On October 30, Potomac Edison filed an application with the State Corporation Commission of Virginia seeking a Certificate of Public Convenience and Necessity for the Virginia portion of the Gore–Doubs–Goose Creek Improvements Project. It is the kind of document that will never make a ribbon-cutting photo, and it is exactly the kind of document on which the northern Virginia grid depends: a request to rebuild about 29 miles of 138-kilovolt transmission lines in Frederick, Clarke, and Loudoun counties, add 500-kV circuits along existing corridors, and build two new 138-kV lines between the existing Stonewall Substation and a proposed Woodside Substation near Clear Brook in Frederick County.
That sentence deserves unpacking, because the filing is simultaneously mundane and revealing. Nothing in it authorizes a single tower to go up. What it does is move a three-state transmission project one step through the permitting maze this desk has described before — the maze in which a line’s benefits are regional, its approvals are state-by-state, and any one jurisdiction along the route can say no. The Virginia application is the second of three state filings; the third has not yet been made. Construction, if approvals come, would not begin until 2028. The Virginia portion would enter service in December 2030. That is the story: a project awarded in 2023, filed state by state across 2026, built starting in 2028, energized in 2030. Seven years from award to in-service date, and that is the schedule going right.
What the filing actually covers
The project, as Potomac Edison describes it, is an upgrade to transmission lines that run through West Virginia, Maryland, and Virginia. The Virginia portion is a rebuild of approximately 29 miles of 138-kV lines across the three counties, located almost entirely within existing power line routes — a deliberate choice the company emphasizes as a way to limit effects on the environment and nearby communities. Two new 138-kV lines would connect the existing Stonewall Substation to the proposed Woodside Substation in Frederick County.
The voltage mix is the technically interesting part. Alongside the rebuilt 138-kV lines, the project would add new 500-kV lines to existing power line routes. Potomac Edison’s own analogy is a highway widening: more lanes on an existing roadbed, so more electricity can move at once, particularly during high-demand periods such as extreme heat or cold. The 138-kV rebuild maintains and modernizes the sub-transmission backbone that serves local load; the 500-kV overlay adds bulk transfer capacity on the same corridors. That is the corridor-by-corridor pattern of most transmission that actually gets built in the United States — not a greenfield backbone across new territory, but a bigger pipe fitted into an existing right-of-way.
The company says the upgrades, if approved, would help electricity travel cost-efficiently to communities, enhance grid reliability, help meet increasing electricity use, and make it easier to connect new electricity sources, including renewables. Chris Beam, FirstEnergy’s president of West Virginia and Maryland, framed it in the company’s announcement as a practical way to strengthen the existing grid for current customers while preparing for future demand. Those are the standard claims of a utility filing, and they should be read as such — but the underlying engineering claim is specific and testable: the corridors in question are the ones carrying power toward the fastest-growing load pocket in PJM.
Three states, three certificates
A Certificate of Public Convenience and Necessity is the permit that confirms a project is needed and meets the relevant statutory requirements. Potomac Edison needs one in each state the project crosses, and the filings have arrived in sequence rather than in parallel. The company filed its Maryland application with the Maryland Public Service Commission in March 2026. The Virginia application followed on October 30, 2026. A West Virginia application to that state’s Public Service Commission is expected next month.
The sequencing matters. Each proceeding has its own intervenors, its own standard of review, and its own timeline, and each can produce route changes, conditions, or delays that ripple into the others. The Virginia filing does not depend on the Maryland proceeding’s outcome in any formal sense, but a project that needs three certificates is only as far along as its slowest proceeding. Until West Virginia’s application is filed and all three commissions have acted, the 2028 construction start and December 2030 in-service date remain plans, not commitments. Potomac Edison’s announcement is careful on this point — “pending approvals” precedes both dates — and the caution is warranted.
It is also worth noting what the filing does not contain, at least in the company’s public announcement: a project-specific price tag. The announcement notes that the project is part of FirstEnergy’s $36 billion capital investment plan. That figure is corporate-wide, covering the company’s broader investment program, and it is not a stated cost for this line. Readers should not mistake it for one. The absence of a headline project cost in the announcement is itself a small lesson in how transmission economics reach the public: the numbers that matter for ratepayers will emerge in commission proceedings and PJM cost-allocation processes, not in press releases.
The 2023 award, and why it took this long to get here
PJM Interconnection, the grid operator for 13 states and the District of Columbia, awarded the project to Potomac Edison in 2023 after soliciting proposals to address system reliability concerns. The solicitation was driven by the load growth reshaping PJM’s planning: data-center demand, concentrated in northern Virginia, that was outrunning the transmission system’s ability to serve it reliably. FirstEnergy said at the time that PJM’s staff evaluated 72 proposals over several months before the PJM Board of Managers approved a short list of projects in December 2023, choosing designs that minimized environmental and community impacts by using existing rights-of-way.
