Act of 1972, as amended |
| FERC | Federal Energy Regulatory Commission |
| FIP | Federal Implementation Plan |
| FSAs | Forward equity sale agreements, entered into with Morgan Stanley & Co. LLC and JPMorgan Chase Bank, National Association, New York Branch on November 20 and 21, 2025 in conjunction with OGE Energy's November 2025 public equity offering |
| GAAP | Accounting principles generally accepted in the U.S. |
| IRP | Integrated Resource Plan |
| kV | Kilovolt |
| LRE | Load Responsible Entity |
| MRG | Member Resource Group |
| MW | Megawatt |
| MWh | Megawatt-hour |
| NAAQS | National Ambient Air Quality Standard |
| NERC | North American Electric Reliability Corporation |
| NOX | Nitrogen oxide |
| OCC | Oklahoma Corporation Commission |
| ODEQ | Oklahoma Department of Environmental Quality |
| OG&E | Oklahoma Gas and Electric Company, wholly-owned subsidiary of OGE Energy |
| OGE Energy | OGE Energy Corp., collectively with its subsidiaries, holding company and parent company of OG&E |
| OMB | White House Office of Management and Budget |
| OSHA | U.S. Department of Labor's Occupational Safety and Health Administration |
| Other operations | Other operations primarily includes the operations of the holding company, other energy-related investments and consolidating eliminations |
| Pension Plan | Qualified defined benefit retirement plan |
| PM | Particulate matter |
| Regional Haze | The EPA's Regional Haze Rule |
| Registrants | OGE Energy and OG&E |
| Restoration of Retirement Income Plan | Supplemental retirement plan to the Pension Plan |
| SB 998 | Oklahoma Senate Bill 998 |
| SIP | State Implementation Plan |
| SO2 | Sulfur dioxide |
| SOFR | Secured Overnight Funding Rate |
| SPP | Southwest Power Pool |
| System sales | Sales to OG&E's customers |
| U.S. | United States of America |
| Winter Storm Uri | Unprecedented, prolonged extreme cold weather event in February 2021 |

---

------

**FILING FORMAT**

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

**FORWARD-LOOKING STATEMENTS**

Except for the historical statements contained herein, the matters discussed within this Form 10-K, including those matters discussed within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations," are forward-looking statements that are subject to certain risks, uncertainties and assumptions. Such forward-looking statements are intended to be identified in this document by the words "anticipate," "believe," "estimate," "expect," "forecast," "intend," "objective," "plan," "possible," "potential," "project," "target" and similar expressions. Actual results may vary materially from those expressed in forward-looking statements. In addition to the specific risk factors discussed within "Item 1A. Risk Factors" and "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" herein, factors that could cause actual results to differ materially from the forward-looking statements include, but are not limited to:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•general economic conditions, including the availability of credit, access to existing lines of credit, access to the commercial paper markets, actions of rating agencies and inflation rates, and their impact on capital expenditures;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•the ability of the Registrants to access the capital markets and obtain financing on favorable terms, as well as inflation rates and monetary fluctuations;

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

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

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•competitive factors, including the extent and timing of the entry of additional competition in the markets served by the Registrants, potentially through deregulation;

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

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

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

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

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•the effect of retroactive pricing of transactions in the SPP markets, adjustments in market pricing mechanisms by the SPP, or allocation of transmission upgrade costs;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•federal or state legislation and regulatory decisions and initiatives that affect cost and investment recovery, have an impact on rate structures or affect the speed and degree to which competition enters the Registrants' markets;

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

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•the ability of the Registrants to meet future capacity requirements mandated by the SPP, which could be impacted by future load growth, environmental regulations, and the availability of resources;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•changes in accounting standards, rules or guidelines;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•the discontinuance of accounting principles for certain types of rate-regulated activities;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•the cost of protecting assets against, or damage due to, terrorism or cyberattacks, including the Registrants losing control of their assets and potential ransoms, and other catastrophic events;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•the availability, cost, coverage and terms of insurance;

------

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•changes in the use, perception or regulation of generative artificial intelligence technologies, which could limit the Registrants' ability to utilize such technology, create risk of enhanced regulatory scrutiny, generate uncertainty around intellectual property ownership, licensing or use, or which could otherwise result in risk of damage to our business, reputation or financial results;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•creditworthiness of suppliers, customers and other contractual parties, including large, new customers from industries such as cryptocurrency and data centers;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•social attitudes regarding the electric utility and power industries;

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

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•increased pension and healthcare costs;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•national and global events that could adversely affect and/or exacerbate macroeconomic conditions, including inflationary pressures, interest rate fluctuations, supply chain disruptions, economic recessions, pandemic health events, tariffs and uncertainty surrounding continued hostilities or sustained military campaigns, and their collateral consequences;

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

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•other risk factors listed in the reports filed by the Registrants with the Securities and Exchange Commission, including those listed within "Item 1A. Risk Factors" herein.

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

------

**PA** **RT I**

**Item 1. Business.**

**Introduction**

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. OGE Energy exited its former midstream business in 2022 as a result of selling all equity securities of Energy Transfer that were previously held by OGE Energy.

The Registrants' principal executive offices are located at 321 North Harvey, P.O. Box 321, Oklahoma City, Oklahoma, 73101-0321 (telephone 405-553-3000). OGE Energy's website address is www.oge.com. Through OGE Energy's website, OGE Energy makes available, free of charge, the Registrants' annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as soon as reasonably practicable after such material is electronically filed with or furnished to the Securities and Exchange Commission. OGE Energy's website and the information contained therein or connected thereto are not intended to be incorporated into this Form 10-K and should not be considered a part of this Form 10-K. Reports filed with the Securities and Exchange Commission are also made available on its website at www.sec.gov.

**Strategy**

OGE Energy's purpose is to energize life, providing life-sustaining and life-enhancing products and services that enrich its communities, encouraging growth and a higher quality of life. Its business model is centered around growth and sustainability for employees (internally referred to as "members"), communities and customers and the owners of OGE Energy, its shareholders.

OGE Energy is focused on:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•strengthening and securing the energy grid to improve reliability and resiliency for all customers;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•maintaining customer rates that are among the lowest rates in the country by continuing to focus on innovation, intellectual curiosity, and execution with excellence;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•delivering top-quartile safety results as it expands capacity of the energy grid with a balanced mix of cost-effective and proven generation technologies to meet unprecedented demand for electricity;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•transforming the customer experience through personalized products, programs, services, and self-service technology by centering decisions on customer impact;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•driving economic development and job growth by attracting new and diverse businesses to improve the communities it serves in Oklahoma and Arkansas;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•delivering on earnings commitments to shareholders to enhance access to lower-cost debt and equity capital that is needed to deploy infrastructure for the long-term economic health of its communities;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•fostering strong regulatory and legislative relationships, built on integrity, for the long-term benefit of our customers, communities, shareholders and members; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•developing and growing our members to provide a greater contribution to the company's success, as they improve their own lives and deliver improved value to communities, customers, and shareholders.

OGE Energy creates long-term shareholder value by targeting the consistent growth of consolidated earnings per share of five to seven percent through 2030, and consolidated earnings per share in the top half of the range in 2027 and 2028, supported by expected strong load growth enabled by low customer rates and a strategy of investing in lower risk infrastructure projects that improve the economic vitality of the communities it serves in Oklahoma and Arkansas. OGE Energy plans to continue to grow its dividend over the next five years, targeting a payout ratio of 60 percent to 70 percent. Over the next several years, earnings per share is expected to grow faster than dividends to support this goal. OGE Energy's financial objectives also include maintaining investment grade credit ratings and providing a strong and reliable dividend for shareholders.

------

OGE Energy's long-term sustainability is predicated on providing exceptional customer engagement, strengthening the energy grid, investing in proven technologies to meet generation capacity needs, environmental stewardship, strong governance practices and caring for and supporting its members and communities.

**Electric Operations - OG&E**

***General***

OG&E provides retail electric service to approximately 913,000 customers in Oklahoma and western Arkansas throughout a service area that covers 30,000 square miles including Oklahoma City, the largest city in Oklahoma, Fort Smith, Arkansas, the third largest city in that state, and other large communities with their contiguous rural and suburban areas. OG&E derived 92 percent of its total electric operating revenues in 2025 from sales in Oklahoma and the remainder from sales in Arkansas. OG&E does not currently serve wholesale customers in either state.

In 2025, OG&E's system control area peak demand was 7,412 MWs on July 30, 2025, and OG&E's load responsibility peak demand was 6,630 MWs on July 30, 2025. The following table presents system sales and variations in system sales for 2025, 2024 and 2023.

---

| | | | | | |
|:---|:---|:---|:---|:---|:---|
| Year Ended December 31 | **2025** | **2025 vs. 2024** | 2024 | 2024 vs. 2023 | 2023 |
| System sales *(Millions of MWh)* | **33.6** | **5.0%** | 32.0 | 7.7% | 29.7 |

---

OG&E is subject to competition in various degrees from government-owned electric systems, municipally-owned electric systems, rural electric cooperatives and, in certain respects, from other private utilities, power marketers and cogenerators. Oklahoma law forbids the granting of an exclusive franchise to a utility for providing electricity.

Besides competition from other suppliers or marketers of electricity, OG&E competes with suppliers of other forms of energy. The degree of competition between suppliers may vary depending on relative costs and supplies of other forms of energy. It is possible that changes in regulatory policies or advances in technologies such as fuel cells, microturbines, windmills and photovoltaic solar cells will reduce costs of new technology to levels that are equal to or below that of most central station electricity production. OG&E is committed to a balanced energy mix of proven and cost-effective technologies, while advancing innovative technologies that show promise. OG&E's ability to maintain relatively low cost, efficient and reliable operations is a significant determinant of its competitiveness.

------

**OKLAHOMA GAS AND ELECTRIC COMPANY**

**CERTAIN OPERATING STATISTICS**

---

| | | | |
|:---|:---|:---|:---|
| Year Ended December 31 | **2025** | 2024 | 2023 |
| ELECTRIC ENERGY *(Millions of MWh)* |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Generation (exclusive of station use) | **13.8** | 14.7 | 13.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Purchased | **22.2** | 19.6 | 18.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total generated and purchased | **36.0** | 34.3 | 32.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;OG&E use, free service and losses | **(1.6)** | (1.5) | (1.6) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Electric energy sold | **34.4** | 32.8 | 30.5 |
| ELECTRIC ENERGY SOLD *(Millions of MWh)* |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Residential | **9.7** | 9.8 | 9.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Commercial | **12.4** | 10.5 | 8.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Industrial | **4.1** | 4.2 | 4.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;Oilfield | **4.3** | 4.4 | 4.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Public authorities and street light | **3.1** | 3.1 | 3.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;System sales | **33.6** | 32.0 | 29.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Integrated market | **0.8** | 0.8 | 0.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total sales | **34.4** | 32.8 | 30.5 |
| ELECTRIC OPERATING REVENUES *(In millions)* |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Residential | $**1205.8** | $1148.5 | $1040.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Commercial | **978.2** | 839.1 | 688.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Industrial | **265.3** | 254.1 | 240.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Oilfield | **242.8** | 227.7 | 211.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Public authorities and street light | **276.1** | 262.0 | 234.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;System sales revenues | **2968.2** | 2731.4 | 2416.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Provision for rate refund and tax refund | **3.0** | (3.0) | 2.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Integrated market | **91.6** | 74.5 | 71.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Transmission | **159.4** | 152.9 | 143.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **37.9** | 29.5 | 41.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total operating revenues | $**3260.1** | $2985.3 | $2674.3 |
| ACTUAL NUMBER OF ELECTRIC CUSTOMERS *(At end of year)* |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Residential | **778307** | 772140 | 762433 |
| &nbsp;&nbsp;&nbsp;&nbsp;Commercial | **107884** | 107943 | 106787 |
| &nbsp;&nbsp;&nbsp;&nbsp;Industrial | **2149** | 2273 | 2377 |
| &nbsp;&nbsp;&nbsp;&nbsp;Oilfield | **6433** | 6644 | 6739 |
| &nbsp;&nbsp;&nbsp;&nbsp;Public authorities and street light | **18532** | 17952 | 17766 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total customers | **913305** | 906952 | 896102 |

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***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 employs accounting and other procedures and controls to protect against subsidization of non-utility activities by OG&E's customers; and (iii) OGE Energy refrains 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.

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For information concerning OG&E's recently completed and currently pending regulatory proceedings, see Note 14 within "Item 8. Financial Statements and Supplementary Data."

***Regulatory Assets and Liabilities***

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. 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. See Note 1 within "Item 8. Financial Statements and Supplementary Data" for further discussion of OG&E's regulatory assets and liabilities.

***Rate Structures*** 

*Oklahoma* 

OG&E's standard tariff rates include a cost of service component (including an authorized return on capital) plus a fuel adjustment clause mechanism that allows OG&E to pass through to customers the actual cost of fuel and purchased power.

OG&E offers several alternative customer programs and rate options, such as those described below.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Under OG&E's Smart Grid-enabled SmartHours programs, time-of-use and variable peak pricing rates offer customers the ability to save on their electricity bills by shifting some of their electricity consumption to off-peak times when demand for electricity is lowest.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•The Guaranteed Flat Bill option for residential and small general service accounts allows qualifying customers the opportunity to purchase their electricity needs at a set monthly price for an entire year.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•The Renewable Energy Credit purchase program, the Green Power Wind Rider and the Utility Solar Program are rate options that make renewable energy resources available as a voluntary option to all OG&E Oklahoma retail customers. OG&E's ownership and access to wind and solar resources makes the renewable option a possible choice in meeting the renewable energy needs of OG&E's conservation-minded customers.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Load Reduction is a voluntary load curtailment program that provides qualifying OG&E commercial and industrial customers who enroll with the opportunity to curtail usage on a voluntary basis when OG&E's system conditions merit curtailment action. Large customers greater than 50 MWs who enroll in the program are also required to participate in Direct Load Control, giving OG&E direct control over the curtailable portion of the customer's load. Customers that curtail their usage will receive credit for their curtailment response.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•OG&E offers certain qualifying customers day-ahead price and flex price rate options which allow participating customers to adjust their electricity consumption based on price signals received from OG&E. The prices for the day-ahead price and flex price rate options are based on OG&E's projected next day hourly operating costs.

In addition to specific rate structures, OG&E provides customers with other programs such as Average Monthly Billing which helps to make the customer's bill more predictable on a monthly basis. Similarly, OG&E has energy efficiency programs which provide qualified customers with programs such as in-home weatherization and opportunities to lower their monthly bill. OG&E also has a Low Income Assistance Program and a Senior Citizen Discount, which provide qualified customers with a monthly bill credit.

OG&E has Public Schools-Demand and Public Schools Non-Demand rate classes that provide OG&E with flexibility to provide targeted programs for load management to public schools and their unique usage patterns. OG&E also provides service level, seasonal

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and time period fuel charge differentiation that allows customers to pay fuel costs that better reflect the underlying costs of providing electric service. Lastly, OG&E has a military base rider that demonstrates Oklahoma's continued commitment to its military partners.

The previously discussed rate options, coupled with OG&E's other rate choices, provide many tariff options for OG&E's Oklahoma retail customers. The revenue impacts associated with these options are not determinable in future years because customers may choose to remain on existing rate options instead of volunteering for the alternative rate option choices. Revenue variations may occur in the future based upon changes in customers' usage characteristics if they choose alternative rate options.

*Arkansas* 

OG&E's standard tariff rates include a cost of service component (including an authorized return on capital) plus an energy cost recovery mechanism that allows OG&E to pass through to customers the actual cost of fuel and purchased power. OG&E's current rate order from the APSC includes a formula rate rider that provides for an annual adjustment to rates if the earned rate of return falls outside of a plus or minus 50 basis point dead-band around the allowed return on equity. Adjustments are limited to plus or minus four percent of revenue for each rate class for the 12 months preceding the test period. Although the initial term for the formula rate rider has expired, the APSC has authorized OG&E to utilize the April 2024 formula rate rider until new rates are set in a future general rate review.

OG&E offers several alternative customer programs and rate options, such as those described below.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•The time-of-use and variable peak pricing tariffs allow participating customers to save on their electricity bills by shifting some of their electricity consumption to off-peak times when demand for electricity is lowest.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•The Demand Rate tariff allows customers to be billed based on demand instead of energy only. This provides a degree of bill stability and is available for both residential and general service customers.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•The Renewable Energy Credit purchase program and the Universal Solar Program are rate options that make renewable energy resources available as a voluntary option to all OG&E Arkansas retail customers. OG&E's ownership and access to wind and solar resources makes the renewable option a possible choice in meeting the renewable energy needs of OG&E's conservation-minded customers.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Load Reduction is a voluntary load curtailment program that provides qualifying OG&E commercial and industrial customers with the opportunity to curtail usage on a voluntary basis and receive a billing credit when OG&E's system conditions merit curtailment action.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•OG&E offers certain qualifying customers day-ahead price and flex price rate options which allow participating customers to adjust their electricity consumption based on a price signal received from OG&E. The day-ahead price and flex price rate options are based on OG&E's projected next day hourly operating costs.

In addition to specific rate structures, OG&E provides customers with other programs such as the Levelized Billing Plan which helps to make the customer's bill more predictable on a monthly basis. Similarly, OG&E has energy efficiency programs which provide qualified customers with programs such as in-home weatherization and opportunities to lower their monthly bill.

***Fuel Supply and Generation*** 

The following table presents the OG&E-generated energy produced and purchased, by type, for the last three years.

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| | | | |
|:---|:---|:---|:---|
|  | **Generation Mix (A)** | **Generation Mix (A)** | **Generation Mix (A)** |
|  | **2025** | 2024 | 2023 |
| Natural gas | **57%** | 74% | 75% |
| Coal | **34%** | 18% | 16% |
| Renewable | **9%** | 8% | 9% |
| &nbsp;&nbsp;&nbsp;&nbsp;Total | **100%** | 100% | 100% |

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(A)Generation mix calculated as a percent of net MWhs generated and includes purchased power agreements.

OG&E participates in the SPP Integrated Marketplace. As part of the Integrated Marketplace, the SPP has balancing authority responsibilities for its market participants. The SPP Integrated Marketplace functions as a centralized dispatch, where market participants, including OG&E, submit offers to sell power to the SPP from their resources and bid to purchase power from the SPP for their customers. The SPP Integrated Marketplace is intended to allow the SPP to optimize supply offers and demand bids based upon reliability and economic considerations and to determine which generating units will run at any given time for maximum

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cost-effectiveness within the SPP area. As a result, OG&E's generating units produce output that is different from OG&E's customer load requirements. Net fuel and purchased power costs are generally recoverable through fuel adjustment clauses.

The following table presents the weighted-average cost of fuel used, by type, for the last three years.

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| | | | |
|:---|:---|:---|:---|
|  | **Fuel Cost (A)**<br> *(In cents/Kilowatt-Hour)* | **Fuel Cost (A)**<br> *(In cents/Kilowatt-Hour)* | **Fuel Cost (A)**<br> *(In cents/Kilowatt-Hour)* |
|  | **2025** | 2024 | 2023 |
| Natural gas | **3.911** | 2.640 | 2.976 |
| Coal | **2.744** | 3.083 | 3.385 |
| Renewable | **—** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Total | **3.343** | 2.637 | 2.926 |

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(A)Total fuel and purchased power weighted-average cost was 3.502, 3.139 and 2.837 cents per kilowatt-hour in 2025, 2024 and 2023, respectively.

The increase in the weighted-average cost of fuel used in 2025 compared to 2024 was primarily due to higher natural gas prices while the decrease in 2024 compared to 2023 was primarily due to lower natural gas prices. Fuel costs are generally recoverable through OG&E's fuel adjustment clauses that are approved by the OCC and the APSC. See Notes 1 and 14 within "Item 8. Financial Statements and Supplementary Data" for further discussion.

The following table presents OG&E's total MWs of generation capability by fuel type for 2025.

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| | | |
|:---|:---|:---|
|  | **Generation Capability** | **Percent of Total** |
| Natural gas | **4560** | 65.9% |
| Coal | **1559** | 22.5% |
| Dual fuel generation (coal/gas) | **321** | 4.6% |
| Wind | **449** | 6.5% |
| Solar | **32** | 0.5% |
| &nbsp;&nbsp;&nbsp;&nbsp;Total | **6921** | 100.0% |

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*Natural Gas*

As a participant in the SPP Integrated Marketplace, OG&E purchases its natural gas supply through short-term agreements. OG&E relies on a diversified portfolio of natural gas supply comprised of (i) base load agreements that include first-of-month agreements with a fixed price for the month term; (ii) call agreements, whereby OG&E has the right but not the obligation to purchase a defined quantity of natural gas; and (iii) day and intra-day purchases to meet the demands of the SPP Integrated Marketplace. OG&E holds two storage service contracts which provide physical storage capacity. These two contracts provide OG&E security in both volume and price to further help protect customers against volatile natural gas prices.

*Coal*

OG&E's coal-fired units are designed to burn primarily low sulfur western sub-bituminous coal. The coal purchased in 2025 had a weighted-average sulfur content of 0.22 percent. Based on the average sulfur content and EPA-certified data, OG&E's coal units have an approximate emission rate of 0.172 lbs. of SO2 per MMBtu.

OG&E has coal supply agreements for 100 percent of its expected coal requirements through 2027 for the Sooner, Muskogee and River Valley facilities. In 2025, OG&E purchased 2.4 million tons of coal from its sub-bituminous suppliers. See "Environmental Laws and Regulations" within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" for a discussion of environmental matters which may affect OG&E in the future, including its utilization of coal.

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*Wind*

OG&E owns the 120 MW Centennial, 101 MW OU Spirit and 228 MW Crossroads wind farms. OG&E's current wind power portfolio also includes purchased power contracts as presented in the following table.

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| | | | | | |
|:---|:---|:---|:---|:---|:---|
| **Company** | **Location** | **Original Term of<br>Contract** | **Expiration of<br>Contract** | **MWs** | **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 |

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*Solar* 

OG&E currently owns and operates the solar sites presented in the following table.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| **Name** | **Location** | **Year Completed** | **Photovoltaic Panels** | **Photovoltaic Panels** | **MWs** | **MWs** |
| Mustang | Oklahoma City, OK | 2015 |  | 9,867 |  | 2.5 |
| Covington | Covington, OK | 2018 |  | 38,000 |  | 9.7 |
| Choctaw Nation | Durant, OK | 2020 |  | 15,344 |  | 5.0 |
| Chickasaw Nation | Davis, OK | 2020 |  | 15,344 |  | 5.0 |
| Branch | Branch, AR | 2021 |  | 15,444 |  | 5.0 |
| Durant 2 | Durant, OK | 2022 |  | 15,471 |  | 5.0 |

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**Environmental Matters**

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.

Changes in presidential administrations can result in uncertainty regarding policy or initiatives relating to activities that may affect the environment. Future developments, such as changes in existing laws, introduction of new laws or regulations, or the emergence of new facts or conditions, may result in significant costs for the Registrants. In the meantime, the Registrants continue to have obligations to take or complete action under current environmental rules.

Management continues to evaluate the Registrants' compliance with existing and proposed environmental legislation and regulations and implement appropriate environmental programs in a competitive market but at the current time, based on existing rules, does not expect capital expenditures for environmental control facilities to be material for 2026 or 2027. For further discussion of environmental matters and capital expenditures related to environmental factors that may affect the Registrants, see "2025 Capital Requirements, Sources of Financing and Financing Activities," "Future Capital Requirements" and "Environmental Laws and Regulations" within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations."

**Human Capital Management**

Our company fulfills a critical role in the nation's electric utility infrastructure. In order to do so, we need to attract, retain, motivate and develop a high quality workforce and provide a safe and productive work environment for everyone. Our company's core values are teamwork, transparency, respect, integrity, public service, and individual safety and well-being. Our company's core beliefs are unleash potential, live safely, achieve together, create shared trust, value diversity and inclusion, take charge and values matter. We believe that our company's values and beliefs serve as a foundation for our relationships with our employees, who we refer to internally as "members" of the Registrants. These core values and beliefs are reinforced to all members at the time of hire, annually through a review of our Code of Ethics and periodically through small and large group meetings. We believe the efforts described herein, among others, contribute to our members' sense of purpose for the work we perform and result in the retention of our members. This belief is supported by OG&E being named a Top Workplace in Oklahoma in 2025 based on employee engagement, including how likely members would be to recommend OG&E as an employer, as well as employee sentiment regarding alignment,

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empowerment, respect and support, enablement to grow and being fairly valued. At December 31, 2025, the Registrants had 2,248 full-time employees.

***Total Rewards***

To help us attract and retain the most qualified individuals for our businesses, we provide a combination of strong compensation and comprehensive benefit offerings, including healthcare, health savings and flexible spending accounts, short-term and long-term incentive plans, retirement savings plans with company matching contributions, disability coverage, paid time off, parental leave and employee assistance programs. We also have a defined benefit pension plan that covers certain members hired on or before December 1, 2009. Our members are also offered two days of paid volunteer leave every year, which is intended to further enrich both their lives and the lives of others in the communities we serve.

***Employee Recruiting, Development and Engagement***

We make it a priority to attract, retain, motivate and develop a high-quality workforce. Our recruitment efforts begin with industry and career awareness efforts directed toward learning institutions, parents and students. We have built partnerships with universities, state career tech systems, state education departments, technical learning/trade schools, military bases and local school districts to increase awareness of the employment opportunities we provide and the total rewards packages that are tied to those opportunities. We build these relationships to create talent pipelines that will funnel qualified individuals back to our organization and the workforce needs we have identified.

We provide our members with a variety of opportunities for career growth and development. Many of the positions in our company are highly specialized, so having appropriate training and succession planning is critical to business continuity and competitiveness. We provide leadership, career development and skill-building opportunities, including internal and external training as well as tuition reimbursement, to invest in the next generation of leaders for our company. The number of annual hours of training per employee that we target, and historically average, aligns with the benchmark published annually by the American Society of Training and Development.

OGE Energy, like many electric companies across the country, is planning for the effects of turnover of our workforce due to a significant percentage of our employee population becoming retirement-eligible during the next five to ten years. This will also be a period impacted by major transformation of our business through technology investments, regulatory changes to our electric generation portfolio and upgrades to our distribution infrastructure. Management engages in ongoing succession planning discussions, which includes the annual involvement of OGE Energy's Board of Directors as it relates to officer succession planning.

OGE Energy conducts and/or participates in employee engagement surveys to seek feedback from its members on a variety of topics, including understanding of and alignment with the company's strategy, objectives, values and beliefs, management practices, operational performance and the employee value proposition. OGE Energy shares the survey results with members, and senior management incorporates the results of the surveys into their action plans in order to respond to the feedback and further enhance member engagement. As referenced above, OG&E was named a Top Workplace in Oklahoma in 2025 as a result of an employee engagement survey conducted by a third party.

***Safety***

At OGE Energy, safety is more than a priority; it is a value and is paramount in the work we perform. Our safety principles are core to who we are and what we do. These principles are communicated, demonstrated and embraced at all levels of the company and supported by our core belief to "Live Safely." To us, "Live Safely" means we protect ourselves and others from injury by constant engagement, "always living safely." Our goal is to have zero safety incidents every year, and we educate all members on our incident and injury-free workplace vision through extensive training on safety culture and task specific training to perform their work safely.

To achieve our vision of safety excellence, our health and safety professionals and supervisors conduct routine work observations to verify members and contractors are following safety protocols and procedures and provide coaching, if necessary. To further drive improvements in our safety performance, we report and analyze all near misses and incidents to understand the causal factors and associated corrective actions necessary to reduce the likelihood of recurrence. We share what we have learned companywide to provide real-time learning opportunities for all members. We continue to analyze trends and engage in discussions with our members,

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creating a dialogue to enhance safety performance and work toward our incident and injury-free workplace. Our focus on safety has contributed to the last ten years being the safest in our 123-year history.

Since the inception of our safety principles and embracing our incident and injury free vision, we have seen a sustained decline in our injury rate. We have reduced our five-year averages for OSHA recordable injuries by 66 percent and our Days Away, Restricted, Transfer Rate by 77 percent since our 2011 baseline. The Days Away, Restricted, Transfer rate is an OSHA calculation that determines how safe businesses have been in a calendar year in reference to particular types of worker compensation injuries.

OG&E is subject to a number of federal, state and local regulations, which are administered by a variety of agencies. These agencies cover areas such as health and safety, transportation and the environment. OG&E has processes and procedures for these areas, and we believe we are in material compliance with all applicable regulations.

***Employee and Community Integration***

We strive to reinforce the belief that our members are one of our greatest assets by creating a culture of inclusion throughout the company. One of our core beliefs is to "Value Diversity and Inclusion," which to us means that we embrace the uniqueness of each individual to make us a stronger and more resourceful organization.

Within our overall recruitment and retention efforts, we are focused on fostering a culture of inclusion so that the company's workforce represents the communities we serve. Supporting a workplace where we share ideas and leverage our different experiences and perspectives results in business decisions that address the needs of our various stakeholders. Our collaborative culture encourages creative and innovative thinking, embraces ideas from all our members, and enables us to grow our business, members, and communities.

Several of the talent pipeline partnerships referenced above are with organizations and trade schools that help integrate into our company local members of our communities. We continue working with others to recruit students to their programs who represent these communities, which can lead to potential employment for our positions. We have also formed relationships with universities to provide scholarships to students from all backgrounds and have focused on hiring individuals transitioning out of the military.

The company currently has ten employee-led MRGs supporting Asian American & Pacific Islander, Black, Hispanic, Indigenous People, LGBTQ+, Veteran, and Women members along with new members, those dedicated to public service and to wellness. All groups are voluntary and inclusive. Each MRG selects an officer of the company to serve as its Executive Sponsor. These MRGs are intended to foster a sense of belonging for all members, inspire conversation, introduce new ways of thinking about issues, drive innovation among our diverse population of members and provide an opportunity for professional development, community involvement and recruitment.

