Small modular reactors and microreactors are real technology with real commercial momentum — but a C&I facility evaluating them today is making four simultaneous bets: on technology maturity, on fuel supply, on vendor financeability, and on regulatory timeline. Get any one of those wrong and you have a stranded capital investment. This post breaks down what those bets actually involve and gives you the diligence framework to evaluate them.

This is for facility executives, operations leaders, and energy decision-makers at large data centers, heavy manufacturing plants, remote industrial sites, and critical infrastructure operations who are evaluating on-site power independence at scale. If a vendor has shown up at your facility with a proposal — or if you are watching this space and trying to figure out whether there is a real near-term option here — you need to understand the difference between what is technically possible and what is commercially available on your timeline.

By the end, you will know how SMRs and microreactors differ as procurement categories, how to rank the four main reactor technology types by commercial readiness, what the HALEU fuel problem actually means for your project, and the five diligence questions that will separate a credible vendor from a pitch deck.

What Small Modular Reactors and Microreactors Actually Are

The term "nuclear" gets applied to a wide range of designs with very different commercial profiles. Before you can evaluate a vendor proposal, you need to know which category you are actually looking at.

Small modular reactors (SMRs) are generally defined as reactors producing 300 megawatts of electricity or less. They are aimed primarily at utilities and large industrial users who need significant baseload generation. The "small" is relative — 300 megawatts is a lot of power. The "modular" refers to factory fabrication: the core units are designed to be built in controlled manufacturing environments and assembled on-site, rather than constructed entirely on-site the way a traditional large nuclear plant is.

Microreactors are a distinct category: 20 megawatts or less. They are aimed at remote industrial sites, off-grid loads, military installations, and facilities that need something compact enough to be transported and deployed without the infrastructure footprint of a conventional power plant. Eielson Air Force Base in Alaska — where Oklo's pilot project has publicly targeted operation in the late 2020s — is the prototype use case for this category.

The sizing distinction is not just academic. It governs your procurement decision. A microreactor is physically different from an SMR, carries different regulatory requirements, serves a different operational problem, and comes from a different vendor set. Confusing the two categories in your evaluation is how you end up comparing proposals that are not actually competing for the same job.

How these show up on your operation: neither category is currently available for commercial C&I purchase in the United States in the way a diesel generator or a battery storage system is. You are not shopping a catalog. You are evaluating development agreements, offtake contracts, and project-specific deployments — with all of the timeline, counterparty, and regulatory risk that entails.

Why This Technology Exists on Paper vs. How It Works in Real Life

The grid-design rationale for SMRs is straightforward: traditional large-scale nuclear provides reliable, zero-emission baseload power, but the capital cost of building a 1,000-megawatt plant on-site is so high that it has become economically unworkable in most markets. SMRs are designed to solve that problem through factory production economics.

Regulators and advocates position this as a pathway to reliable always-on power without the fuel price exposure of natural gas and without the intermittency of solar and wind. That framing is accurate as a technology description.

Here is where the operator reality diverges. Over 100 SMR designs are currently in development worldwide. Most will not reach commercial scale. The gap between a design that works in a laboratory or a regulatory application and a design that can be financed, permitted, fueled, staffed, and operated at your site — on a timeline that matches your capital planning cycle — is enormous.

The financial case for SMRs rests on a manufacturing thesis, not a nuclear thesis. The argument is that factory fabrication and serial production will drive costs down the way they did in aerospace. Rolls-Royce has stated that approximately 90% of their SMR's manufacturing and assembly is carried out in factory conditions. The World Nuclear Association describes the shift as a move from economies of scale to economies of series production.

That thesis is credible. It is also unproven at commercial scale. A vendor projecting unit cost reductions based on a production ramp that has not yet happened is giving you a financial model, not a track record. Those are different things, and your diligence process needs to treat them differently.

When Small Modular Reactors and Microreactors Actually Help Facilities Like Yours

The operational case for on-site nuclear is strongest in a specific set of conditions. If your facility has several of these, the technology is worth serious evaluation — with the diligence framework below.

24/7 load with no flexibility. Nuclear is baseload generation. It does not throttle well. If your process runs continuously and you cannot shift load, nuclear's constant output is a fit. If you have significant load variability, you will be paying for capacity you are not using.

Constrained or unreliable grid access. Remote industrial sites — mining operations, remote processing facilities, military installations — are the clearest near-term case. If extending transmission to your site would cost more than the alternative generation, or if your utility cannot guarantee the reliability your process requires, on-site baseload generation changes the math.

Large data centers with power density growth. Hyperscale data centers are signing development agreements with SMR vendors precisely because their load growth is outpacing grid capacity expansion in many markets, and their uptime requirements are not negotiable.

Process heat requirements at high temperature. High-temperature gas reactor designs can supply both electricity and industrial process heat — relevant for hydrogen production, chemical manufacturing, and other thermally intensive processes. This is a longer-dated opportunity than pure power generation, but it is real.

Long planning horizon and patient capital. If your capital planning cycle extends to 2035 and beyond, and your organization can carry a development-stage investment, the technology maturity risk is more manageable. This is not a 2026 solution for most facilities.

