OLD DOMINION ELECTRIC COOPERATIVE

Generating Facility · OwnershipInterest · Location · PrimaryFuel · CommercialOperation Date · Net CapacityEntitlement (1)

Wildcat Point · 100 · Cecil County, Maryland · Natural Gas · 04/2018 · 980 MW

North Anna · 11.6 · Louisa County, Virginia · Nuclear · Unit 1 – 06/1978 (2)Unit 2 – 12/1980 (2) · 110 MW110 MW

220 MW

Clover · 50 · Halifax County, Virginia · Coal · Unit 1 – 10/1995Unit 2 – 03/1996 · 220 MW218 MW

438 MW

Louisa · 100 · Louisa County, Virginia · Natural Gas (3) · 06/2003 · 504 MW

Marsh Run · 100 · Fauquier County, Virginia · Natural Gas (3) · 09/2004 · 504 MW

Distributed Generation · 100 · Multiple · Diesel · 07/200205/2016 · 20 MW6 MW

26 MW

Total · 2,672 MW

Net capacity entitlement represents (a) the projected maximum dependable capacity in summer conditions for Wildcat Point, (b) an approximation of our entitlement to the maximum dependable capacity in summer conditions for North Anna and Clover, and (c) a nominal average of summer and winter capacities for Louisa and Marsh Run.

We purchased our 11.6% undivided ownership interest in North Anna in December 1983.

The units at this facility also operate on No. 2 distillate fuel oil as an alternate fuel source.

Wildcat Point

Wildcat Point is a combined-cycle generation facility that consists of two combustion turbines, two heat recovery steam generators, and one steam turbine generator. We are responsible for the operation and maintenance of Wildcat Point and we supply all services, goods, and materials required to operate and maintain the facility, including arranging for the transportation and supply of the natural gas required by the facility.

North Anna

Virginia Power is responsible for operating and procuring nuclear fuel for North Anna. See “Power Supply Resources—Fuel Supply—Nuclear” in Item 1. We are entitled to 11.6% of the power generated by North Anna. We are responsible for and must fund 11.6% of all post-acquisition date additions and operating costs associated with North Anna, as well as a pro-rata portion of Virginia Power’s administrative and general expenses directly attributable to North Anna. In addition, we separately fund our pro-rata portion of the decommissioning costs of North Anna. ODEC and Virginia Power also bear pro-rata any liability arising from ownership of North Anna, except for liabilities resulting from the gross negligence of the other.

In 2024, the NRC renewed the operating licenses for an additional 20 years for both units at North Anna. The operating licenses now extend through April 1, 2058, and August 21, 2060, for North Anna Unit 1 and Unit 2, respectively.

Clover

Virginia Power, the co-owner of Clover, is responsible for operating, and procuring and arranging for the transportation of the fuel required to operate Clover. See “Power Supply Resources—Fuel Supply—Coal” in Item 1. ODEC and Virginia Power are each entitled to half of the power generated by Clover. We are

responsible for and must fund half of all additions and operating costs associated with Clover, as well as half of Virginia Power’s administrative and general expenses directly attributable to Clover. When Clover was constructed in 1995, it was intended to operate as a baseload generating facility. As changes in the industry have occurred, Clover now serves us principally as a capacity resource with on-site storage of fuel. In this role, Clover is dispatched by PJM when it is economical or required for reliability.

The Virginia Clean Economy Act requires that substantially all investor-owned utility generating facilities that emit CO2 as a by-product of combustion close by December 31, 2045, which would include Clover. However, if the reliability or security of providing electric service to customers is threatened, a petition may be made by Virginia Power to the VSCC requesting relief from the closure requirement.

In 2024, the EPA published a final rule containing performance standards for both new and existing generating units for reducing CO2 emissions. The rule, which is subject to legal challenges, includes emissions guidelines that set limits for new gas-fired combustion turbines, existing coal, oil, and gas-fired steam generating units, and certain existing gas-fired combustion turbines. On June 17, 2025, the EPA published a proposed rule to repeal a rule that became effective on July 8, 2024. The EPA’s proposed rule contained two alternative proposals. The EPA requested comments on the 2025 proposed rule by August 7, 2025. For further discussion, see “Regulation—Environmental—Clean Air Act (“CAA”)—CAA Performance Standards for GHGs for New and Existing Electric Generating Facilities” in Item 1.

Combustion Turbine Facilities

Louisa

Louisa consists of five combustion turbines. We are responsible for the operation and maintenance of Louisa and we supply all services, goods, and materials required to operate and maintain the facility, including arranging for the transportation and supply of the natural gas and No. 2 distillate fuel oil required by the facility.

Marsh Run

Marsh Run consists of three combustion turbines. We are responsible for the operation and maintenance of Marsh Run and we supply all services, goods, and materials required to operate and maintain the facility, including arranging for the transportation and supply of the natural gas and No. 2 distillate fuel oil required by the facility.

Distributed Generation Facilities

• OPERATIONAL RISKS
• We may have operational deficiencies or catastrophic events related to our generating or transmission facilities.
• We are subject to fuel procurement and delivery risks.
• Construction of new, or expansion of existing, generating and transmission facilities may not result in the anticipated value to our power supply resource portfolio.
• We are subject to risks associated with owning an interest in a nuclear generating facility.
• Failure to attract and retain a qualified workforce could have an adverse effect on our operations.
• If we are unable to protect our information systems against service interruption, misappropriation of data, or breaches of security, our operations could be disrupted and our reputation may be damaged.
• Technological advancements and other changes impacting power requirements of our member distribution cooperatives’ customers may alter energy and demand requirements for power from us.
• War, acts and threats of terrorism, sabotage, natural disasters, extreme weather events, pandemics, and other catastrophic events could adversely affect our operations.