PJM Files Plan to Shift Data Center Cost Burden Onto States
PJM's FERC filing last week forces state regulators to absorb costs from 30-34 gigawatts of AI-driven demand growth, rather than spreading them across its 67-million-customer base.
PJM Interconnection sent proposals to the Federal Energy Regulatory Commission during the week of 2026-07-27 that would make individual states responsible for managing the costs of data center load growth, rather than distributing them across PJM's full 13-state, 67-million-customer territory. FERC must approve the proposals before PJM can act on them.7
PJM forecasts that data centers and other large loads will add between 30 and 34 gigawatts of new demand to its system by the early 2030s. According to Canary Media's reporting, PJM is "making a definitive request to the states to accomplish what it needs" — language that signals the grid operator has concluded it cannot absorb this load without a structural change in how costs are allocated.7
The demand pressure is concentrated and visible. Just northeast of Columbus, Ohio, the township of New Albany hosts one of the densest clusters of AI computing in the country, with mile after mile of large data hall facilities. Intel is constructing a $28 billion chip factory at the northern end of the same industrial corridor. The load these facilities place on the PJM grid is what is driving the regulatory push.6
Storage developers are building into that demand. Elevate Infrastructure and ArcLight Capital Partners brought the 150-MW/600-MWh Prospect Power battery energy storage project online on June 11 (2026-06-11) in Rockingham County, Virginia, claiming it as the largest battery installation east of the Mississippi River. At the ribbon-cutting, developers argued that battery resources are becoming essential to grid reliability as electricity demand accelerates across Virginia and the broader PJM footprint.3
But storage additions are competing against a demand forecast with a wide margin of uncertainty. PJM's 30-to-34 GW range reflects genuine difficulty in predicting how quickly hyperscalers will energize capacity currently in development or permitting. Undershoot the build-out and you get reliability stress of the kind seen during the Independence Day weekend (2026-07-04), when severe storms knocked out power to more than 373,000 customers and a heat dome pushed demand close to historic highs, prompting grid operators to activate emergency conservation measures.5
Utilities are also pursuing longer-dated supply. Elementl Power announced on June 18 (2026-06-18) an agreement with GE Vernova Hitachi Nuclear Energy for a small modular reactor facility sited along the Ohio River about 100 miles southeast of Columbus, with planned capacity of up to 1.5 GW. SMR timelines remain long and uncertain, but the announcement signals that some developers view the Ohio load cluster as large enough to justify nuclear-scale commitments.4
Corporate consolidation is running in parallel. NextEra Energy's $67 billion all-stock deal to acquire Virginia-based Dominion Energy, announced on May 18 (2026-05-18), would create a combined entity serving roughly 10 million utility customer accounts across Florida, Virginia, North Carolina and South Carolina, with 110 gigawatts of generation. The combined enterprise value would reach approximately $420 billion, making it the third-largest US energy company and the biggest electricity acquisition since ExxonMobil acquired Mobil in 1998.1,2
Markets were skeptical at announcement. NextEra's stock fell nearly 5% on May 18 (2026-05-18) even as Dominion's rose 9%, with investors focused on whether NextEra had overpaid — the deal represented a 23% premium to Dominion's $54.3 billion market cap at the close on May 15 (2026-05-15). NextEra proposed $2.25 billion in customer bill credits spread over two years for Dominion customers in Virginia, North Carolina and South Carolina, partly to ease anticipated regulatory opposition.1,2
PJM Western Hub spot power was priced at $62.49 per MWh on August 5 (2026-08-05), reflecting current summer demand conditions rather than the structural load additions PJM is trying to plan around. NYMEX Henry Hub front-month gas was trading at $2.67 per MMBtu on August 6 (2026-08-06), cheap enough that Appalachian Basin gas-fired generation remains cost-competitive and there is no near-term fuel-cost pressure on PJM dispatch.
The immediate test is whether FERC accepts PJM's framing that states should carry the cost-allocation burden. If FERC pushes back and requires a different distribution mechanism, the investment signals for new generation and storage inside PJM shift materially. The Prospect Power battery in Virginia is already operating. The SMR project near Columbus is still years from first power. Everything in between — transmission upgrades, additional storage, gas peakers — depends on how FERC rules, and that decision has not yet been made.7,34