The PJM Interconnection's Board of Managers has authorized additions and changes to the Regional Transmission Expansion Plan.
Among the projects approved Feb. 26 were those recommended to solve reliability needs identified in Window 1 of the 2024 Regional Transmission Expansion Plan (RTEP).
These projects address accelerated load growth in various areas of the PJM region, changes in the mix of generation resources and the resulting shifts to regional power flows. The forecasted demand growth is driven in part by data center load additions and the electrification of vehicles and building heating systems.
"The proposals resolve critical west-east regional transfer reinforcement needs by introducing 765 kV transmission lines connecting the AEP system in the western portion of the PJM footprint with the rest of the network in the central and southern parts of PJM, primarily Virginia. The work also includes several regional projects that are driven by more local needs," the grid operator said.
The collection of solutions is expected to require an investment of approximately $6 billion. Baseline reliability project allocations are calculated using a distribution factor methodology that allocates cost to the load zones most served by the new facility.
The selected regional transfer reinforcement projects were proposed through a collaborative planning initiative among transmission owners Dominion Energy, FirstEnergy and Transource, PJM said. "PJM further optimized and staged the projects to allow for an orderly development of assets as the electricity demand materializes, while advancing longer-lead transmission development components."
After the window for submissions closed Sept. 17, 2024, PJM discussed the proposed solutions extensively with stakeholders, members and ratepayers attending the Oct. 8, Nov. 6, Nov. 19, Dec. 3, 2024, and Jan. 7, 2025 , meetings of the Transmission Expansion Advisory Committee (TEAC).
In addition to receiving verbal feedback and comments during the TEAC meetings, PJM requested that written comments be submitted to communicate any concerns with project recommendations. PJM received significant stakeholder feedback and follow-up inquiries. PJM said it considered all feedback received in deciding which solutions to recommend to the PJM Board for approval. PJM will be publishing to the PJM website a summary of the comments received together with PJM responses.
Now that the projects have been approved, the developers will initiate more detailed routing, siting and consultation activities as part of the established state approval regulatory process. PJM does not choose the exact route, seek siting approvals or develop the projects; that is up to the individual project developers.
Changes to Previously Approved Projects
The Board also approved a revised cost estimate for the Brandon Shores Deactivation Project. The total cost has increased from $738.83 million to $1,513.96 million. The scope of the project has not changed.
The increases are due to a higher cost of long lead equipment, changes resulting from detailed design and engineering, constructability reviews, additional contracting resources and the significant volume and complexity of work, according to PJM.
Also as part of Board approval, three baseline projects were canceled in the ATSI, JCPL and AEP zones, removing $48.7 million from the RTEP. The Board approved two other scope changes as well for two projects with a net increase of approximately $7.8 million.
Full details of the projects are posted on PJM.com.
PJM’s RTEP analysis identifies system violations to reliability criteria and standards, determines the potential to improve the market efficiency and operational performance of the system, and incorporates any public policy requirements. PJM then develops transmission system enhancements to be integrated into a regional solution set and reviews them with stakeholders through the TEAC before submitting its recommendations to the Board.
Follow all projects through the process with PJM’s Project Status & Cost Allocation page.
