The next time a brutal cold front locks in over the Mid-Atlantic and Midwest for several days, the electric grid serving 65 million people may not have enough power plants running to keep the lights on. That is the core warning now moving through federal regulatory channels after PJM Interconnection, the organization that coordinates the largest power grid in the United States, projected that its reserve margins could fall below mandatory reliability standards as soon as the 2027/2028 delivery year.
PJM’s territory stretches across all or part of Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia, and the District of Columbia. The grid operator’s own planning data, reinforced by the North American Electric Reliability Corporation’s 2024 Long-Term Reliability Assessment, shows that demand is climbing faster than new firm generation is being built, while older coal and gas plants continue to retire. NERC categorized parts of PJM’s footprint as facing “elevated risk” of insufficient supply during peak conditions, a designation that has sharpened federal attention.
Federal regulators are treating this as a present-tense problem
Three recent actions at the Federal Energy Regulatory Commission signal that Washington views PJM’s tightening margins as urgent, not theoretical.
On February 19, 2026, FERC and NERC held a joint briefing on long-term reliability findings that placed PJM’s reserve-margin trajectory squarely on the federal agenda. The session confirmed that the supply-demand imbalance is being tracked at the highest levels of grid oversight, not just inside PJM’s market operations.
Separately, FERC Commissioner David Rosner filed a formal concurrence to an order accepting tariff revisions under docket ER26-455. Rosner drew a direct line between PJM’s recent capacity auction results and the flood of large-load interconnection requests, many of them from data center developers and industrial electrification projects, arguing that the mismatch between new demand and new supply has become a tangible near-term threat. PJM’s 2025/2026 Base Residual Auction had already cleared at record-high prices, a market signal that available generation is growing scarce relative to projected need.
Third, the institutional memory of what happens when winter stress meets an unprepared grid is well documented. FERC’s final report on the February 2021 freeze established that extreme cold triggers cascading outages when generating plants lack proper winterization and when natural gas pipelines and power plants fail to coordinate fuel delivery. That disaster left millions without heat in Texas and neighboring states for days.
Winter Storm Elliott showed PJM is not immune
The 2021 freeze hit hardest in the South and Central U.S., but PJM’s own stress test came less than two years later. During Winter Storm Elliott on December 23-24, 2022, temperatures plunged across PJM’s footprint and roughly 46,000 megawatts of generation, nearly a quarter of the fleet, experienced forced outages or significant output reductions. PJM narrowly avoided rolling blackouts by issuing emergency alerts and leaning on demand response. A joint FERC-NERC inquiry into Elliott found many of the same failures identified after the 2021 freeze: generators that had not been adequately weatherized, fuel supply disruptions, and communication breakdowns between gas pipelines and power plants.
Elliott demonstrated that the vulnerabilities exposed in Texas are not confined to southern grids. PJM’s mix of aging coal units, gas-fired plants dependent on just-in-time fuel delivery, and weather-sensitive renewables leaves limited margin for error when a deep cold snap persists for more than 24 hours.
Demand is surging while supply additions lag
The supply side of PJM’s equation is under pressure from two directions. Retirements of coal-fired and older gas-fired plants are accelerating, driven by economics, environmental regulations, and age. At the same time, the interconnection queue is clogged. PJM reported that its queue held more than 260 gigawatts of proposed projects as of late 2024, the vast majority of them solar, wind, and battery storage. But the queue’s backlog means that only a fraction of those projects will reach commercial operation in time to offset retirements before 2027.
On the demand side, large-load growth is rewriting forecasts that had been essentially flat for a decade. Data center campuses in Virginia’s “Data Center Alley” and across Ohio, Indiana, and Pennsylvania are requesting grid connections measured in hundreds of megawatts each. Industrial electrification, including hydrogen production and advanced manufacturing, adds further load. PJM revised its peak-demand forecast upward significantly in its most recent planning cycle, and Commissioner Rosner’s concurrence suggests that even those revised numbers may understate the pace of growth if a large share of queued projects proceed on schedule.
Not all of that demand will materialize on time. Data center developers frequently reserve capacity years before breaking ground, and some projects are delayed or canceled by financing, permitting, or market shifts. If a meaningful share of queued load drops out, the reliability picture improves without any new generation being built. But if most projects proceed as planned, the gap between supply and demand widens faster than current planning assumes.
PJM has moved to reform its capacity market, but the clock is tight
PJM is not standing still. In 2024, the grid operator completed its Critical Issue Fast Path (CIFP) process, an expedited stakeholder effort that produced changes to capacity market rules designed to better value reliability during extreme conditions. Those reforms, which FERC approved, adjust how generators are compensated for being available during winter peaks and tighten performance penalties for plants that fail to deliver during emergencies.
Whether those reforms translate into enough new or retained generation by the 2027/2028 delivery year is an open question. Building a new gas-fired peaking plant typically takes three to four years from permitting to operation. Battery storage projects can move faster but face supply-chain constraints. Demand-side resources like efficiency programs and interruptible industrial loads can help at the margins but are unlikely to close a large structural gap on their own.
Winterization compliance is another unresolved variable. FERC’s post-2021 recommendations called for mandatory cold-weather reliability standards, and NERC has moved toward enforceable rules. But the pace and completeness of adoption across the hundreds of generating units in PJM’s territory is not detailed in available federal filings. A system with adequate capacity on paper can still fail in practice if too many units trip offline when temperatures plunge below design thresholds.
What this means for 65 million people in PJM’s footprint
None of the federal documents reviewed here prove that a specific storm in a specific year will cause blackouts. Weather patterns, fuel prices, plant performance, and emergency responses all shape outcomes. A mild winter could pass without incident even in a tight capacity environment, while a once-in-a-generation cold wave could overwhelm a system that appears adequate on average.
But the direction of the evidence is clear: PJM’s reliability buffer is shrinking at the same time demand is accelerating, and the winter resilience problems identified after both the 2021 freeze and Winter Storm Elliott have not been fully resolved. The window for adding firm generation or hardening existing plants before the next major cold event is narrowing.
For households, that means the value of basic preparedness is rising. Backup heating plans, battery-powered lighting and communications, knowledge of local warming centers, and an understanding of how emergency alerts work in your county are no longer abstract precautions. They are practical steps for a grid environment where the margin between normal operations and emergency conditions is thinner than it has been in years.
For businesses that depend on uninterrupted power, from hospitals and grocery chains to the very data centers driving demand growth, contingency planning around on-site generation, fuel storage, and load-shedding protocols deserves fresh scrutiny.
For policymakers and regulators, the path forward is narrow but actionable: accelerate winterization enforcement, improve gas-electric coordination, clear the interconnection backlog, and align capacity procurement with the reality of large-load growth. The federal record now makes plain that the vulnerabilities are identified and the tools exist. What remains scarce is time.
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*This article was researched with the help of AI, with human editors creating the final content.