When Small Modular Reactors and Microreactors Are a Terrible Idea (or Lock You In)

Your timeline is the next three to five years. No Western SMR is currently operating commercially. The NuScale flagship U.S. project was cancelled in 2023 on cost grounds. Rolls-Royce's development agreements in the UK, Sweden, and with CEZ Group in the Czech Republic are at the selection and site-work stage — meaningful momentum, but not construction. Oklo's Eielson pilot has targeted the late 2020s, with the caveat that nuclear project timelines routinely slip. If your energy problem needs a solution before 2030, SMRs should not be in your capital plan as a primary answer.

You are evaluating a design that requires HALEU fuel without a documented supply plan. More than half of the SMR designs currently in development require high-assay low-enriched uranium — uranium enriched between 5% and 20%. HALEU is not yet commercially available at scale in the West. The only current large-scale producers are Russia and China. Centrus Energy began demonstration-scale production in the United States in October 2023 — that is early-stage. The transport infrastructure does not yet exist at the volumes needed. A stranded reactor is still a capital expenditure.

The vendor's financial model depends on sustained government subsidy. Many SMR development timelines are predicated on DOE loan guarantees, production tax credits, or direct government contracts. That is not inherently disqualifying — but you need to ask what happens to the project economics and the vendor's viability if that support changes. Government energy policy has changed before.

Your load profile is highly variable. Nuclear plants are not designed to ramp up and down with process variability. You will pay for the full capacity whether you use it or not. Facilities with significant load flexibility have better economics with generation assets that can follow load.

You have not modeled staffing. Even the most automated microreactor designs require licensed operators on duty continuously. That is a fixed labor line that no solar array, wind contract, or gas engine carries. If your total cost of ownership analysis does not include a fully-loaded staffing line, you do not have an analysis — you have a projection.

Vendor Pitches, Red Flags, and Questions That Smoke Out BS

The SMR vendor landscape includes serious organizations with real engineering behind them and organizations selling a compelling story. The diligence questions below will separate them.

Ask about factory floor reality, not factory floor plans. The financial case for SMRs is built on factory fabrication. The right question is not "Is your design modular?" — every vendor will say yes. The right questions are: How much of this unit is actually being assembled in your factory today? What is your current unit-per-year production throughput? A projection is not a factory floor. If they cannot show you current production rate, the manufacturing thesis is still theoretical.

Ask about fuel before you ask about the reactor. If the design requires HALEU, ask: What is your documented fuel supply plan, and who is your supply agreement with? If the answer is "we expect the supply chain to develop" or "we are in discussions with Centrus," that is not a supply plan. You need a contracted supply chain before you commit capital to the reactor.

Ask for financeability without government support. A credible vendor can answer: Can this project reach financial close without sustained government subsidy, and if not, what is the specific subsidy dependency and what triggers would change the project economics? If they cannot answer that clearly, your counterparty risk is higher than the pitch suggests.

Watch capacity factor projections on novel deployment models. Modern stationary nuclear achieves over 90% capacity factor — that track record is real. Remote and transportable designs being pitched today do not have an equivalent track record. The closest historical analog, the MH-1A floating plant in the Panama Canal Zone, ran at roughly 54% capacity factor in a fundamentally different technology context. That is one data point from a different era — but it is a reminder that vendor capacity factor projections for novel deployment models are unproven. Ask what assumptions are driving their projection and what the downside scenario looks like.

Verify technology readiness level. Ask directly: What TRL is this design, and where is the most recent independent third-party assessment of your reactor's readiness? More differentiated designs — molten salt, sodium-cooled — carry higher technology readiness risk than light water SMRs. That is a direct relationship, and the vendor should be able to state it plainly.

What You Can Do This Week

You do not need to make a capital decision on SMRs this week. But if you are in a sector or operational context where this technology is relevant — large data centers, remote industrial sites, heavy manufacturing with process heat needs — there are concrete steps worth taking now.

1. Map your load profile against nuclear's constraints. Pull 12 months of interval data and identify what percentage of your load is flat and continuous versus variable. Nuclear's economics work best on the flat portion. If most of your load is variable, document that before a vendor models it for you.
2. Identify your grid access constraints. If you are evaluating on-site generation at scale, get a clear picture of your current transmission capacity, your utility's stated expansion timeline, and any interconnection queue position you hold or would need to obtain. These constraints are what make nuclear's baseload profile an asset rather than a liability.
3. Track the deployment signals. The Rolls-Royce agreements in the UK, Sweden, and with CEZ Group in the Czech Republic, and the Oklo pilot at Eielson Air Force Base, are the near-term indicators of whether SMR vendor timelines are translating into operational reality. Set up monitoring on those specific projects. When they cross from site work to construction, that is a meaningful signal.
4. Run a staffing line item analysis. Before any vendor presents you with a total cost of ownership model, build your own staffing assumption. Licensed nuclear operators are a continuous, fixed cost. Get a current labor market estimate for your region and put it in the model before the vendor does.
5. Ask your legal and procurement team to review development agreement structures. If you are being asked to sign a development agreement, offtake contract, or letter of intent with an SMR vendor, understand what your exposure is if the vendor misses their commercial operation date by two, four, or six years. Those provisions matter more than the technology spec sheet.