**Information About the Registrants' Executive Officers** 

The following table presents the names, titles and business experience for the most recent five years for those persons serving as Executive Officers of the Registrants as of February 17, 2026:

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| | | | |
|:---|:---|:---|:---|
| **Name** | **Age** | **Current Title and Business Experience** | **Current Title and Business Experience** |
| Sean Trauschke | 58 | 2021 - Present: | Chairman of the Board, President and Chief Executive Officer of OGE Energy Corp. |
| Charles B. | 51 | 2025 - Present: | Chief Financial Officer of OGE Energy Corp. |
| Walworth |  | 2024 - 2025: | Chief Financial Officer and Treasurer of OGE Energy Corp. |
|  |  | 2021 - 2024: | Treasurer of OGE Energy Corp. |
| Sarah R. Stafford | 44 | 2021 - Present: | Controller and Chief Accounting Officer of OGE Energy Corp. |
| Donnie O. Jones | 59 | 2025 - Present: | Senior Vice President - Utility Operations of OG&E |
|  |  | 2021 - 2025: | Vice President - Utility Operations of OG&E |
| David A. Parker | 49 | 2025 - Present: | Chief Information Officer of OG&E |
|  |  | 2021 - 2025: | Vice President - Technology, Data and Security of OG&E |
| William H. | 58 | 2022 - Present: | General Counsel, Corporate Secretary and Chief Compliance Officer of OGE Energy Corp. |
| Sultemeier |  | 2021 - 2022: | General Counsel and Chief Compliance Officer of OGE Energy Corp. |

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No family relationship exists between any of the Executive Officers of the Registrants. Messrs. Trauschke, Walworth, Sultemeier and Ms. Stafford are also officers of OG&E. Each Executive Officer is to hold office until the next annual election of officers by the Board of Directors which is typically accomplished at the first regular board meeting following the Annual Meeting of Shareholders, currently scheduled for May 14, 2026.

**Item 1A. Risk Factors.** 

In the discussion of risk factors set forth below, unless the context otherwise requires, the terms "we," "our" and "us" refer to the Registrants. In addition to the other information in this Form 10-K and other documents filed by us and/or our subsidiaries with the Securities and Exchange Commission from time to time, the following factors should be carefully considered in evaluating OGE Energy and its subsidiaries. Such factors could affect actual results and cause results to differ materially from those expressed in any forward-looking statements made by or on behalf of us or our subsidiaries. Additional risks and uncertainties not currently known to us or that we currently view as immaterial may also impair our business operations.

The Registrants are subject to a variety of risks which can be classified as regulatory, operational, financial and general. Risk factors of OG&E are also risk factors of OGE Energy.

**REGULATORY RISKS**

***The Registrants' profitability depends to a large extent on the ability of OG&E to fully recover its costs, including its cost of capital, from its customers in a timely manner, and there may be changes in the regulatory environment that impair its ability to recover costs from its customers.*** 

OG&E is subject to comprehensive regulation by several federal and state regulatory agencies, which significantly influences its operating environment and its ability to fully recover its costs, including its cost of capital, from customers. Recoverability of any under recovered amounts from OG&E's customers due to a rise in fuel costs is a significant risk. The utility commissions in the states where OG&E operates regulate many aspects of its electric operations including siting and construction of facilities, customer service and the rates that OG&E can charge customers. The profitability of the electric operations is dependent on OG&E's ability to fully recover costs related to providing electricity and power services to its customers in a timely manner. Any failure to obtain commission approval to increase rates to fully recover costs, or a delay in the receipt of such approval, could have an adverse impact on OG&E's results of operations. In addition, OG&E's jurisdictions have fuel adjustment clauses that permit OG&E to recover fuel and purchased power costs through rates without a general rate review, subject to a later determination that such costs were prudently incurred. If the state regulatory commissions determine that such costs were not prudently incurred, recovery could be disallowed.

In recent years, the regulatory environments in which OG&E operates have received an increased amount of attention. It is possible that there could be changes in the regulatory environment that would impair OG&E's ability to fully recover costs historically paid by OG&E's customers. State regulatory commissions generally possess broad powers to ensure that the needs of the utility customers are being met. OG&E cannot assure that the OCC, APSC and the FERC will grant rate increases in the future or in the amounts requested, and they could instead lower OG&E's rates.

The Registrants are unable to predict the impact on their operating results from future regulatory activities of any of the agencies that regulate OG&E. Changes in regulations, legislation or the imposition of additional regulations or legislation could have an adverse impact on the Registrants' results of operations.

***OG&E's rates are subject to rate regulation by the states of Oklahoma and Arkansas, as well as by a federal agency, whose regulatory paradigms and goals may not be consistent.*** 

OG&E is a vertically integrated electric company. Most of its revenue results from the sale of electricity to retail customers subject to bundled rates that are approved by the applicable state regulatory commission.

OG&E operates in Oklahoma and western Arkansas and is subject to rate regulation by the OCC and the APSC, in addition to FERC regulation of its transmission activities and any wholesale sales. Exposure to inconsistent state and federal regulatory standards may limit our ability to operate profitably. Further alteration of the regulatory landscape in which we operate, including a change in the authorized cost of capital, may harm our financial position and results of operations.

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***Costs of compliance with environmental and other laws and regulations are significant, and the cost of compliance with future environmental and other laws and regulations may adversely affect our results of operations, financial position or liquidity.***

We are subject to extensive federal, state and local environmental statutes, rules and regulations relating to air quality, water quality, waste management, wildlife conservation, natural resources and health and safety that could, among other things, restrict or limit the output of certain facilities or the use of certain fuels required for the production of electricity and/or require additional pollution control equipment and otherwise increase costs. We are also subject to SPP-related capacity methodologies which are expected to continue to impact our future capacity needs. There are significant capital, operating and other costs associated with compliance with these environmental and other statutes, rules and regulations and those costs may be even more significant in the future.

In response to recent regulatory and judicial decisions and international accords, emissions of greenhouse gases including, most significantly, CO2, could be restricted in the future as a result of federal or state legal requirements or litigation relating to greenhouse gas emissions. Rules from the EPA to reduce emissions of greenhouse gases from fossil fuel-fired electric generating units under the Clean Air Act Section 111 were finalized in 2024, but the rules still might change before implementation. For example, as detailed further below, power plant-specific rules are currently under judicial review and could ultimately be upheld, modified, or overturned. In addition, legislation reflecting a focus on reducing greenhouse gas emissions may potentially be introduced in Congress. Any such changes, as well as any enforcement actions or judicial decisions regarding those laws and regulations, could result in significant additional compliance costs that would affect our future financial position, results of operations and cash flows if such costs are not recovered through regulated rates. Such changes also could affect the manner in which we conduct our business and could require us to make substantial additional capital expenditures or abandon certain projects.

Recent environmental regulations may also impact our plan to comply with potential additional changes to the SPP's planning reserve margin and, as further discussed in Note 14 within "Item 8. Financial Statements and Supplementary Data," changes to the resource capacity accreditation methodologies for both thermal and renewable resources. Both changes may increase OG&E's generation capacity needs. We may be constrained by the ability to procure resources or labor that is needed to construct projects on time and at a reasonable price, which could significantly impact the extent to which we can successfully comply with these proposed environmental regulations and SPP requirements.

There is inherent risk of the incurrence of environmental costs and liabilities in our operations and historical industry practices. These activities are subject to stringent and complex federal, state and local laws and regulations that can restrict or impact OG&E's business activities in many ways, such as restricting the way OG&E can handle or dispose of its wastes or requiring remedial action to mitigate pollution conditions that may be caused by its operations or that are attributable to former operators. OG&E may be unable to recover these costs from insurance or other regulatory mechanisms, or certain insurance may be unavailable to us. If regulations are enacted regarding any of our generating units, as listed in "Item 2. Properties," it could potentially result in stranded assets.

In addition, we may be required to make significant expenditures in connection with the investigation and remediation of alleged or actual spills, personal injury or property damage claims, and the repair, upgrade or expansion of our facilities to meet future requirements and obligations under environmental laws.

For further discussion of environmental matters that may affect the Registrants, see "Environmental Laws and Regulations" within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations."

***We are subject to financial risks associated with climate change and the transition to a lower carbon economy.***

In addition to the potential for physical risks (discussed below), climate change, and the risks related to our transition to a lower carbon economy, creates financial risk. Transition risks represent those risks related to the social and economic changes needed to shift toward a lower carbon future. These risks are often interconnected, representing policy and regulatory changes, technology and market risks, and risks to our reputation and financial performance.

Potential regulation associated with climate change legislation could pose financial risks to OGE Energy and its affiliates. Potential legislation and regulation as discussed above, could result in enforceable greenhouse gas emission reduction requirements that could lead to increased compliance costs for OGE Energy and its affiliates. Although May 2024 EPA regulations reducing emissions of greenhouse gases from fossil fuel-fired electric generating units for both new units and existing units are currently under judicial review, they could ultimately be upheld, modified, or overturned. For further discussion, see "Environmental Laws and Regulations"

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within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations." It is unknown what the outcome, or any potential material impacts, if any, will be from the litigation or any final action by the EPA.

As we expand our cleaner energy generation asset mix, the ability to integrate renewable technologies into our operations and maintain reliability and affordability is key. The intermittency of renewables remains a critical challenge particularly as long-duration energy storage is still in development. Other technology risks include the need for significant upfront financial investments, lengthy development timelines, and the uncertainty of integration and scalability across our entire service territory.

In addition, to the extent that any climate change adversely affects the national or regional economic health through physical impacts or increased rates caused by the inclusion of additional regulatory costs, CO2 taxes or imposed costs, OGE Energy and its affiliates may be adversely impacted. To the extent financial markets view climate change and emissions of greenhouse gases as a financial risk, this could negatively affect our ability to access capital markets or cause us to receive less than ideal terms and conditions.

In addition, we may be subject to financial risks from private party litigation relating to greenhouse gas emissions. Defense costs associated with such litigation can be significant and an adverse outcome could require substantial capital expenditures and could possibly require payment of substantial penalties or damages. Such payments or expenditures could affect results of operations, financial condition or cash flows if such costs are not recovered through regulated rates.

***We may not be able to recover the costs of our substantial investments in capital improvements and additions.***

Our business plan calls for extensive investments in capital improvements and additions in OG&E, including modernizing existing infrastructure as well as other initiatives. Significant portions of OG&E's facilities were constructed many years ago. Older generation equipment, even if maintained in accordance with good engineering practices, may require significant capital expenditures to maintain efficiency, to comply with environmental requirements or to provide reliable operations. The Infrastructure Investment and Jobs Act, Inflation Reduction Act, and "One Big Beautiful Bill" present opportunities for federal grants, loans and tax incentives aimed at electrical infrastructure development. We have been awarded grant funds for specific projects through the Infrastructure Investment and Jobs Act, and we plan to pursue additional opportunities available to us under these Acts. For awarded grants where funding has not yet been received, there is no guarantee that funding will materialize. We expect to typically be responsible for any project costs not covered by federal funding on further investments related to these Acts although there is no guarantee we will be successful in obtaining any such grants. OG&E currently provides service at rates approved by one or more regulatory commissions. If these regulatory commissions do not approve adjustments to the rates OG&E charges, it would not be able to recover the costs associated with its planned extensive investment. This could adversely affect the Registrants' financial position and results of operations. While OG&E may seek to limit the impact of any denied recovery by attempting to reduce the scope of its capital investment, there can be no assurance as to the effectiveness of any such mitigation efforts, particularly with respect to previously incurred costs and commitments.

***The regional power market in which OG&E operates has changing transmission regulatory structures, which may affect the transmission assets and related revenues and expenses.***

OG&E currently owns and operates transmission and generation facilities as part of a vertically integrated electric company. 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 regional day ahead and real-time markets for energy and operating reserves, 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. Our revenues, expenses, assets and liabilities may be adversely affected by changes in the organization, operation and regulation of the SPP Integrated Marketplace by the FERC or the SPP.

As a member of the SPP, OG&E is subject to risks associated with planning decisions that the SPP makes in the exercise of control over the planning of OG&E's transmission assets that are under the SPP's operational control. These risks include upward pressure on OG&E's rates arising from the potential additional cost allocation to OG&E from transmission projects of others or changes in FERC policies or regulation related to cost responsibility for transmission projects. This potential upward pressure could decrease the capacity available in OG&E's rates for other projects.

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***Increased competition resulting from efforts to restructure utility and energy markets or deregulation could have a significant financial and load growth impact on us and consequently impact our revenue and affordability of services.***

We have been and will continue to be affected by competitive changes to the utility and energy industries. Significant changes have occurred and additional changes have been proposed to the wholesale electric market. Retail competition and the unbundling of regulated energy service could have a significant financial impact on us due to possible impairments of assets, a loss of retail customers, impact profit margins and/or increased costs of capital. Further, we regularly engage in negotiations on renewals of franchise agreements with municipal governments within our service territories. Any such restructuring could have a significant impact on our financial position, results of operations and cash flows. Further, our load growth could be impacted, which could result in an impact on the affordability of our services. We cannot predict when we will be subject to changes in legislation or regulation, nor can we predict the impact of these changes on our financial position, results of operations or cash flows.

***We are subject to substantial regulation by governmental agencies. Compliance with current and future regulatory requirements and procurement of necessary approvals, permits and certifications may result in significant costs to us.***

We are subject to substantial regulation from federal, state and local regulatory agencies. We are required to comply with numerous laws and regulations and to obtain permits, approvals and certifications from the governmental agencies that regulate various aspects of our businesses, including customer rates, service regulations, retail service territories, sales of securities, asset acquisitions and sales, accounting policies and practices and the operation of generating facilities. We believe the necessary permits, approvals and certificates have been obtained for our existing operations and that our business is conducted in accordance with applicable laws; however, we are unable to predict the impact on our operating results from future regulatory activities of these agencies.

The NERC is responsible for the development and enforcement of mandatory reliability and cyber security standards for the wholesale electric power system. OG&E's plan is to comply with all applicable standards and to expediently correct a violation should it occur. As one of OG&E's regulators, the NERC has comprehensive regulations and standards related to the reliability and security of our operating systems and is continuously developing additional mandatory compliance requirements for the electric power industry. The increasing development of NERC rules and standards will increase compliance costs and our exposure for potential violations of these standards.

**OPERATIONAL RISKS** 

***Our results of operations may be impacted by disruptions to fuel supply or the electric grid that are beyond our control.***

We are exposed to risks related to performance of contractual obligations by our suppliers and transporters. We are dependent on coal and natural gas for much of our electric generating capacity. We rely on suppliers to deliver coal and natural gas in accordance with short- and long-term contracts. We have certain supply and transportation contracts in place; however, there can be no assurance that the counterparties to these agreements will fulfill their obligations to supply and transport coal and natural gas to us. The suppliers and transporters under these agreements may experience financial or technical problems that inhibit their ability to fulfill their obligations to us. In addition, the suppliers and transporters under these agreements may not be required to provide the commodity or service under certain circumstances, such as in the event of a natural disaster. Deliveries may be subject to short-term interruptions or reductions due to various factors, including transportation problems, weather, availability of equipment and labor shortages. Failure or delay by our suppliers and transporters of coal and natural gas could disrupt our ability to deliver electricity and require us to incur additional expenses to meet the needs of our customers.

Additionally, due to our generation and transmission systems being part of an interconnected regional grid, we face the risk of possible loss of business due to a disruption or black-out caused by an event such as a severe storm, generator or transmission facility outage on a neighboring system or the actions of a neighboring utility. Any such disruption could result in a significant decrease in revenues and significant additional costs to repair assets, which could have a material adverse impact on our financial position, results of operations and cash flows.

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***OG&E's electric generation, transmission and distribution assets are subject to operational risks that could result in unscheduled plant outages, unanticipated operation and maintenance expenses, increased purchased power costs, accidents and third-party liability.*** 

OG&E owns and operates coal-fired, natural gas-fired, wind-powered and solar-powered generating assets. Operation of electric generation, transmission and distribution assets involves risks that can adversely affect energy output and efficiency levels or that could result in loss of human life, significant damage to property, environmental pollution and impairment of OG&E's operations. Included among these risks are:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•increased prices for fuel, fuel transportation, purchased power and purchased capacity as existing contracts expire;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•facility shutdowns due to a breakdown or failure of equipment or processes or interruptions in fuel supply;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•operator or contractor error or safety related stoppages;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•disruptions in the delivery of electricity;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•intentional destruction of electric grid equipment; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•catastrophic events such as fires, explosions, tornadoes, floods, earthquakes or other similar occurrences.

The occurrence of any of these events, if not fully covered by insurance or if insurance is not available to us, could have a material effect on our financial position and results of operations. Further, when unplanned maintenance work is required on power plants or other equipment, OG&E will not only incur unexpected maintenance expenses, but it may also have to make spot market purchases of replacement electricity that could exceed OG&E's costs of generation or be forced to retire a generation unit if the cost or timing of the maintenance is not reasonable and prudent. If OG&E is unable to recover any of these increased costs in rates, it could have a material adverse effect on our financial performance.

***Changes in technology, regulatory policies and customer electricity consumption may cause our assets to be less competitive and impact our results of operations.*** 

OG&E is a vertically integrated electric company and primarily generates electricity at large central facilities. We believe this method is the most efficient and cost-effective method for power delivery, as it typically results in economies of scale and lower costs than newer technologies such as fuel cells, microturbines, wind turbines and photovoltaic solar cells. It is possible that advances in technologies or changes in regulatory policies will reduce costs of new technology to levels that are equal to or below that of most central station electricity production, which could have a material adverse effect on our results of operations. OG&E's widespread use of Smart Grid technology allowing for two-way communications between the electric company and its customers could enable the entry of technology companies into the interface between OG&E and its customers, resulting in unpredictable effects on our current business.

Reductions in customer electricity consumption, thereby reducing electric sales, could result from increased deployment of renewable energy technologies as well as increased efficiency of household appliances, among other general efficiency gains in technology. However, this potential reduction in load would not reduce our need for ongoing investments in our infrastructure to reliably serve our customers. Continued electric infrastructure investment without increased electricity sales could cause increased rates for customers, potentially resulting in further reductions in electricity sales and reduced profitability.

***Weather conditions such as tornadoes, thunderstorms, ice storms, windstorms, flooding, earthquakes, prolonged droughts and the occurrence of wildfires, as well as seasonal temperature variations may adversely affect our financial position, results of operations and cash flows.***

Weather conditions directly influence the demand for electric power. In OG&E's service area, demand for power peaks during the hot summer months, with market prices also typically peaking at that time. As a result, overall operating results may fluctuate on a seasonal and quarterly basis. In addition, we have historically sold less power, and consequently received less revenue, when weather conditions are milder. Unusually mild weather in the future could reduce our revenues, net income, available cash and borrowing ability. Severe weather, such as tornadoes, thunderstorms, ice storms, windstorms, flooding, earthquakes, prolonged droughts and the occurrence of wildfires, may cause outages and property damage which may require us to incur additional costs that may not be adequately insured and that may not be recoverable from customers. The effect of the failure of our facilities to operate as planned, as described above, would be particularly burdensome during a peak demand period. In addition, prolonged droughts could cause a lack of sufficient water for use in cooling during the electricity generating process.

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Physical risks from climate change can be considered in both acute (event-driven) and chronic (longer-term shifts in climate patterns) terms. The effects of climate change could exacerbate physical changes in weather and the extreme weather events discussed above, including prolonged droughts, rise in temperatures and more extreme weather events like wildfires and ice storms, among other weather impacts. We have observed some of these events in recent years, and the trend could continue. OG&E is committed to strengthening and securing our energy grid and infrastructure against extreme weather by upgrading physical infrastructure, deploying advanced monitoring technologies and devices, and enhancing emergency preparedness and response plans. These measures aim to ensure reliable service and rapid recovery during severe weather events. OG&E can incur significant restoration costs as a result of these weather events. If OG&E is unable to recover any of these increased costs in rates, either due to increased investments or restoration costs, it could have a material adverse effect on our financial performance.

**FINANCIAL RISKS**

***Market performance, increased retirements, changes in retirement plan regulations and increasing costs associated with our Pension Plan, health care plans and other employee-related benefits may adversely affect our financial position, results of operations or cash flows.***

We have a Pension Plan that covers certain employees hired before December 1, 2009. We also have defined benefit postretirement plans that cover certain employees hired prior to February 1, 2000. Assumptions related to future costs, returns on investments, interest rates and other actuarial assumptions with respect to the defined benefit retirement and postretirement plans have a significant impact on our results of operations and funding requirements. We expect to make future contributions to maintain required funding levels as necessary, and it has been our practice to also make voluntary contributions to maintain more prudent funding levels than minimally required. We may continue to make voluntary contributions in the future. These amounts are estimates and may change based on actual stock market performance, changes in interest rates and any changes in governmental regulations.

If the employees who participate in the Pension Plan retire when they become eligible for retirement over the next several years, or if our plan experiences adverse market returns on its investments, or if interest rates materially fall, our pension expense and contributions to the plans could rise substantially over historical levels. The timing and number of employees retiring and selecting the lump-sum payment option could result in pension settlement charges that could materially affect our results of operations if we are unable to recover these costs through our electric rates. In addition, assumptions related to future costs, returns on investments, interest rates and other actuarial assumptions, including projected retirements, have a significant impact on our financial position and results of operations. Those factors are outside of our control.

In addition to the costs of our Pension Plan, the costs of providing health care benefits to our employees and retirees have increased in recent years. We believe that our employee benefit costs, including costs related to health care plans for our employees, will continue to rise. The increasing costs and funding requirements with our Pension Plan, health care plans and other employee benefits may adversely affect our financial position, results of operations or liquidity.

***OGE Energy is a holding company with its primary asset being its subsidiary, OG&E.***

OGE Energy is a holding company and thus its primary asset is its subsidiary, OG&E. Substantially all of OGE Energy's operations are conducted by this subsidiary. Consequently, OGE Energy's operating cash flow and its ability to pay dividends and service its indebtedness are dependent upon the operating cash flow of OG&E and the payment of funds by OG&E to OGE Energy in the form of dividends. At December 31, 2025, OGE Energy and OG&E had outstanding indebtedness and other liabilities of $9.4 billion. OG&E is a separate legal entity that has no obligation to pay any amounts due on OGE Energy's indebtedness or to make any funds available for that purpose. In addition, OG&E's ability to pay dividends to OGE Energy depends on any statutory and contractual restrictions that may be applicable to the entity, which may include requirements to maintain minimum levels of working capital and other assets. Claims of creditors, including general creditors, of OG&E on its assets will generally have priority over OGE Energy claims (except to the extent that OGE Energy may be a creditor and its claims are recognized) and claims by OGE Energy shareholders.

In addition, as discussed above, OG&E is regulated by state utility commissions in Oklahoma and Arkansas as well as a federal regulatory agency which generally possess broad powers to ensure that the needs of customers are being met. To the extent that the state commissions or federal regulatory agency attempt to impose restrictions on the ability of OG&E to pay dividends to OGE Energy, it could adversely affect its ability to continue to pay dividends.

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**GENERAL RISKS**

***Governmental and market reactions to events involving other public companies or other energy companies that are beyond our control may have negative impacts on our business, financial position, results of operations, cash flows and access to capital.*** 

Accounting irregularities at public companies in general, and energy companies in particular, and investigations by governmental authorities into energy trading activities and political contributions, could lead to public and regulatory scrutiny and suspicion for public companies, including those in the regulated and unregulated utility business. Accounting irregularities could cause regulators and legislators to review current accounting practices, financial disclosures and relationships between companies and their independent auditors. The capital markets and rating agencies also could increase their level of scrutiny. We believe that we are complying with all applicable laws and accounting standards, but it is difficult or impossible to predict or control what effect any of these types of events may have on our business, financial position, cash flows or access to the capital markets. It is unclear what additional laws or regulations may develop, and we cannot predict the ultimate impact of any future changes in accounting regulations or practices in general with respect to public companies, the energy industry or our operations specifically. Any new accounting standards could affect the way we are required to record revenues, expenses, assets, liabilities and equity. These changes in accounting standards could lead to negative impacts on reported earnings or decreases in assets or increases in liabilities that could, in turn, affect our financial position, results of operations and cash flows.

***Economic conditions, including inflationary pressures and supply chain disruptions, could negatively impact our business and our results of operations.***

Our operations have been and are affected by local, national and worldwide economic conditions. National and global events could adversely affect and/or exacerbate macroeconomic conditions, including inflationary pressures, interest rate fluctuations, supply chain disruptions, potential tariffs and economic recessions, which in turn affect our operations and our customers. OG&E has experienced rising costs to produce electricity through increased fuel prices, raw material inflation, logistical challenges and certain component shortages. We are dependent upon others, such as fuel suppliers and transporters and suppliers for our capital projects, to help execute our operations. Supply chain disruption has resulted, and may continue to result, in delays in construction activities and equipment deliveries related to our capital projects.

The consequences of a recession could include a lower level of economic activity and uncertainty regarding energy prices and the capital and commodity markets. A lower level of economic activity and general inflation could result in a decline in energy consumption, which could adversely affect our revenues and future growth. Instability in the financial markets, as a result of recession or otherwise, also could affect the cost of capital and our ability to raise capital. Economic conditions may also impact the valuation of certain long-lived assets that are subject to impairment testing, potentially resulting in impairment charges, which could have a material adverse impact on our results of operations.

Economic conditions may be impacted by insufficient financial sector liquidity or inflationary pressures, leading to potential increased unemployment, which could impact the ability of our customers to pay timely, increase customer bankruptcies, and could lead to increased bad debt. If such circumstances occur, we expect that commercial and industrial customers would be impacted first, with residential customers following.

In addition, economic conditions, particularly budget shortfalls, could increase the pressure on federal, state and local governments to raise additional funds by increasing corporate tax rates and/or delaying, reducing or eliminating tax credits, grants or other incentives that could have a material adverse impact on our results of operations and cash flows.

***We are subject to cybersecurity risks and increased reliance on processes dependent on technology.***

In the regular course of our business, we handle a range of sensitive security and customer information. We are subject to numerous laws and rules concerning safeguarding and maintaining the confidentiality of this information. A significant security breach of our 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 material adverse impact on our financial position, results of operations and cash flows.

OG&E operates in a highly regulated industry that requires the continued operation of sophisticated information technology systems and network infrastructure. Despite implementation of security measures, the technology systems are vulnerable to disability,

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failures or unauthorized access. Such failures or breaches of the systems could impact the reliability of OG&E's generation, transmission and distribution systems which may result in a loss of service to customers and also subject OG&E to financial harm due to the significant expense to respond to security breaches or repair system damage. Our generation and transmission systems are part of an interconnected system. Therefore, a disruption caused by the impact of a cybersecurity incident of the regional electric transmission grid, natural gas pipeline infrastructure or other fuel sources of our third-party service providers' operations could also negatively impact our business. If the technology systems were to fail or be breached and not recovered in a timely manner, critical business functions could be impaired and sensitive confidential data could be compromised, which could have a material adverse impact on our financial position, results of operations and cash flows.

Security threats continue to evolve and adapt, notably with artificial intelligence which may be used to enhance malicious cyber-attacks. We and our third-party vendors, many of whom leverage artificial intelligence capabilities, have been subject to, and will likely continue to be subject to, attempts to gain unauthorized access to systems and/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 our financial condition or results of operations. Despite implementation of security and control measures, there can be no assurance that we will be able to prevent the unauthorized access of our systems and data, or the disruption of our operations, either of which could have a material impact. Our security procedures, which include among others, virus protection software, cybersecurity controls and monitoring and our business continuity planning, including disaster recovery policies and back-up systems, may not be adequate or implemented properly to fully address the adverse effect of cybersecurity attacks on our systems, which could adversely impact our operations.

We maintain property, casualty and cybersecurity insurance that may cover certain resultant cyber and physical damage or third-party injuries caused by potential cyber events. However, damage and claims arising from such incidents may exceed the amount of any insurance available, certain insurance may be unavailable to us, and other damage and claims arising from such incidents may not be covered at all. For these reasons, a significant cyber incident could reduce future net income and cash flows and impact financial condition.

***The failure of our technology infrastructure, or the failure to enhance existing technology infrastructure and implement new technology, including artificial intelligence, could adversely affect our business.*** 

Our operations are dependent upon the proper functioning of our internal systems, including the technology and network infrastructure that support our underlying business processes. Any significant failure or malfunction of such technology infrastructure may result in disruptions of our operations. In the ordinary course of business, we rely on technology infrastructure, including the internet and third-party hosted services, to support a variety of business processes and activities and to store sensitive data. Our technology infrastructure is dependent upon global communications and cloud service providers, as well as their respective vendors, many of whom have at some point experienced significant system failures and outages in the past and may experience such failures and outages in the future. These providers' systems are susceptible to cybersecurity and data breaches, outages from fire, floods, power loss, telecommunications failures, physical attack and similar events. Failure to prevent or mitigate data loss from system failures or outages could materially adversely affect our results of operations, financial position and cash flows.

In addition to maintaining our current technology infrastructure, we believe the digital transformation of our business, including the implementation of artificial intelligence, is key to driving internal efficiencies as well as providing additional capabilities to customers. Leveraging artificial intelligence capabilities to potentially improve internal functions and operations presents further risks and challenges. While we aim to use artificial intelligence ethically and attempt to identify and mitigate ethical or legal issues presented by its use, we may nevertheless be unsuccessful in identifying or resolving issues before they arise. The use of artificial intelligence to support business operations carries inherent risks related to data privacy and security, such as intended, unintended, or inadvertent transmission of proprietary or sensitive information, as well as challenges related to implementing and maintaining artificial intelligence tools, such as developing and maintaining appropriate datasets for such support. Further, dependence on artificial intelligence without adequate safeguards to make certain business decisions may introduce additional operational vulnerabilities by impacting our relationships with customers, partners, and suppliers, by producing inaccurate outcomes based on flaws in the underlying data, or other unintended results.

Our technology infrastructure is critical to cost-effective, reliable daily operations and our ability to effectively serve our customers. We expect our customers to continue to demand more sophisticated technology-driven solutions, and we must enhance or replace our technology infrastructure in response. This involves significant development and implementation costs to keep pace with changing technologies and customer demand. If we fail to successfully implement critical technology infrastructure, or if it does

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not provide the anticipated benefits or meet customer demands, such failure could materially adversely affect our business strategy as well as impact our results of operations, financial position and cash flows.

