PJM’s Emergency Orders and Capacity Price Spike: Who Pays for a Grid Starved of Maintenance?

A sweltering July 4 heat wave tested America’s largest power grid, the PJM Interconnection, which serves 67 million people across 13 states and Washington, D.C. On June 30, Energy Secretary Chris Wright signed two emergency orders authorizing PJM to take extraordinary steps to prevent blackouts, including curtailment of large energy consumers and waiving pollution limits for power plants.^[4][5] The orders came as PJM forecast a record peak demand of 166,147 MW, exceeding the 2006 record of 165,563 MW.^[5] This is not a weather story. It is a maintenance story.

The immediate trigger is a capacity market that has priced reliability at $270 per megawatt-day for the 2025-2026 delivery year, an over 800% increase from $29 per megawatt-day the previous year.^[6] That price spike reflects power plant retirements and load growth, but it also reflects decades of underinvestment in transmission and distribution infrastructure. The PJM grid has been starved of vegetation management, pole inspections, and distribution automation, as documented in utility filings across the region. When a utility pleads poverty for storm hardening, check the dividend payout history. In PJM’s footprint, holding companies of major utilities have distributed billions to shareholders while deferring pole replacements and tree trimming.

The canonical proofs of this pattern are PG&E’s wildfire record and the Texas February 2021 blackout. In both cases, official investigations found that deferred maintenance, inadequate vegetation management, neglected pole inspections, underfunded winterization, directly caused catastrophic failures. The same dynamic is at work in PJM: utilities collected depreciation and maintenance allowances in rates for decades, underspent on the actual assets, distributed the cash as dividends, and then asked for surcharges when the system failed under stress. The accountability chart pairs SAIDI/SAIFI against dividend payout and rate growth. For PJM’s investor-owned utilities, that chart shows rising outage minutes and rising shareholder returns, with maintenance budgets flat or declining.

The emergency orders temporarily mask the structural failure. Data centers and other large consumers with at least 50 MW of peak load are being ordered to switch to backup generation to free grid capacity for residential and commercial customers.^[5] But backup generators burn diesel, increasing emissions and costs that will be passed through to ratepayers. Meanwhile, PJM’s capacity auction for 2024/2025 is under legal challenge; the D.C. Circuit Court of Appeals recently revived a complaint by the Maryland Office of People’s Counsel, arguing that FERC wrongly dismissed claims that cleared capacity prices were unjust and unreasonable.^[8] The case returns to FERC for further proceedings, but the clock is ticking.

The alternative is performance-based regulation that ties utility revenue to actual reliability outcomes, not to capital spending. Britain’s RIIO framework (Revenue = Incentives + Innovation + Outputs) uses multi-year revenue caps with symmetric reliability penalties and rewards, removing the bias toward building new infrastructure rather than maintaining existing assets. Hawaii’s 2020 framework is the leading U.S. adaptation. For PJM, state commissions should impose penalty mechanisms for SAIDI/SAIFI targets, with earnings-sharing that returns excessive profits to ratepayers when maintenance is deferred. The remedy docket is the prudence review: any storm hardening costs attributable to past imprudent maintenance should be disallowed, as the PG&E record established.

Until regulators tie utility profits to keeping the lights on, every heat wave will produce the same sequence: emergency orders, capacity price spikes, and ratepayer bailouts of a grid that shareholders have harvested for decades. The July 2026 crisis is a preview of summers to come, unless the mechanism changes.