NuScale and Nucor’s SMR talks put firm power back in industrial planning

NuScale Power and Nucor are forcing a question many industrial operators have sidestepped: for energy-intensive plants that need electricity around the clock, what provides “firm” supply in 2026?

NuScale and Nucor signed a memorandum of understanding to look at placing NuScale’s VOYGR small modular nuclear reactor power plants near Nucor’s scrap-based electric arc furnace (EAF) steel mills, according to a POWER Magazine press release. The agreement calls out practical items, including site suitability, transmission interconnection capability, and capital costs.

From an operations angle, the MOU points to a changing reality in “clean power procurement.” Behind-the-meter solar and storage continue to pencil out more often, and managed load is starting to earn revenue. But plants that run continuously still come back to a hard requirement: power that is available when it is needed.

The MOU centers on siting, interconnection, and steelmaking operating hours

POWER Magazine reported that NuScale’s VOYGR plants can be configured up to 924 MWe. For industrial buyers, the modular format matters as an engineering sizing tool. It can let an energy team align capacity with staged mill upgrades, additional melt shops, and future electrification loads.

The safety language is also worth separating carefully. POWER Magazine reports NuScale says the plant has “fully passive safety features” that allow key safety functions to be performed without depending on an external grid connection, and the article ties that to siting flexibility for industrial users. That does not establish that the plant would keep powering the mill through a grid outage, which is why the distinction should be checked early in technical due diligence.

According to POWER Magazine, Nucor also said it would explore supplying Econiq, its net-zero steel product line, into NuScale projects. If the studies move forward, that could set up a two-direction supply link: electricity for steel and steel for reactor projects, with implications for procurement and long-lead contracting.

DER returns may be improving, but the right mix depends on what a site can run day to day

The NuScale-Nucor MOU is about nuclear, but it comes as many facilities keep evaluating solar, batteries, and demand programs. pv magazine USA said those evaluations are tightening because commercial and industrial owners are treating distributed energy as a capital allocation decision, weighing how durable and operationally workable each revenue stream is, not only the modeled return.

pv magazine USA’s Massachusetts example presents a rate picture that can get CFO attention. Citing U.S. Energy Information Administration data, the outlet reported Massachusetts average commercial electricity rates increased from roughly 13.0 cents/kWh in 2014 to 20.9 cents/kWh in 2024, about a 61% rise. Over the same period, industrial rates in the state increased from about 12.0 cents/kWh to 18.2 cents/kWh, about 52%. pv magazine USA also reported the 2024 Massachusetts commercial rate was higher than the national commercial average of about 13.9 cents/kWh.

pv magazine USA’s takeaway was about how projects should be evaluated, not about claiming a universal “winner.” For operators, the practical point is that modeled value depends on the tariff terms, market rules, and the operating partner responsible for turning a dispatch plan into actual performance.

Managed EV charging and V2G are emerging as grid tools, if policy and telemetry keep pace

Firm supply is also being challenged by load shaping. Renewable Energy World’s Factor This Policycast said Elizabeth Stears and Leah Brams discussed policy reforms intended to unlock vehicle-to-everything (V2X) value and highlighted obstacles to wider adoption. For sites electrifying fleets, this can move from a transportation detail to an energy item: it may support grid services revenue and help manage peak demand charges, if programs exist and dispatch can be contractually defined.

Charged EVs said the underlying drivers of EV energy use set real planning bounds. The outlet notes weight and aerodynamic drag (CdA) are major determinants of consumption, and that climate control, especially heating, can have a large effect that is often missed. For fleet charging plans, that means the same route and duty cycle can require very different kWh in winter, which affects how confidently a facility can commit flexibility into a utility program.

Charged EVs also argues regenerative braking does not change total energy consumption as much as many people expect. In planning terms, the bigger forecasting inputs are vehicle specifications, route speed profile, and HVAC loads, rather than assuming “driver behavior improvements” will drive large energy savings.

What to do with all this in 2027 budgets

Most operators will not sign an SMR MOU this quarter. Still, the NuScale-Nucor announcement shows what “clean baseload” looks like once it turns into engineering and procurement work: interconnection studies, siting limits, modularity decisions, and upstream manufacturing capacity considerations happening together.

It also hints at how options may sort in the near term. In higher-rate regions such as the Massachusetts example cited by pv magazine USA, behind-the-meter solar and storage can look attractive in modeled economics. At sites where the cost of constrained production overwhelms the energy bill, companies may accept longer timelines and pursue options that start with feasibility work and an interconnection reality check, including dedicated supply arrangements.

Questions to put in front of energy, facilities, and procurement teams now

• For any long-lived “firm power” option (including nuclear, long-duration storage, or new interconnections), what is the earliest credible in-service date after siting and interconnection constraints are counted, not just equipment lead times (POWER Magazine)?
• In DER proposals, which value streams are guaranteed in the contract and which depend on market participation rules or utility program enrollment, and who is accountable for operating performance (pv magazine USA)?
• For fleet electrification plans, what winter and summer kWh-per-mile assumptions are being used, and do they explicitly account for HVAC loads and route speed effects described by Charged EVs, before committing any charging load to managed charging or V2G programs (Charged EVs; Renewable Energy World)?
• If pursuing managed charging or V2X, what telemetry, control interface, and settlement requirements will the utility or aggregator impose, and are they compatible with the site’s charging hardware and network architecture (Renewable Energy World)?