New England still expects growth, just less of it
ISO New England has trimmed its long-range electricity demand outlook again, saying annual consumption in the region is now expected to grow about 9% by 2035. The revised forecast reflects what the grid operator described as more conservative assumptions around future adoption of electric vehicles and heat pumps in light of changes in government policy.
The update, published in the grid operator’s 2026-2035 Forecast Report of Capacity, Energy, Loads, and Transmission, does not suggest electrification has stopped. Instead, it shows a slower trajectory than ISO New England had projected in its previous two reports. In 2024, the operator expected a 17% rise in annual energy use by 2033. In 2025, that outlook was cut to 11% growth by 2034. The latest forecast lowers the expected increase again.
The new numbers
ISO New England said annual electricity consumption is projected to rise from 116,679 gigawatt-hours this year to 127,660 gigawatt-hours in 2035, equivalent to average annual growth of about 0.9%. That is still a meaningful shift for a region where net annual energy use had trended downward since 2005, a decline the operator attributes mainly to more efficient heating and cooling systems, appliances, lighting and growth in behind-the-meter solar.
The revised outlook therefore marks two things at once: a moderation in expected electrification speed and a continued expectation that the long-running downward demand trend will reverse over the next decade.
Why the forecast changed
The main driver is not a rejection of electrification as a long-term direction, but a recalibration of policy assumptions. ISO New England said state decarbonization goals still support future electrification of transportation and heating, yet it now assumes a slower pace of electric vehicle and heat pump adoption than it had previously modeled.
This distinction matters because long-term power planning depends heavily on the timing of load growth. If electrification arrives more slowly, the region may have slightly more room to sequence infrastructure, generation and reliability investments. But slower growth does not eliminate the planning challenge. It simply changes its slope.
A dual-peaking grid is taking shape
One of the more consequential points in the report is ISO New England’s view that the region is heading toward a dual-peaking system. Historically, New England’s electricity demand has peaked during the summer. By 2035, however, the operator expects winter and summer peaks to be roughly the same, around 26.5 gigawatts.
That shift reflects the growing role of electric heating load. ISO New England projects heating electrification will contribute 5,533 megawatts to the winter peak in 2035-2036, while transportation electrification will contribute 1,509 megawatts. In other words, even with a softer long-term consumption forecast, electrification still changes the shape of demand in ways that can materially affect reliability planning.
The dual-peaking transition is important because systems built around summer stress may need to adapt to a world where cold-weather demand is equally critical. Fuel security, winter operations and capacity planning all become more complex when seasonal peaks converge.
What it means for regional planning
For policymakers and utilities, the revised forecast is not a signal to relax. It is a signal to plan with more precision. Lower expected growth can affect resource procurement, transmission timing and distributed energy assumptions, but the system still needs to prepare for rising annual use and a more demanding winter profile.
ISO New England expects summer peak demand of 25.2 gigawatts this year and winter peak demand of 20.5 gigawatts in the upcoming season. Its all-time peak remains the 28.1-gigawatt record set in summer 2006. Those figures show that the region is not immediately facing a new peak crisis, but it is moving toward a more balanced and potentially more operationally complex demand profile.
The broader message from the forecast is that electrification is still coming, only with more uncertainty around pace. That makes flexible planning more valuable than ever. New England’s grid will likely need to accommodate higher load, more winter sensitivity and policy-driven changes in end-use consumption patterns, even if the curve is now less steep than planners once expected.
This article is based on reporting by Utility Dive. Read the original article.
Originally published on utilitydive.com
