Heating Electrification Will Add 6.8 Gigawatts of Commercial Load by 2035, and Northeast Grids Face the Sharpest Percentage Increase

Enverus Intelligence Research projects that electrifying American buildings, vehicles, and factories will add roughly 24 gigawatts of new electricity demand by 2035, and about 78 gigawatts by 2050.

The composition is the instructive part. Commercial buildings account for 6.8 GW of the 2035 figure, or 29 percent. Residential buildings add 5.7 GW, or 24 percent. Together, buildings make up 53 percent of the new load. The balance, implied by the stated building shares, comes from industry and transportation.

Most of the buildings half of that load traces to a single change: heat pumps replacing gas and oil furnaces in offices, multifamily towers, hospitals, and retail.

Where the growth concentrates. Electrification load does not spread evenly across the country. PJM, MISO, and NYISO together absorb about 69 percent of the 24 GW total. By percentage growth, the two systems that feel it most are in the Northeast. Enverus projects ISO New England load rising 27 percent by 2035 and the New York ISO 21 percent. Those figures describe the rate of increase, not the largest absolute share, which is spread across the three larger systems.

Those grids also carry heavy building-decarbonization mandates. New York City’s Local Law 97 caps emissions on large buildings and tightens its limits over time. A widening set of state and municipal codes points the same way: take the gas burner out of the building and run the heat on electricity.

From summer afternoons to winter mornings. A gas furnace draws nothing from the grid. A heat pump sized to replace it draws its heaviest load on the coldest mornings of the year, precisely when a cold-soaked building demands the most heat and the heat pump runs least efficiently.

For a region, that changes the timing of peak demand. New England and New York have historically set their system peaks on summer afternoons running air conditioning. As heating electrifies at the scale Enverus describes, the annual peak shifts toward winter mornings. The forecast puts a load figure on a transition grid operators have anticipated for some time.

The demand-charge arithmetic. A commercial electricity bill is not only energy. For most buildings above a modest size, a large share of the bill is the demand charge: a dollar figure applied to the single highest interval of power draw, measured in kilowatts, during the billing period.

Replace a furnace with a heat pump and the building’s peak kilowatt draw rises. The demand charge rises with it. A building owner who electrifies heating to comply with Local Law 97 can satisfy the carbon mandate and, in the same act, raise the demand-charge line on every monthly bill that follows. The compliance obligation and the bill increase are the same event, viewed from two ledgers.

The solar gap. The instinct to pair electrification with rooftop solar runs into the calendar. A winter peak set at seven in the morning, or on an overcast January afternoon, sits outside the hours when solar produces meaningfully. Panels do not shave a peak that occurs in darkness or under heavy cloud.

Shaving a winter morning peak requires energy stored in advance and dischargeable on command. That is the function of a battery, charged overnight on cheaper energy and drawn down through the morning heating ramp. The load shape that heating electrification creates is a stationary-storage problem before it is a generation problem. The asset that decouples a building’s carbon compliance from its demand charge is the one that can flatten the new peak the heat pumps produce.

A different load driver. Most of the load-growth coverage of the past year has fixed on data centers, a concentrated demand parked at a few dozen hyperscale nodes and fought over in interconnection queues and cost-allocation dockets. The electrification load Enverus describes behaves differently. It is distributed across hundreds of thousands of individual buildings, each adding a few hundred kilowatts, and it is mandated rather than speculative. A data center can be sited elsewhere or delayed. A Manhattan office tower under a Local Law 97 cap electrifies on a fixed schedule, in place.

The two load types also land in different places. Data-center load shows up at the transmission level and in capacity auctions. Heating electrification shows up at the meter of the building that installed the heat pump, as a higher coincident peak and a higher demand charge, building by building.

The supply side does not loosen. The Northeast is adding this winter demand into a supply picture that is tightening, not easing. Seven states are in litigation with the Interior Department over a federal deal that pays developers to abandon permitted offshore wind. Firm winter capacity in the region is scarce, which keeps wholesale and capacity prices firm and feeds back into the delivery charges commercial customers pay.

Rising demand into constrained supply is the textbook setting for durable price pressure. The Enverus forecast adds a specific, regionally concentrated load to one side of that equation, on a schedule set by building codes rather than market sentiment. The policy that requires the heat pump and the rate structure that prices its peak draw were written by different bodies for different reasons, yet they converge on the same building on the same January morning.

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