Grid OEMs are racing to build in the U.S., but transformers still take 2–3 years

U.S. grid equipment is getting the kind of demand signal that normally shows up as a line of trucks outside a plant gate. Renewable Energy World reported this week that major original equipment manufacturers are expanding U.S. operations to supply the hardware utilities are short on, especially transformers, circuit breakers, and high-voltage cable.

The catch is timing. A September 2025 supply-chain executive summary published by POWER Magazine, produced in partnership with American Clean Power and drawing on Wood Mackenzie Supply Chain data, puts sustained lead times for power transformers and generator step-up transformers (GSUs) at 2 to 3 years. That is long enough to decide when a substation can be rebuilt, when a renewable project can energize, or when a data center can take load.

Domestic factory expansions are landing, but the queue is still real

Renewable Energy World’s report frames the latest wave of OEM investments as a response to “unrelenting” electricity demand and the need for critical grid infrastructure. The emphasis is on hardware with long procurement cycles and limited supplier options: transformers, breakers, and high-voltage cable.

POWER Magazine’s executive summary explains why those announcements matter to operators, but also why they may not show up as immediate relief. Strong demand growth has pushed parts of the equipment market into deficit, according to the report, and competition for production slots has driven up both lead times and prices for key equipment.

For procurement teams, the actionable point is that domestic capacity expansions do not automatically compress delivery windows. The same POWER Magazine report notes that OEMs have cited raw material constraints and technical labor shortages as bottlenecks to capacity expansion. That is the kind of constraint that shows up as “we can’t commit to that delivery month” in the final round of negotiations.

What’s driving the shortage: load growth, old assets, and faster rebuild cycles

The POWER Magazine report lays out a stack of demand drivers that interact in a nasty way for utilities. It estimates U.S. electricity demand increased 7% between 2019 and 2024, reversing an earlier decade of decline (2010, 2020). When load is rising again, deferring equipment replacement gets harder, because spare capacity is no longer a given.

It also points to a structural replacement problem inside the fence line. A U.S. Department of Energy study cited in the POWER Magazine summary found 55% of in-service distribution transformers, about 40 million units, are more than 33 years old. Operators don’t need to be told what that means: failure risk rises, and maintenance crews spend more time on triage.

Then there is the pace of new large loads. The same report says manufacturing construction spending increased 96% over the past three years and cites a data center pipeline above 125 GW in Q1 2025, with monthly additions averaging 226 MW per month over the past two years. Those projects don’t just consume megawatts. They pull demand for distribution transformers, switchgear and breakers, and wire into the same delivery pipeline utilities use for replacements.

Materials and labor are now part of the transformer spec conversation

The grid equipment story is no longer only about nameplate capacity at factories. According to POWER Magazine, equipment lead times and prices for key equipment have surged as competition for production slots increases. The report also says power transformers and generator step-up units are seeing sustained lead times of 2 to 3 years.

That changes how operators should write procurement documents. Price-adjustment clauses that were once boilerplate become operational decisions, because they determine whether a project absorbs commodity risk or reopens the commercial negotiation mid-build. And qualification language around substitutions matters more when vendors are managing constrained materials across multiple builds.

Trade and policy conditions are another planning input. The POWER Magazine report says evolving trade policy is expected to add upward pressure on both imported and domestically produced equipment. Even when a utility intends to buy U.S.-built units, tariffs can still matter by increasing competition for domestic production slots.

Batteries are becoming grid equipment, not just generation add-ons

While transformers and breakers set the pace for many projects, grid-scale storage is changing what “reliability equipment” can do when it arrives. Civil Engineering Magazine, published by ASCE, reported on the Kapolei Energy Storage project on Oahu, developed by Plus Power. The site uses 158 Tesla Megapack 2 XL lithium iron phosphate batteries on about 8 acres and provides 185 MW of rated power and 565 MWh of energy capacity.

ASCE reported the project began operations in December after construction from April 2022 to December 2023, and that it is operated under a 20-year contract by Hawaiian Electric. ASCE also reported that the Kapolei Energy Storage project comprises 158 Tesla Megapack 2 XL lithium iron phosphate batteries and provides 185 MW of rated power capacity and 565 MWh of energy capacity. Plus Power said in a Jan. 11 news release that it develops, owns, and operates standalone battery energy storage systems that provide capacity, energy, and ancillary services.

For utility planners, the operational implication is that battery procurements increasingly come with protection, controls, and performance obligations similar to substation gear. Fast response and frequency support are not “nice to have” marketing bullets when inverter settings, interconnection requirements, and control-room procedures must all agree under disturbance conditions.

Where this lands for utility ops and procurement teams in 2026

• In transformer and GSU RFPs, require a schedule-backed delivery plan, not a target date. POWER Magazine’s 2 to 3 year lead time range is a useful baseline to push vendors on slot reservation, critical-path materials, and factory test dates.
• Treat commodity adjustment formulas as an operational risk decision.
• When evaluating storage, ask for grid-services performance in engineering terms. ASCE’s Kapolei reporting describes the project’s 185 MW rated power capacity and 565 MWh energy capacity, along with its ability to meet 17% of Oahu’s electricity demand for three hours at peak load or six hours at half load. Map any proposed grid services to measurable controls requirements and acceptance tests, not marketing claims.
• If a project depends on domestic sourcing, confirm what “domestic” means in the bill of materials. POWER Magazine flags trade-policy pressure across imported and domestic equipment, which can still reshape lead times if upstream components tighten.

The next signal to watch is whether the factory expansions reported by Renewable Energy World translate into shorter quoted lead times for power transformers, or whether utilities simply see a longer list of projects competing for the same production slots the POWER Magazine report says are already oversubscribed.