When Winter Storm Elliott slammed the Eastern United States in December 2022, power plants across PJM Interconnection’s territory failed at a staggering rate. Generators responsible for roughly 46,000 megawatts of capacity tripped offline or could not start, forcing the grid operator to issue emergency alerts and leaving utilities scrambling to avoid rolling blackouts for the 65 million people it serves across 13 states and the District of Columbia. A joint inquiry by FERC and NERC later confirmed what grid watchers had feared: the same cold-weather failures documented after the 2014 Polar Vortex, the January 2018 cold snap, and the February 2021 crisis in Texas were repeating themselves, and the fixes recommended after each event had not been fully implemented.
Now the problem is getting worse. PJM, which coordinates the flow of electricity from New Jersey to Illinois and operates the largest wholesale power market in the country, has told federal regulators that its reserve margin, the cushion of spare generation that stands between normal operations and forced outages, is on track to fall below the minimum reliability standard within the next few years. The Federal Energy Regulatory Commission has responded with a burst of regulatory activity: new orders, technical conferences, and winter-event reviews that together paint a picture of a grid entering a period of heightened vulnerability just as electricity demand is surging.
A shrinking safety cushion
PJM’s reliability target calls for enough spare capacity to maintain a reserve margin of roughly 14.7 percent above projected peak demand. For years, the grid comfortably exceeded that number. But a combination of accelerating power-plant retirements and explosive load growth has begun to close the gap. PJM’s own load forecast, updated in January 2025, projected that peak summer demand across its footprint could grow by more than 40,000 megawatts over the next 15 years, driven in large part by a wave of data-center construction concentrated in northern Virginia, central Ohio, and other PJM zones.
At the same time, coal-fired plants that once provided a large share of PJM’s baseload generation are closing at a pace that outstrips the arrival of replacements. Between tightening environmental regulations, rising maintenance costs, and competition from cheaper natural gas and renewables, coal’s share of PJM’s generation mix has dropped from roughly 45 percent a decade ago to below 20 percent. Many of the remaining units have announced retirement dates in the late 2020s. Natural gas plants, while newer, face their own risks: during extreme cold, fuel supply constraints and equipment failures have repeatedly knocked gas-fired generators offline at the worst possible moments.
The July 2024 Base Residual Auction for the 2025/2026 delivery year offered a stark market signal. Capacity clearing prices across much of PJM jumped to roughly $270 per megawatt-day, up from about $29 the year before, an increase that reflected tightening supply conditions and will flow through to consumer bills. That price spike told generators and investors what regulators had been warning: the era of comfortable surplus is ending.
FERC steps in
FERC has taken several direct steps to address the gap. In a 2024 order, the commission directed PJM to overhaul its interconnection process, the queue through which new power plants, solar farms, battery storage projects, and wind installations must pass before they can connect to the grid and begin delivering electricity. That queue has become a bottleneck: thousands of projects representing hundreds of thousands of megawatts sit in various stages of study, many waiting five years or longer for approval. FERC’s order acknowledged that the current pace of connecting new generation is not keeping up with the rate of retirements, a mismatch that directly threatens the grid’s ability to serve peak demand.
Separately, FERC and the North American Electric Reliability Corporation published a joint staff report on the January 2025 Arctic event, cataloged under docket AD25-9-000. That review examined how generators performed during another bout of extreme cold and found, once again, that units failed to weatherize adequately and that fuel-supply chains broke down under stress. The pattern has now been documented across five major winter events in just over a decade, and each successive report has found that many of the same vulnerabilities persist.
FERC also convened a commissioner-led technical conference on resource adequacy that brought together grid operators, generators, state regulators, and consumer advocates from across the country. PJM submitted detailed filings to that proceeding. The discussions treated the challenge not as a distant planning exercise but as a near-term operational risk already shaping investment decisions and retirement timelines.
What it means for households and businesses
For the roughly 65 million people who depend on PJM’s grid, the stakes are personal. When reserve margins drop below the reliability standard during a severe cold front, grid operators have fewer tools to balance supply and demand. If available generation cannot meet consumption, PJM must order utilities to cut power to blocks of customers on a rotating basis to prevent cascading equipment failures that could cause longer, uncontrolled outages.
Households that rely on electric heat pumps, medical devices, or well pumps would lose service during the most dangerous weather of the year. Businesses could be forced to halt production. Critical services like water treatment plants and communications networks would fall back on diesel generators that may not be sized or fueled for extended runs. During Winter Storm Elliott, some PJM utilities came within minutes of ordering rolling blackouts, a scenario that grid officials have said could become more likely as margins tighten.