***Terrorist attacks, and the threat of terrorist attacks, have resulted in increased costs to our business and could impact our ability to operate critical infrastructure. Continued hostilities or sustained military campaigns may adversely impact our financial position, results of operations and cash flows.***

In recent years, physical attacks on electric equipment owned by other electric companies in the U.S. resulted in the loss of power for a period of time. Authorities have indicated they believe these attacks may have been carried out by domestic extremists, as the U.S. electric grid is noted as being highly vulnerable to domestic terrorism. While OG&E has experienced physical attacks on its electric equipment, these incidents have not been material to its operations. The long-term impact of terrorist attacks and the magnitude of the threat of future terrorist attacks on the electric utility in general, and on us in particular, cannot be known. Increased security measures taken by us as a precaution against possible terrorist attacks have resulted in increased costs to our business. Uncertainty surrounding continued hostilities or sustained military campaigns may affect our operations in unpredictable ways, including disruptions of supplies and markets for our products, and the possibility that our infrastructure facilities could be direct targets of, or indirect casualties of, an act of terror. Changes in the insurance markets attributable to terrorist attacks may make certain types of insurance more difficult for us to obtain. Moreover, the insurance that may be available to us may be significantly more expensive than existing insurance coverage.

***Health epidemics and other outbreaks could adversely impact economic activity and conditions worldwide, which could have a material adverse effect on our results of operations and financial condition.***

Health epidemics and other outbreaks could adversely impact economic activity and conditions worldwide, by, among other things, leading to shutdowns, disrupting supply chains, increasing unemployment, resulting in customer slow payment or non-payment and decreasing commercial and industrial load. In response to health epidemics and other outbreaks, an extended slowdown of the United States' economic growth, demand for commodities and/or material changes in governmental policy could result in lower economic growth and lower demand for electricity in our key markets as well as the ability of various customers, contractors, suppliers and other business partners to fulfill their obligations, which could have a material adverse effect on our results of operations, financial condition and prospects.

***We face certain human resource risks associated with the availability of trained and qualified labor to meet our future staffing requirements.***

Workforce demographic issues challenge employers nationwide and are of particular concern to the electric utility industry. The median age of utility workers is higher than the national average. Over the next three years, 27.8 percent of our current employees will meet the eligibility requirements to retire. Failure to hire and adequately train replacement employees, including the transfer of significant internal historical knowledge and expertise to the new employees, may adversely affect our ability to manage and operate our business.

The terms of the indentures governing our debt securities do not fully prohibit OGE Energy or OG&E from incurring additional indebtedness. If we are in compliance with the financial covenants set forth in our revolving credit agreements and the indentures governing our debt securities, we may be able to incur substantial additional indebtedness. If we incur additional indebtedness, the related risks that we now face may intensify.

***Any reductions in our credit ratings or changes in benchmark interest rates could increase our financing costs and the cost of maintaining certain contractual relationships or limit our ability to obtain financing on favorable terms.***

We cannot assure you that any of the current credit ratings of the Registrants will remain in effect for any given period of time or that a rating will not be lowered or withdrawn entirely by a rating agency if, in its judgment, circumstances so warrant. Our ability to access the commercial paper market could be adversely impacted by a credit ratings downgrade or major market disruptions. Pricing grids associated with our 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 our short-term borrowings, but a reduction in our credit

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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 us to post collateral or letters of credit.

***Our debt levels may limit our flexibility in obtaining additional financing and in pursuing other business opportunities.***

We have revolving credit agreements for working capital, capital expenditures, acquisitions and other corporate purposes. The credit facilities for OGE Energy and OG&E have a financial covenant requiring them to maintain a maximum debt to capitalization ratio of 70 percent and 65 percent, respectively. The levels of our debt could have important consequences, including the following:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•the ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired or the financing may not be available on favorable terms;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•a portion of cash flows will be required to make interest payments on the debt, reducing the funds that would otherwise be available for operations and future business opportunities; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•our debt levels may limit our flexibility in responding to changing business and economic conditions.

***We are exposed to the credit risk of our key customers and counterparties, and any material nonpayment or nonperformance by our key customers and counterparties could adversely affect our financial position, results of operations and cash flows.***

We are exposed to credit risks in our generation and retail distribution operations. Credit risk includes the risk that counterparties who owe us money or energy will breach their obligations. If the counterparties to these arrangements fail to perform, we may be forced to enter into alternative arrangements. In that event, our financial results could be adversely affected, and we could incur losses.

We have seen increased interest for electric service from industries such as crypto mining and data mining, to support artificial intelligence, which are both large consumers of electricity. If this continues, these types of customers could represent a significant portion of our revenues.

**Item 1B. Unresolved Staff Comments.** 

None.

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**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:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•U.S. Department of Energy's Cybersecurity Capability Maturity Model standard,

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•National Institute of Standards and Technology Cybersecurity Framework, and, particularly for the bulk electric system,

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•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.

------

**Item 2. Properties.**

OG&E owns and operates an interconnected electric generation, transmission and distribution system, located in Oklahoma and western Arkansas, which included 18 generating stations with an aggregate capability of 6,921 MWs at December 31, 2025. The following table presents information with respect to OG&E's electric generating facilities. Unless otherwise indicated, these electric generating facilities are located in Oklahoma.

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| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| **Station & Unit** |  | **Year<br>Installed** | **Unit Design<br>Type** | **Fuel<br>Capability** | **2025<br>Capacity<br>Factor (A)** | **Unit<br>Capability<br>(MW)** | **Station<br>Capability<br>(MW)** |
| Seminole | 1 | 1971 | Steam-Turbine | Gas | 12.0% | 500 |  |
|  | 2 | 1973 | Steam-Turbine | Gas | 8.5% | 513 |  |
|  | 3 | 1975 | Steam-Turbine | Gas | 25.7% | 508 | 1521 |
| Muskogee | 4 | 1977 | Steam-Turbine | Gas | 14.5% | 498 |  |
|  | 5 | 1978 | Steam-Turbine | Gas | 16.5% | 491 |  |
|  | 6 | 1984 | Steam-Turbine | Coal | 34.6% | 521 | 1510 |
| Sooner | 1 | 1979 | Steam-Turbine | Coal | 30.5% | 519 |  |
|  | 2 | 1980 | Steam-Turbine | Coal | 33.5% | 519 | 1038 |
| Horseshoe Lake | 5A<br> (B) | 1971 | Combustion-Turbine | Gas/Jet Fuel |  | 33 |  |
|  | 5B<br> (B) | 1971 | Combustion-Turbine | Gas/Jet Fuel | 3.3% | 31 |  |
|  | 8 | 1969 | Steam-Turbine | Gas | 8.1% | 377 |  |
|  | 9 | 2000 | Combustion-Turbine | Gas | 22.2% | 45 |  |
|  | 10 | 2000 | Combustion-Turbine | Gas | 21.7% | 46 | 532 |
| Redbud (C) | 1 | 2003 | Combined Cycle | Gas | 45.1% | 156 |  |
|  | 2 | 2003 | Combined Cycle | Gas | 30.7% | 154 |  |
|  | 3 | 2003 | Combined Cycle | Gas | 32.1% | 154 |  |
|  | 4 | 2003 | Combined Cycle | Gas | 41.2% | 155 | 619 |
| Mustang | 6 | 2018 | Combustion-Turbine | Gas | 21.3% | 57 |  |
|  | 7 | 2018 | Combustion-Turbine | Gas | 18.2% | 56 |  |
|  | 8 | 2017 | Combustion-Turbine | Gas | 12.9% | 58 |  |
|  | 9 | 2018 | Combustion-Turbine | Gas | 3.0% | 57 |  |
|  | 10 | 2018 | Combustion-Turbine | Gas | 18.7% | 55 |  |
|  | 11 | 2018 | Combustion-Turbine | Gas | 10.6% | 58 |  |
|  | 12 | 2018 | Combustion-Turbine | Gas |  | 57 | 398 |
| McClain (D) | 1 | 2001 | Combined Cycle | Gas | 28.8% | 375 | 375 |
| Frontier | 1 | 1989 | Combined Cycle | Gas | 47.8% | 126 | 126 |
| River Valley | 1 | 1991 | Steam-Turbine | Coal/Gas | 13.5% | 161 |  |
|  | 2 | 1991 | Steam-Turbine | Coal/Gas | 19.9% | 160 | 321 |
| Total Generating Capability (all stations, excluding renewable) | Total Generating Capability (all stations, excluding renewable) | Total Generating Capability (all stations, excluding renewable) | Total Generating Capability (all stations, excluding renewable) | Total Generating Capability (all stations, excluding renewable) |  |  | 6440 |

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(A)2025 Capacity Factor = 2025 Net Actual Generation / (2025 Net Maximum Capacity (Nameplate Rating in MWs) x Period Hours (8,760 Hours)). Capacity Factors are impacted by events that reduce Net Actual Generation such as outages.

(B)Represents units located at Tinker Air Force Base that are maintained by Horseshoe Lake.

(C)Represents OG&E's 51 percent ownership interest in the Redbud Plant.

(D)Represents OG&E's 77 percent ownership interest in the McClain Plant.

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---

| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| ***Renewable*** |  |  |  |  | **2025** |  |  |
| **Station** | **Year Installed** | **Location** | **Number of<br>Units** | **Fuel Capability** | **Capacity Factor<br>(A)** | **Unit<br>Capability<br>(MW)** | **Station<br>Capability<br>(MW)** |
| Crossroads | 2011 | Canton, OK | 98 | Wind | 19.1% | 2.3 | 228 |
| Centennial | 2007 | Laverne, OK | 80 | Wind | 15.2% | 1.5 | 120 |
| OU Spirit | 2009 | Woodward, OK | 44 | Wind | 14.3% | 2.3 | 101 |
| Mustang | 2015 | Oklahoma City, OK | 90 | Solar | 18.9% | < 0.1 | 2 |
| Covington | 2018 | Covington, OK | 4 | Solar | 15.7% | 2.5 | 10 |
| Choctaw Nation | 2020 | Durant, OK | 2 | Solar | 20.5% | 2.5 | 5 |
| Chickasaw Nation | 2020 | Davis, OK | 2 | Solar | 21.9% | 2.5 | 5 |
| Branch | 2021 | Branch, AR | 2 | Solar | 15.7% | 2.5 | 5 |
| Durant 2 | 2022 | Durant, OK | 2 | Solar | 25.0% | 2.5 | 5 |
| Total Generating Capability (renewable) | Total Generating Capability (renewable) | Total Generating Capability (renewable) |  |  |  |  | 481 |

---

(A)2025 Capacity Factor = 2025 Net Actual Generation / (2025 Net Maximum Capacity (Nameplate Rating in MWs) x Period Hours (8,760 Hours)). Capacity Factors are impacted by events that reduce Net Actual Generation such as outages.

The following table presents certain operating data relating to the OG&E's electricity transmission and distribution assets at December 31, 2025.

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| | | |
|:---|:---|:---|
|  | **Oklahoma** | **Arkansas** |
| Transmission system: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Substations | 55 | 7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total capacity (million kV-amps) | 15.7 | 2.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Structure miles - lines | 5208 | 347 |
| Distribution system: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Substations | 353 | 30 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total capacity (million kV-amps) | 11.4 | 1.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Structure miles - overhead | 29729 | 2810 |
| &nbsp;&nbsp;&nbsp;&nbsp;Miles of underground conduit | 3535 | 296 |
| &nbsp;&nbsp;&nbsp;&nbsp;Miles of underground conductors | 11900 | 760 |

---

During the three years ended December 31, 2025, both Registrants' gross property, plant and equipment (excluding construction work in progress) additions were $3.1 billion, and gross retirements were $621.0 million. These additions were provided by cash generated from operations, short-term borrowings (through a combination of bank borrowings and commercial paper), long-term borrowings and permanent financings. The additions during this three-year period amounted to 17.5 percent of gross property, plant and equipment (excluding construction work in progress) for both Registrants at December 31, 2025.

**Item 3. Legal Proceedings.**

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 Registrants' 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 disclosed in Note 13 within "Item 8. Financial Statements and Supplementary Data," 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 the Registrants' financial position, results of operations or cash flows.

**Item 4. Mine Safety Disclosures.** 

Not Applicable.

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**PAR** **T II**

**Item 5. Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.** 

OGE Energy's common stock is listed for trading on the New York Stock Exchange under the ticker symbol "OGE." At December 31, 2025, there were 10,496 holders of record of OGE Energy's common stock.

Currently, all of OG&E's outstanding common stock is held by OGE Energy. Therefore, there is no public trading market for OG&E's common stock.

**Performance Graph**

The below graph shows a five-year comparison of cumulative total returns for OGE Energy's common stock, the S&P 500 Index and the S&P 1500 Composite Utilities Sector Index. The graph assumes that the value of the investment in OGE Energy's common stock and each index was $100 as of December 31, 2020, and that all dividends were reinvested.

![img67622643_0.jpg](img67622643_0.jpg)

The above graph and related information should not be deemed "soliciting material" or to be "filed" with the Securities Exchange Commission, nor should such information be incorporated by reference into any future filing under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, except to the extent that OGE Energy specifically incorporates such information by reference into such a filing. The graph and information are included for historical comparative purposes only and should not be considered indicative of future stock performance.

**Issuer Purchases of Equity Securities**

None.

**Item 6. [Reserved]**

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**Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.**

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

**Overview**

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.

**Recent Developments**

***OG&E's Regulatory Matters***

On March 27, 2025, the OCC issued a final order approving the settlement agreement relating to OG&E's 2023 general rate review and approved the ALJ report on the remaining one MW issue with one exception. OG&E also issued its 2025 IRP to the OCC and APSC and has filed for and/or received preapproval, in both Oklahoma and Arkansas, of certain generation and capacity investments identified by OG&E's IRP and related request for proposals process. These matters, as well as other regulatory matters, are discussed in Note 14 within "Item 8. Financial Statements and Supplementary Data."

***Legislative Matters***

*Federal*

On July 4, 2025, the legislation known as the "One Big Beautiful Bill" was signed into law, which includes significant changes to federal tax law and other regulatory provisions that may impact the Registrants. The Registrants will consider the legislation's provisions, such as changes to tax credits for renewables, and the potential impact on future investment decisions.

*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. OG&E began deferring such costs to a regulatory asset in September 2025, as further discussed in Note 1 within "Item 8. Financial Statements and Supplementary Data."

*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.

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**Summary of OGE Energy 2025 Operating Results Compared to 2024**

OGE Energy's net income was $470.7 million, or $2.32 per diluted share, in 2025 as compared to $441.5 million, or $2.19 per diluted share, in 2024. The increase in net income of $29.2 million, or $0.13 per diluted share, in 2025 as compared to 2024 is further discussed below.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•An increase in net income at OG&E of $29.9 million, or $0.14 per diluted share of OGE Energy's common stock, was primarily due to higher operating revenues (excluding the impact of recoverable fuel, purchased power and direct transmission expense not impacting earnings) driven by the recovery of capital investments, which offset the impact of milder weather, partially offset by higher depreciation and amortization expense driven by additional assets being placed into service, operation and maintenance expense, income tax expense, and interest expense driven by OG&E's senior notes issuances in August 2024 and April 2025.

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•An increase in net loss of other operations of $0.7 million, or $0.01 per diluted share of OGE Energy's common stock, was primarily due to higher interest expense, partially offset by higher net other income driven by a one-time benefit related to activity at OGE Energy's legacy midstream operations and a higher income tax benefit.

A more detailed discussion regarding the financial performance for the year ended December 31, 2025 as compared to December 31, 2024 can be found under "Results of Operations" below. A discussion of the financial performance for the year ended December 31, 2024 compared to December 31, 2023 for OGE Energy and OG&E can be found within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" of the Registrants' [<u>2024 Form 10-K</u>](https://www.sec.gov/ix?doc=/Archives/edgar/data/74145/000095017025022560/oge-20241231.htm).

**2026 Outlook** 

Key assumptions for the 2026 outlook are discussed below.

OGE Energy is projected to earn approximately $494 million to $514 million, or $2.38 to $2.48 per average diluted share, with a midpoint of approximately $504 million, or $2.43 per average diluted share in 2026 and is based off the following assumptions:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•OGE Energy forecasts earnings for OG&E of approximately $533 million, or $2.57 per average diluted share;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•OGE Energy forecasts a loss of approximately $30 million for other operations (primarily the holding company), or a loss of $0.14 per average diluted share;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•OG&E experiences normal weather patterns for the year; OG&E has significant seasonality in its earnings; OG&E typically shows minimal earnings in the first and fourth quarters with a majority of its earnings in the third quarter due to the seasonal nature of air conditioning demand;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•total retail load growth of approximately 4 to 6 percent;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•operating expenses of approximately $1.228 billion to $1.238 billion, with operation and maintenance expenses comprising approximately 45 percent of the total;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•net interest expense of approximately $256 million to $261 million which assumes a $14 million allowance for borrowed funds used during construction reduction to interest expense, and assumes a debt issuance at OG&E of approximately $300 million;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•other income of approximately $24 million including $26 million of allowance for equity funds used during construction;

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•an effective consolidated tax rate of approximately 16.8 percent; and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•approximately 207.3 million average diluted shares outstanding.

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**Results of Operations**

The following discussion and analysis presents factors that affected the Registrants' results of operations for the years ended December 31, 2025 and 2024 and the Registrants' financial positions at December 31, 2025 and 2024. The following information should be read in conjunction with the financial statements and notes thereto. Known trends and contingencies of a material nature are discussed to the extent considered relevant.

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| | | |
|:---|:---|:---|
| **OGE Energy** | **Year Ended December 31,** | **Year Ended December 31,** |
| *(In millions except per share data)* | **2025** | 2024 |
| Net income | $**470.7** | $441.5 |
| Basic average common shares outstanding | **201.9** | 200.8 |
| Diluted average common shares outstanding | **202.5** | 201.3 |
| Basic earnings per average common share | $**2.33** | $2.20 |
| Diluted earnings per average common share | $**2.32** | $2.19 |
| Dividends declared per common share | $**1.6925** | $1.6789 |

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***Results by Business Segment***

---

| | | |
|:---|:---|:---|
|  | **Year Ended December 31,** | **Year Ended December 31,** |
| *(In millions)* | **2025** | 2024 |
| Net income: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;OG&E (Electric Company) | $**499.8** | $469.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other operations | **(29.1)** | (28.4) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OGE Energy net income | $**470.7** | $441.5 |

---

------

The following discussion of results of operations for OG&E includes intercompany transactions that are eliminated in OGE Energy's consolidated financial statements.

***OG&E (Electric Company)***

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| | | |
|:---|:---|:---|
| Year Ended December 31 *(Dollars in millions)* | **2025** | 2024 |
| Operating revenues | $**3260.1** | $2985.3 |
| Fuel, purchased power and direct transmission expense | **1259.9** | 1076.4 |
| Other operation and maintenance | **531.0** | 514.1 |
| Depreciation and amortization | **559.8** | 539.5 |
| Taxes other than income | **109.4** | 109.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Operating income | **800.0** | 745.6 |
| Allowance for equity funds used during construction | **26.0** | 25.5 |
| Other net periodic benefit expense | **10.3** | 1.6 |
| Other income | **17.3** | 12.5 |
| Other expense | **2.6** | 4.5 |
| Interest expense | **225.5** | 214.4 |
| Income tax expense | **105.1** | 93.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;Net income | $**499.8** | $469.9 |
| Operating revenues by classification: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Residential | $**1205.8** | $1148.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Commercial | **978.2** | 839.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Industrial | **265.3** | 254.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Oilfield | **242.8** | 227.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Public authorities and street light | **276.1** | 262.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;System sales revenues | **2968.2** | 2731.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Provision for rate refund | **3.0** | (3.0) |
| &nbsp;&nbsp;&nbsp;&nbsp;Integrated market | **91.6** | 74.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Transmission | **159.4** | 152.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **37.9** | 29.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total operating revenues | $**3260.1** | $2985.3 |
| MWh sales by classification *(In millions)* |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Residential | **9.7** | 9.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;Commercial | **12.4** | 10.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Industrial | **4.1** | 4.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;Oilfield | **4.3** | 4.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Public authorities and street light | **3.1** | 3.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;System sales | **33.6** | 32.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Integrated market | **0.8** | 0.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total sales | **34.4** | 32.8 |
| Number of customers | **913305** | 906952 |
| Weighted-average cost of energy per kilowatt-hour *(In cents)* |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Natural gas | **3.911** | 2.640 |
| &nbsp;&nbsp;&nbsp;&nbsp;Coal | **2.744** | 3.083 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total fuel | **3.343** | 2.637 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total fuel and purchased power | **3.502** | 3.139 |
| Degree days (A) |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Heating - Actual | **3052** | 2791 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Heating - Normal | **3572** | 3568 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Cooling - Actual | **2060** | 2313 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Cooling - Normal | **1890** | 1893 |

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(A)Degree days are calculated as follows: The high and low degrees of a particular day are added together and then averaged. If the calculated average is above 65 degrees, then the difference between the calculated average and 65 is expressed as cooling degree days, with each degree of difference equaling one cooling degree day. If the calculated average is below 65 degrees, then the difference between the calculated average and 65 is expressed as heating degree days, with each degree of difference equaling one heating degree day. The daily calculations are then totaled for the particular reporting period. The calculation of heating and cooling degree normal days is based on a 30-year average and weighted on a jurisdictional split.

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OG&E's net income increased $29.9 million, or 6.4 percent, in 2025 as compared to 2024. The following section discusses the primary drivers for the increase in net income in 2025 as compared to 2024.

Operating revenues increased $274.8 million, or 9.2 percent, primarily driven by the below factors.

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| | |
|:---|:---|
| *(In millions)* | **$ Change** |
| Fuel, purchased power and direct transmission expense (A) | $183.5 |
| Price variance (B) | 66.4 |
| Non-residential demand and related revenues | 15.1 |
| New customer growth | 11.6 |
| Guaranteed Flat Bill program (C) | 7.8 |
| Wholesale transmission revenue | 4.8 |
| Other | 0.5 |
| Industrial and oilfield sales | (1.5) |
| Quantity impacts (primarily weather) (D) | (13.4) |
| &nbsp;&nbsp;&nbsp;&nbsp;Change in operating revenues | $274.8 |

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

(B)Increased primarily due to new rates effective July 1, 2024 resulting from the Oklahoma general rate review interim order received in November 2024 and finalized in March 2025.

(C)The Guaranteed Flat Bill program allows qualifying customers the opportunity to purchase their electricity needs at a set monthly price for an entire year which can result in variances when actual fuel and purchased power prices differ from what is included in Guaranteed Flat Bill rates.

(D)Decreased primarily due to a decrease of 11 percent in cooling degree days.

Fuel, purchased power and direct transmission expense for OG&E consists of fuel used in electric generation, purchased power and transmission related charges. As described above, the actual cost of fuel used in electric generation and certain purchased power costs are generally recoverable from OG&E's customers through fuel adjustment clauses. The fuel adjustment clauses are subject to periodic review by the OCC and the APSC. OG&E's fuel, purchased power and direct transmission expense increased $183.5 million, or 17.0 percent, primarily driven by the below factors.

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| | |
|:---|:---|
| *(In millions)* | **$ Change** |
| Fuel expense (A) | $73.5 |
| Purchased power costs: |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Purchases from SPP (B) | 86.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | 7.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Capacity | 4.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Wind | 0.5 |
| Transmission expense | 11.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Change in fuel, purchased power and direct transmission expense | $183.5 |

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(A)Increased primarily due to higher fuel costs related to the generating assets utilized during 2025.

(B)Increased primarily due to higher market prices and increased MWhs purchased during 2025.

Other operation and maintenance expense increased $16.9 million, or 3.3 percent, primarily due to an increase in vegetation management activities, resulting from approvals in OG&E's most recent Oklahoma rate review, energy efficiency program activities and uncollectible accounts, partially offset by lower contract technical and construction services driven by the timing of certain projects.

Depreciation and amortization expense increased $20.3 million, or 3.8 percent, primarily due to additional assets being placed into service and increased amortization of certain regulatory assets, partially offset by deferrals of allowable depreciation and amortization expense of $12.7 million to a regulatory asset in accordance with SB 998 as further discussed in Note 1 within "Item 8. Financial Statements and Supplementary Data."

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Net other income decreased $1.5 million, or 4.7 percent, primarily due to higher other net periodic benefit cost driven by changes to the level of pension expense included in base rates as a result of OG&E's most recent Oklahoma rate review, partially offset by increased interest income related to the carrying charge for the higher fuel under recovery balance in early 2025.

Interest expense increased $11.1 million, or 5.2 percent, primarily due to the $350.0 million in senior notes issuance in April 2025 and the full year effect of the issuance of $350.0 million in senior notes in August 2024, partially offset by a decrease in other interest expense related to borrowings under OG&E's revolving credit agreement during the second and third quarters of 2024, as well as the deferral of certain interest expense to a regulatory asset in accordance with SB 998.

Income tax expense increased $11.9 million, or 12.8 percent, primarily due to higher pretax income combined with an increase in other nondeductible items.

**Liquidity and Capital Resources**

***Cash Flows*** 

*OGE Energy*

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| | | | | |
|:---|:---|:---|:---|:---|
| Year Ended December 31 *(In millions)* | **2025** | 2024 | **$ Change** | **% <br>Change** |
| Net cash provided from operating activities (A) | $**1137.1** | $812.8 | $**324.3** | **39.9** |
| Net cash used in investing activities (B) | $**(1126.6)** | $(1161.2) | $**34.6** | **(3.0)** |
| Net cash (used in) provided from financing activities (C) | $**(10.9)** | $348.8 | $**(359.7)** | **\*** |

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\* Change is greater than 100 percent.

(A)Changed primarily due to increased cash received from customers, including cash related to fuel recoveries, partially offset by increased payments for fuel and purchased power.

(B)Changed primarily due to timing of power delivery, power supply and enterprise services projects.

(C)Changed primarily due to a decrease in senior notes issuances in 2025 compared to 2024 and a decrease in commercial paper borrowings, partially offset by the equity issuance in November 2025.

***Working Capital***

Working capital is defined as the difference in current assets and current liabilities. OGE Energy's working capital requirements are driven generally by changes in accounts receivable, accounts payable, commodity prices, credit extended to and the timing of collections from OG&E's customers, the level and timing of spending for maintenance and expansion activity, inventory levels and fuel recoveries. The following discussion addresses changes in OGE Energy's working capital balances at December 31, 2025 compared to December 31, 2024.

Accounts Receivable and Accrued Unbilled Revenues increased $108.8 million, or 34.5 percent, primarily due to an increase in billings to OG&E's retail customers reflecting higher usage in 2025 compared to 2024 and receivables related to customer connections.

Fuel Inventories decreased $36.3 million, or 24.5 percent, primarily due to net withdrawals of coal and natural gas, as well as a decrease in coal prices.

Fuel Clause Recoveries changed $130.5 million from an under recovery to an over recovery, primarily due to higher recoveries from OG&E retail customers as compared to the actual cost of fuel and purchased power.

Other Current Assets decreased $17.2 million, or 19.3 percent, primarily due to SPP security deposit refunds received during 2025, as well as a decrease in the SPP transmission formula rate true-up.

Short-term debt decreased $177.3 million, or 37.8 percent, primarily due to proceeds from OG&E's $350.0 million senior notes issuance in April 2025 and OGE Energy's equity issuance in November 2025, which proceeds were used to pay down short-term debt, partially offset by increased borrowings for general operating needs. The Registrants borrow on a short-term basis, as necessary, through the issuance of commercial paper.

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Accounts Payable increased $44.9 million, or 14.7 percent, primarily due to timing of vendor payments, partially offset by a decrease in purchased power payables.

Customer Deposits increased $16.1 million, or 14.5 percent, primarily due to an increase in large commercial customers.

Long-Term Debt Due Within One Year decreased $32.4 million, or 100.0 percent, due to the repayment of the Muskogee industrial authority bonds that matured in January 2025.

***2025 Capital Requirements, Sources of Financing and Financing Activities***

In 2025, OGE Energy's primary sources of capital were cash generated from operations, the proceeds from the issuance of long- and short-term debt and proceeds from the issuance of common stock. Changes in working capital reflect the seasonal nature of OGE Energy's business, the revenue lag between billing and collection from customers and fuel inventories. See "Working Capital" for a discussion of significant changes in net working capital requirements as it pertains to operating cash flow and liquidity.

In addition, OGE Energy's liquidity was further enhanced in 2025 by FSAs, entered into in conjunction with OGE Energy's November 2025 public equity offering, which as of December 31, 2025 could have been physically settled with common shares in exchange for cash of $193.0 million. For more information concerning the FSAs, see Note 8 within "Item 8. Financial Statements and Supplementary Data."

***Future Material Cash Requirements***

OGE Energy's primary material cash requirements are related to acquiring or constructing new facilities and replacing or expanding existing facilities at OG&E. Other working capital requirements include items such as maturing debt, operating lease obligations, fuel clause under recoveries and other general corporate purposes. Further, working capital requirements can be seasonal. OGE Energy generally meets its cash needs through a combination of cash generated from operations, short-term borrowings (through a combination of bank borrowings and commercial paper) and permanent financings. OGE Energy believes its cash flows from operations, existing borrowing capacity, and access to debt and equity capital markets as needed, should be sufficient to satisfy our material cash requirements over the short-term and long-term.

*Capital Expenditures*

OGE Energy's estimates of capital expenditures, which represent base maintenance capital expenditures plus capital expenditures for known and committed projects, for the years 2026 through 2030 are presented in the following table. The capital investments are customer-focused and targeted to maintain and improve the safety, resiliency and reliability of OG&E's distribution and transmission grid and generation fleet, enhance the ability of OG&E's system to perform during extreme weather events and to serve OG&E's growing customer base.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| *(In millions)* | **2026** | **2027** | **2028** | **2029** | **2030** | **Total** |
| Transmission (A)(B) | $200 | $310 | $305 | $270 | $240 | $1325 |
| Oklahoma distribution | 585 | 705 | 725 | 775 | 825 | 3615 |
| Arkansas distribution | 45 | 25 | 25 | 25 | 25 | 145 |
| Generation reliability | 245 | 160 | 165 | 165 | 165 | 900 |
| Generation capacity projects (C) | 180 | 190 | 165 | 65 |  | 600 |
| Technology, fleet & facilities | 130 | 135 | 145 | 145 | 145 | 700 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total | $1385 | $1525 | $1530 | $1445 | $1400 | $7285 |

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(A)Transmission includes the Fort Smith to Muskogee transmission project discussed in Note 14 within "Item 8. Financial Statements and Supplementary Data," with projected capital expenditures of approximately $70 million in 2026, $80 million in 2027, $65 million in 2028, and $35 million in 2029.

(B)Capital expenditures associated with the SPP's 2025 Integrated Transmission Plan, including the Seminole to Shreveport Transmission Line that is discussed in Note 14 within "Item 8. Financial Statements and Supplementary Data," will be included in OG&E's capital plan upon final notice to construct acceptances.

