As we enter the new year, Vineyard families — like many across the Northeast — are bracing for a familiar shock: the financial gut punch of opening their utility bills. Electricity in the region is already among the most expensive in the country, and winter is when prices reliably spike. And yet the Trump administration chose this moment to suspend five offshore wind projects that would collectively add more than 7 gigawatts of new generation to the Northeast’s energy grid — enough electricity to power well over two million homes once fully operational.
The order — issued in late December, just weeks after a federal judge ruled that Trump’s broad wind-permit halt was unlawful — stops work for 90 days under a vaguely defined “national security” review. The projects include Vineyard Wind; Revolution Wind, in Rhode Island and Connecticut; Coastal Virginia Offshore Wind; and two large New York developments, Sunrise Wind and Empire Wind. Courts have since allowed work on at least some of these projects, including Vineyard Wind, to proceed while litigation continues.
The administration’s decision makes an expensive problem worse. As temperatures drop, electricity use rises just as heating demand strains natural gas pipelines. Power plants that run on gas — the fuel that often sets wholesale electricity prices — must compete with homes and businesses for limited supply. When pipelines hit capacity, gas prices spike and electricity prices rise with them.
The result is a recurring winter premium. In November 2025, average wholesale electricity prices in New England jumped by more than 50 per cent compared with the prior year, driven largely by surging regional natural gas prices. Retail customers feel that volatility with a lag, as high wholesale prices work their way into monthly bills.
Those bills start from a high baseline. New England already has some of the highest residential electricity prices in the country, averaging just over 29 cents per kilowatt-hour — nearly double the national average. Federal energy forecasters expect electricity spending to rise again this winter, including in the Northeast.
Offshore wind matters here because it can address the affordability problem in the way the Northeast actually experiences it: as winter volatility driven by gas. Much of the new capacity is contracted through long-term power purchase agreements, which means the consumer benefit is not a hand-wavy promise that “more supply lowers prices,” but something more concrete — locking in a large block of energy at a predictable price for years.
That predictability is itself a form of savings. Wind has no fuel cost, so its economics are insulated from the pipeline constraints and gas price spikes that push winter bills higher. In Massachusetts, the Vineyard Wind contract price has been reported as below current wholesale market prices, providing an immediate hedge against today’s gas-driven market.
And the broader market effects still matter. In competitive wholesale markets, prices are set by the marginal unit—often a gas-fired plant during periods of high demand. Adding fuel-free generation into coastal load centers reduces how often the region has to rely on the most expensive units at exactly the moments when gas is tight. Offshore wind doesn’t need pipeline capacity, and it doesn’t become more expensive when fuel markets seize up. When it runs, it displaces higher-cost generation and relieves price pressure across the system—precisely the mechanism that turns winter fuel stress into bill shock.
The administration’s order is therefore not a harmless pause. Delays in large infrastructure projects are expensive, especially when specialized vessels and crews are already mobilized. Dominion Energy, the developer of the Coastal Virginia Offshore Wind project, has warned that the halt could cost more than $5 million per day in standby and delay costs. Developers of the New York and Massachusetts projects have similarly warned that regulatory uncertainty raises borrowing costs and risks cascading delays — expenses that do not disappear, but ultimately reappear in project economics and, eventually, customer bills.
The scale of what is being delayed makes those costs harder to dismiss. Taken together, the paused projects represent millions of homes’ worth of electricity removed from an already strained regional market—and a delay in unlocking the East Coast’s full offshore wind potential. The legal uncertainty also sends a chilling signal to developers nationwide, raising doubts about whether major clean-energy projects can rely on stable federal permitting once construction begins.
All of this is happening as electricity demand is rising nationwide, driven in part by data centers, electrification, and population growth in already constrained regions. Federal forecasts show continued growth in power consumption through 2026. Simply put, the system needs more energy supply, not less.
A serious affordability agenda would focus on expanding reliable generation, reducing exposure to volatile fuel markets, and minimizing regulatory whiplash that drives up financing costs. Instead, the administration has chosen to inject uncertainty into one of the few large sources of new power planned for the Northeast—right when households can least afford it.
Duncan Pickard, a graduate of Island schools, is an attorney in New York.
This article appears in January 30, 2026.