The Bottom Line on Small Modular Reactors for Commercial & Industrial Facilities

Small modular reactors and microreactors are not vaporware. The technology is advancing, the commercial signals are real, and for the right operational context, on-site nuclear is a credible long-term answer to grid dependency and reliability risk.

But a C&I facility evaluating these options today is making four bets simultaneously: a technology maturity bet, a fuel supply chain bet, a vendor financeability bet, and a regulatory timeline bet. The clearest near-term case is remote industrial sites and large data centers with constrained grid access and long planning horizons. Heavy manufacturing with process heat needs is a real but longer-dated opportunity. Indiana manufacturers with a near-term energy problem should be looking at other tools first — demand charge management, on-site generation with proven technology, and rate structure optimization — while keeping an eye on SMR deployment signals for the longer horizon.

The vendors building the most differentiated technology often carry the most technology and fuel supply risk. A compelling pitch deck is not a commercial operation date.

Frequently Asked Questions: Small Modular Reactors and Microreactors for C&I Power

Q: What is the difference between a small modular reactor and a microreactor?

A: Small modular reactors (SMRs) are generally defined as producing 300 megawatts or less and are aimed at utilities and large industrial users needing significant baseload generation. Microreactors are a distinct, smaller category — 20 megawatts or less — designed for remote sites, off-grid loads, and facilities that need compact, transportable power. The two categories serve different operational problems and come from different vendor sets; they are not interchangeable in a procurement evaluation.

Q: Which SMR designs are closest to commercial operation?

A: Light water SMRs carry the lowest technology risk because they are scaled-down versions of proven reactor designs using the same low-enriched uranium fuel already in operation in U.S. reactors. However, no Western light water SMR is yet operating commercially — NuScale's flagship U.S. project was cancelled in 2023 on cost grounds. Rolls-Royce's development agreements and Oklo's Eielson Air Force Base pilot are the most concrete near-term deployment signals, but both are at pre-construction or early-stage phases, and nuclear project timelines routinely slip.

Q: What is HALEU fuel and why does it matter for SMR procurement?

A: HALEU — high-assay low-enriched uranium — is uranium enriched between 5% and 20%, required by more than half of the SMR designs currently in development. HALEU is not yet commercially available at scale in the West; only Russia and China currently produce it at scale, and Centrus Energy began demonstration-scale U.S. production only in October 2023. If a vendor is pitching a design that requires HALEU, your first diligence question should be about the fuel supply plan, not the reactor — a stranded reactor is still a capital expenditure.

Q: How many staff does a microreactor or SMR require to operate?

A: Even the most automated microreactor designs require licensed nuclear operators on continuous duty — that is a fixed labor line that no solar array, wind contract, or gas generator carries. The exact staffing level depends on the design and regulatory license conditions, but operators should model a fully-loaded continuous staffing cost before accepting any total cost of ownership projection from a vendor. If the vendor's model does not include a staffing line, the analysis is incomplete.

Q: What should a C&I operator ask an SMR vendor before signing anything?

A: Five questions that separate credible vendors from pitch decks: How much of your unit is actually being assembled in your factory today, and what is your current production throughput? If your design requires HALEU, what is your documented fuel supply agreement? Can this project reach financial close without sustained government subsidy, and what happens to the economics if that support changes? What is your reactor's technology readiness level per an independent third-party assessment? And what are the contractual consequences for your facility if the commercial operation date slips by two, four, or six years?

Q: Is on-site nuclear power a realistic near-term option for Indiana manufacturers?

A: For most Indiana manufacturers, no — not as a near-term solution. No Western SMR is commercially operating today, HALEU supply chains are pre-commercial, and nuclear project timelines routinely extend beyond initial projections. The strongest near-term case is remote industrial sites and large data centers with constrained grid access and long planning horizons extending to 2035 and beyond. Indiana manufacturers with an immediate energy cost or reliability problem should prioritize proven tools — demand charge management, on-site generation with established technology, and rate structure optimization — while tracking SMR deployment signals for longer-horizon planning.

If this post surfaced questions about how on-site power fits into your broader energy strategy, the next step is the TEG Energy Decision Blueprint. It is built for Indiana C&I operators spending five figures or more on electricity each month who are evaluating major energy decisions — rate structures, on-site generation, storage, or capital projects. We look at your actual bills and interval data, model the economics against your specific rate, and give you a written opinion on whether the numbers are real.

If you want to understand the full reliability and cost-control picture for on-site generation, the post on C&I microgrids for industrial facilities covers the business case architecture in detail. And if you are evaluating backup power alongside on-site generation, the C&I backup power strategy post walks through how diesel, natural gas, and battery architectures compare before you commit capital to any of them.

Watch this episode of The TEG Podcast on small modular reactors and microreactors for C&I power — on YouTube