(C)Generation capacity projects include the Tinker Air Force Base, Horseshoe Lake Units 11 and 12, and Horseshoe Lake Units 13 and 14 generation projects. Additional generation capacity projects will be included in OG&E's capital plan when final preapproval orders are received.

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Additional capital expenditures beyond those identified in the table above, including additional incremental growth opportunities, will be evaluated based upon the requirements of OG&E's power supply, transmission and distribution operational teams and the expected resultant customer benefits. The annual level of investments in the transmission and distribution system could vary depending on the amount and timing of incremental generation capacity investments.

*Contractual Obligations*

The following table presents OGE Energy's total contractual obligations for the next five years at December 31, 2025. For further detail of OGE Energy's contractual obligations, which include operating leases, long-term debt and purchase obligations and commitments (including information for maturities beyond the next five years), see Notes 4, 9 and 13, respectively, within "Item 8. Financial Statements and Supplementary Data."

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| *(In millions)* | **2026** | **2027** | **2028** | **2029** | **2030** | **Total** |
| Total contractual obligations | $425.4 | $917.6 | $768.0 | $524.1 | $758.6 | $3393.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Amounts recoverable through fuel adjustment clause and other regulatory mechanisms (A) | (274.0) | (173.1) | (158.0) | (149.4) | (149.5) | (904.0) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total contractual obligations, net | $151.4 | $744.5 | $610.0 | $374.7 | $609.1 | $2489.7 |

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(A)Includes expected recoveries of costs incurred for OG&E's railcar operating lease obligations, OG&E's minimum fuel purchase commitments, OG&E's expected wind purchase commitments and OG&E's capacity agreements.

The actual cost of fuel used in electric generation (which includes the operating lease obligations for OG&E's railcar leases shown in Note 4 within "Item 8. Financial Statements and Supplementary Data") and certain purchased power costs are passed on to OG&E's customers through fuel adjustment clauses and other regulatory mechanisms. Accordingly, while the cost of fuel related to operating leases and the vast majority of minimum fuel purchase commitments of OG&E noted in Notes 4 and 13, respectively, within "Item 8. Financial Statements and Supplementary Data" may increase capital requirements, such costs are generally recoverable through fuel adjustment clauses and have little, if any, impact on net capital requirements and future contractual obligations. OG&E's fuel adjustment clauses are subject to periodic review by the OCC and the APSC. Otherwise, as discussed above, OGE Energy expects to meet these cash requirement needs through cash generated from operations, short-term borrowings and permanent financings.

*Pension and Postretirement Benefit Plans*

At December 31, 2025, 14.5 percent of the Pension Plan investments were in listed common stocks with the balance primarily invested in corporate fixed income and other securities, U.S. Treasury notes and bonds and mutual funds, as presented in Note 11 within "Item 8. Financial Statements and Supplementary Data." During 2025, the actual return on the Pension Plan was $23.3 million, compared to an expected return on plan assets of $16.5 million. During the same time, corporate bond yields, which are used in determining the discount rate for future pension obligations, decreased. Funding levels are dependent on returns on plan assets and future discount rates. OGE Energy made contributions to its Pension Plan of $13.5 million in 2025 and $10.0 million in 2024. OGE Energy expects to contribute $15.0 million to the 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.

The following table presents the status of OGE Energy's Pension Plan, the Restoration of Retirement Income Plan and the postretirement benefit plans at December 31, 2025 and 2024. 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 within "Item 8. Financial Statements and Supplementary Data") 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.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
|  | **Pension Plan** | **Pension Plan** | **Restoration of Retirement<br>Income Plan** | **Restoration of Retirement<br>Income Plan** | **Postretirement<br>Benefit Plans** | **Postretirement<br>Benefit Plans** |
| December 31 *(In millions)* | **2025** | 2024 | **2025** | 2024 | **2025** | 2024 |
| Benefit obligations | $**315.2** | $303.1 | $**9.3** | $7.0 | $**90.4** | $98.1 |
| Fair value of plan assets | **262.2** | 246.9 | **—** |  | **28.4** | 30.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Funded status at end of year | $**(53.0)** | $(56.2) | $**(9.3)** | $(7.0) | $**(62.0)** | $(68.1) |

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*Common Stock Dividends*

OGE Energy's dividend policy is reviewed by the Board of Directors at least annually and is based on numerous factors, including management's estimation of the long-term earnings power of its businesses. In 2025, the Board of Directors reviewed a recommendation from management of an increase in the quarterly dividend to $0.425 per share from $0.42125 per share and subsequently approved the recommendation to become effective with the dividend payment in October 2025.

***Financing Activities and Future Sources of Financing***

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

*Short-Term Debt and Credit Facilities*

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

OGE Energy has unsecured five-year revolving credit facilities totaling $1.1 billion ($550.0 million for OGE Energy and $550.0 million for OG&E), which can also be used as letter of credit facilities. OGE Energy also has a $120.0 million floating rate unsecured three-year credit agreement, of which $60.0 million is considered a revolving loan. The following table presents information about OGE Energy's revolving credit agreements as of December 31, 2025.

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| | |
|:---|:---|
| *(Dollars in millions)* | **December 31, 2025** |
| Balance of outstanding supporting letters of credit | $0.4 |
| Weighted-average interest rate of outstanding supporting letters of credit | 1.20% |
| Net available liquidity under revolving credit agreements, commercial paper borrowings and letters of credit | $867.6 |
| Balance of cash and cash equivalents | $0.2 |

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The following table presents information about OGE Energy's total short-term debt activity for the year ended December 31, 2025.

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| | |
|:---|:---|
| *(Dollars in millions)* | **Year Ended December 31, 2025** |
| Average balance of short-term debt | $529.9 |
| Weighted-average interest rate of average balance of short-term debt | 4.62% |
| Maximum month-end balance of short-term debt | $766.7 |

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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.

*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.

In 2026, OG&E expects to issue approximately $300 million in long-term debt to help fund general operating needs.

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*Security Ratings*

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
|  | **Moody's Investors Service** | **Moody's Investors Service** | **S&P's Global Ratings** | **S&P's Global Ratings** | **Fitch Ratings** | **Fitch Ratings** |
|  | **Rating** | **Outlook** | **Rating** | **Outlook** | **Rating** | **Outlook** |
| OG&E Senior Notes | A3 | Negative | A- | Negative | A | Stable |
| OG&E Commercial Paper | P2 | Negative | A2 | Negative | F2 | Stable |
| OGE Energy Senior Notes | Baa1 | Negative | BBB | Stable | BBB+ | Stable |
| OGE Energy Commercial Paper | P2 | Negative | A2 | Stable | F2 | Stable |

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

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

On April 14, 2025, Moody's Investors Service revised their ratings outlook on both OGE Energy and OG&E from stable to negative. Moody's Investors Service indicated that the revised outlook reflects pressure related to OG&E's capital expenditure plan and higher debt levels at the holding company.

On November 18, 2025, S&P's Global Ratings revised their ratings outlook on OG&E from stable to negative and affirmed their stable ratings outlook on OGE Energy. S&P's Global Ratings indicated the revised outlook for OG&E reflects the elevated wildfire exposure and the mitigation efforts needed to reduce such risks.

Future financing requirements may be dependent, to varying degrees, upon numerous factors such as general economic conditions, abnormal weather, load growth, commodity prices, acquisitions of other businesses and/or development of projects, actions by rating agencies, inflation, changes in environmental laws or regulations, rate increases or decreases allowed by regulatory agencies, new legislation, and market entry of competing electric power generators.

*Common Stock*

OGE Energy expects to issue between $15 million to $25 million of common stock from its Automatic Dividend Reinvestment and Stock Purchase Plan in 2026.

In November 2025, OGE Energy entered into a public offering of approximately $397 million (9,226,744 shares) of its common stock, which included 4,613,372 common shares that were issued and sold by OGE Energy to the underwriters and 4,613,372 common shares that are subject to FSAs. Total cash proceeds received in November 2025 related to the public offering was $192.4 million. Settlement of the FSAs, which is at OGE Energy's discretion, is expected to occur no later than 18 months following the completion of the offering.

See Note 8 within "Item 8. Financial Statements and Supplementary Data" for a discussion of OGE Energy's common stock activity.

**Critical Accounting Policies and Estimates**

The financial statements and notes thereto contain information that is pertinent to management's discussion and analysis. 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.

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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. The selection, application and disclosure of the following critical accounting estimates have been discussed with the Audit Committee of OGE Energy's Board of Directors. The Registrants discuss their significant accounting policies, including those that do not require management to make difficult, subjective or complex judgments or estimates, in Note 1 within "Item 8. Financial Statements and Supplementary Data."

***Pension and Postretirement Plan Assumptions***

OGE Energy has a Pension Plan that covers certain employees, including OG&E's employees, hired before December 1, 2009. Effective December 1, 2009, OGE Energy's Pension Plan is no longer being offered to employees hired on or after December 1, 2009. OGE Energy also has defined benefit postretirement plans that cover certain employees, including OG&E's employees hired prior to February 1, 2000. Pension and other postretirement plan expenses and liabilities are determined on an actuarial basis and are affected by the market value of plan assets, estimates of the expected return on plan assets, assumed discount rates, and the level of funding. Actual changes in the fair market value of plan assets and differences between the actual return on plan assets and the expected return on plan assets could have a material effect on the amount of pension expense ultimately recognized. The Pension Plan rate assumptions are shown in Note 11 within "Item 8. Financial Statements and Supplementary Data." The assumed return on plan assets is based on management's expectation of the long-term return on the plan assets portfolio. 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. Funding levels are dependent on returns on plan assets and future discount rates. Higher returns on plan assets and an increase in discount rates will reduce funding requirements to the Pension Plan.

The following table presents the sensitivity of the Pension Plan funded status to these variables.

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| | | |
|:---|:---|:---|
|  | **Change** | **Impact on Funded Status** |
| Actual plan asset returns | +/- 1 percent | +/- $2.6 million |
| Discount rate | +/- 0.25 percent | +/- $4.7 million |
| Contributions | +/- $10 million | +/- $10.0 million |

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***Income Taxes***

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 application of income tax law is complex. Laws and regulations in this area are voluminous and often ambiguous. Interpretations and guidance surrounding income tax laws and regulations change over time. Accordingly, it is necessary to make judgments regarding income tax exposure. As a result, changes in these judgments can materially affect amounts the Registrants recognized in their financial statements. Tax positions taken by the Registrants on their income tax returns that are recognized in the financial statements must satisfy a more likely than not recognition threshold, assuming that the position will be examined by taxing authorities with full knowledge of all relevant information.

***Contingency Reserves***

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.

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***Regulatory Assets and Liabilities***

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. 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.

**Accounting Pronouncements**

See Note 2 within "Item 8. Financial Statements and Supplementary Data" for further discussion of recently adopted accounting standards and recently issued accounting standards that are not yet effective that could have a material impact on the Registrants' financial position, results of operations or cash flows upon adoption.

**Commitments and Contingencies**

In the normal course of business, the Registrants are confronted with issues or events that may result in a contingent liability. These generally relate to lawsuits or claims made by third parties, including governmental agencies. When appropriate, management consults with legal counsel and other experts to assess the claim. If, in management's opinion, the Registrants have incurred a probable loss as set forth by GAAP, an estimate is made of the loss, and the appropriate accounting entries are reflected in the 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 disclosed in Note 13 within "Item 8. Financial Statements and Supplementary Data," 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. See Notes 13 and 14 within "Item 8. Financial Statements and Supplementary Data" and "Item 3. Legal Proceedings" for further discussion of the Registrants' commitments and contingencies.

**Environmental Laws and Regulations**

The activities of OG&E are subject to numerous stringent and complex federal, state and local laws and regulations governing environmental protection. These laws and regulations can change, restrict or otherwise impact 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.

Changes in presidential administrations can result in uncertainty regarding policy or initiatives relating to activities that may affect the environment. In March 2025, the EPA announced that it would begin reconsideration of numerous regulations, including several that apply to OG&E. The EPA has begun this process for certain regulations as described below and must adhere to the legal requirements for enacting, revising, repealing, or replacing agency regulations. Future developments, such as changes in existing laws, introduction of new laws or regulations, or the emergence of new facts or conditions, may result in significant costs for the Registrants.

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

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***Air***

OG&E's operations are subject to the Federal Clean Air Act of 1970, as amended, and comparable state laws and regulations. These laws regulate air pollutant emissions from industrial sources, including electric generating units, and require monitoring and reporting. These laws and regulations may require OG&E to secure pre-approval for constructing or modifying projects or facilities that are anticipated to generate air emissions or increase current emission levels. Additionally, OG&E may need to obtain and comply with air permits outlining specific emission and operational requirements or implement emission control equipment. OG&E likely will be required to incur certain capital expenditures in the future for air pollution control equipment and technology in connection with obtaining and maintaining operating permits and approvals for air emissions.

*Cross State Air Pollution Rule*

In 2015, the EPA updated the ambient air standards for ozone. Although Oklahoma meets these standards, the Clean Air Act requires states to submit implementation plans to the EPA to ensure their emissions do not affect other states. Oklahoma submitted its SIP in 2018. However, in January 2023, the EPA disapproved the SIPs of 19 states, including Oklahoma. In response, the Oklahoma Attorney General, the ODEQ and OG&E filed petitions for review in March 2023. A stay on the EPA's disapproval was granted in July 2023. The timing of further action is currently unknown.

In a related matter, in April 2022, the EPA published a proposed FIP related to the "Good Neighbor" requirements intended to reduce interstate NOx emissions. OG&E commented on this proposed FIP in June 2022. By June 2023, the EPA finalized this plan for 23 states, including Oklahoma. This final Good Neighbor FIP would revise Oklahoma's NOx emissions budget for electric generating units, including OG&E's, starting in 2023. The emissions budget would decrease over time based on achievable reductions. OG&E estimated a 34.5 percent reduction by 2026 from 2023 levels and a 50 percent reduction by 2027 from 2021 levels. Following the FIP issuance, OG&E has been considering options to cut emissions at its generating units, including buying emission allowances, installing selective catalytic reduction systems, switching coal units to gas, or retiring and replacing capacity. OG&E submitted its final 2024 IRP to the OCC and APSC on March 29, 2024, which evaluates various compliance options related to the EPA's Good Neighbor FIP. Due to the uncertainty surrounding the SIP disapproval and FIP implementation, OG&E cannot determine the exact cost of compliance. The costs depend on the litigation outcome, chosen control strategies, regulatory approvals, and project timelines. However, OG&E estimated in mid-2023 that compliance costs could range from $2.4 billion to $2.8 billion, including $100 million to $300 million over the first 12 to 18 months following the FIP's effectiveness. OG&E plans to seek recovery of necessary environmental expenditures but cannot guarantee approval or timely recovery of all such expenditures. In October 2023, several petitioners sought a stay of the final FIP from the U.S. Supreme Court, pending review of the challenges in the U.S. Court of Appeals for the District of Columbia. The U.S. Supreme Court granted the stay in June 2024. The EPA requested a delay in the case in February 2025, which was denied. In March 2025, the EPA sought to reconsider the rule without vacating it. The D.C. Circuit Court agreed to hold the case in abeyance in April 2025, requiring status reports every 90 days. The timing of further action is unknown.

The EPA has indicated that it intends to reconsider both the SIP disapprovals and the final FIP in a two-phase reconsideration rulemaking. In January 2026, the EPA proposed its "Phase 1" reconsideration of SIP disapprovals for several states. The EPA did not include the disapproved Oklahoma SIP in "Phase 1" but indicated that it intends to address the remaining states, including Oklahoma, in a separate action. The timing of further action is unknown.

*New Source Performance Standards*

In December 2024, the EPA published in the Federal Register a proposed rule that would revise the new source performance standards regulating NOx and SO2 emissions from new, modified, and reconstructed stationary combustion turbines. OG&E participated with trade associations to submit comments on the proposed rule on April 15, 2025. On January 15, 2026, the EPA published in the Federal Register its final rule establishing NOx emissions standards for several subcategories of stationary combustion turbines based on the size, rates of utilization, design efficiency, and fuel type of these turbines. The rule applies to affected sources constructed, modified, or reconstructed after the December 2024 publication date. As only future, currently unknown activities are affected by this regulation, it is unknown what potential material impacts, if any, there will be from this final action by EPA.

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*Particulate Matter NAAQS*

In February 2024, the EPA issued a final rule resulting from its reconsideration of the primary (health-based) and secondary (welfare-based) NAAQS for PM, which were set in 2013 and which the EPA declined to revise in 2020. The final rule lowers the primary annual PM2.5 NAAQS from 12.0 µg/m<sup>3</sup> to 9.0 µg/m<sup>3</sup> and retains the other PM standards at their current levels, including the 24-hour PM2.5 NAAQS. The EPA will determine which areas of the country meet the standards, such as making initial attainment and nonattainment designations, no later than two years after new standards are issued. States must develop and submit attainment plans no later than 18 months after the EPA finalizes nonattainment designations.

Litigation on the final rule is proceeding in the D.C. Circuit. A coalition of 24 states, including Oklahoma, filed challenges to the final rule, and a separate coalition of states and other stakeholders filed to intervene in these challenges on behalf of the EPA. A coalition of 22 state governors separately requested the EPA to pause implementation of the final rule.

The revised NAAQS could impact regional air quality goals and emission limits for emission sources; however, it is unknown at this time what, if any, potential material impacts to OG&E individual operating permit emission limits will result from the EPA actions.

*Regional Haze* 

In July 2020, the ODEQ notified OG&E that the Horseshoe Lake generating units that were in-service at the time would be included in Oklahoma's second Regional Haze implementation period evaluation of visibility impairment impacts to the Wichita Mountains. OG&E submitted an analysis of all potential control measures for NOx on these units to the ODEQ. The ODEQ submitted a revised SIP to the EPA in August 2022. In February 2026, the EPA proposed to approve the Oklahoma SIP revision, and a 2024 consent decree requires the EPA to take final action no later than December 31, 2026. It is unknown at this time what the outcome, or any potential material impacts, if any, will be from the evaluations by OG&E, the ODEQ and the EPA.

*Mercury and Air Toxics Standards*

In April 2024, the EPA released the final revised Mercury and Air Toxics Standards regulation with a compliance date in July 2027. A coalition of states, including Oklahoma, challenged this rule in the D.C. Circuit Court and sought a stay, which was denied. This coalition of states then filed an emergency stay application with the U.S. Supreme Court, which was also denied. In April 2025, the EPA extended the compliance deadline to July 8, 2029. In June 2025, the EPA proposed to repeal the revised Mercury and Air Toxics Standards, which would remove the revised emission limit and monitoring requirements. In December 2025, the EPA sent to the OMB for review a rule finalizing the proposed repeal. The potential material impacts, if any, of further actions by the EPA or final action by the D.C. Circuit Court are currently unknown.

*Greenhouse Gas*

OG&E monitors developments in federal greenhouse gas ("GHG") emissions regulations applicable to fossil fuel-fired electric generating units. Changes in legal standards, including the implementation of rules for the power sector finalized by the EPA in 2024 or the adoption of new regulations, could require significant capital investment and compliance expenditures. If such costs are not recoverable through regulated rates, OG&E's financial position, results of operations, and cashflows could be materially affected.

In May 2024, the EPA issued final rules establishing (i) emission guidelines under Section 111(d) of the Clean Air Act for existing fossil fuel-fired steam generating units and (ii) revised standards of performance under Section 111(b) for new natural gas-fired combustion turbines. Under these rules, existing coal-fired units that intend to operate beyond 2039 must achieve 90 percent carbon capture by 2032. Units that plan to operate until 2039 must co-fire with natural gas at 40 percent by 2030. Units that retire by 2032 are exempt from these requirements. State compliance plans reflecting affected unit owners' compliance decisions are required to be submitted to the EPA by May 2026.

OG&E's existing natural gas-fired boilers satisfy the new standards and therefore require no additional compliance measures other than reporting. For new natural gas-fired combustion turbines commencing construction after May 23, 2023, the 2024 GHG rules establish three subcategories—baseload, intermediate-load, and low-load—based on capacity factor thresholds, all of which are subject to efficiency requirements. Baseload units, defined as units with capacity factors greater than 40 percent, are also required to achieve 90 percent CO₂ capture by January 1, 2032.

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Significant litigation related to these 2024 GHG rules is ongoing. In February 2025, the D.C. Circuit placed the litigation in abeyance at the EPA's request while the agency reconsiders the 2024 GHG rules.

In June 2025, the EPA proposed to repeal the 2024 GHG rules for both existing and new units or, alternatively, to repeal the 2024 GHG rules for existing units and rescind the carbon capture requirements applicable to new combustion turbines. OG&E submitted comments on the 2025 proposed rules individually and through trade associations. Although the EPA has initiated reconsideration and proposed repeal, the 2024 power sector GHG rules have not been stayed, and future compliance timelines remain in effect. If the new emission standards and guidelines are implemented, compliance costs could be significant. OG&E continues to monitor these developments and plan for compliance with 2024 GHG rules standards currently in effect.

Separately, in February 2026, the EPA released a final rule that rescinds the agency's 2009 Endangerment Finding, which determined that GHG emissions endanger public health and welfare. While rescinding the Endangerment Finding would not directly alter the 2024 GHG regulations, it may result in increased regulatory uncertainty for the power sector as future generation needs are considered.

OG&E cannot predict the outcome of the EPA's reconsideration process, the proposed repeal, or the pending litigation. However, the 2024 GHG rules remain in effect and could result in material compliance obligations and associated costs. OG&E continues to monitor these regulatory developments and evaluate potential impacts on its operations.

***Endangered Species***

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

***Waste***

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

Ash from OG&E's River Valley, Muskogee and Sooner facilities is recovered and reused off-site in various ways, including soil stabilization, landfill cover, road base construction and cement and concrete production. Reusing fly ash reduces the need to manufacture cement resulting in reductions in greenhouse gas emissions from cement and concrete production.

OG&E has sought and will continue to seek pollution prevention opportunities and to evaluate the effectiveness of its waste reduction, reuse and recycling efforts. In 2025, OG&E obtained refunds of $2.2 million from the recycling of scrap metal, salvaged transformers and used transformer oil. This figure does not include the additional savings gained through the reduction and/or avoidance of disposal costs and the reduction in material purchases due to the reuse of existing materials. Similar savings are anticipated in future years.

***Water*** 

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

In 2015, the EPA issued a final rule addressing the effluent limitation guidelines for power plants under the Federal Clean Water Act. The final rule establishes technology- and performance-based standards that may apply to discharges of six waste streams including bottom ash transport water. In April 2024, the EPA released a supplemental effluent limitations guidelines rule. OG&E's installation of dry bottom ash handling technology at an affected facility complies with the 2024 rule requiring facilities to cease

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discharging bottom ash transport water. OG&E is evaluating compliance options at another affected facility, and in December 2025, the EPA published a final rule revising the deadline to cease bottom ash transport water discharge to December 31, 2034.

OG&E has made investments in its infrastructure at Redbud and McClain that have led to OG&E's use of treated municipal effluent for cooling water at each plant, which offsets the need for fresh water as cooling water, making fresh water available for other beneficial uses like drinking water, irrigation and recreation.

***Site Remediation***

The Comprehensive Environmental Response, Compensation and Liability Act of 1980 and comparable state laws impose liability, without regard to the legality of the original conduct, on certain classes of persons responsible for the release of hazardous substances into the environment. Because OG&E utilizes various products and generates wastes that are considered hazardous substances for purposes of the Comprehensive Environmental Response, Compensation and Liability Act of 1980, OG&E could be subject to liability for the costs of cleaning up and restoring sites where those substances have been released to the environment. No associated liability is expected to significantly impact OG&E at this time.

**Item 7A. Quantitative and Qualitative Disclosures About Market Risk.**

Market risks are, in most cases, risks that are actively traded in a marketplace and have been well studied in regards to quantification. Market risks include, but are not limited to, changes in interest rates and commodity prices. The Registrants' exposure to changes in interest rates relates primarily to variable-rate debt, commercial paper and future long-term debt issuances. The Registrants are exposed to commodity prices in their operations to the extent any fuel price changes are not recovered in customer rates.

**Risk Oversight Committee**

The Registrants manage market risks using a risk committee structure. OGE Energy's Risk Oversight Committee, which consists of the Chief Financial Officer, other corporate officers and members of management, is responsible for the overall development, implementation and enforcement of strategies and policies for all significant risk management activities of the Registrants. In 2025, this committee and the Registrants' management applied a holistic perspective of risk assessment and application of its strategies and policies to manage the Registrants' overall financial performance. The Chief Financial Officer, acting in his role as the principal financial officer and as a member of the Risk Oversight Committee, reports periodically to the Audit Committee of OGE Energy's Board of Directors on the Registrants' risk profile affecting anticipated financial results, including any significant risk issues. The Audit Committee updates the Board of Directors regarding the company's risk management practices and the steps management has taken to monitor and control applicable risks.

**Risk Policies**

Management utilizes risk policies to control the amount of market risk exposure. These policies are designed to provide the Audit Committee of OGE Energy's Board of Directors and senior executives of the Registrants with confidence that the risks taken on by the Registrants' business activities are in accordance with their expectations for financial returns and that the approved policies and controls related to market risk management are being followed.

**Interest Rate Risk**

The Registrants' exposure to changes in interest rates primarily relates to variable-rate debt and commercial paper. The Registrants manage their interest rate exposure by monitoring and limiting the effects of market changes in interest rates. The Registrants may utilize interest rate derivatives to alter interest rate exposure in an attempt to reduce the effects of these changes. Interest rate derivatives would be used solely to modify interest rate exposure and not to modify the overall leverage of the debt portfolio, but the Registrants have no intent at this time to utilize interest rate derivatives.

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The fair value of the Registrants' long-term debt is based on quoted market prices and estimates of current rates available for similar issues with similar maturities or by calculating the net present value of the monthly payments discounted by the Registrants' current borrowing rate. The following table presents the Registrants' long-term debt maturities and the weighted-average interest rates by maturity date.

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| | | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|:---|
| Year Ended December 31*<br>(Dollars in millions)* | **2026** | **2027** | **2028** | **2029** | **2030** | **Thereafter** | **Total** | **12/31/25 Fair Value** |
| OGE Energy (holding company) fixed-rate debt (A): |  |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Principal amount | $— | $— | $— | $350.0 | $— | $— | $350.0 | $362.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Weighted-average interest rate | —% | —% | —% | 5.45% | —% | —% | 5.45% |  |
| OGE Energy (holding company) variable-rate debt (A): |  |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Principal amount | $— | $60.0 | $— | $— | $— | $— | $60.0 | $60.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Weighted-average interest rate | —% | 4.89% | —% | —% | —% | —% | 4.89% |  |
| OG&E fixed-rate debt (A): |  |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Principal amount | $— | $125.0 | $500.0 | $— | $600.0 | $3671.5 | $4896.5 | $4653.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;Weighted-average interest rate | —% | 6.65% | 4.34% | —% | 3.28% | 5.08% | 4.82% |  |
| OG&E variable-rate debt (B): |  |  |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Principal amount | $— | $56.0 | $— | $— | $— | $47.0 | $103.0 | $103.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Weighted-average interest rate | —% | 2.40% | —% | —% | —% | 2.40% | 2.40% |  |

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(A)Prior to or when these debt obligations mature, the Registrants may refinance all or a portion of such debt at then-existing market interest rates which may be more or less than the interest rates on the maturing debt.

(B)A hypothetical change of 100 basis points in the underlying variable interest rate incurred by OG&E would change interest expense by $1.0 million annually.

