PJM Interconnection capacity-auction prices hit regulatory price cap, indicating reserve margins shrinking and grid capacity severely constrained.

The latest PJM capacity auction clearing at its price cap is revealing deepening structural problems in the market's ability to attract new generation and demand response resources.

Julia Hoos, head of USA East at Aurora Energy Research, captured the core issue: "We knew that the shortfall was coming, but the outcome demonstrates that the current system doesn't work to bring online new capacity or stimulate demand response, the two things we need the most." According to Hoos, new generation requires "significantly more" than the $325/MW-day price cap to be financially viable.

The auction results underscore how tight supply and demand have become across PJM's 13-state footprint and the District of Columbia. Without the price collar, the auction would have cleared at nearly $555/MW-day across the region and $777/MW-day in PJM's Commonwealth Edison zone in northern Illinois. That would have cost $29.7 billion instead of the actual $16.4 billion. The amount of demand response that cleared the auction fell by 277 MW to 7,365 MW of unforced capacity, a troubling decline in a low-cost, quickly deployable resource. A roughly 2 GW increase in forecast demand, largely driven by data center development, also pressured the market.

For ratepayers, the near-term news is mixed. Since the auction cleared at roughly the same price as the previous one, electric bills should see little change when the delivery year begins June 1, 2028. However, industrial customers face steep increases: a 10-MW industrial customer's monthly capacity charge is projected to jump from around $6,000 in 2024 to roughly $70,000 in 2028, with Peter Cavan, head of strategy for Unison Energy, warning "Do not expect this to materially change in 2029/30."

The price cap itself may have created a new problem. Hoos warned: "The [planned] backstop auction was intended to be a one-off, but it's hard to see how we can return to normal after this. Lowering prices [with the price collar] was definitely politically attractive in the short term, but now we're well on our way to facing an intervention doom loop."

Regional disparities are glaring. The massive price separation between PJM and northern Illinois reflects transmission constraints. Clara Summers, director of the Citizens Utility Board's Consumers for a Better Grid Campaign, noted that last winter energy prices in the ComEd zone went negative due to congestion, but "transmission is needed to access capacity elsewhere when prices are high." Yet transmission planning remains inadequate.

The absence of demand response is particularly concerning to observers. Summers added: "It's clear that something isn't working when you see less of a low-cost and quick-to-deploy resource like DR showing up despite a high price environment."

Market participants and trade groups are calling for fundamental reforms. Jefferies equity analysts expect "long-term structural reforms in the [base residual auction] toward a continuing operating cost model with materially lower prices," noting that "reforming the PJM capacity auction for lower prices is among the single most impactful potential drivers of affordability." The Edison Electric Institute, representing investor-owned utilities, argued that "the status quo benefits generation owners and fails to attract sufficient new supply," leaving "customers to pay high capacity costs while also facing the risks of undersupply."

Competitive power suppliers have stepped in, with the Electric Power Supply Association reporting "tens of gigawatts of generation projects" since mid-2024, though these face barriers to development. Todd Snitchler, EPSA president and CEO, called for "continued progress on improving and accelerating permitting and siting processes, interconnection, load forecasting, policies that encourage investor certainty and development, and market reforms."

The Natural Resources Defense Council proposed addressing near-term issues by "removing large loads — like data centers — that have not brought their own new supply from the capacity auction," implementing a strong "Connect and Manage" construct, and ensuring "data centers pay for power plants and transmission built to serve them without risking public dollars."

Several major power producers reported higher cleared capacity. Constellation Energy cleared 18,875 MW, up from 17,950 MW, positioning it to garner about $2.2 billion in capacity revenue for 2028/29. Vistra cleared 10,924 MW (up from 10,566 MW) and Talen Energy cleared 10,180 MW (up from 8,745 MW), expecting $1.3 billion and $1.2 billion respectively in capacity revenue.