Federal regulators took two separate emergency actions targeting data centers and other large electricity consumers whose rapid expansion is threatening grid reliability across the eastern United States. The Federal Energy Regulatory Commission ordered all six regional transmission organizations and independent system operators under its jurisdiction to justify or reform their tariff rules for connecting large loads. Days later, the Department of Energy invoked rarely used emergency authority under the Federal Power Act to let PJM Interconnection direct backup generators at data centers and similar facilities to run during a dangerous heatwave in the Mid-Atlantic. Together, the moves represent the most aggressive federal intervention yet into how the nation’s power grid absorbs the surge of electricity demand driven by artificial intelligence infrastructure and cloud computing.
Why two federal agencies acted on data-center grid strain at once
The twin actions reflect a single problem that has outpaced normal regulatory timelines: large electricity customers, led by data centers, are requesting grid connections faster than utilities and grid operators can build the transmission and generation capacity to serve them. FERC’s show-cause proceedings target the formal interconnection process itself. The commission ordered all six jurisdictional RTOs and ISOs to demonstrate that their existing tariff rules adequately protect both reliability and ratepayers as these large loads come online. If any grid operator cannot make that case, FERC can compel tariff changes, including new fees, faster study timelines, or stricter technical requirements for large-load applicants.
The DOE’s action addressed the immediate physical risk rather than the procedural backlog. Under Section 202(c) of the Federal Power Act, the Energy Secretary issued Order No. 202-26-06 authorizing PJM to direct data centers and other large-load customers to activate their on-site backup generators during periods of extreme grid stress. That authority is a last-resort reliability tool, reserved for conditions where normal market operations cannot keep the lights on.
A central question raised by FERC’s proceedings is whether tariff reforms will speed up or slow down large-load interconnection. One hypothesis holds that uniform reforms could shorten timelines in at least three RTOs by mid-2026 while raising average interconnection fees by more than 15 percent. No primary document in the current record contains specific fee projections or timeline commitments at that level of detail. The show-cause orders require each grid operator to respond, but the resulting reforms, if any, will depend on what the filings reveal about queue backlogs, cost allocation, and technical capacity in each region.
Emergency backup orders and FERC proceedings in the record
The DOE’s emergency order is narrow in scope but broad in signal. The full text of the order spells out the conditions under which PJM can require backup generation to run: only when grid conditions deteriorate to the point that voluntary conservation and market-based tools have been exhausted. The Energy Secretary’s announcement explicitly tied the order to a heatwave bearing down on the Mid-Atlantic, linking extreme weather to the structural strain that data centers place on a transmission system originally built for a different load profile.
For households and businesses in PJM’s territory, which stretches from New Jersey to Illinois, the practical effect is that diesel and natural-gas backup generators at large commercial facilities could be ordered to fire up during peak demand. That keeps the grid from shedding residential load, meaning fewer rolling blackouts, but it also raises local air-quality concerns that the order’s primary documents do not address with quantitative emissions estimates. State environmental regulators and local governments may face pressure to reconcile short-term reliability needs with longer-term pollution-reduction goals if backup units run frequently in densely populated areas.
FERC’s proceedings operate on a longer timeline but carry wider geographic reach. The commission’s action covers every major wholesale electricity market in the country, not just PJM. Each RTO and ISO must now open its tariff books and defend how it handles large-load requests. The proceedings place data centers squarely in the regulatory spotlight, treating their grid impact as a systemic issue rather than a series of individual interconnection applications. Depending on how aggressively FERC responds to the filings, the outcome could reshape how and where new digital infrastructure is built for years to come.
Unanswered questions about costs, timelines, and emissions
Several gaps in the public record limit how far anyone can project the outcome of these actions. FERC’s show-cause orders do not name specific data-center projects or disclose aggregate load volumes in each RTO’s queue. Without those figures, it is difficult to estimate how much new transmission investment will be needed or how costs will be split between data-center operators and existing ratepayers. The filings that grid operators submit in response will be the first window into those numbers, offering clues about whether the current wave of large-load requests is a temporary surge or a structural shift in electricity demand.
The DOE’s emergency order similarly lacks detail on how long or how often backup generators might need to run. No runtime forecasts or cumulative emissions projections appear in the published documents. That leaves open the question of whether repeated use of the 202(c) authority could become a recurring feature of summer grid management rather than a one-time emergency measure. If PJM were to rely on backup units during multiple heatwaves or winter cold snaps, the legal and political pressure to narrow or replace that authority with more durable solutions would likely grow.
No public statements from PJM itself or from affected data-center operators appear in the primary federal documents released so far. That silence matters because the practical success of both the FERC reforms and the DOE’s backup-generation authority depends on cooperation from the companies building and operating these large facilities. Data-center operators will ultimately decide whether to accept higher interconnection costs, relocate projects to less congested regions, or invest in on-site resources such as battery storage and renewable generation to reduce their impact on the bulk power system.
State regulators and local communities also sit at the center of these unresolved questions. Land-use approvals, air permits for backup generators, and state-level reliability standards will all influence how quickly new data centers can move from proposal to operation. If federal reforms accelerate interconnection studies but state or local opposition intensifies over noise, traffic, and emissions, the net effect on project timelines could be modest. Conversely, coordinated planning among federal agencies, states, and grid operators could channel data-center growth toward locations where existing infrastructure can absorb the load with fewer upgrades.
For now, the record shows a federal government trying to catch up to a technology-driven demand shock using both emergency tools and procedural reforms. FERC is asking whether the rules for connecting large loads still work in an era dominated by data traffic rather than heavy industry, while DOE is using its emergency authority to prevent near-term blackouts as that question is answered. The next set of filings from grid operators, and any follow-on actions from the agencies, will determine whether these interventions become a bridge to a more robust grid or a recurring feature of a system perpetually on the edge of its capacity.
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*This article was researched with the help of AI, with human editors creating the final content.