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**Item 8. Financial Statements and Supplementary Data.**

**OGE ENERGY CORP.**

**CONSOLIDATED STATEMENTS OF INCOME**

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| | | | |
|:---|:---|:---|:---|
| Year Ended December 31 *(In millions except per share data)* | **2025** | 2024 | 2023 |
| OPERATING REVENUES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Revenues from contracts with customers | $**3190.9** | $2916.6 | $2607.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other revenues | **69.2** | 68.7 | 67.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Operating revenues | **3260.1** | 2985.3 | 2674.3 |
| FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE | **1259.9** | 1076.4 | 911.7 |
| OPERATING EXPENSES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Other operation and maintenance | **531.6** | 514.4 | 502.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Depreciation and amortization | **559.8** | 539.5 | 506.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Taxes other than income | **109.4** | 109.7 | 103.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Operating expenses | **1200.8** | 1163.6 | 1112.4 |
| OPERATING INCOME | **799.4** | 745.3 | 650.2 |
| OTHER INCOME (EXPENSE) |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Allowance for equity funds used during construction | **26.0** | 25.5 | 19.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other net periodic benefit (expense) income | **(11.0)** | (2.2) | 5.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other income | **39.4** | 30.6 | 48.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other expense | **(23.0)** | (24.1) | (29.0) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net other income | **31.4** | 29.8 | 44.2 |
| INTEREST EXPENSE |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Interest on long-term debt | **261.0** | 228.3 | 205.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Allowance for borrowed funds used during construction | **(15.8)** | (14.6) | (7.1) |
| &nbsp;&nbsp;&nbsp;&nbsp;Interest on short-term debt and other interest charges | **25.1** | 40.8 | 23.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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 |

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

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**OGE ENERGY CORP.**

**CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME**

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| | | | |
|:---|:---|:---|:---|
| Year Ended December 31 *(In millions)* | **2025** | 2024 | 2023 |
| Net income | $**470.7** | $441.5 | $416.8 |
| Other comprehensive income (loss), net of tax: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Pension Plan and Restoration of Retirement Income Plan: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Amortization of prior service cost, net of tax of $0.1, $0.1 and $0.1, respectively | **0.2** | 0.2 | 0.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Amortization of deferred net loss, net of tax of $0.1, $0.1 and $0.2, respectively | **0.3** | 0.2 | 0.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Regulatory classification of certain pension costs, net of tax of $0.0, $1.2 and $0.0, respectively | **—** | 3.9 |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Settlement cost, net of tax of $0.0, $0.0 and $0.4, respectively | **—** |  | 1.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;Postretirement benefit plans: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Amortization of deferred net gain, net of tax of $(0.1), $(0.1) and $(0.1), respectively | **(0.1)** | (0.1) | (0.1) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other comprehensive income, net of tax | **0.1** | 4.5 | 4.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Comprehensive income | $**470.8** | $446.0 | $421.5 |

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

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**OGE ENERGY CORP.**

**CONSOLIDATED STATEMENTS OF CASH FLOWS**

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| | | | |
|:---|:---|:---|:---|
| Year Ended December 31 (*In millions*) | **2025** | 2024 | 2023 |
| CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Net income | $**470.7** | $441.5 | $416.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;Adjustments to reconcile net income to net cash provided from operating activities: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Depreciation and amortization | **559.8** | 539.5 | 506.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Deferred income taxes and other tax credits, net | **59.5** | 15.6 | 11.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Allowance for equity funds used during construction | **(26.0)** | (25.5) | (19.4) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Stock-based compensation expense | **14.0** | 11.7 | 13.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Regulatory assets | **(66.9)** | (52.4) | (92.1) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Regulatory liabilities | **0.5** | (2.8) | (12.2) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other assets | **(32.5)** | (16.8) |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other liabilities | **39.4** | 30.6 | 5.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other | **(8.7)** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Change in certain current assets and liabilities: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Accounts receivable and accrued unbilled revenues, net | **(108.8)** | (33.6) | 42.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Income taxes receivable | **(37.3)** | 18.2 | 2.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Fuel, materials and supplies inventories | **81.9** | 25.7 | (122.8) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Fuel recoveries | **130.5** | (123.9) | 535.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other current assets | **17.1** | (30.1) | 44.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Accounts payable | **34.9** | (14.7) | (136.3) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other current liabilities | **9.0** | 29.8 | 36.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net cash provided from operating activities | **1137.1** | 812.8 | 1232.3 |
| CASH FLOWS FROM INVESTING ACTIVITIES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Capital expenditures (less allowance for equity funds used during construction) | **(1054.4)** | (1090.9) | (1178.2) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Cost of removal and other | **(72.2)** | (70.3) | (93.9) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net cash used in investing activities | **(1126.6)** | (1161.2) | (1272.1) |
| CASH FLOWS FROM FINANCING ACTIVITIES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Proceeds from long-term debt | **344.4** | 706.3 | 788.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Payment of long-term debt | **(32.6)** | (0.1) | (1000.1) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(Decrease) increase in short-term debt | **(177.3)** | (29.9) | 499.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Dividends paid on common stock | **(341.9)** | (338.5) | (333.2) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Proceeds (costs) from issuance of common stock | **203.8** | 17.1 |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Cash paid for employee equity-based compensation | **(7.3)** | (6.1) | (2.3) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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 |  |  |  |
| Cash paid during the period for: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Interest (net of interest capitalized of $15.8, $14.6 and $7.1, respectively) | $**268.7** | $251.1 | $202.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Federal income taxes (net of income tax refunds) | $**73.9** | $44.0 | $44.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;State income taxes (net of income tax refunds) | $**1.2** | $(7.1) | $(2.5) |
| NON-CASH INVESTING AND FINANCING ACTIVITIES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Power plant long-term service agreement | $**3.4** | $6.4 | $0.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Tinker Air Force Base distribution assets purchase | $**—** | $2.6 | $— |

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

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**OGE ENERGY CORP.**

**CONSOLIDATED BALANCE SHEETS**

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| | | |
|:---|:---|:---|
| December 31 (*In millions*) | **2025** | 2024 |
| **ASSETS** |  |  |
| CURRENT ASSETS |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Cash and cash equivalents | $**0.2** | $0.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accounts receivable, less reserve of $4.1 and $2.0, respectively | **347.8** | 240.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued unbilled revenues | **76.2** | 74.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Income taxes receivable | **37.3** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Fuel inventories | **112.0** | 148.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Materials and supplies, at average cost | **212.7** | 229.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Fuel clause under recoveries | **—** | 112.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **71.7** | 88.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total current assets | **857.9** | 895.1 |
| OTHER PROPERTY AND INVESTMENTS |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **129.4** | 124.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total other property and investments | **129.4** | 124.2 |
| PROPERTY, PLANT AND EQUIPMENT |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;In service | **17203.0** | 16254.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Construction work in progress | **744.9** | 814.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total property, plant and equipment | **17947.9** | 17068.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Less: accumulated depreciation | **5217.5** | 4982.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net property, plant and equipment | **12730.4** | 12086.6 |
| DEFERRED CHARGES AND OTHER ASSETS |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Regulatory assets | **557.2** | 568.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **95.6** | 42.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total deferred charges and other assets | **652.8** | 610.1 |
| TOTAL ASSETS | $**14370.5** | $13716.0 |

---

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

------

**OGE ENERGY CORP.**

**CONSOLIDATED BALANCE SHEETS (Continued)**

---

| | | |
|:---|:---|:---|
| December 31 (*In millions*) | **2025** | 2024 |
| **LIABILITIES AND STOCKHOLDERS' EQUITY** |  |  |
| CURRENT LIABILITIES |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Short-term debt | $**292.0** | $469.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accounts payable | **350.6** | 305.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Dividends payable | **87.6** | 84.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Customer deposits | **127.2** | 111.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued taxes | **53.0** | 58.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued interest | **68.8** | 63.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued compensation | **54.3** | 53.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Long-term debt due within one year | **—** | 32.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Fuel clause over recoveries | **27.1** | 9.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **33.5** | 41.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total current liabilities | **1094.1** | 1229.8 |
| LONG-TERM DEBT | **5369.2** | 5020.9 |
| DEFERRED CREDITS AND OTHER LIABILITIES |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued benefit obligations | **164.4** | 170.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Deferred income taxes | **1489.3** | 1371.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Deferred investment tax credits | **9.8** | 10.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Regulatory liabilities | **957.1** | 1016.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **309.3** | 255.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total deferred credits and other liabilities | **2929.9** | 2824.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total liabilities | **9393.2** | 9075.1 |
| COMMITMENTS AND CONTINGENCIES (NOTE 13) |  |  |
| STOCKHOLDERS' EQUITY |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Common stockholders' equity | **1378.4** | 1167.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Retained earnings | **3601.5** | 3475.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accumulated other comprehensive loss, net of tax | **(2.6)** | (2.7) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total stockholders' equity | **4977.3** | 4640.9 |
| TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY | $**14370.5** | $13716.0 |

---

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

------

**OGE ENERGY CORP.**

**CONSOLIDATED STATEMENTS OF CAPITALIZATION**

---

| | | | |
|:---|:---|:---|:---|
| December 31 *(In millions except per share data)* | December 31 *(In millions except per share data)* | **2025** | 2024 |
| STOCKHOLDERS' EQUITY | STOCKHOLDERS' EQUITY |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Common stock, par value $0.01 per share; authorized 450.0 shares; and outstanding 206.1 shares and 201.0 shares, respectively | &nbsp;&nbsp;&nbsp;&nbsp;Common stock, par value $0.01 per share; authorized 450.0 shares; and outstanding 206.1 shares and 201.0 shares, respectively | $**2.1** | $2.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Premium on common stock | &nbsp;&nbsp;&nbsp;&nbsp;Premium on common stock | **1376.3** | 1165.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Retained earnings | &nbsp;&nbsp;&nbsp;&nbsp;Retained earnings | **3601.5** | 3475.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accumulated other comprehensive loss, net of tax | &nbsp;&nbsp;&nbsp;&nbsp;Accumulated other comprehensive loss, net of tax | **(2.6)** | (2.7) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total stockholders' equity | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total stockholders' equity | **4977.3** | 4640.9 |
| LONG-TERM DEBT |  |  |  |
| <u>SERIES</u> | <u>DUE DATE</u> |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;<u>Senior Notes - OGE Energy</u> |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.89% - 5.53% | Term Loan Due May 24, 2027 | **60.0** | 60.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.45% | Senior Notes, Series Due May 15, 2029 | **350.0** | 350.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;<u>Senior Notes - OG&E</u> |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;6.65% | Senior Notes, Series Due July 15, 2027 | **125.0** | 125.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;6.50% | Senior Notes, Series Due April 15, 2028 | **100.0** | 100.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.80% | Senior Notes, Series Due August 15, 2028 | **400.0** | 400.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.30% | Senior Notes, Series Due March 15, 2030 | **300.0** | 300.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.25% | Senior Notes, Series Due April 1, 2030 | **300.0** | 300.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.40% | Senior Notes, Series Due January 15, 2033 | **450.0** | 450.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.75% | Senior Notes, Series Due January 15, 2036 | **110.0** | 110.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;6.45% | Senior Notes, Series Due February 1, 2038 | **200.0** | 200.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.85% | Senior Notes, Series Due June 1, 2040 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.25% | Senior Notes, Series Due May 15, 2041 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.90% | Senior Notes, Series Due May 1, 2043 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.55% | Senior Notes, Series Due March 15, 2044 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.00% | Senior Notes, Series Due December 15, 2044 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.15% | Senior Notes, Series Due April 1, 2047 | **300.0** | 300.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.85% | Senior Notes, Series Due August 15, 2047 | **300.0** | 300.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.60% | Senior Notes, Series Due April 1, 2053 | **700.0** | 700.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.80% | Senior Notes, Series Due April 1, 2055 | **350.0** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.00% | Tinker Debt, Due August 31, 2062 | **11.5** | 11.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;<u>Other Bonds - OG&E</u> |  |  |  |
|  | Muskogee Industrial Authority, January 1, 2025 | **—** | 32.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;1.65% - 4.60% | Muskogee Industrial Authority, June 1, 2027 | **56.0** | 56.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;1.80% - 4.60% | Garfield Industrial Authority, October 1, 2039 | **47.0** | 47.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Unamortized debt expense | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Unamortized debt expense | **(33.4)** | (32.9) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Unamortized discount | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Unamortized discount | **(6.9)** | (5.9) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total long-term debt | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total long-term debt | **5369.2** | 5053.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Less: long-term debt due within one year | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Less: long-term debt due within one year | **—** | 32.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total long-term debt (excluding long-term debt due within one year) | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total long-term debt (excluding long-term debt due within one year) | **5369.2** | 5020.9 |
| Total capitalization (including long-term debt due within one year) | Total capitalization (including long-term debt due within one year) | $**10346.5** | $9694.2 |

---

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

------

**OGE ENERGY CORP.**

**CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY**

---

| | | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|:---|
|  | Common Stock | Common Stock | Treasury Stock | Treasury Stock | Premium on Common | Retained | Accumulated Other Comprehensive (Loss) |  |
| *(In millions)* | Shares | Value | Shares | Value | Stock | Earnings | Income | Total |
| Balance at December 31, 2022 | 200.2 | $2.0 |  | $(0.1) | $1132.5 | $3290.9 | $(11.9) | $4413.4 |
| &nbsp;&nbsp;Net income |  |  |  |  |  | 416.8 |  | 416.8 |
| &nbsp;&nbsp;Other comprehensive income, net of tax |  |  |  |  |  |  | 4.7 | 4.7 |
| &nbsp;&nbsp;Dividends declared on common stock ($1.6646 per share) |  |  |  |  |  | (334.0) |  | (334.0) |
| &nbsp;&nbsp;Stock-based compensation | 0.1 |  |  | 0.1 | 10.6 |  |  | 10.7 |
| Balance at December 31, 2023 | 200.3 | $2.0 |  | $— | $1143.1 | $3373.7 | $(7.2) | $4511.6 |
| &nbsp;&nbsp;Net income |  |  |  |  |  | 441.5 |  | 441.5 |
| &nbsp;&nbsp;Other comprehensive income, net of tax |  |  |  |  |  |  | 4.5 | 4.5 |
| &nbsp;&nbsp;Dividends declared on common stock ($1.6789 per share) |  |  |  |  |  | (339.5) |  | (339.5) |
| &nbsp;&nbsp;Issuance of common stock | 0.5 |  |  |  | 17.1 |  |  | 17.1 |
| &nbsp;&nbsp;Stock-based compensation | 0.2 |  |  |  | 5.7 |  |  | 5.7 |
| Balance at December 31, 2024 | 201.0 | $2.0 |  | $— | $1165.9 | $3475.7 | $(2.7) | $4640.9 |
| &nbsp;&nbsp;Net income | **—** | **—** |  | **—** | **—** | **470.7** | **—** | **470.7** |
| &nbsp;&nbsp;Other comprehensive income, net of tax | **—** | **—** |  | **—** | **—** | **—** | **0.1** | **0.1** |
| &nbsp;&nbsp;Dividends declared on common stock ($1.6925 per share) | **—** | **—** |  | **—** |  | **(344.9)** | **—** | **(344.9)** |
| &nbsp;&nbsp;Issuance of common stock | **4.9** | **0.1** |  | **—** | **203.7** | **—** | **—** | **203.8** |
| &nbsp;&nbsp;Stock-based compensation | **0.2** | **—** |  | **—** | **6.7** | **—** | **—** | **6.7** |
| Balance at December 31, 2025 | **206.1** | $**2.1** |  | $**—** | $**1376.3** | $**3601.5** | $**(2.6)** | $**4977.3** |

---

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

------

**OKLAHOMA GAS AND ELECTRIC COMPANY**

**STATEMENTS OF INCOME AND COMPREHENSIVE INCOME**

---

| | | | |
|:---|:---|:---|:---|
| Year Ended December 31 *(In millions)* | **2025** | 2024 | 2023 |
| OPERATING REVENUES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Revenues from contracts with customers | $**3190.9** | $2916.6 | $2607.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other revenues | **69.2** | 68.7 | 67.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Operating revenues | **3260.1** | 2985.3 | 2674.3 |
| FUEL, PURCHASED POWER AND DIRECT TRANSMISSION EXPENSE | **1259.9** | 1076.4 | 911.7 |
| OPERATING EXPENSES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Other operation and maintenance | **531.0** | 514.1 | 505.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Depreciation and amortization | **559.8** | 539.5 | 506.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Taxes other than income | **109.4** | 109.7 | 99.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Operating expenses | **1200.2** | 1163.3 | 1111.0 |
| OPERATING INCOME | **800.0** | 745.6 | 651.6 |
| OTHER INCOME (EXPENSE) |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Allowance for equity funds used during construction | **26.0** | 25.5 | 19.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other net periodic benefit (expense) income | **(10.3)** | (1.6) | 6.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other income | **17.3** | 12.5 | 23.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other expense | **(2.6)** | (4.5) | (6.3) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net other income | **30.4** | 31.9 | 43.5 |
| INTEREST EXPENSE |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Interest on long-term debt | **237.8** | 212.0 | 200.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Allowance for borrowed funds used during construction | **(15.8)** | (14.6) | (7.1) |
| &nbsp;&nbsp;&nbsp;&nbsp;Interest on short-term debt and other interest charges | **3.5** | 17.0 | 6.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other comprehensive income, net of tax | **—** |  |  |
| COMPREHENSIVE INCOME | $**499.8** | $469.9 | $426.4 |

---

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

------

**OKLAHOMA GAS AND ELECTRIC COMPANY**

**STATEMENTS OF CASH FLOWS**

---

| | | | |
|:---|:---|:---|:---|
| Year Ended December 31 (*In millions*) | **2025** | 2024 | 2023 |
| CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Net income | $**499.8** | $469.9 | $426.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Adjustments to reconcile net income to net cash provided from operating activities: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Depreciation and amortization | **559.8** | 539.5 | 506.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Deferred income taxes and other tax credits, net | **61.7** | 16.8 | 15.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Allowance for equity funds used during construction | **(26.0)** | (25.5) | (19.4) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Stock-based compensation expense | **14.0** | 11.7 | 3.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Regulatory assets | **(66.9)** | (52.4) | (92.1) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Regulatory liabilities | **0.5** | (2.8) | (12.2) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other assets | **(37.9)** | (9.8) | 4.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other liabilities | **36.8** | 28.0 | 0.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Change in certain current assets and liabilities: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Accounts receivable and accrued unbilled revenues, net | **(108.7)** | (33.2) | 42.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Fuel, materials and supplies inventories | **81.9** | 25.7 | (122.8) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Fuel recoveries | **130.5** | (123.9) | 535.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other current assets | **11.7** | (36.5) | 51.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Accounts payable | **66.4** | (0.3) | (131.1) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Income taxes payable - parent | **(47.6)** | 23.8 | 9.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other current liabilities | **15.2** | 30.8 | 34.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net cash provided from operating activities | **1191.2** | 861.8 | 1251.5 |
| CASH FLOWS FROM INVESTING ACTIVITIES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Capital expenditures (less allowance for equity funds used during construction) | **(1054.4)** | (1090.9) | (1178.2) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Cost of removal | **(70.3)** | (67.5) | (91.0) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net cash used in investing activities | **(1124.7)** | (1158.4) | (1269.2) |
| CASH FLOWS FROM FINANCING ACTIVITIES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Proceeds from long-term debt | **344.4** | 350.5 | 788.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Payment of long-term debt | **(32.6)** | (0.1) | (500.1) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Changes in advances with parent | **(148.3)** | (53.8) | 229.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Capital contribution from OGE Energy | **150.0** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Dividends paid on common stock | **(380.0)** |  | (500.0) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net cash (used in) provided from financing activities | **(66.5)** | 296.6 | 17.9 |
| NET CHANGE IN CASH AND CASH EQUIVALENTS | **—** |  | 0.2 |
| CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR | **0.2** | 0.2 |  |
| CASH AND CASH EQUIVALENTS AT END OF YEAR | $**0.2** | $0.2 | $0.2 |
| SUPPLEMENTAL CASH FLOW INFORMATION |  |  |  |
| Cash paid during the period for: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Interest (net of interest capitalized of $15.8, $14.6 and $7.1, respectively) | $**216.9** | $206.3 | $180.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Federal income taxes (net of income tax refunds) | $**90.7** | $51.9 | $43.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;State income taxes (net of income tax refunds) | $**1.2** | $0.1 | $0.7 |
| NON-CASH INVESTING AND FINANCING ACTIVITIES |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Power plant long-term service agreement | $**3.4** | $6.4 | $0.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Tinker Air Force Base distribution assets purchase | $**—** | $2.6 | $— |

---

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

------

**OKLAHOMA GAS AND ELECTRIC COMPANY**

**BALANCE SHEETS**

---

| | | |
|:---|:---|:---|
| December 31 (*In millions*) | **2025** | 2024 |
| **ASSETS** |  |  |
| CURRENT ASSETS |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Cash and cash equivalents | $**0.2** | $0.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accounts receivable, less reserve of $4.1 and $2.0, respectively | **347.2** | 240.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued unbilled revenues | **76.2** | 74.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Advances to parent | **78.3** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Fuel inventories | **112.0** | 148.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Materials and supplies, at average cost | **212.7** | 229.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Fuel clause under recoveries | **—** | 112.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **71.5** | 83.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total current assets | **898.1** | 888.5 |
| OTHER PROPERTY AND INVESTMENTS | **4.1** | 4.5 |
| PROPERTY, PLANT AND EQUIPMENT |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;In service | **17196.9** | 16248.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Construction work in progress | **744.9** | 814.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total property, plant and equipment | **17941.8** | 17062.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Less: accumulated depreciation | **5217.5** | 4982.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Net property, plant and equipment | **12724.3** | 12080.5 |
| DEFERRED CHARGES AND OTHER ASSETS |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Regulatory assets | **557.2** | 568.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **93.8** | 39.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total deferred charges and other assets | **651.0** | 607.8 |
| TOTAL ASSETS | $**14277.5** | $13581.3 |

---

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

------

**OKLAHOMA GAS AND ELECTRIC COMPANY**

**BALANCE SHEETS (Continued)**

---

| | | |
|:---|:---|:---|
| December 31 (*In millions*) | **2025** | 2024 |
| **LIABILITIES AND STOCKHOLDER'S EQUITY** |  |  |
| CURRENT LIABILITIES |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Accounts payable | $**348.7** | $272.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;Advances from parent | **—** | 247.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Customer deposits | **127.2** | 111.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued taxes | **52.3** | 51.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued interest | **66.4** | 61.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued compensation | **54.3** | 53.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Long-term debt due within one year | **—** | 32.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Fuel clause over recoveries | **27.1** | 9.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **33.5** | 41.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total current liabilities | **709.5** | 880.2 |
| LONG-TERM DEBT | **4961.7** | 4614.3 |
| DEFERRED CREDITS AND OTHER LIABILITIES |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued benefit obligations | **93.2** | 102.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;Deferred income taxes | **1531.3** | 1410.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Deferred investment tax credits | **9.8** | 10.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Regulatory liabilities | **957.1** | 1016.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **274.7** | 220.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total deferred credits and other liabilities | **2866.1** | 2760.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total liabilities | **8537.3** | 8254.9 |
| COMMITMENTS AND CONTINGENCIES (NOTE 13) |  |  |
| STOCKHOLDER'S EQUITY |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Common stockholder's equity | **1753.5** | 1589.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Retained earnings | **3986.7** | 3736.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total stockholder's equity | **5740.2** | 5326.4 |
| TOTAL LIABILITIES AND STOCKHOLDER'S EQUITY | $**14277.5** | $13581.3 |

---

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

------

**OKLAHOMA GAS AND ELECTRIC COMPANY**

**STATEMENTS OF CAPITALIZATION**

---

| | | | |
|:---|:---|:---|:---|
| December 31 *(In millions except per share data)* | December 31 *(In millions except per share data)* | **2025** | 2024 |
| STOCKHOLDER'S EQUITY | STOCKHOLDER'S EQUITY |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Common stock, par value $2.50 per share; authorized 100.0 shares; and outstanding 40.4 shares and 40.4 shares, respectively | &nbsp;&nbsp;&nbsp;&nbsp;Common stock, par value $2.50 per share; authorized 100.0 shares; and outstanding 40.4 shares and 40.4 shares, respectively | $**100.9** | $100.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Premium on common stock | &nbsp;&nbsp;&nbsp;&nbsp;Premium on common stock | **1652.6** | 1488.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Retained earnings | &nbsp;&nbsp;&nbsp;&nbsp;Retained earnings | **3986.7** | 3736.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total stockholder's equity | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total stockholder's equity | **5740.2** | 5326.4 |
| LONG-TERM DEBT |  |  |  |
| <u>SERIES</u> | <u>DUE DATE</u> |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;<u>Senior Notes</u> |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;6.65% | Senior Notes, Series Due July 15, 2027 | **125.0** | 125.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;6.50% | Senior Notes, Series Due April 15, 2028 | **100.0** | 100.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.80% | Senior Notes, Series Due August 15, 2028 | **400.0** | 400.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.30% | Senior Notes, Series Due March 15, 2030 | **300.0** | 300.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.25% | Senior Notes, Series Due April 1, 2030 | **300.0** | 300.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.40% | Senior Notes, Series Due January 15, 2033 | **450.0** | 450.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.75% | Senior Notes, Series Due January 15, 2036 | **110.0** | 110.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;6.45% | Senior Notes, Series Due February 1, 2038 | **200.0** | 200.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.85% | Senior Notes, Series Due June 1, 2040 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.25% | Senior Notes, Series Due May 15, 2041 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.90% | Senior Notes, Series Due May 1, 2043 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.55% | Senior Notes, Series Due March 15, 2044 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.00% | Senior Notes, Series Due December 15, 2044 | **250.0** | 250.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.15% | Senior Notes, Series Due April 1, 2047 | **300.0** | 300.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3.85% | Senior Notes, Series Due August 15, 2047 | **300.0** | 300.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.60% | Senior Notes, Series Due April 1, 2053 | **700.0** | 700.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;5.80% | Senior Notes, Series Due April 1, 2055 | **350.0** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;4.00% | Tinker Debt, Due August 31, 2062 | **11.5** | 11.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;<u>Other Bonds</u> |  |  |  |
|  | Muskogee Industrial Authority, January 1, 2025 | **—** | 32.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;1.65% - 4.60% | Muskogee Industrial Authority, June 1, 2027 | **56.0** | 56.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;1.80% - 4.60% | Garfield Industrial Authority, October 1, 2039 | **47.0** | 47.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;Unamortized debt expense |  | **(31.2)** | (29.9) |
| &nbsp;&nbsp;&nbsp;&nbsp;Unamortized discount |  | **(6.6)** | (5.5) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total long-term debt |  | **4961.7** | 4646.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Less: long-term debt due within one year | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Less: long-term debt due within one year | **—** | 32.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total long-term debt (excluding long-term debt due within one year) | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total long-term debt (excluding long-term debt due within one year) | **4961.7** | 4614.3 |
| Total capitalization (including long-term debt due within one year) | Total capitalization (including long-term debt due within one year) | $**10701.9** | $9973.1 |

---

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

------

**OKLAHOMA GAS AND ELECTRIC COMPANY**

**STATEMENTS OF CHANGES IN STOCKHOLDER'S EQUITY**

---

| | | | | | |
|:---|:---|:---|:---|:---|:---|
|  | Common Stock | Common Stock |  |  |  |
| *(In millions)* | Shares Outstanding | Value | Premium on Common Stock | Retained Earnings | Total |
| Balance at December 31, 2022 | 40.4 | $100.9 | $1473.7 | $3470.6 | $5045.2 |
| &nbsp;&nbsp;Net income |  |  |  | 426.4 | 426.4 |
| &nbsp;&nbsp;Dividends declared on common stock |  |  |  | (500.0) | (500.0) |
| &nbsp;&nbsp;Stock-based compensation |  |  | 3.1 |  | 3.1 |
| Balance at December 31, 2023 | 40.4 | $100.9 | $1476.8 | $3397.0 | $4974.7 |
| &nbsp;&nbsp;Net income |  |  |  | 469.9 | 469.9 |
| &nbsp;&nbsp;Dividends declared on common stock |  |  |  | (130.0) | (130.0) |
| &nbsp;&nbsp;Stock-based compensation |  |  | 11.8 |  | 11.8 |
| Balance at December 31, 2024 | 40.4 | $100.9 | $1488.6 | $3736.9 | $5326.4 |
| &nbsp;&nbsp;Net income | **—** | **—** | **—** | **499.8** | **499.8** |
| &nbsp;&nbsp;Capital contribution from OGE Energy | **—** | **—** | **150.0** | **—** | **150.0** |
| &nbsp;&nbsp;Dividends declared on common stock | **—** | **—** | **—** | **(250.0)** | **(250.0)** |
| &nbsp;&nbsp;Stock-based compensation | **—** | **—** | **14.0** | **—** | **14.0** |
| Balance at December 31, 2025 | **40.4** | $**100.9** | $**1652.6** | $**3986.7** | $**5740.2** |

---

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

------

**COMBINED NOTES TO FINANCIAL STATEMENTS**

**Index of Combined Notes to Financial Statements**

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

---

| | | |
|:---|:---|:---|
|  | **OGE Energy** | **OG&E** |
| [<u>Note 1. Summary of Significant Accounting Policies</u>](#section122) | X | X |
| [<u>Note 2. Accounting Pronouncements</u>](#section145) | X | X |
| [<u>Note 3. Revenue Recognition</u>](#revenue) | X | X |
| [<u>Note 4. Leases</u>](#section147) | X | X |
| [<u>Note 5. Fair Value Measurements</u>](#section150) | X | X |
| [<u>Note 6. Stock-Based Compensation</u>](#section152) | X | X |
| [<u>Note 7. Income Taxes</u>](#section153) | X | X |
| [<u>Note 8. Common Equity</u>](#section154) | X | X |
| [<u>Note 9. Long-Term Debt</u>](#section155) | X | X |
| [<u>Note 10. Credit Facilities and Short-Term Debt</u>](#section156) | X | X |
| [<u>Note 11. Retirement Plans and Postretirement Benefit Plans</u>](#section157) | X | X |
| [<u>Note 12. Report of Business Segments</u>](#section158) | X |  |
| [<u>Note 13. Commitments and Contingencies</u>](#section159) | X | X |
| [<u>Note 14. Rate Matters and Regulation</u>](#section160) | X | X |

---

**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 |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Current: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;SPP cost tracker under recoveries (A) | $**7.1** | $— |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma fuel clause under recoveries | **—** | 112.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma Energy Efficiency Rider under recoveries (A) | **—** | 7.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other (A) | **4.3** | 3.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total current regulatory assets | $**11.4** | $123.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Non-current: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma deferred storm expenses | $**224.7** | $244.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Pension tracker | **88.7** | 94.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Benefit obligations regulatory asset | **85.6** | 90.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Arkansas Winter Storm Uri costs | **54.2** | 63.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma SB 998 deferred costs, net | **22.9** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma SAP S/4 HANA deferred expenses | **16.5** | 14.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Sooner Dry Scrubbers | **15.5** | 16.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma vegetation management program deferred costs | **13.9** | 6.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Arkansas deferred pension expenses | **9.3** | 11.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Arkansas capacity power purchase agreements | **6.7** | 3.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Unamortized loss on reacquired debt | **5.5** | 6.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;COVID-19 impacts | **4.1** | 5.4 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other | **9.6** | 12.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total non-current regulatory assets | $**557.2** | $568.1 |
| REGULATORY LIABILITIES |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Current: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma fuel clause over recoveries | $**15.7** | $— |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Arkansas fuel clause over recoveries | **11.4** | 9.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma Energy Efficiency Rider over recoveries (B) | **5.8** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Oklahoma Investment Tax Credit over recoveries (B) | **2.0** | 6.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other (B) | **—** | 4.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total current regulatory liabilities | $**34.9** | $20.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Non-current: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Income taxes refundable to customers, net | $**718.9** | $780.8 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Accrued removal obligations, net | **234.7** | 231.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other | **3.5** | 3.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total non-current regulatory liabilities | $**957.1** | $1016.4 |

---

(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: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Net loss | $**74.0** | $76.5 |
| Postretirement Benefit Plans: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Net loss | **11.6** | 14.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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.

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| | | | | |
|:---|:---|:---|:---|:---|
| **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** |

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(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.

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| | | | | |
|:---|:---|:---|:---|:---|
| 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 |

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(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.

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

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| | | | |
|:---|:---|:---|:---|
| **December 31, 2025** *(In millions)* | **Total Property, Plant and Equipment** | **Accumulated Depreciation** | **Net Property, Plant and Equipment** |
| OG&E: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Distribution assets | $**7075.1** | $**1744.3** | $**5330.8** |
| &nbsp;&nbsp;&nbsp;&nbsp;Electric generation assets (A) | **5873.5** | **2285.0** | **3588.5** |
| &nbsp;&nbsp;&nbsp;&nbsp;Transmission assets (B) | **3524.8** | **781.1** | **2743.7** |
| &nbsp;&nbsp;&nbsp;&nbsp;Intangible plant | **2.5** | **0.7** | **1.8** |
| &nbsp;&nbsp;&nbsp;&nbsp;Other property and equipment | **1465.9** | **406.4** | **1059.5** |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&E property, plant and equipment | **17941.8** | **5217.5** | **12724.3** |
| Non-OG&E property, plant and equipment | **6.1** | **—** | **6.1** |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total OGE Energy property, plant and equipment | $**17947.9** | $**5217.5** | $**12730.4** |

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(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.