The financial ripple effects extend beyond any single storm. Tighter reserve margins are already influencing utility investment plans, insurance underwriting, and corporate site-selection decisions. Companies evaluating where to build new facilities, particularly energy-intensive operations like data centers and manufacturing plants, weigh grid reliability as a factor. When the operator of the nation’s largest grid signals that its margin of error is shrinking, state regulators and local officials face difficult tradeoffs between keeping electricity affordable and funding the infrastructure needed to maintain reliable service.
The data-center wildcard
One factor that has transformed PJM’s outlook in just the past two years is the explosive growth in electricity demand from data centers, driven by the expansion of cloud computing and artificial intelligence workloads. Northern Virginia’s “Data Center Alley” in Loudoun County already hosts the largest concentration of data centers on Earth, and new campuses are under development or proposed across PJM’s footprint in Ohio, Indiana, and other states.
PJM’s updated load forecasts reflect this surge, but the precise trajectory remains uncertain. Data-center developers often request grid connections for enormous blocks of power, sometimes hundreds of megawatts per facility, and the timing of when those loads actually materialize depends on construction schedules, corporate investment decisions, and the pace of AI adoption. If even a fraction of the projects currently in PJM’s interconnection queue come online on schedule, peak demand could grow faster than any historical precedent in the region. That would compress the timeline for reserve-margin shortfalls and increase the urgency of connecting new generation.
Gaps in the public record
Despite the volume of regulatory activity, several important details remain unclear. PJM’s filings to FERC’s technical conference reference tightening conditions in general terms but have not provided a single public figure projecting exactly how far below the 14.7 percent reliability standard the reserve margin could fall, or in precisely which delivery year the shortfall first appears. The specific capacity auction results and forward-looking calculations that would quantify the gap have not been broken down by fuel type, zone, or timeline in the commission’s publicly available proceeding documents reviewed for this report.
That distinction matters. A shortfall concentrated in a few zones where large coal plants are scheduled to close could potentially be managed through targeted transmission upgrades or local generation incentives. A system-wide deficit would require broader market reforms and significant new investment across the footprint. Without granular data, outside observers cannot fully assess whether the primary constraint is generation capacity, fuel deliverability, transmission congestion, or some combination of all three.
How effective FERC’s interconnection reforms will be is another open question. The commission ordered PJM to propose changes, but the rulemaking process itself takes time, and developers still face supply-chain constraints, permitting delays, and financing hurdles that no federal order can eliminate overnight. Whether the reforms will shorten queue timelines enough to close the gap before the next prolonged Arctic event is a bet that regulators, grid planners, and power companies are all making without a guaranteed outcome.
There is also uncertainty around how market participants will respond. Some generators may delay retirement decisions if they expect scarcity conditions to drive up capacity prices, temporarily easing the shortfall but raising costs for consumers. Others may proceed with closures based on corporate decarbonization commitments or local environmental pressures, regardless of market signals. FERC’s proceedings acknowledge these dynamics but do not yet resolve them.
Why regulators are treating this as urgent
The strongest evidence in this story comes directly from FERC’s own dockets and orders. When the commission tells the operator of a grid serving tens of millions of people to rewrite its rules, the signal is that existing procedures are failing to keep pace with physical reality. The directive to PJM, the joint FERC-NERC winter event reports, and the technical conference proceedings are primary regulatory documents carrying the weight of official findings and binding orders, not opinion or advocacy.
What separates this moment from earlier reliability debates is the convergence of multiple pressures at once: accelerating retirements, surging demand from data centers and electrification, persistent cold-weather generator failures, and an interconnection queue that cannot process new projects fast enough. Each of those challenges has been discussed individually for years. Their simultaneous arrival on PJM’s grid is what has pushed FERC from routine oversight into active intervention.
For consumers and policymakers, the most prudent reading of the available evidence is that the risk is real, directionally worsening, and unlikely to be resolved by any single policy fix. FERC’s actions represent a floor for concern, not a ceiling. The commission typically moves with this level of urgency only after problems have been documented across multiple events and regions. Until more detailed projections are released and the effects of interconnection reforms become measurable, the precise scale of the shortfall will remain uncertain. But the pattern is clear enough that grid operators, state regulators, and the millions of households that depend on PJM’s network are all planning as though the next deep freeze could be the one that tests the system’s limits.
More from Morning Overview
*This article was researched with the help of AI, with human editors creating the final content.