The gap between that December 2023 award and the October 2026 Virginia filing — nearly three years — is not dead time, though it can look that way from outside. Between award and application sits route refinement, environmental and engineering study, landowner and community engagement, and the preparation of the evidentiary record a commission proceeding requires. That is the unglamorous middle of transmission development: the years in which a project on a planning map becomes a project with surveyed routes, substation sites, and a filing a regulator can act on. It is also the phase in which projects most often change shape, as route feedback and study results feed back into design.
The timeline also illustrates a structural point this desk has made before. Transmission planning operates on decade timescales while load growth does not wait for it. The reliability concerns PJM identified in 2023 were already pressing then; the Virginia portion of the answer, if everything goes to plan, arrives in December 2030. In the interim, the grid serving northern Virginia must absorb whatever load arrives with the infrastructure it already has, plus whatever interim measures — reconductoring, grid-enhancing technologies, operational adjustments — planners can deploy faster than a rebuilt corridor.
Why northern Virginia makes this filing different from an ordinary rebuild
A 29-mile rebuild in three rural and exurban counties would ordinarily be a routine reliability project, the kind that moves through a commission docket with modest attention. This one lands differently because of where it sits. Northern Virginia is home to the highest concentration of data centers on Earth, and the region’s load growth has become the central fact of PJM planning. This desk covered the July 22, 2026 event in which a normally cleared 230-kV fault in Dominion Energy’s territory triggered the loss of roughly 3,800 MW of data-center load — the largest such event in PJM’s history — and the subsequent push for reliability standards treating large computational loads as grid actors with enforceable obligations.
The Gore–Doubs–Goose Creek project is the other side of that story. The standards work governs how large loads behave when the grid is stressed. This project governs whether the wires into the region can carry the load in the first place. Both are responses to the same underlying condition: a load pocket growing faster than the transmission that serves it, in a planning system that identifies needs years before it can energize solutions. The filing’s emphasis on existing corridors is also a response to the political reality of building in the region — new rights-of-way through northern Virginia’s exurbs would face opposition that could stretch the timeline further still.
None of this makes the project a data-center project as such. Its stated purposes are system reliability, cost-efficient power movement, and accommodating growing electricity use generally, and its benefits would flow to all customers on the affected system. But it would be misleading to describe the filing without the load context that motivated PJM’s original solicitation. The lines are being rebuilt where they are, at the voltages proposed, because that is where the growth is.
What happens next
The immediate milestones are procedural, and they are worth tracking precisely because they are procedural. First, the expected West Virginia application next month, which completes the three-state set. Second, the Virginia commission’s proceeding itself: the schedule it sets, the intervenors who appear, and whether any party challenges the project’s need, its route, or its cost allocation. Third, the Maryland proceeding, already underway since March, and whether its outcome suggests anything about how the other two commissions will view the project. Fourth, and only after all three certificates are in hand, construction authorization and the mobilization of crews and equipment — large power transformers and specialized lineworkers being the supply-chain constraints that can bind even a fully permitted project.
There is also a question the filing does not answer and that will follow the project through its proceedings: who pays, and in what proportion. PJM projects are typically cost-allocated under the operator’s tariff, with regional beneficiaries sharing costs under FERC’s beneficiary-pays principle. The allocation for this project will be worked out through processes the press release does not detail, and it is the kind of question that can generate its own litigation. For now, the public record establishes need and scope; the bill comes later.
The timeline is the argument
It is tempting to read a filing like this as a nonevent — paper, not power lines — and move on to the next announcement. That would be a mistake. The Gore–Doubs–Goose Creek filing is a useful exhibit in the central argument about American transmission: the system is not failing to identify needed projects, and it is not failing to award them. PJM identified the need, solicited proposals, evaluated 72 of them, and awarded the project in 2023. What the system does slowly is everything after the award — the state-by-state approvals, the route work, the proceedings, the construction. Three years from award to the second state filing; two more years, at best, to construction; two more to energization.
If the Virginia portion enters service in December 2030, it will have taken seven years from PJM’s award to electrons on a rebuilt corridor — and that, by the standards of American transmission development, will count as a project that went reasonably well. That is the unglamorous truth the filing lays bare, and the reason it deserves more attention than a groundbreaking would. Groundbreakings celebrate the end of the hard part. Filings like this one mark the beginning of it, and the length of the road between the two is the story of the grid northern Virginia is actually getting.