utility power

PJM’s Capacity Auction Sends a Message: Big Load Demand is Repricing Power. Buildings Will Feel the Impact.

Energy & Solar Integration
January 21, 2026•7 min read

By Keith Reynolds

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The hottest signal in the Mid-Atlantic power market right now is not a new data center announcement or a flashy battery project. It is a number most real estate owners never see until it shows up in a utility bill: the price of “capacity,” the grid’s insurance policy against blackouts.

In PJM’s latest base residual auction — the market that pays power plants (and demand response providers) to be available years in advance — prices again hit the top of the allowed range. PJM also said the auction cleared short of its reliability requirement, a rare and uncomfortable outcome that underscores how quickly load forecasts have shifted. PJM’s own summary was blunt: Data centers’ demand for electricity continues to outstrip new supply.

For real estate investors, planners and property managers, the capacity market is not an inside-baseball grid story. It is a leading indicator for the long-run price expectations that filter into commercial bills, tenant negotiations and underwriting — especially in PJM territory, which spans 13 states and Washington, D.C., and serves about 67 million people.

Capacity is the quiet line item that becomes a loud cost

If energy is the electricity you use minute to minute, capacity is what you pay for the grid to have on standby when demand spikes — the hottest summer afternoons and cold winter mornings, when the system is most stressed. In PJM, those standby commitments are bought through auctions held well before the delivery year, meaning they embed forward-looking assumptions about demand growth, retirements and what kinds of resources will actually show up when called.

That matters to commercial customers because many suppliers and utilities pass capacity costs through in retail rates. Even when a property’s usage is steady, capacity-driven rate pressure can show up as higher supply charges, new riders, or more aggressive demand-related tariffs. For large users — campuses, logistics facilities, big-box retail, healthcare portfolios and master-metered multifamily — capacity costs can become a material piece of the total electricity spend

PJM reported that the cleared supply times the clearing price totals about $16.4 billion for the 2027/2028 delivery year, though PJM cautioned that not all load pays that clearing price because some is hedged through self-supply and bilateral contracts.

The core driver: load forecasts that moved faster than supply

PJM said the forecast peak load for the 2027/2028 delivery year was about 5,250 megawatts higher than what was used for the prior auction — and that nearly 5,100 megawatts of that increase was attributable to data center demand.

That is the part CRE teams should underline. These are not “someday” loads in a national forecast. They are regionally concentrated, large, and increasingly time-sensitive — and the market is attempting to price reliability around them before all of them are built.

The grid’s independent market monitor has warned that data center forecasts are injecting unprecedented uncertainty into auctions that were designed for steadier, more predictable load growth. In a report summarized by Utility Dive, the monitor estimated that data center load accounted for $6.5 billion, or 40%, of the $16.4 billion in costs from PJM’s December capacity auction — with most of that tied to projected data centers that have not yet been built.

The monitor also flagged a structural concern that resonates beyond PJM: if a capacity auction clears based on aggressive forecasts that later do not materialize on schedule, ratepayers could be paying for “insurance” sized to a world that arrived late.

Reliability debates are becoming governance debates

One reason capacity is in the headlines is that PJM said the auction cleared 6,623 megawatts short of its reliability requirement for the one-event-in-10-years standard, even though PJM emphasized that this does not necessarily mean it cannot serve load in that delivery year. PJM cited mitigating factors such as potential reductions in peak demand forecasts, possible extensions of generator retirements, and other resources expected to be available.

That shortfall and the price outcomes have pushed grid policy — usually a technical domain — into mainstream political and regulatory conflict. The Associated Press reported that federal officials and governors pressed PJM to take steps to boost power supplies and limit price hikes, including ideas aimed at shifting more cost responsibility to large new loads rather than existing customers.

Meanwhile, PJM has moved to tighten how it handles large-load interconnections and emergency operations. Reuters reported that PJM outlined a plan that would require new large power users to bring their own generation or participate in a “connect and manage” framework subject to early curtailment, among other measures.

For developers and planners, those proposals translate into a practical question: when a region is power-constrained, do large loads get connected as a matter of right — or as a negotiated privilege that comes with curtailment and self-supply obligations?

What this means for buildings and tenant deals

Capacity-market outcomes don’t just “happen” to building owners. They shape three core parts of portfolio strategy:

1) Underwriting and operating expense risk

When forward prices hit caps and reliability margins tighten, the market is signaling that future power is expected to be scarce (or expensive) at the margin. That does not automatically mean every customer’s bill explodes — hedges, retail contracts and state policy all matter — but it increases the probability of sustained rate pressure. Owners with energy-intensive tenants are more likely to see operating expenses become a leasing issue, not just a facilities issue.

2) Lease language gets more sophisticated

As curtailment becomes a real tool — and as utilities and grid operators discuss load flexibility — “power availability” starts to look like water rights or parking ratios: something that can be negotiated, constrained, and priced. Expect more requests for clauses covering: backup generation, demand response participation, limits on peak demand, and what happens during emergency curtailment events.

3) On-site flexibility becomes a competitive advantage

The capacity market rewards reliability, and the cheapest way to improve reliability is often not building a new plant. It is shaving peaks, shifting load, and aggregating behind-the-meter resources. In CRE terms: batteries, intelligent building controls, thermal storage, and managed EV charging can become “bill insurance” — not because they make energy free, but because they help a property avoid being exposed to the most expensive hours and demand charges.

The CRE playbook: treat “flex” as infrastructure

Here is the non-obvious takeaway from PJM’s capacity signal: buildings that can flex load will increasingly outcompete buildings that only consume.

That does not require turning every property into an energy project. It does require moving beyond “how many chargers do we have?” to “how do we manage our peak, our tariff, and our tenant expectations?”

A practical starting point for owners and planners in PJM territory:

  • Benchmark your exposure: Ask your supplier or utility how capacity and peak-related components flow through your bill and what drives them.

  • Build the control layer first: A modern building management system that can coordinate HVAC schedules, EV charging and onsite storage is often the highest-leverage investment.

  • Use storage strategically: Batteries do not have to be huge to be valuable — they have to be sized to your peaks and your tariff.

  • Design “EV-ready” with constraints in mind: Conduit and panel capacity today can prevent expensive rework later, but load management is what keeps the utility bill from becoming a surprise.

PJM’s auction results are a reminder that electricity is no longer a background utility expense in many growth markets. It is becoming a managed input — one that shows up in cap rates, tenant retention and development timelines.

Key sources and further reading

PJM capacity auctionMid-Atlantic power marketelectricity capacity pricescommercial real estate energy costsgrid reliabilitycapacity market signals
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