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| | | | |
|:---|:---|:---|:---|
| December 31, 2024 *(In millions)* | Total Property, Plant and Equipment | Accumulated Depreciation | Net Property, Plant and Equipment |
| OG&E: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Distribution assets | $6654.5 | $1639.8 | $5014.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Electric generation assets (A) | 5518.5 | 2145.9 | 3372.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Transmission assets (B) | 3432.1 | 748.5 | 2683.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Intangible plant | 752.3 | 203.7 | 548.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other property and equipment | 705.3 | 244.3 | 461.0 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&E property, plant and equipment | 17062.7 | 4982.2 | 12080.5 |
| Non-OG&E property, plant and equipment | 6.1 |  | 6.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total OGE Energy property, plant and equipment | $17068.8 | $4982.2 | $12086.6 |

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(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.

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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.

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

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(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

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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

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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.

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**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.

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| | | | | |
|:---|:---|:---|:---|:---|
|  | **Pension Plan and Restoration of Retirement Income Plan** | **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) |
| &nbsp;&nbsp;&nbsp;&nbsp;Other comprehensive income (loss) before reclassifications | (0.2) |  | 0.5 | 0.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Amounts reclassified from accumulated other comprehensive income (loss) | 0.2 | 0.2 | (0.1) | 0.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Regulatory classification of certain pension costs | 3.9 |  |  | 3.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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) |
| &nbsp;&nbsp;&nbsp;&nbsp;Other comprehensive income (loss) before reclassifications | **(1.7)** | **—** | **1.4** | **(0.3)** |
| &nbsp;&nbsp;&nbsp;&nbsp;Amounts reclassified from accumulated other comprehensive income (loss) | **0.3** | **0.2** | **(0.1)** | **0.4** |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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)** |

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

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| | | | |
|:---|:---|:---|:---|
| **Details about Accumulated Other Comprehensive Income (Loss) Components** | **Amount Reclassified from Accumulated Other Comprehensive Income (Loss)** | **Amount Reclassified from Accumulated Other Comprehensive Income (Loss)** | **Affected Line Item in <br>OGE Energy's Statements of Income** |
|  | **Year Ended December 31,** | **Year Ended December 31,** |  |
| *(In millions)* | **2025** | 2024 |  |
| Amortization of Pension Plan and Restoration of Retirement Income Plan items: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Actuarial losses | $**(0.4)** | $(0.3) | (A) |
| &nbsp;&nbsp;&nbsp;&nbsp;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: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;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 |

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

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**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.

**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.

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**3. Revenue Recognition** 

The following table presents OG&E's revenues from contracts with customers disaggregated by customer classification. OG&E's operating revenues disaggregated by customer classification can be found in "OG&E (Electric Company) Results of Operations" within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations."

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| | | | |
|:---|:---|:---|:---|
|  | **Year Ended December 31,** | **Year Ended December 31,** | **Year Ended December 31,** |
| *(In millions)* | **2025** | 2024 | 2023 |
| Residential | $**1172.1** | $1116.4 | $1008.6 |
| 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 |
| &nbsp;&nbsp;&nbsp;&nbsp;System sales revenues | **2899.0** | 2662.7 | 2349.1 |
| 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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Revenues from contracts with customers | $**3190.9** | $2916.6 | $2607.3 |

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**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.

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| | | | |
|:---|:---|:---|:---|
| **OGE Energy and OG&E** | **Year Ended December 31,** | **Year Ended December 31,** | **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: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;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 | $— |

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| | | |
|:---|:---|:---|
| **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% |

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(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.

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| | |
|:---|:---|
| **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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total future minimum lease payments | 35.7 |
| Less: Imputed interest | 6.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Present value of net minimum lease payments | $29.2 |

---

**5. Fair Value Measurements** 

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

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

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

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

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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.

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| | | | | | |
|:---|:---|:---|:---|:---|:---|
|  | **2025** | **2025** | 2024 | 2024 |  |
| December 31 *(In millions)* | **Carrying<br>Amount** | **Fair <br>Value** | Carrying<br>Amount | Fair <br>Value | **Classification** |
| &nbsp;&nbsp;&nbsp;&nbsp;Long-term Debt (including Long-term Debt due within one year): |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OGE Energy Senior Notes | $**347.6** | $**362.5** | $346.9 | $355.7 | Level 2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OGE Energy Term Loan | $**59.9** | $**60.0** | $59.7 | $60.0 | Level 2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&E Senior Notes | $**4847.2** | $**4644.7** | $4499.6 | $4174.9 | Level 2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&E Industrial Authority Bonds | $**103.0** | $**103.0** | $135.4 | $135.4 | Level 2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;OG&E Tinker Debt | $**11.5** | $**9.1** | $11.7 | $9.0 | Level 3 |

---

**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.

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.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** | **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 |
| &nbsp;&nbsp;&nbsp;&nbsp;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 |

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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.

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**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.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** | **OG&E** |
|  | **2025** | 2024 | 2023 | **2025** | 2024 | 2023 |
| Number of units granted | **216426** | 275499 | 213442 | **216426** | 275499 | 65069 |
| 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 |

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**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.

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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.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** | **OG&E** |
|  | **2025** | 2024 | 2023 | **2025** | 2024 | 2023 |
| Restricted stock units granted | **121056** | 148345 | 114926 | **121056** | 148345 | 35034 |
| Fair value of restricted stock units granted | $**43.69** | $32.74 | $37.52 | $**43.69** | $32.74 | $37.52 |

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**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.

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| | | | | |
|:---|:---|:---|:---|:---|
| **OGE Energy and OG&E** | **Performance Units** | **Performance Units** | **Restricted Stock Units** | **Restricted Stock Units** |
| *(Dollars in millions)* | **Number<br>of Units** | **Aggregate Intrinsic Value** | **Number<br>of Shares** | **Aggregate Intrinsic Value** |
| Units/shares outstanding at 12/31/24 | 646192 |  | 244054 |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Granted | **216426**<br> **(A)** |  | **121056** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Converted | **(191918)**<br> **(B)** | $**12.5** | **N/A** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Vested | **N/A** |  | **(100933)** | $**4.3** |
| &nbsp;&nbsp;&nbsp;&nbsp;Forfeited | **(12756)** |  | **(9924)** |  |
| Units/shares outstanding at 12/31/25 | **657944** | $**19.7** | **254253** | $**10.9** |
| Units/shares fully vested at 12/31/25 | **191740**<br> **(C)** | $**8.2** | **N/A** | **N/A** |

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(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.

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.

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| | | | | |
|:---|:---|:---|:---|:---|
| **OGE Energy and OG&E** | **Performance Units** | **Performance Units** | **Restricted Stock Units** | **Restricted Stock Units** |
|  | **Number<br>of Units** | **Weighted-Average<br>Grant Date<br>Fair Value** | **Number<br>of Shares** | **Weighted-Average<br>Grant Date<br>Fair Value** |
| Units/shares non-vested at 12/31/24 | 454274 | $39.28 | 244054 | $34.81 |
| &nbsp;&nbsp;&nbsp;&nbsp;Granted | **216426**<br> **(A)** | $**55.43** | **121056** | $**43.69** |
| &nbsp;&nbsp;&nbsp;&nbsp;Vested | **(191740)** | $**43.74** | **(100933)** | $**42.79** |
| &nbsp;&nbsp;&nbsp;&nbsp;Forfeited | **(12756)** | $**42.49** | **(9924)** | $**36.73** |
| Units/shares non-vested at 12/31/25 | **466204** | $**44.86** | **254253** | $**37.88** |

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(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.

**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.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** | **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 |

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**Unrecognized Compensation Cost**

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.

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

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**7. Income Taxes** 

**Income Tax Expense** 

The following table presents the components of income tax expense.

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

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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.

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

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| **OGE Energy** |  |  |  |  |  |  |
| Year Ended December 31 *(Dollars in millions)* | **2025** | **2025** | 2024 | 2024 | 2023 | 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<br>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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Effective income tax rate | $**89.8** | **16.0%** | $79.1 | 15.2% | $56.2 | 11.9% |

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| **OG&E** |  |  |  |  |  |  |
| Year Ended December 31 *(Dollars in millions)* | **2025** | **2025** | 2024 | 2024 | 2023 | 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<br>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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Effective income tax rate | $**105.1** | **17.4%** | $93.2 | 16.6% | $68.8 | 13.9% |

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(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.

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| | | | | |
|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** |
| December 31 *(In millions)* | **2025** | 2024 | **2025** | 2024 |
| Deferred income tax liabilities, net: |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Accelerated depreciation and other property related differences | $**1907.6** | $1809.5 | $**1907.6** | $1809.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Regulatory assets | **66.6** | 65.6 | **66.6** | 65.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Pension Plan | **21.5** | 22.0 | **38.5** | 38.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;Corporate owned life insurance | **3.1** | 2.8 | **—** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Bond redemption-unamortized costs | **1.0** | 1.2 | **1.0** | 1.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;State tax credits | **(223.6)** | (223.8) | **(208.6)** | (208.5) |
| &nbsp;&nbsp;&nbsp;&nbsp;Income taxes recoverable from customers, net | **(173.6)** | (188.6) | **(173.6)** | (188.6) |
| &nbsp;&nbsp;&nbsp;&nbsp;Regulatory liabilities | **(59.8)** | (57.3) | **(59.8)** | (57.3) |
| &nbsp;&nbsp;&nbsp;&nbsp;Asset retirement obligations | **(18.8)** | (20.9) | **(18.8)** | (20.9) |
| &nbsp;&nbsp;&nbsp;&nbsp;Postretirement medical and life insurance benefits | **(21.5)** | (19.1) | **(15.1)** | (12.6) |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued liabilities | **(9.0)** | (15.7) | **(2.7)** | (9.8) |
| &nbsp;&nbsp;&nbsp;&nbsp;Deferred federal investment tax credits | **(2.4)** | (2.5) | **(2.4)** | (2.5) |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued vacation | **(1.7)** | (1.9) | **(1.7)** | (1.9) |
| &nbsp;&nbsp;&nbsp;&nbsp;Uncollectible accounts | **(1.0)** | (0.5) | **(1.0)** | (0.5) |
| &nbsp;&nbsp;&nbsp;&nbsp;Other | **0.9** | 0.3 | **1.3** | (1.6) |
| Total deferred income tax liabilities, net | $**1489.3** | $1371.1 | $**1531.3** | $1410.7 |

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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.

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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.

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

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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.

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

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N/A - not applicable

**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

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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.

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| | | | |
|:---|:---|:---|:---|
| *(In millions except per share data)* | **2025** | 2024 | 2023 |
| Net income | $**470.7** | $441.5 | $416.8 |
| Average common shares outstanding: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Basic average common shares outstanding | **201.9** | 200.8 | 200.3 |
| &nbsp;&nbsp;&nbsp;&nbsp;Effect of dilutive securities: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Contingently issuable shares (performance and restricted stock units) | **0.6** | 0.5 | 0.6 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Forward equity sale agreements | **—** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;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 | **—** | **—** | **—** |

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***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.

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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.

**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.

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| | | | |
|:---|:---|:---|:---|
| **Series** | **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) | Total (redeemable during next 12 months) | Total (redeemable during next 12 months) | $103.0 |

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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

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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.

**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.

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| | | | | |
|:---|:---|:---|:---|:---|
| **Entity** | **Aggregate Commitment** | **Amount Outstanding (A)** | **Weighted-Average Interest Rate** | **Expiration** |
|  | *(In millions)* | *(In millions)* |  |  |
| OGE Energy (B) | $550.0 | $292.0 | 4.12% (F) | December 18, 2029 |
| OGE Energy (C) | 60.0 |  | —<br> (F) | May 24, 2027 |
| OG&E (D)(E) | 550.0 | 0.4 | 1.20% (F) | December 18, 2029 |
| Total | $1160.0 | $292.4 | 4.12% |  |

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(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.

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

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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.

**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** 

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.

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| | | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** | **OG&E** | **OG&E** |
|  | **Pension Plan** | **Pension Plan** | **Restoration of Retirement<br>Income Plan** | **Restoration of Retirement<br>Income Plan** | **Pension Plan** | **Pension Plan** | **Restoration of Retirement<br>Income Plan** | **Restoration of Retirement<br>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) | **—** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;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) | **—** |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Ending fair value | $**262.2** | $246.9 | $**—** | $— | $**226.2** | $211.6 | $**—** | $— |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;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 |

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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.

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| | | | | |
|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** |
|  | **Postretirement Benefit Plans** | **Postretirement Benefit Plans** | **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) |
| &nbsp;&nbsp;&nbsp;&nbsp;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) |
| &nbsp;&nbsp;&nbsp;&nbsp;Ending fair value | $**28.4** | $30.0 | $**26.2** | $27.2 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Funded status at end of year | $**(62.0)** | $(68.1) | $**(43.5)** | $(47.5) |

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**Net Periodic Benefit Cost** 

The following tables present the net periodic benefit cost components, before consideration of capitalized amounts, of OGE Energy's Pension Plan, Restoration of Retirement Income Plan and postretirement benefit plans that are included in the 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.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| **OGE Energy** | **Pension Plan** | **Pension Plan** | **Pension Plan** | **Restoration of Retirement<br>Income Plan** | **Restoration of Retirement<br>Income Plan** | **Restoration of Retirement<br>Income Plan** |
| Year Ended December 31 <br>*(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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Net periodic benefit cost | $**11.8** | $10.9 | $34.9 | $**1.8** | $1.6 | $2.1 |

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(A)Unamortized prior service cost is amortized on a straight-line basis over the average remaining service period to the first eligibility age of participants who are expected to receive a benefit and are active at the date of the plan amendment.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| **OG&E** | **Pension Plan** | **Pension Plan** | **Pension Plan** | **Restoration of Retirement<br>Income Plan** | **Restoration of Retirement<br>Income Plan** | **Restoration of Retirement<br>Income Plan** |
| Year Ended December 31 <br>*(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 |
| &nbsp;&nbsp;&nbsp;&nbsp;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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Net periodic benefit cost | $**11.7** | $10.9 | $34.4 | $**1.8** | $1.6 | $2.1 |

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

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| | | | |
|:---|:---|:---|:---|
| 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: |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Oklahoma jurisdiction (A) | $**0.5** | $— | $20.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Arkansas jurisdiction (A) | $**—** | $— | $1.9 |

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

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** | **OG&E** |
|  | **Postretirement Benefit Plans** | **Postretirement Benefit Plans** | **Postretirement Benefit Plans** | **Postretirement Benefit Plans** | **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** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Net periodic benefit cost | $**4.2** | $3.5 | $3.4 | $**3.7** | $3.1 | $2.9 |

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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:

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| | | | |
|:---|:---|:---|:---|
| 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 |

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

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.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
|  | **OGE Energy** | **OGE Energy** | **OGE Energy** | **OG&E** | **OG&E** | **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 |

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**Rate Assumptions**

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

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.

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| | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|
| **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% |

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

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| | | | |
|:---|:---|:---|:---|
| **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% |

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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.

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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.

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

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(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).

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*Pension Plan Investments*

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.

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| | | | | |
|:---|:---|:---|:---|:---|
| *(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: |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Cash collateral | **0.9** | **0.9** | **—** | **—** |
| Forward contracts: |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Receivable (foreign currency) | **0.1** | **—** | **0.1** | **—** |
| &nbsp;&nbsp;&nbsp;&nbsp;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)** |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Total OGE Energy Pension Plan assets | $**262.2** |  |  |  |
| Pension Plan investments attributable to affiliates | **(36.0)** |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Total OG&E Pension Plan assets | $**226.2** |  |  |  |

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| | | | | |
|:---|:---|:---|:---|:---|
| *(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: |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Cash collateral | 0.1 | 0.1 |  |  |
| Forward contracts: |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Receivable (foreign currency) | 0.1 |  | 0.1 |  |
| &nbsp;&nbsp;&nbsp;&nbsp;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) |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Total OGE Energy Pension Plan assets | $246.9 |  |  |  |
| Pension Plan investments attributable to affiliates | (35.3) |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Total OG&E Pension Plan assets | $211.6 |  |  |  |

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(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.

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(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***

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.

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| | | |
|:---|:---|:---|
| *(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 |

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**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.

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***Postretirement Plans Investments***

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.

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

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

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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).

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

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**Medicare Prescription Drug, Improvement and Modernization Act of 2003** 

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.

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| | | |
|:---|:---|:---|
| *(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 |

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**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.

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**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.

**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.

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| | | | | |
|:---|:---|:---|:---|:---|
| **2025** | **Electric Company** | **Other<br>Operations** | **Eliminations** | **Total** |
| *(In millions)* |  |  |  |  |
| Operating revenues | $**3260.1** | $**—** | $**—** | $**3260.1** |
| Fuel, purchased power and direct transmission expense | **1259.9** | **—** | **—** | **1259.9** |
| 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** |
| &nbsp;&nbsp;&nbsp;&nbsp;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** |
| &nbsp;&nbsp;&nbsp;&nbsp;Net income (loss) | $**499.8** | $**(29.1)** | $**—** | $**470.7** |
| Total assets | $**14277.5** | $**134.1** | $**(41.1)** | $**14370.5** |
| Capital expenditures | $**1054.4** | $**—** | $**—** | $**1054.4** |

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| | | | | |
|:---|:---|:---|:---|:---|
| 2024 | Electric Company | Other<br>Operations | Eliminations | Total |
| *(In millions)* |  |  |  |  |
| Operating revenues | $2985.3 | $— | $— | $2985.3 |
| Fuel, purchased power and direct transmission expense | 1076.4 |  |  | 1076.4 |
| 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 |
| &nbsp;&nbsp;&nbsp;&nbsp;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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Net income (loss) | $469.9 | $(28.4) | $— | $441.5 |
| Total assets | $13581.3 | $402.9 | $(268.2) | $13716.0 |
| Capital expenditures | $1090.9 | $— | $— | $1090.9 |

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| | | | | |
|:---|:---|:---|:---|:---|
| 2023 | Electric Company | Other<br>Operations | Eliminations | Total |
| *(In millions)* |  |  |  |  |
| Operating revenues | $2674.3 | $— | $— | $2674.3 |
| 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 |
| &nbsp;&nbsp;&nbsp;&nbsp;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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Net income (loss) | $426.4 | $(9.6) | $— | $416.8 |
| Total assets | $12642.6 | $301.1 | $(153.0) | $12790.7 |
| Capital expenditures | $1178.2 | $— | $— | $1178.2 |

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**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.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| *(In millions)* | **2026** | **2027** | **2028** | **2029** | **2030** | **Total** |
| Purchase obligations and commitments: |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Minimum purchase commitments | $110.4 | $72.5 | $67.1 | $63.8 | $63.9 | $377.7 |
| &nbsp;&nbsp;&nbsp;&nbsp;Wind purchase commitments | 57.3 | 57.8 | 58.4 | 58.6 | 57.8 | 289.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;Capacity commitments | 105.0 | 41.5 | 31.3 | 26.9 | 27.8 | 232.5 |
| &nbsp;&nbsp;&nbsp;&nbsp;Long-term service agreement commitments | 50.1 | 19.0 | 8.9 | 4.5 | 5.6 | 88.1 |
| &nbsp;&nbsp;&nbsp;&nbsp;Generation capacity construction commitments | 98.3 | 481.5 | 98.0 | 17.1 |  | 694.9 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total purchase obligations and commitments | $421.1 | $672.3 | $263.7 | $170.9 | $155.1 | $1683.1 |

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***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.

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| | | | | | |
|:---|:---|:---|:---|:---|:---|
| **Company** | **Location** | **Original Term of<br>Contract** | **Expiration of<br>Contract** | **MWs** | **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 |

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

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| | | | |
|:---|:---|:---|:---|
| 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 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total wind power purchased | $**54.8** | $54.3 | $48.8 |

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***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.

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**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.

**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.

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***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 [<u>2024 Form 10-K</u>](https://www.sec.gov/ix?doc=/Archives/edgar/data/0001021635/000095017025022560/oge-20241231.htm). 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.

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*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.

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**Pending Regulatory Matters** 

Various proceedings pending before state or federal regulatory agencies are described below. Unless stated otherwise, the Registrants cannot predict when the regulatory agency will act or what action the regulatory agency will take. The Registrants' financial results are dependent in part on timely and 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

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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

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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.

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**REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM**

To the Stockholders and the Board of Directors of OGE Energy Corp.

**Opinion on the Financial Statements**

We have audited the accompanying consolidated balance sheets and consolidated statements of capitalization of OGE Energy Corp. (the Company) as of December 31, 2025 and 2024, the related consolidated statements of income, comprehensive income, changes in stockholders' 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 "consolidated financial statements"). In our opinion, the consolidated 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.

**Basis for Opinion**

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

**Critical Audit Matter**

The critical audit matter communicated below is a matter arising from the current period audit of the financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of the critical audit matter does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

------

**Regulatory Assets and Liabilities**

---

| | |
|:---|:---|
| &nbsp;&nbsp;*Description of the Matter* | &nbsp;&nbsp;As discussed in Note 1 to the consolidated financial statements, the Company conducts its electric utility operations through Oklahoma Gas & Electric Company (OG&E). OG&E is a regulated utility subject to accounting principles for rate-regulated activities. As such, certain incurred costs that would otherwise be charged to expense are 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 are deferred as regulatory liabilities, based on the expected refund to customers in future rates. OG&E records items 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. |
|  | &nbsp;&nbsp;Auditing regulatory assets and liabilities is complex as it requires specialized knowledge of rate-regulated activities as to matters that could affect the recording or updating of regulatory assets and regulatory liabilities. |
| &nbsp;&nbsp;*How We Addressed the Matter in Our Audit* | &nbsp;&nbsp;We obtained an understanding, evaluated the design, and tested the operating effectiveness of internal controls over the Company's accounting for regulatory assets and liabilities, including, among others, controls over management's evaluation of regulatory orders for any new matters and controls over the evaluation of filings with regulatory bodies on existing regulatory assets and liabilities, including factors that may affect the timing or nature of recoverability of regulatory assets and sufficiency of regulatory liabilities.  |
|  | &nbsp;&nbsp;We performed audit procedures that included, among others, reviewing evidence of correspondence with regulatory bodies to test that the Company appropriately evaluated information obtained from regulatory rulings. For example, we assessed the recoverability of regulatory assets and sufficiency of regulatory liabilities, considering information obtained from regulatory rulings. In addition, we tested that amortization of regulatory assets and liabilities corresponded to relevant regulatory rulings.  |

---

/s/ Ernst & Young LLP

We have served as the Company's auditor since 2002.

Oklahoma City, Oklahoma

February 17, 2026

------

**REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM**

To the Stockholder and the Board of Directors of Oklahoma Gas and Electric Company

**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.

**Basis for Opinion**

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

**Critical Audit Matter**

The critical audit matter communicated below is a matter arising from the current period audit of the financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of the critical audit matter does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

------

**Regulatory Assets and Liabilities**

---

| | |
|:---|:---|
| &nbsp;&nbsp;*Description of the Matter* | &nbsp;&nbsp;As discussed in Note 1 to the consolidated financial statements, the Company is a regulated utility subject to accounting principles for rate-regulated activities. As such, certain incurred costs that would otherwise be charged to expense are 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 are deferred as regulatory liabilities, based on the expected refund to customers in future rates. The Company records items 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. |
|  | &nbsp;&nbsp;Auditing regulatory assets and liabilities is complex as it requires specialized knowledge of rate-regulated activities as to matters that could affect the recording or updating of regulatory assets and regulatory liabilities. |
| &nbsp;&nbsp;*How We Addressed the Matter in Our Audit* | &nbsp;&nbsp;We obtained an understanding, evaluated the design, and tested the operating effectiveness of internal controls over the Company's accounting for regulatory assets and liabilities, including, among others, controls over management's evaluation of regulatory orders for any new matters and controls over the evaluation of filings with regulatory bodies on existing regulatory assets and liabilities, including factors that may affect the timing or nature of recoverability of regulatory assets and sufficiency of regulatory liabilities.  |
|  | &nbsp;&nbsp;We performed audit procedures that included, among others, reviewing evidence of correspondence with regulatory bodies to test that the Company appropriately evaluated information obtained from regulatory rulings. For example, we assessed the recoverability of regulatory assets and sufficiency of regulatory liabilities, considering information obtained from regulatory rulings. In addition, we tested that amortization of regulatory assets and liabilities corresponded to relevant regulatory rulings. |

---

/s/ Ernst & Young LLP

We have served as the Company's auditor since 2002.

Oklahoma City, Oklahoma

February 17, 2026

------

**Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.** 

None.

**Item 9A. Controls and Procedures.** 

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

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

**Management's Report on Internal Control Over Financial Reporting** 

The management of the Registrants is responsible for establishing and maintaining adequate internal control over financial reporting. The Registrants' internal control systems were designed to provide reasonable assurance to management and OGE Energy's Board of Directors regarding the preparation and fair presentation of published financial statements. All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

The Registrants' management assessed the effectiveness of their internal control over financial reporting as of December 31, 2025. In making this assessment, it used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control-Integrated Framework (2013). Based on our assessment, we believe that, as of December 31, 2025, the Registrants' internal control over financial reporting is effective based on those criteria.

The Registrants' independent auditors have issued an attestation report on the Registrants' internal control over financial reporting. This report appears on the following page.

---

| | |
|:---|:---|
| /s/ Sean Trauschke | /s/ Sarah R. Stafford |
| Sean Trauschke, Chairman of the Board, President | Sarah R. Stafford, Controller |
| &nbsp;&nbsp;&nbsp;&nbsp;and Chief Executive Officer | &nbsp;&nbsp;&nbsp;&nbsp;and Chief Accounting Officer |
| /s/ Charles B. Walworth |  |
| Charles B. Walworth |  |
| Chief Financial Officer |  |

---

------

**REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM**

To the Stockholders and the Board of Directors of OGE Energy Corp.

**Opinion on Internal Control Over Financial Reporting**

We have audited OGE Energy Corp.'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), (the COSO criteria). In our opinion, OGE Energy Corp. (the Company) maintained, in all material respects, effective internal control over financial reporting as of December 31, 2025, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets and consolidated statements of capitalization of the Company as of December 31, 2025 and 2024, the related consolidated statements of income, comprehensive income, changes in stockholders' 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) and our report dated February 17, 2026 expressed an unqualified opinion thereon.

**Basis for Opinion**

The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.

Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

**Definition and Limitations of Internal Control Over Financial Reporting**

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ Ernst & Young LLP

Oklahoma City, Oklahoma

February 17, 2026

------

**REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM**

To the Stockholder and the Board of Directors of Oklahoma Gas and Electric Company

**Opinion on Internal Control Over Financial Reporting**

We have audited Oklahoma Gas and Electric 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), (the COSO criteria). In our opinion, Oklahoma Gas and Electric Company (the Company) maintained, in all material respects, effective internal control over financial reporting as of December 31, 2025, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the balance sheets and statements of capitalization of 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) and our report dated February 17, 2026 expressed an unqualified opinion thereon.

**Basis for Opinion**

The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.

Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

**Definition and Limitations of Internal Control Over Financial Reporting**

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ Ernst & Young LLP

Oklahoma City, Oklahoma

February 17, 2026

------

**Item 9B. Other Information.** 

During the three months ended December 31, 2025, no director or officer of the Registrants adopted or terminated a "Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement," as each term is defined in Item 408(a) of Regulation S-K.

**Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections.**

None.

------

**PAR** **T III**

**Item 10. Directors, Executive Officers and Corporate Governance.** 

**Code of Ethics Policy** 

OGE Energy maintains a code of ethics for our chief executive officer and senior financial officers, including the chief financial officer and chief accounting officer, which is available for public viewing on OGE Energy's website at www.oge.com/governance. The code of ethics will be provided, free of charge, upon request. OGE Energy intends to satisfy the disclosure requirements under Section 5, Item 5.05 of Form 8-K regarding an amendment to, or waiver from, a provision of the code of ethics by posting such information on its website at the location specified above. OGE Energy will also include in its proxy statement information regarding the Audit Committee financial experts.

OGE Energy maintains insider trading policies and procedures governing the purchase, sale, and/or other dispositions of OGE Energy's securities by directors, officers and employees that are reasonably designed to promote compliance with insider trading laws, rules and regulations, and any listing standards applicable to OGE Energy. It is also the policy of OGE Energy that it will not engage in transactions in OGE Energy securities while in possession of material non-public information relating to OGE Energy or its securities. A copy of OGE Energy's Insider Trading Policy is filed as Exhibit 19.01 to this Form 10-K.

*OGE Energy.* Information regarding OGE Energy's executive officers is set forth in "Part I, Item 1. Business - Information About the Registrants' Executive Officers." As permitted by General Instruction G of Form 10-K, the information required by Item 10, other than information regarding the executive officers, the Code of Ethics, and the insider trading policies and procedures will be set forth in OGE Energy's definitive proxy statement for the 2026 Annual Meeting of Shareholders, which is expected to be filed with the Securities and Exchange Commission on or about April 1, 2026. Such proxy statement is incorporated herein by reference.

*OG&E.* Under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K, the information otherwise required by Item 10 for OG&E has been omitted.

**Item 11. Executive Compensation**

*OGE Energy*. As permitted by General Instruction G of Form 10-K, the information required by Item 11 will be set forth in OGE Energy's definitive proxy statement for the 2026 Annual Meeting of Shareholders, which is expected to be filed with the Securities and Exchange Commission on or about April 1, 2026. Such proxy statement is incorporated herein by reference.

*OG&E.* Under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K, the information otherwise required by Item 11 for OG&E has been omitted.

**Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.** 

*OGE Energy*. As permitted by General Instruction G of Form 10-K, the information required by Item 12 will be set forth in OGE Energy's definitive proxy statement for the 2026 Annual Meeting of Shareholders, which is expected to be filed with the Securities and Exchange Commission on or about April 1, 2026. Such proxy statement is incorporated herein by reference.

*OG&E.* Under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K, the information otherwise required by Item 12 for OG&E has been omitted.

**Item 13. Certain Relationships and Related Transactions, and Director Independence.**

*OGE Energy*. As permitted by General Instruction G of Form 10-K, the information required by Item 13 will be set forth in OGE Energy's definitive proxy statement for the 2026 Annual Meeting of Shareholders, which is expected to be filed with the Securities and Exchange Commission on or about April 1, 2026. Such proxy statement is incorporated herein by reference.

*OG&E.* Under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K, the information otherwise required by Item 13 for OG&E has been omitted.

------

**Item 14. Principal Accountant Fees and Services.** 

The following discussion relates to the audit fees paid by OGE Energy to its principal independent accountants for the services provided to OGE Energy and its subsidiaries, including OG&E.

**Fees for Principal Independent Accountants**

---

| | | |
|:---|:---|:---|
| Year Ended December 31 | **2025** | 2024 |
| Integrated audit of OGE Energy and its subsidiaries financial statements and internal control over financial reporting | $**2107512** | $1718060 |
| Services in support of debt and stock offerings | **178350** | 198600 |
| Other (A) | **315018** | 337720 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total audit fees (B) | **2600880** | 2254380 |
| Employee benefit plan audits | **173430** | 169200 |
| Other compliance services | **21320** | 40370 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total audit-related fees | **194750** | 209570 |
| Assistance with examinations and other return issues | **204200** | 205823 |
| Review of federal and state tax returns | **31693** | 36366 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total tax preparation and compliance fees | **235893** | 242189 |
| &nbsp;&nbsp;&nbsp;&nbsp;Total tax fees | **235893** | 242189 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Total fees | $**3031523** | $2706139 |

---

(A)Includes reviews of the financial statements included in the Registrants' Quarterly Reports on Form 10-Q, audits of OGE Energy's subsidiaries, agreed-upon procedures and fees for consulting with the Registrants' executives regarding accounting issues.

(B)The aggregate audit fees include fees billed for the audit of the Registrants' annual financial statements and for the reviews of the financial statements included in the Registrants' Quarterly Reports on Form 10-Q. For 2025, this amount includes estimated billings for the completion of the 2025 audit, which services were rendered after year-end.

**All Other Fees**

There were no other fees billed by the principal independent accountants to OGE Energy in 2025 and 2024 for other services.

**Audit Committee Pre-Approval Procedures** 

Rules adopted by the Securities and Exchange Commission in order to implement requirements of the Sarbanes-Oxley Act of 2002 require public company audit committees to pre-approve audit and non-audit services. OGE Energy's Audit Committee follows procedures pursuant to which audit, audit-related and tax services, and all permissible non-audit services are pre-approved by category of service. The fees are budgeted, and actual fees versus the budget are monitored throughout the year. During the year, circumstances may arise when it may become necessary to engage the principal independent accountants for additional services not contemplated in the original pre-approval. In those instances, OGE Energy will obtain the specific pre-approval of the Audit Committee before engaging the principal independent accountants. The procedures require the Audit Committee to be informed of each service, and the procedures do not include any delegation of the Audit Committee's responsibilities to management. The Audit Committee may delegate pre-approval authority to one or more of its members. The member to whom such authority is delegated will report any pre-approval decisions to the Audit Committee at its next scheduled meeting.

For 2025, 100 percent of the audit fees, audit-related fees and tax fees were pre-approved by the Audit Committee or the Chair of the Audit Committee pursuant to delegated authority.

------

**PART IV**

**Item 15. Exhibit and Financial Statement Schedules.** 

**(a) 1. Financial Statements**

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(i)The following financial statements are included in Part II, Item 8 of this Annual Report:

**OGE Energy**

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Consolidated Statements of Income for the years ended December 31, 2025, 2024 and 2023

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Consolidated Statements of Comprehensive Income for the years ended December 31, 2025, 2024 and 2023

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Consolidated Statements of Cash Flows for the years ended December 31, 2025, 2024 and 2023

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Consolidated Balance Sheets at December 31, 2025 and 2024

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Consolidated Statements of Capitalization at December 31, 2025 and 2024

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Consolidated Statements of Changes in Stockholders' Equity for the years ended December 31, 2025, 2024 and 2023

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Notes to Consolidated Financial Statements

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Report of Independent Registered Public Accounting Firm (Audit of Financial Statements)

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Management's Report on Internal Control Over Financial Reporting

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Report of Independent Registered Public Accounting Firm (Audit of Internal Control over Financial Reporting)

**OG&E**

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Statements of Income for the years ended December 31, 2025, 2024 and 2023

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Statements of Comprehensive Income for the years ended December 31, 2025, 2024 and 2023

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Statements of Cash Flows for the years ended December 31, 2025, 2024 and 2023

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Balance Sheets at December 31, 2025 and 2024

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Statements of Capitalization at December 31, 2025 and 2024

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Statements of Changes in Stockholder's Equity for the years ended December 31, 2025, 2024 and 2023

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Notes to Financial Statements

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Report of Independent Registered Public Accounting Firm (Audit of Financial Statements)

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Management's Report on Internal Control Over Financial Reporting

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Report of Independent Registered Public Accounting Firm (Audit of Internal Control over Financial Reporting)

The reports of the Registrants' independent registered public accounting firm (PCAOB ID:42) with respect to the above-referenced financial statements and their reports on internal control over financial reporting are included in Item 8 and Item 9A of this Form 10-K. Their consents for each Registrant appear as Exhibit 23.01 and Exhibit 23.02 of this Form 10-K.

**2. Financial Statement Schedule (included in Part IV)** 

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;•Schedule II - Valuation and Qualifying Accounts

All other schedules have been omitted since the required information is not applicable or is not material, or because the information required is included in the respective financial statements or notes thereto.

------

**3. Exhibits**

---

| | | | |
|:---|:---|:---|:---|
| &nbsp;&nbsp;**Exhibit No.**  | &nbsp;&nbsp;**Description** | &nbsp;&nbsp;**OGE Energy** | &nbsp;&nbsp;**OG&E** |
| &nbsp;&nbsp;1.01 | &nbsp;&nbsp;[<u>Underwriting Agreement, dated November 20, 2025, by and among OGE Energy, Morgan Stanley & Co. LLC and J.P. Morgan Securities LLC as representatives of the several underwriters named therein, Morgan Stanley & Co. LLC and J.P. Morgan Securities LLC, acting in their capacity as forward sellers, and Morgan Stanley & Co. LLC and JPMorgan Chase Bank, National Association, New York Branch, acting in their capacity as forward purchasers. (Filed as Exhibit 1.01 to OGE Energy's 8-K filed November 24, 2025 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000110465925115429/tm2530364d3_ex1-01.htm) | &nbsp;&nbsp;X |  |
| &nbsp;&nbsp;3.01 | &nbsp;&nbsp;[<u>Copy of Restated OGE Energy Corp. Certificate of Incorporation. (Filed as Exhibit 3.01 to OGE Energy's Form 10-Q for the quarter ended June 30, 2013 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163513000418/q22013oge10-qxex301.htm) | &nbsp;&nbsp;X |  |
| &nbsp;&nbsp;3.02 | &nbsp;&nbsp;[<u>Copy of Amended OGE Energy Corp. By-laws dated February 22, 2017. (Filed as Exhibit 3.01 to OGE Energy's Form 8-K filed February 23, 2017 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163517000016/exhibit3012-22x17.htm) | &nbsp;&nbsp;X |  |
| &nbsp;&nbsp;3.03 | &nbsp;&nbsp;[<u>Copy of Restated Oklahoma Gas and Electric Company Certificate of Incorporation. (Filed as Exhibit 3.01 to OG&E's Form 8-K filed May 19, 2011 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414511000011/ogande8k051911ex301.htm) |  | &nbsp;&nbsp;X |
| &nbsp;&nbsp;3.04 | &nbsp;&nbsp;[<u>Copy of Amended Oklahoma Gas and Electric Company By-laws dated November 30, 2015. (Filed as Exhibit 3.02 to OGE Energy's Form 8-K filed November 30, 2015 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163515000124/exhibit302-11x30x15.htm) |  | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.01 | &nbsp;&nbsp;[<u>Trust Indenture dated October 1, 1995, from OG&E to Boatmen's First National Bank of Oklahoma, Trustee. (Filed as Exhibit 4.02 to OG&E's Form 8-K filed October 24, 1995 and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/0000912057-95-008871.txt) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.02 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 2, dated as of July 1, 1997, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed July 17, 1997 (File No. 33-1532) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/0000912057-97-024456.txt) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.03 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 3, dated as of April 1, 1998, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed April 16, 1998 (File No. 33-1532) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/0001047469-98-015233.txt) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.04 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 5 dated as of October 24, 2001, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.06 to OG&E's Registration Statement No. 333-104615 and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000104746903013797/a2108633zex-4_06.txt) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.05 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 6 dated as of August 1, 2004, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.02 to OG&E's Form 8-K filed August 6, 2004 (File No 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465904023015/a04-9061_1ex4d02.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.06 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 7 dated as of January 1, 2006</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465906000995/a05-22189_4ex4d02.htm)[<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465906000995/a05-22189_4ex4d02.htm)[<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.02 to OG&E's Form 8-K filed January 6, 2006 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465906000995/a05-22189_4ex4d02.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.07 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 8 dated as of January 15, 2008</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000006/ogande8k013108ex401.htm)[<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000006/ogande8k013108ex401.htm)[<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed January 31, 2008 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000006/ogande8k013108ex401.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.08 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 9 dated as of September 1, 2008</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000032/ogande8kex401.htm)[<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000032/ogande8kex401.htm)[<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed September 9, 2008 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000032/ogande8kex401.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.09 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 10 dated as of December 1, 2008</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000041/exhibit401.htm)[<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000041/exhibit401.htm)[<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed December 11, 2008 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414508000041/exhibit401.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.10 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 11 dated as of June 1, 2010</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414510000017/ogande401exhibit.htm)[<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414510000017/ogande401exhibit.htm)[<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed June 8, 2010 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414510000017/ogande401exhibit.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |

---

------

4.11 [<u>Supplemental Indenture No. 12 dated as of May 15, 2011</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465911031882/a11-12617_4ex4d01.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465911031882/a11-12617_4ex4d01.htm) [<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed May 27, 2011 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465911031882/a11-12617_4ex4d01.htm) X X

4.12 [<u>Supplemental Indenture No. 13 dated as of May 1, 2013</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414513000012/exhibit401-5x13x13.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414513000012/exhibit401-5x13x13.htm) [<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed May 13, 2013 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414513000012/exhibit401-5x13x13.htm) X X

4.13 [<u>Supplemental Indenture No. 14 dated as of March 15, 2014</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414514000009/exhibit401-3x25x14.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414514000009/exhibit401-3x25x14.htm) [<u>being</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414514000009/exhibit401-3x25x14.htm) [<u>a</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414514000009/exhibit401-3x25x14.htm) [<u>supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed March 25, 2014 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414514000009/exhibit401-3x25x14.htm) X X

4.14 [<u>Supplemental Indenture No. 15 dated as of December 1, 2014</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414514000033/exhibit401-12x11x14.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414514000033/exhibit401-12x11x14.htm) [<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed December 11, 2014 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414514000033/exhibit401-12x11x14.htm) X X

4.15 [<u>Supplemental Indenture No. 16 dated as of March 15, 2017</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465917020587/a17-8483_4ex4d01.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465917020587/a17-8483_4ex4d01.htm) [<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed March 31, 2017 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000110465917020587/a17-8483_4ex4d01.htm) X X

4.16 [<u>Supplemental Indenture No. 17 dated as of August 1, 2017</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414517000024/exhibit4018-11x17.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414517000024/exhibit4018-11x17.htm) [<u>being</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414517000024/exhibit4018-11x17.htm) [<u>a</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414517000024/exhibit4018-11x17.htm) [<u>supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed August 11, 2017 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000007414517000024/exhibit4018-11x17.htm) X X

4.17 [<u>Supplemental Indenture No. 18 dated as of April 26, 2018</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4212018.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4212018.htm) [<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.21 to</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4212018.htm) [<u>OG&E</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4212018.htm) [<u>'s Registration Statement on Form S-3ASR filed May 18, 2018 (File No. 333-225030</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4212018.htm) [<u>-01</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4212018.htm) [<u>) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4212018.htm) X X

4.18 [<u>Supplemental Indenture No. 19 dated as of August 15, 2018</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414518000024/exhibit4018-17x18.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414518000024/exhibit4018-17x18.htm) [<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to O</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414518000024/exhibit4018-17x18.htm) [<u>G&</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414518000024/exhibit4018-17x18.htm) [<u>E</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414518000024/exhibit4018-17x18.htm) [<u>'s Form 8-K filed August 17, 2018 (File No. 1-1</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414518000024/exhibit4018-17x18.htm) [<u>097</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414518000024/exhibit4018-17x18.htm) [<u>) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414518000024/exhibit4018-17x18.htm) X X

4.19 [<u>Supplemental Indenture No. 20 dated as of June 1, 2019</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414519000017/exhibit4016-7x19.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414519000017/exhibit4016-7x19.htm) [<u>being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414519000017/exhibit4016-7x19.htm) [<u>&</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414519000017/exhibit4016-7x19.htm) [<u>E</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414519000017/exhibit4016-7x19.htm) [<u>'s Form 8-K filed June 7, 2019 (File No. 1-1</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414519000017/exhibit4016-7x19.htm) [<u>097</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414519000017/exhibit4016-7x19.htm) [<u>) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414519000017/exhibit4016-7x19.htm) X X

4.20 [<u>Supplemental Indenture No. 21 dated as of April 1, 2020</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>being a supplemental instrument to Exhibit 4</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>.01 hereto.</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>(Filed as Exhibit 4.01 to OG</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>&</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>E</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>'s Form 8-K filed April 1, 2020 (File No. 1-1</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>097</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) [<u>) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000007414520000014/exhibit4014-1x20.htm) X X

4.21 [<u>Supplemental Indenture No. 22 dated as of May 27, 2021</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163521000122/exhibit4025-27x21.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163521000122/exhibit4025-27x21.htm) [<u>be</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163521000122/exhibit4025-27x21.htm) [<u>ing a supplemental instrument to Exhibit 4.01 hereto.</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163521000122/exhibit4025-27x21.htm) [<u>(Filed as Exhibit 4.02 to OG&E's Form 8-K filed May 27</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163521000122/exhibit4025-27x21.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163521000122/exhibit4025-27x21.htm) [<u>2021 (File No. 1-</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163521000122/exhibit4025-27x21.htm) [<u>1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163521000122/exhibit4025-27x21.htm) X X

4.22 [<u>Supplemental Indenture No. 23 dated as of January 5, 2023, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed January 5, 2023 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000095017023000197/oge-ex4_01.htm) X X

4.23 [<u>Supplemental Indenture No. 24 dated as of April 3, 2023, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed April 3, 2023 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017023011514/oge-ex4_01.htm) X X

4.24 [<u>Supplemental Indenture No. 25 dated as of April 1, 2025, being a supplemental instrument to Exhibit 4.01 hereto. (Filed as Exhibit 4.01 to OG&E's Form 8-K filed April 1, 2025 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017025048180/oge-ex4_01.htm) X X

4.25 [<u>Indenture dated as of November 1, 2004 between OGE Energy Corp. and UMB Bank, N.A., as trustee. (Filed as Exhibit 4.01 to OGE Energy's Form 8-K filed November 12, 2004 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000110465904035530/a04-13380_1ex4d01.htm) X

4.26 [<u>Supplemental Indenture No. 2 dated as of November 24, 2014 between OGE Energy and UMB Bank, N.A, as trustee, creating the Senior Notes. (Filed as Exhibit 4.01 to OGE Energy's Form 8-K filed November 24, 2014 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163514000254/exhibit401-11x24x14.htm) X

4.27 [<u>Supplemental Indenture No. 3 dated as of April 26, 2018</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4042018.htm) [<u>,</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4042018.htm) [<u>being a supplemental instrument to Exhibit 4.24</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4042018.htm) [<u>hereto. (Filed as Exhibit 4.04 to OGE Energy's Registration Statement on Form S-3ASR filed May 18, 2018 (File No. 333-225030) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000102163518000070/s-3asrxex4042018.htm) X

------

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| | | |
|:---|:---|:---|
| &nbsp;&nbsp;4.28 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 4 dated as of May 27, 2021</u>](https://www.sec.gov/Archives/edgar/data/0001021635/000102163521000122/exhibit4015-27x21.htm)[<u>,</u>](https://www.sec.gov/Archives/edgar/data/0001021635/000102163521000122/exhibit4015-27x21.htm)[<u>be</u>](https://www.sec.gov/Archives/edgar/data/0001021635/000102163521000122/exhibit4015-27x21.htm)[<u>ing a supplemental instrument to Exhibit 4.24 hereto</u>](https://www.sec.gov/Archives/edgar/data/0001021635/000102163521000122/exhibit4015-27x21.htm)[<u>.</u>](https://www.sec.gov/Archives/edgar/data/0001021635/000102163521000122/exhibit4015-27x21.htm)[<u>(Filed as Exhibit 4.01 to OGE Energy's Form 8-K filed May 27, 2021 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/0001021635/000102163521000122/exhibit4015-27x21.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.29 | &nbsp;&nbsp;[<u>Supplemental Indenture No. 5 dated as of May 9, 2024, being a supplemental instrument to Exhibit 4.24 hereto. (Filed as Exhibit 4.01 to OGE Energy's Form 8-K filed May 9, 2024 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000095017024056423/oge-ex4_01.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;4.30+ | &nbsp;&nbsp;[<u>Description of Capital Stock.</u>](oge-ex4_30.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.01 | &nbsp;&nbsp;[<u>Amended and Restated Facility Operating Agreement for the McClain Generating Facility dated as of July 9, 2004 between OG&E and the Oklahoma Municipal Power Authority. (Filed as Exhibit 10.03 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163504000195/ogesecondquarter10q.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.02 | &nbsp;&nbsp;[<u>Amended and Restated Ownership and Operation Agreement for the McClain Generating Facility dated as of July 9, 2004 between OG&E and the Oklahoma Municipal Power Authority. (Filed as Exhibit 10.04 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163504000195/ogesecondquarter10q.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.03 | &nbsp;&nbsp;[<u>Operating and Maintenance Agreement for the Transmission Assets of the McClain Generating Facility dated as of August 25, 2003 between OG&E and the Oklahoma Municipal Power Authority. (Filed as Exhibit 10.05 to OGE Energy's Form 10-Q for the quarter ended June 30, 2004 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163504000195/ogesecondquarter10q.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.04\* | &nbsp;&nbsp;[<u>Form of Split Dollar Agreement. (Filed as Exhibit 10.32 to OGE Energy's Form 10-K for the year ended December 31, 2004 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163505000037/oge10k123104.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.05\* | &nbsp;&nbsp;[<u>OGE Energy Supplemental Executive Retirement Plan, as amended and restated. (Filed as Exhibit 10.01 to OGE Energy's Form 10-Q for the quarter ended September 30, 2019 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163519000116/q32019ogeenergy10-qxex1001.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.06\* | &nbsp;&nbsp;[<u>Amendment No. 1 to the OGE Energy Corp. Supplemental Executive Retirement Plan. (Filed as Exhibit 10.01 to OGE Energy's Form 10-Q for the quarter ended June 30, 2021 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163521000140/q22021ogeenergy10-qxex1001.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.07\* | &nbsp;&nbsp;[<u>OGE Energy Restoration of Retirement Income Plan, as amended and restated. (Filed as Exhibit 10.04 to OGE Energy's Form 10-Q for the quarter ended March 31, 2008 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163508000137/oge1stqex1004.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.08\* | &nbsp;&nbsp;[<u>Amendment No. 1 to OGE Energy's Restoration of Retirement Income Plan. (Filed as Exhibit 10.40 to OGE Energy's Form 10-K for the year ended December 31, 2009 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163510000011/exhibit1040.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.09\* | &nbsp;&nbsp;[<u>Form of Employment Agreement for all existing and future officers of OGE Energy relating to change of control. (Filed as Exhibit 10.28 to OGE Energy's Form 10-K for the year ended December 31, 2011 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163512000006/oge201110-kxex1028.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.10\*+ | &nbsp;&nbsp;[<u>OGE Energy's Director Compensation.</u>](oge-ex10_10.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.11\*+ | &nbsp;&nbsp;[<u>OGE Energy's Executive Officer Compensation.</u>](oge-ex10_11.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.12\* | &nbsp;&nbsp;[<u>OGE Energy's 2022 Stock Incentive Plan. (Filed as Appendix B to OGE Energy's Proxy Statement for the 2022 Annual Meeting of Shareholder (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163522000089/a2022proxystatementdefinit.htm#i5d9efc78f2224f79b35d8bd09b680677_184) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.13\* | &nbsp;&nbsp;[<u>OGE Energy's 2023 Annual Executive Incentive Compensation Plan. (Filed as Exhibit 10.14 to OGE Energy's Form 10-K for the year ended December 31, 2022 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017023003858/oge-ex10_14.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.14\* | &nbsp;&nbsp;[<u>Form of Performance Unit Agreement under OGE Energy's 2022 Stock Incentive Plan. (Filed as Exhibit 10.17 to OGE Energy's Form 10-K for the year ended December 31, 2022 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017023003858/oge-ex10_17.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.15\* | &nbsp;&nbsp;[<u>Form of Restricted Stock Unit Agreement under OGE Energy's 2022 Stock Incentive Plan. (Filed as Exhibit 10.18 to OGE Energy's Form 10-K for the year ended December 31, 2022 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017023003858/oge-ex10_18.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.16\* | &nbsp;&nbsp;[<u>OGE Energy Corp. Deferred Compensation Plan (As amended and restated effective October 1, 2016). (Filed as Exhibit 10.37 to OGE Energy's Form 10-K for the year ended December 31, 2016 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163517000013/a2016oge10-kxex1037.htm) | &nbsp;&nbsp;X |
| &nbsp;&nbsp;10.17 | &nbsp;&nbsp;[<u>Copy of the Settlement Agreement filed with the APSC on April 20, 2017. (Filed as Exhibit 99.02 to OGE Energy's Form 8-K filed May 24, 2017 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163517000052/exhibit99025-19x17jointmot.htm) | &nbsp;&nbsp;X |

---

------

10.18 [<u>Amended and Restated Credit Agreement dated as of December 17, 2021 by and among OGE Energy Corp. and Wells Fargo Bank, National Association, as Agent, JPMorgan Chase Bank, N.A. and Mizuho Bank, Ltd., as Co-Syndication Agents, MUFG Union Bank, N.A., Royal Bank of Canada and U.S. Bank National Association, as Co-Documentation Agents, and the lenders from time to time parties thereto. (Filed as Exhibit 99.01 to OGE Energy's Form 8-K filed December 21, 2021 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/0001021635/000102163521000195/exhibit990112-17x21.htm) X

10.19 [<u>First Amendment dated as of December 19, 2022, to Amended and Restated Credit Agreement dated as of December 17, 2021, by and among OGE Energy, the Lenders thereto, Wells Fargo Bank, National Association, as Agent, JPMorgan Chase Bank, N.A. and Mizuho Bank, Ltd., as Co-Syndication Agents, and MUFG Bank, Ltd., Royal Bank of Canada and U.S. Bank National Association, as Co-Documentation Agents. (Filed as Exhibit 10.01 to OGE Energy's Form 8-K filed December 19, 2022 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000095017022026730/oge-ex10_01.htm) X

10.20 [<u>Amended and Restated Credit Agreement dated as of December 17, 2021 by and among Oklahoma Gas and Electric Company and Wells Fargo Bank, National Association, as Agent, JPMorgan Chase Bank, N.A. and Mizuho Bank, Ltd., as Co-Syndication Agents, MUFG Union Bank, N.A., Royal Bank of Canada and U.S. Bank National Association, as Co-Documentation Agents, and the lenders from time to time parties thereto. (Filed as Exhibit 99.02 to OG&E's Form 8-K filed December 21, 2021 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/0000074145/000102163521000195/exhibit990212-17x21.htm) X X

10.21 [<u>First Amendment dated as of December 19, 2022, to Amended and Restated Credit Agreement dated as of December 17, 2021, by and among OG&E, the Lenders thereto, Wells Fargo Bank, National Association, as Agent, JPMorgan Chase Bank, N.A. and Mizuho Bank, Ltd., as Co-Syndication Agents, and MUFG Bank, Ltd., Royal Bank of Canada and U.S. Bank National Association, as Co-Documentation Agents. (Filed as Exhibit 10.02 to OG&E's Form 8-K filed December 19, 2022 (File No. 1-1097) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000095017022026730/oge-ex10_02.htm) X X

10.22 [<u>Letter of extension dated as of December 18, 2023 for OGE Energy's and OG&E's credit agreements dated as of December 17, 2021, as amended, by and among OGE Energy and OG&E, for their respective credit facility, the Lenders thereto, Wells Fargo Bank, National Association, as Agent, JPMorgan Chase Bank, N.A. and Mizuho Bank, Ltd., as Co-Syndication Agents, and MUFG Bank, Ltd., Royal Bank of Canada and U.S. Bank National Association, as Co-Documentation Agents. (Filed as Exhibit 10.01 to OGE Energy's Form 8-K filed December 20, 2023 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017023071821/oge-ex10_01.htm) X X

10.23 [<u>Letter of extension dated as of December 18, 2024 for OGE Energy's and OG&E's credit agreements dated as of December 17, 2021, as amended, by and among OGE Energy and OG&E, for their respective credit facility, the Lenders thereto, Wells Fargo Bank, National Association, as Agent, JPMorgan Chase Bank, N.A. and Mizuho Bank, Ltd., as Co-Syndication Agents, and MUFG Bank, Ltd., Royal Bank of Canada and U.S. Bank National Association, as Co-Documentation Agents. (Filed as Exhibit 10.01 to OGE Energy's Form 8-K filed December 18, 2024 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017024138466/oge-ex10_01.htm) X X

10.24 [<u>Forward Sale Agreement, dated November 20, 2025, by and between OGE Energy and Morgan Stanley & Co. LLC. (Filed as Exhibit 10.01 to OGE Energy's Form 8-K filed on November 24, 2025 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000110465925115429/tm2530364d3_ex10-01.htm) X

10.25 [<u>Forward Sale Agreement, dated November 20, 2025, between OGE Energy and JPMorgan Chase Bank, National Association, New York Branch. (Filed as Exhibit 10.02 to OGE Energy's Form 8-K filed on November 24, 2025 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000110465925115429/tm2530364d3_ex10-02.htm) X

10.26 [<u>Additional Forward Sale Agreement, dated November 21, 2025, by and between OGE Energy and Morgan Stanley & Co. LLC. (Filed as Exhibit 10.03 to OGE Energy's Form 8-K filed on November 24, 2025 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000110465925115429/tm2530364d3_ex10-03.htm) X

10.27 [<u>Additional Forward Sale Agreement, dated November 21, 2025, between OGE Energy and JPMorgan Chase Bank, National Association, New York Branch. (Filed as Exhibit 10.04 to OGE Energy's Form 8-K filed on November 24, 2025 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000110465925115429/tm2530364d3_ex10-04.htm) X

------

---

| | | | |
|:---|:---|:---|:---|
| &nbsp;&nbsp;19.01 | &nbsp;&nbsp;[<u>OGE Energy Insider Trading Policy. (Filed as Exhibit 19.01 to OGE Energy's Form 10-K for the year ended December 31, 2024 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000095017025022560/oge-ex19_01.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;21.01+ | &nbsp;&nbsp;[<u>Subsidiaries of OGE Energy.</u>](oge-ex21_01.htm) | &nbsp;&nbsp;X |  |
| &nbsp;&nbsp;23.01+ | &nbsp;&nbsp;[<u>Consent of Ernst & Young LLP.</u>](oge-ex23_01.htm) | &nbsp;&nbsp;X |  |
| &nbsp;&nbsp;23.02+ | &nbsp;&nbsp;[<u>Consent of Ernst & Young LLP.</u>](oge-ex23_02.htm) |  | &nbsp;&nbsp;X |
| &nbsp;&nbsp;24.01+ | &nbsp;&nbsp;[<u>Power of Attorney.</u>](oge-ex24_01.htm) | &nbsp;&nbsp;X |  |
| &nbsp;&nbsp;24.02+ | &nbsp;&nbsp;[<u>Power of Attorney.</u>](oge-ex24_02.htm) |  | &nbsp;&nbsp;X |
| &nbsp;&nbsp;31.01+ | &nbsp;&nbsp;[<u>Certifications Pursuant to Rule 13a-14(a)/15d-14(a) As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.</u>](oge-ex31_01.htm) | &nbsp;&nbsp;X |  |
| &nbsp;&nbsp;31.02+ | &nbsp;&nbsp;[<u>Certifications Pursuant to Rule 13a-14(a)/15d-14(a) As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.</u>](oge-ex31_02.htm) |  | &nbsp;&nbsp;X |
| &nbsp;&nbsp;32.01+ | &nbsp;&nbsp;[<u>Certification Pursuant to 18 U.S.C. Section 1350 As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.</u>](oge-ex32_01.htm) | &nbsp;&nbsp;X |  |
| &nbsp;&nbsp;32.02+ | &nbsp;&nbsp;[<u>Certification Pursuant to 18 U.S.C. Section 1350 As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.</u>](oge-ex32_02.htm) |  | &nbsp;&nbsp;X |
| &nbsp;&nbsp;97.01 | &nbsp;&nbsp;[<u>Executive Compensation Clawback Policy. (Filed as Exhibit 97.01 to OGE Energy's Form 10-K for the year ended December 31, 2023 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017024017400/oge-ex97_01.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;99.01 | &nbsp;&nbsp;[<u>Credit Agreement dated as of June 26, 2024 by and among OGE Energy Corp., the Lenders and BOKF NA, dba Bank of Oklahoma as Sole Administrative Agent, Sole Syndication Agent, Lead Arranger and Sole Bookrunner (Filed as Exhibit 99.01 to OGE Energy's Form 10-Q for the quarter ended June 30, 2024 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017024092035/oge-ex99_01.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;99.02 | &nbsp;&nbsp;[<u>Copy of the APSC Settlement Agreement approval dated May 18, 2017. (Filed as Exhibit 99.01 to OGE Energy's Form 8-K filed May 24, 2017 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/1021635/000102163517000052/exhibit99015-19x17.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;99.03 | &nbsp;&nbsp;[<u>Copy of the Settlement Agreement filed with the OCC on June 12, 2024. (Filed as Exhibit 99.01 to OGE Energy's Form 8-K filed June 13, 2024 (File No. 1-12579) and incorporated by reference herein).</u>](https://www.sec.gov/Archives/edgar/data/74145/000095017024072718/oge-ex99_01.htm) | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;101.INS | &nbsp;&nbsp;Inline XBRL Instance Document - the instance document does not appear in the interactive data file because its XBRL tags are embedded within the Inline XBRL document. | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;101.SCH | &nbsp;&nbsp;Inline XBRL Taxonomy Extension Schema With Embedded Linkbase Documents. | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp;104 | &nbsp;&nbsp;Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document (included in Exhibit 101). | &nbsp;&nbsp;X | &nbsp;&nbsp;X |
| &nbsp;&nbsp; \* Represents executive compensation plans and arrangements. | &nbsp;&nbsp; \* Represents executive compensation plans and arrangements. |  |  |
| &nbsp;&nbsp; + Represents exhibits filed herewith. All exhibits not so designated are incorporated by reference to a <br>&nbsp;&nbsp;&nbsp;&nbsp;prior filing, as indicated. | &nbsp;&nbsp; + Represents exhibits filed herewith. All exhibits not so designated are incorporated by reference to a <br>&nbsp;&nbsp;&nbsp;&nbsp;prior filing, as indicated. |  |  |

---

------

**OGE ENERGY CORP.**

**OKLAHOMA GAS AND ELECTRIC COMPANY**

**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)* | *(In millions)* | *(In millions)* | *(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.

**Item 16. Form 10-K Summary.**

None.

------

**SIGNATURES**

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, as amended, the Registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Oklahoma City, and State of Oklahoma on February 17<sup>th</sup>, 2026.

---

| | |
|:---|:---|
| **OGE ENERGY CORP.** | **OGE ENERGY CORP.** |
| (Registrant) | (Registrant) |
| By /s/ | Sean Trauschke |
|  | Sean Trauschke |
|  | Chairman of the Board, President |
|  | and Chief Executive Officer |

---

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, this Report has been signed below by the following persons on behalf of the Registrant in the capacities and on the dates indicated.

---

| | | |
|:---|:---|:---|
| Signature | Title | Date |
| /s/ Sean Trauschke |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Sean Trauschke | Principal Executive |  |
|  | &nbsp;&nbsp;&nbsp;&nbsp;Officer and Director; | February 17, 2026<br>|
| /s/ Charles B. Walworth |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Charles B. Walworth | Principal Financial Officer; | February 17, 2026 |
| /s/ Sarah R. Stafford |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Sarah R. Stafford | Principal Accounting Officer; | February 17, 2026 |
| &nbsp;&nbsp;&nbsp;&nbsp;Frank A. Bozich | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Peter D. Clarke | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Lyle G. Ganske | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Cathy R. Gates | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;David L. Hauser | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Luther C. Kissam, IV | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Judy R. McReynolds | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;David E. Rainbolt | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Sheila G. Talton | Director; |  |

---

---

| | |
|:---|:---|
| /s/ Sean Trauschke |  |
| By Sean Trauschke (attorney-in-fact) | February 17, 2026 |

---

------

**SIGNATURES**

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, as amended, the Registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Oklahoma City, and State of Oklahoma on February 17<sup>th</sup>, 2026.

---

| | |
|:---|:---|
| **OKLAHOMA GAS AND ELECTRIC COMPANY** | **OKLAHOMA GAS AND ELECTRIC COMPANY** |
| (Registrant) | (Registrant) |
| By /s/ | Sean Trauschke |
|  | Sean Trauschke |
|  | Chairman of the Board, President |
|  | and Chief Executive Officer |

---

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, this Report has been signed below by the following persons on behalf of the Registrant in the capacities and on the dates indicated.

---

| | | |
|:---|:---|:---|
| Signature | Title | Date |
| /s/ Sean Trauschke |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Sean Trauschke | Principal Executive |  |
|  | &nbsp;&nbsp;&nbsp;&nbsp;Officer and Director; | February 17, 2026 |
| /s/ Charles B. Walworth |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Charles B. Walworth | Principal Financial Officer; | February 17, 2026 |
| /s/ Sarah R. Stafford |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Sarah R. Stafford | Principal Accounting Officer; | February 17, 2026 |
| &nbsp;&nbsp;&nbsp;&nbsp;Frank A. Bozich | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Peter D. Clarke | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Lyle G. Ganske | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Cathy R. Gates | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;David L. Hauser | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Luther C. Kissam, IV | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Judy R. McReynolds | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;David E. Rainbolt | Director; |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Sheila G. Talton | Director; |  |

---

---

| | |
|:---|:---|
| /s/ Sean Trauschke |  |
| By Sean Trauschke (attorney-in-fact) | February 17, 2026 |

---

------

## Exhibit 4.30

**Exhibit 4.30**

**DESCRIPTION OF SECURITIES**

The following description of the common stock of OGE Energy Corp., an Oklahoma corporation, is a summary of the general terms thereof and is qualified in its entirety by the provisions of our certificate of incorporation, as amended and restated (the "Restated Certificate of Incorporation"), and bylaws, as amended and restated (the "Bylaws"), copies of both of which have been filed as exhibits to our most recent Annual Report on Form 10-K filed with the Securities and Exchange Commission, and the laws of the state of Oklahoma.

**Authorized Shares**

Under our Restated Certificate of Incorporation, we are authorized to issue 450,000,000 shares of common stock, par value $0.01 per share, of which 206,259,022 shares were outstanding on January 31, 2026. We are also authorized to issue 5,000,000 shares of preferred stock, par value $0.01 per share. No shares of preferred stock are currently outstanding. Our common stock is our only security registered under Section 12 of the Securities Exchange Act of 1934.

Without shareholder approval, we may issue preferred stock in the future in such series as may be designated by our board of directors. In creating any such series, our board of directors has the authority to fix the rights and preferences of each series with respect to, among other things, the dividend rate, redemption provisions, liquidation preferences, sinking fund provisions, conversion rights and voting rights. The terms of any series of preferred stock that we may issue in the future may provide the holders of such preferred stock with rights that are senior to the rights of the holders of our common stock.

**Dividend Rights**

Before we can pay any dividends on our common stock, the holders of our 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. Currently, there are no shares of our preferred stock outstanding. Because we are a holding company and conduct all of our operations through our subsidiary, our cash flow and ability to pay dividends will be dependent on the earnings and cash flow of our subsidiary and the distribution or other payment of those earnings to us in the form of dividends. We expect to derive principally all of the funds required by us to enable us to pay dividends on our common stock from dividends paid by Oklahoma Gas and Electric Company ("OG&E") on its common stock. Our ability to receive dividends on OG&E's common stock is subject to the prior rights of the holders of any OG&E preferred stock that may be outstanding, any covenants of OG&E's certificate of incorporation and OG&E's debt instruments limiting the ability of OG&E to pay dividends and the ability of public utility commissions that regulate OG&E to effectively restrict the payment of dividends by OG&E.

**Voting Rights**

Each holder of common stock is entitled to one vote per share upon all matters upon which shareowners have the right to vote and generally will vote together as one class. Our board of directors has the authority to fix conversion and voting rights for any new series of preferred stock (including the right to elect directors upon a failure to pay dividends), provided that no share of preferred stock can have more than one vote per share.

Our Restated Certificate of Incorporation also contains "fair price" provisions, which require the approval by the holders of at least 80 percent of the voting power of our outstanding voting stock as a condition for mergers, consolidations, sales of substantial assets, issuances of capital stock and certain other business combinations and transactions involving us and any substantial (10 percent or more) holder of our voting stock unless the transaction is either approved by a majority of the members of our board of directors who are unaffiliated with the substantial holder or specified minimum price and procedural requirements are met. The provisions summarized in the foregoing sentence may be amended only by the approval of the holders of at least 80 percent of the voting power of our outstanding voting stock. Our voting stock consists of all outstanding shares entitled to vote generally in the election of directors and currently consists of our common stock.

Our voting stock does not have cumulative voting rights for the election of directors. Our Restated Certificate of Incorporation and By-Laws currently contain provisions stating that: (1) directors may be removed only with the approval of the holders of at least a majority of the voting power of our shares generally entitled to vote; (2) any vacancy on the board of directors will be filled only by the remaining directors then in office, though less than a quorum; (3) advance notice of introduction by shareowners of business at annual shareowner meetings and of shareowner nominations for the election of directors must be given and that certain information must be provided with respect to such matters; (4) shareowner action may be taken only at an annual meeting of shareowners or a

------

special meeting of shareowners called by the President or the board of directors; and (5) the foregoing provisions may be amended only by the approval of the holders of at least 80 percent of the voting power of the shares generally entitled to vote. These provisions, along with the "fair price" provisions discussed above, the business combination and control share acquisition provision discussed below, may deter attempts to cause a change in control of our company (by proxy contest, tender offer or otherwise) and will make more difficult a change in control that is opposed by our board of directors.

**Liquidation Rights**

Subject to possible prior rights of holders of preferred stock that may be issued in the future, in the event of our liquidation, dissolution or winding up, whether voluntary or involuntary, the holders of our common stock are entitled to receive the remaining assets and funds pro rata, according to the number of shares of common stock held.

**Other Provisions**

Oklahoma has enacted legislation aimed at regulating takeovers of corporations and restricting specified business combinations with interested shareholders. Under the Oklahoma General Corporation Act, a shareowner who acquires more than 15 percent of the outstanding voting shares of a corporation subject to the statute, but less than 85 percent of such shares, is prohibited from engaging in specified "business combinations" with the corporation for three years after the date that the shareowner became an interested stockholder. This provision does not apply if (1) before the acquisition date the corporation's board of directors has approved either the business combination or the transaction in which the shareowner became an interested shareowner or (2) the corporation's board of directors approves the business combination and at least two- thirds of the outstanding voting stock of the corporation not owned by the interested shareowner vote to authorize the business combination. The term "business combination" encompasses a wide variety of transactions with or caused by an interested shareowner in which the interested shareowner receives or could receive a benefit on other than a pro rata basis with other shareowners, including mergers, specified asset sales, specified issuances of additional shares to the interested shareowner, transactions with the corporation that increase the proportionate interest of the interested shareowner or transactions in which the interested shareowner receives certain other benefits.

Oklahoma law also contains control share acquisition provisions. These provisions generally require the approval of the holders of a majority of the corporation's voting shares held by disinterested shareowners before a person purchasing one-fifth or more of the corporation's voting shares can vote the shares in excess of the one-fifth interest. Similar shareholder approvals are required at one-third and majority thresholds.

The board of directors may allot and issue shares of common stock for such consideration, not less than the par value thereof, as it may from time to time determine. No holder of common stock has the preemptive right to subscribe for or purchase any part of any new or additional issue of stock or securities convertible into stock. Our common stock is not subject to further calls or to assessment by us.

**Listing**

Our common stock is listed on the New York Stock Exchange.

**Transfer Agent and Registrar**

Computershare is the Transfer Agent and Registrar for our common stock.

------

## Exhibit 10.10

**Exhibit 10.10**

**OGE Energy Corp.**

**Director Compensation**

Compensation of non-management directors of OGE Energy Corp. ("OGE Energy") in 2025 included an annual retainer fee of $282,500, of which $115,000 was payable in cash in quarterly installments and $167,500 was deposited in the director's account under OGE Energy's Deferred Compensation Plan and converted to 3,889.0 common stock units based on the closing price of OGE Energy's Common Stock on December 9, 2025. In 2025, the independent directors did not receive additional compensation for attending Board or committee meetings but were instead paid a quarterly cash retainer. The lead director that served in 2025 received an additional $30,000 annual cash retainer in 2025. The chair of each of the committees that served in 2025 received an additional $20,000 annual cash retainer in 2025. Each member of the Audit Committee also received an additional annual cash retainer of $5,000. These amounts represent the total fees paid to directors in their capacities as directors of OGE Energy and Oklahoma Gas and Electric Company in 2025.

Under OGE Energy's Deferred Compensation Plan, non-management directors may defer payment of all or part of their quarterly and annual cash retainer fee, which deferred amounts in 2025 were credited to their account as of the scheduled payment date. Amounts credited to the accounts are assumed to be invested in one or more of the investment options permitted under OGE Energy's Deferred Compensation Plan. 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. When an individual ceases to be a director of OGE Energy, all amounts credited under OGE Energy's Deferred Compensation Plan are paid in cash in a lump sum or installments. In certain circumstances, participants may also be entitled to in-service withdrawals from OGE Energy's Deferred Compensation Plan.

On December 3, 2025, the Compensation Committee met to consider director compensation. At that meeting, the Compensation Committee recommended, and the Board subsequently approved, to make no changes in the annual cash retainer in 2026, and the annual equity retainer, credited on December 9, 2025, was increased from $160,000 to $167,500.

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## Exhibit 10.11

**Exhibit 10.11**

**OGE Energy Corp.**

**Executive Officer Compensation**

**Executive Compensation**

In December 2025, the Compensation Committee of the OGE Energy Corp. ("OGE Energy") board of directors took actions setting executives' salaries and target amount of annual incentive awards for 2026. In February 2026, the Compensation Committee took action setting executives' target amounts of long-term compensation awards for 2026. Executive compensation was set by the Compensation Committee after consideration of, among other things, individual performance and market-based data on compensation for executives with similar duties. Payouts of 2026 annual incentive award targets and performance-based long-term awards are dependent on achievement of specified corporate goals established by the Compensation Committee, and no officer is assured of any payout.

**Salary**

The Compensation Committee established the base salaries for its senior executive group. The salaries for 2026 for the OGE Energy officers who are expected to be named in the Summary Compensation Table in OGE Energy's 2026 Proxy Statement are listed in the following table.

---

| | |
|:---|:---|
| **Executive Officer** | **2026 Base Salary** |
| Sean Trauschke, Chairman, President and Chief Executive Officer | $1277994 |
| Charles B. Walworth, Chief Financial Officer | $644030 |
| William H. Sultemeier, General Counsel, Corporate Secretary and Chief Compliance Officer | $548912 |
| Donnie O. Jones, Senior Vice President - Utility Operations of OG&E | $482227 |
| David A. Parker, Chief Information Officer of OG&E | $389958 |

---

**Establishment of 2026 Annual Incentive Awards**

As stated above, at its December 2025 meeting, the Compensation Committee approved the target amount of annual incentive awards, expressed as a percentage of salary, with the officer having the ability, depending upon achievement of the 2026 corporate goals to receive from 0 percent to 200 percent of such targeted amount. For 2026, the targeted amount ranged from 75 percent to 120 percent of the approved 2026 base salary for the executive officers in the above table.

**Establishment of Long-Term Awards**

At its February 2026 meeting, the Compensation Committee approved the level of target long-term incentive awards, expressed as a percentage of salary. For the 2026 awards granted, the targeted amount ranged from 100 percent to 450 percent of the approved 2026 base salary for the executive officers receiving this long-term award in the above table. The performance-based portion of the long-term incentive awards allow the officer to receive from 0 percent to 200 percent of such targeted amount at the end of a three-year performance period depending upon achievement of the corporate goals. The time-based portion of the long-term incentive awards allow the officers to receive the granted amount at the end of a three-year vesting period depending upon continued employment.

**Other Benefits**

***Retirement Benefits.*** A significant amount of OGE Energy's employees hired before December 1, 2009, including executive officers, are eligible to participate in OGE Energy's Pension Plan and certain employees are eligible to participate in OGE Energy's Restoration of Retirement Income Plan that enables participants, including executive officers, to 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. In addition, the supplemental executive retirement plan, which was adopted in 1993 and amended in subsequent years, provides a supplemental executive retirement plan in order to attract and retain 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. Mr. Trauschke is the only employee who participates in the supplemental executive retirement plan.

Almost all employees of OGE Energy, including executive officers, also are eligible to participate in our 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 attained 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

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limitations thereof; (ii) an after-tax Roth contribution; or (iii) a contribution made on a non-Roth after-tax basis. 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 his or her 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. OGE Energy contribution for employees hired or rehired before December 1, 2009 varies depending on the participant's hire date, election with respect to participation in the Pension Plan and, in some cases, years of service.

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, 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 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 the Board of Directors of OGE Energy 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 incentive awards or (ii) eligible employees may elect a deferral percentage of base salary and annual incentive 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.

Normally, payments under the deferred compensation plan begin within one year after retirement. For these purposes, normal retirement age is 65 and the minimum age to qualify for early retirement is age 55 with at least five years of service. Benefits will be paid, at the election of the participant, either in a lump sum or a stream of annual payments for up to 15 years, or a combination thereof. Participants whose employment terminates before they qualify for retirement will receive their vested account balance in one lump sum following termination as provided in the plan. Participants also will be entitled to pre- and post-retirement survivor benefits. If the participant dies while in employment before retirement, his or her beneficiary will receive a payment of the account balance plus a supplemental survivor benefit equal to two times the total amount of base salary and annual incentive payments deferred under the plan. If the participant dies following retirement, his or her beneficiary will continue to receive the remaining vested account balance. Additionally, eligible surviving spouses will be entitled to a lifetime survivor annuity payable annually. The amount of the annuity is based on 50 percent of the participant's account balance at retirement, the spouse's age and actuarial assumptions established by OGE Energy's Plan Administration Committee.

At any time prior to retirement, a participant may withdraw all or part of amounts attributable to his or her vested account balance under the deferred compensation plan at December 31, 2004, subject to a penalty of 10 percent of the amount withdrawn. In addition, at the time of the initial deferral election, a participant may elect to receive one or more in-service distributions on specified dates without penalty. Hardship withdrawals, without penalty, may also be permitted at the discretion of OGE Energy's Plan Administration Committee.

***Perquisites.*** OGE Energy also offers executive officers a limited amount of perquisites. These include payment of social membership dues at dining and country clubs for certain executive officers, an annual physical exam for all executive officers, a relocation program and in some instances the use of a company car. In reviewing the perquisites and the benefits under the 401(k) Plan, Deferred Compensation Plan, Pension Plan, Restoration of Retirement Income Plan and supplemental executive retirement plan,

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the Compensation Committee seeks to provide participants with benefits at least commensurate with those offered by other utilities of comparable size.

***Change-of-Control Provisions and Employment Agreements.*** None of OGE Energy's executive officers has an employment agreement with OGE Energy. Each of the executive officers has a change of control agreement that becomes effective upon a change of control. If an executive officer's employment is terminated by OGE Energy "without cause" following a change of control, the executive officer is entitled to the following payments: (i) all accrued and unpaid compensation and a prorated annual incentive payout and (ii) a severance payment equal to 2.99 times the sum of such officer's (a) annual base salary and (b) highest recent annual incentive payout. The change of control agreements are considered to be double trigger agreements because payment will only be made following a change of control and termination of employment. The 2.99 times multiple for change-of-control payments was selected because at the time it was considered standard. Although many companies also include provisions for tax gross-up payments to cover any excise taxes on excess parachute payments, OGE Energy's Board of Directors decided not to include this additional benefit in OGE Energy's agreements. Instead, under OGE Energy's agreements if the excise tax would be imposed, the change-of-control payments will be reduced to a point where no excise tax would be payable, if such reduction would result in a greater after-tax payment.

In addition, pursuant to the terms of OGE Energy's incentive compensation plans, upon a change of control, all performance units will vest and be paid out immediately in cash as if the applicable performance goals had been satisfied at target levels; all restricted stock units will vest and be paid out immediately in cash; and any annual incentive award outstanding for the year in which the participant's termination occurs for any reason, other than cause, within 24 months after the change of control will be paid in cash at target level on a prorated basis.

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## Exhibit 21.01

**Exhibit 21.01**

**OGE Energy Corp.**

**Subsidiaries of the Registrant** 

---

| | | |
|:---|:---|:---|
| Name of Subsidiary | Jurisdiction of Incorporation | Percentage of <br>Ownership |
| Oklahoma Gas and Electric Company | Oklahoma | 100.0 |

---

The above listed subsidiary has been consolidated in the Registrant's financial statements. Certain of OGE Energy's subsidiaries have been omitted from the list above in accordance with Rule 1-02(w) of Regulation S-X.

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## Exhibit 23.01

**Exhibit 23.01** 

**Consent of Independent Registered Public Accounting Firm** 

We consent to the incorporation by reference in the following Registration Statements:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(1)Registration Statement (Form S-8 No. 333-92423) pertaining to the deferred compensation plan of OGE Energy Corp.,

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(2)Registration Statement (Form S-8 No. 333-104497) pertaining to the employees' stock ownership and retirement savings plan of OGE Energy Corp.,

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(3)Registration Statement (Form S-8 No. 333-190406) pertaining to the employees' stock ownership and retirement savings plan of OGE Energy Corp.,

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(4)Registration Statement (Form S-3ASR No. 333-279061) pertaining to common stock and debt securities of OGE Energy Corp.,

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(5)Registration Statement (Form S-8 No. 333-266540) pertaining to the OGE Energy Corp. 2022 Stock Incentive Plan of OGE Energy Corp., and

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;(6)Registration Statement (Form S-3ASR No. 333-274748) pertaining to the dividend reinvestment and stock purchase plan of OGE Energy Corp.;

of our reports dated February 17, 2026, with respect to the consolidated financial statements and schedule of OGE Energy Corp. and the effectiveness of internal control over financial reporting of OGE Energy Corp. included in this Annual Report (Form 10-K) of OGE Energy Corp. for the year ended December 31, 2025.

/s/ Ernst & Young LLP<br>

Oklahoma City, Oklahoma

February 17, 2026

------

## Exhibit 23.02

**Exhibit 23.02** 

**Consent of Independent Registered Public Accounting Firm** 

We consent to the incorporation by reference in the Registration Statement (Form S-3ASR No. 333-279061-01) of Oklahoma Gas and Electric Company and in the related Prospectus of our reports dated February 17, 2026, with respect to the financial statements and schedule of Oklahoma Gas and Electric Company, and the effectiveness of internal control over financial reporting of Oklahoma Gas and Electric Company, included in this Annual Report (Form 10-K) for the year ended December 31, 2025.

/s/ Ernst & Young LLP<br>

Oklahoma City, Oklahoma

February 17, 2026

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## Exhibit 24.01

**Exhibit 24.01** 

**Power of Attorney**

WHEREAS, OGE ENERGY CORP., an Oklahoma corporation (herein referred to as the "Company"), is about to file with the Securities and Exchange Commission, under the provisions of the Securities Exchange Act of 1934, as amended, its annual report on Form 10-K for the year ended December 31, 2025; and

WHEREAS, each of the undersigned holds the office or offices in the Company herein-below set opposite his or her name, respectively;

NOW, THEREFORE, each of the undersigned hereby constitutes and appoints SEAN TRAUSCHKE, CHARLES B. WALWORTH and SARAH R. STAFFORD and each of them individually, his or her attorney with full power to act for him or her and in his or her name, place and stead, to sign his or her name in the capacity or capacities set forth below to said Form 10-K and to any and all amendments thereto, and hereby ratifies and confirms all that said attorney may or shall lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned have hereunto set their hands this 17<sup>th</sup> day of February, 2026.

---

| | | |
|:---|:---|:---|
| Sean Trauschke, Chairman, Principal<br>&nbsp;&nbsp;&nbsp;&nbsp;Executive Officer and Director | /s/ | Sean Trauschke |
| Frank A. Bozich, Director | /s/ | Frank A. Bozich |
| Peter D. Clarke, Director | /s/ | Peter D. Clarke |
| Lyle G. Ganske, Director | /s/ | Lyle G. Ganske |
| Cathy R. Gates, Director | /s/ | Cathy R. Gates |
| David L. Hauser, Director | /s/ | David L. Hauser |
| Luther C. Kissam, IV | /s/ | Luther C. Kissam, IV |
| Judy R. McReynolds, Director | /s/ | Judy R. McReynolds |
| David E. Rainbolt, Director | /s/ | David E. Rainbolt |
| Sheila G. Talton, Director | /s/ | Sheila G. Talton |
| Charles B. Walworth, Principal Financial<br>&nbsp;&nbsp;&nbsp;&nbsp;Officer | /s/ | Charles B. Walworth |
| Sarah R. Stafford, Principal Accounting<br>&nbsp;&nbsp;&nbsp;&nbsp;Officer | /s/ | Sarah R. Stafford |

---

---

| | | |
|:---|:---|:---|
| STATE OF OKLAHOMA |) |  |
|  |) | SS |
| COUNTY OF OKLAHOMA |) |  |

---

On the date indicated above, before me, Kelly Hamilton-Coyer, Notary Public in and for said County and State, the above named directors and officers of OGE ENERGY CORP., an Oklahoma corporation, known to me to be the persons whose names are subscribed to the foregoing instrument, severally acknowledged to me that they executed the same as their own free act and deed.

IN WITNESS WHEREOF, I have hereunto set my hand and affixed my official seal on the 17<sup>th</sup> day of February, 2026.

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| |
|:---|
| /s/ Kelly G. Hamilton-Coyer |
| By: Kelly G. Hamilton-Coyer |
| *Notary Public* |

---

My commission expires: July 6, 2029

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## Exhibit 24.02

**Exhibit 24.02** 

**Power of Attorney**

WHEREAS, OKLAHOMA GAS AND ELECTRIC COMPANY, an Oklahoma corporation (herein referred to as the "Company"), is about to file with the Securities and Exchange Commission, under the provisions of the Securities Exchange Act of 1934, as amended, its annual report on Form 10-K for the year ended December 31, 2025; and

WHEREAS, each of the undersigned holds the office or offices in the Company herein-below set opposite his or her name, respectively;

NOW, THEREFORE, each of the undersigned hereby constitutes and appoints SEAN TRAUSCHKE, CHARLES B. WALWORTH and SARAH R. STAFFORD and each of them individually, his or her attorney with full power to act for him or her and in his or her name, place and stead, to sign his or her name in the capacity or capacities set forth below to said Form 10-K and to any and all amendments thereto, and hereby ratifies and confirms all that said attorney may or shall lawfully do or cause to be done by virtue hereof.

IN WITNESS WHEREOF, the undersigned have hereunto set their hands this 17<sup>th</sup> day of February, 2026.

---

| | | |
|:---|:---|:---|
| Sean Trauschke, Chairman, Principal<br>&nbsp;&nbsp;&nbsp;&nbsp;Executive Officer and Director | /s/ | Sean Trauschke |
| Frank A. Bozich, Director | /s/ | Frank A. Bozich |
| Peter D. Clarke, Director | /s/ | Peter D. Clarke |
| Lyle G. Ganske, Director | /s/ | Lyle G. Ganske |
| Cathy R. Gates, Director | /s/ | Cathy R. Gates |
| David L. Hauser, Director | /s/ | David L. Hauser |
| Luther C. Kissam, IV | /s/ | Luther C. Kissam, IV |
| Judy R. McReynolds, Director | /s/ | Judy R. McReynolds |
| David E. Rainbolt, Director | /s/ | David E. Rainbolt |
| Sheila G. Talton, Director | /s/ | Sheila G. Talton |
| Charles B. Walworth, Principal Financial<br>&nbsp;&nbsp;&nbsp;&nbsp;Officer | /s/ | Charles B. Walworth |
| Sarah R. Stafford, Principal Accounting<br>&nbsp;&nbsp;&nbsp;&nbsp;Officer | /s/ | Sarah R. Stafford |

---

---

| | | |
|:---|:---|:---|
| STATE OF OKLAHOMA |) |  |
|  |) | SS |
| COUNTY OF OKLAHOMA |) |  |

---

On the date indicated above, before me, Kelly Hamilton-Coyer, Notary Public in and for said County and State, the above named directors and officers of OKLAHOMA GAS AND ELECTRIC COMPANY, an Oklahoma corporation, known to me to be the persons whose names are subscribed to the foregoing instrument, severally acknowledged to me that they executed the same as their own free act and deed.

IN WITNESS WHEREOF, I have hereunto set my hand and affixed my official seal on the 17<sup>th</sup> day of February, 2026.

---

| |
|:---|
| /s/ Kelly G. Hamilton-Coyer |
| By: Kelly G. Hamilton-Coyer |
| *Notary Public* |

---

My commission expires:

July 6, 2029

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## Exhibit 31.01

**Exhibit 31.01** 

**CERTIFICATIONS**

I, Sean Trauschke, certify that:

1. I have reviewed this annual report on Form 10-K of OGE Energy Corp.;

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

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

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

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

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

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

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

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

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

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

Date: February 17, 2026

---

| |
|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;/s/ Sean Trauschke |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Sean Trauschke |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Chairman of the Board, President and Chief Executive Officer |

---

------

**CERTIFICATIONS**

I, Charles B. Walworth, certify that:

1. I have reviewed this annual report on Form 10-K of OGE Energy Corp.;

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

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

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

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

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

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

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

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

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

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

Date: February 17, 2026

---

| |
|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;/s/ Charles B. Walworth |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Charles B. Walworth |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Chief Financial Officer |

---

------

## Exhibit 31.02

**Exhibit 31.02** 

**CERTIFICATIONS**

I, Sean Trauschke, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: February 17, 2026

---

| |
|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;/s/ Sean Trauschke |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Sean Trauschke |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Chairman of the Board, President and Chief Executive Officer |

---

------

**CERTIFICATIONS**

I, Charles B. Walworth, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date: February 17, 2026

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| |
|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;/s/ Charles B. Walworth |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Charles B. Walworth |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Chief Financial Officer |

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## Exhibit 32.01

**Exhibit 32.01** 

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

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

In connection with the Annual Report of OGE Energy Corp. ("OGE Energy") on Form 10-K for the year ended December 31, 2025, as filed with the Securities and Exchange Commission (the "Report"), each of the undersigned does hereby certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of OGE Energy.

February 17, 2026

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| |
|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; /s/ Sean Trauschke |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Sean Trauschke |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Chairman of the Board, President and Chief Executive Officer |

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| |
|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; /s/ Charles B. Walworth |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Charles B. Walworth |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Chief Financial Officer |

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## Exhibit 32.02

**Exhibit 32.02** 

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

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

In connection with the Annual Report of Oklahoma Gas and Electric Company ("OG&E") on Form 10-K for the year ended December 31, 2025, as filed with the Securities and Exchange Commission (the "Report"), each of the undersigned does hereby certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of OG&E.

February 17, 2026

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| |
|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; /s/ Sean Trauschke |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Sean Trauschke |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Chairman of the Board, President and Chief Executive Officer |

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| |
|:---|
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; /s/ Charles B. Walworth |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp; Charles B. Walworth |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Chief Financial Officer |

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