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Build an SMR market model around a specific site, customer, energy product and delivery date—not a global deployment forecast. Start with evidence of local demand, identify a credible route to revenue, then test whether the project can deliver at a competitive cost and on a schedule its customers can accept. Treat every result as a scenario until its inputs are supported by project documents, counterparties and current jurisdiction-specific evidence.
What an SMR market model needs to answer
A market model is a decision tool for one proposed project. It should establish whether there is enough addressable demand, whether the project can serve that demand, how output could be sold or used, and whether the resulting economics justify further development. It is not the same as estimating how many small modular reactors might be built worldwide.
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The OECD Nuclear Energy Agency (NEA) defines small modular reactors as reactors with power output between 10 MWe and 300 MWe in its 2021 report Small Modular Reactors: Challenges and Opportunities. That range defines the category in that report; it does not establish that every design is suitable for a particular customer, grid or industrial process.
The model should connect five questions rather than answering them in isolation: what service the customer needs, what local alternatives can provide it, what the proposed reactor can deliver, what the commercial arrangement pays for, and what development conditions must be met before revenue can begin. A promising global market narrative cannot substitute for any of these project-level tests.
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Define the project and the market boundary
Before estimating demand or revenue, write down exactly what is being modeled. A market boundary that is too broad can make a project appear to have customers it cannot reach, products it cannot deliver or a timeline it cannot meet.
Record the project definition
- Jurisdiction and candidate site: identify the market rules, regulator, grid or industrial setting, and geographic area in which demand and competing supply will be assessed.
- Reactor design and capacity: identify the proposed design and the relevant output measure. Keep electrical output distinct from useful heat or other products.
- Target in-service date: state the expected date revenue could begin, and link it to the schedule assumptions used elsewhere in the model.
- Customer or offtaker: name the intended buyer or host, or state that one has not yet been identified. Distinguish a prospective customer from a signed counterparty.
- Energy product: specify grid electricity, direct power, heat, hydrogen, synthetic fuels, or another product only where the design and customer arrangement support it.
- Delivery route: say whether output is sold into a grid, contracted to a host, or used on site; identify any grid connection or industrial interface the route requires.
Then define the modeled market by geography, product and time period. For example, an industrial host’s heat requirement at a named site is a different addressable market from regional wholesale electricity demand. Keep these markets separate unless the project has a technically and commercially credible way to serve both.
Separate addressable demand from total demand
Total electricity use, industrial energy consumption or a global reactor deployment estimate is not automatically demand the project can serve. Addressable demand is the portion that matches the project’s location, output, timing, delivery capability and customer requirements. Exclude loads the project cannot reach, products it cannot produce, and demand already covered by a binding supply arrangement unless there is evidence it will be available to the project.
The NEA’s 2016 report Small Modular Reactors: Nuclear Energy Market Potential for Near-term Deployment identified small grid systems and energy mixes with large shares of variable renewables as contexts where SMRs may have potential. Treat this as a description of possible market conditions, not a conclusion that any particular system needs an SMR. Local evidence must establish the fit.
Build the demand case from the customer and energy system
Demand should come from the customer’s requirements and the relevant energy system, not from a top-down market-share assumption. Use the best available evidence for the specific product and site, and label forecasts separately from measured or contracted demand.
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Use evidence that matches the product
- Grid electricity: use jurisdiction-specific demand forecasts, load data and market information relevant to the project’s connection and delivery area.
- Industrial power or heat: obtain the host’s consumption profile, process requirements, operating schedule and expected changes. An annual energy total alone may not show whether demand coincides with the proposed supply.
- Off-grid applications: document the site’s existing supply, load growth, fuel or logistics constraints and reliability requirements.
- Hydrogen or synthetic fuels: establish the intended customer, product specification, production arrangement and credible demand for the output. Do not count potential production capacity as contracted demand.
Where value depends on the timing of delivery, model the load at the appropriate interval—hourly, seasonal or another interval supported by the available evidence. Compare the customer’s demand shape with the project’s proposed supply and operating assumptions. A project can have a large annual energy total in a model and still fail to match the customer’s actual timing or delivery needs.
Account for the rest of the system
Compare demand with existing and planned generation, grid connections, storage, demand response and other alternatives that matter in the jurisdiction. The NEA’s 2021 report Advanced Nuclear Reactor Systems and Future Energy Market Needs frames future electricity systems as changing alongside renewables, storage and demand-side management. These are not optional background details if they affect the volume, timing or value of energy the project could sell.
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Choose commercial routes and map revenue
Revenue depends on the product, market design and contract—not on reactor capacity alone. Select only routes the proposed design, location and customer can support. The NEA publications establish a range of market and application contexts, but they do not prescribe one universal SMR revenue stack.
Possible routes to test
- Wholesale electricity: model sales under the applicable market rules and price assumptions, including the project’s exposure to changing market prices.
- Capacity or reliability value: include it only if the jurisdiction’s market or a contract compensates the project for that service and the project can meet the relevant requirements.
- Long-term power contract: specify the buyer, term, price basis, contracted volume, delivery point and allocation of delivery, price and performance risks.
- Direct supply to an industrial host: define the electricity or heat product, interface, customer obligation and consequences if either party cannot deliver or take the contracted amount.
- Heat, hydrogen or other products: include revenue only where the reactor configuration, site infrastructure, customer demand and commercial arrangement support production and sale.
Separate contracted revenue from merchant revenue, policy support and uncontracted upside. For every contract assumption, record whether it is executed, under negotiation, indicated by a prospective counterparty or merely assumed by the sponsor. Model prices and volumes on the same basis as the agreement, including the delivery point and term. Do not treat policy support as permanent or available unless the relevant program, eligibility and duration are established.
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Show the revenue bridge
For each product, show how modeled revenue is derived from deliverable volume and the applicable contract or market price. Make deductions or constraints visible where they apply, such as delivery limitations or periods when the customer does not take output. This makes it possible to see whether the case depends on signed offtake, price forecasts, unawarded support or an unproven secondary product. If a revenue line lacks an identified customer, market mechanism or qualifying arrangement, label it as an assumption rather than presenting it as secured income.
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Keep project costs in separate, documented categories. Combining them into one headline cost makes it difficult to identify which assumptions drive the result or whether a claimed saving is actually reflected in the project plan.
| Model line | What to document | Evidence to seek |
|---|---|---|
| Construction | Scope, cost basis, estimate date, design maturity and included or excluded work | Project estimate, vendor or engineering basis, and clearly stated exclusions |
| Owner’s costs | Owner-side development and delivery costs included in the project boundary | Project budget and a reconciliation to the construction estimate |
| Financing during construction | Financing structure, draw timing, rate assumptions and schedule basis | Financing plan, lender or investor terms where available, and schedule inputs |
| Fuel | Fuel cost assumptions and the availability arrangement relevant to the design | Current project or counterparty information; do not infer a supply arrangement from design claims |
| Operations and maintenance | Operating cost assumptions, scope and basis for expected performance | Project-specific estimates or documented assumptions |
| Decommissioning and waste management | Whether and how these obligations are represented in the project economics | Applicable jurisdictional requirements and project provisions |
| Grid connection and interfaces | Connection work and any heat or industrial interface required to deliver the product | Site, grid and host requirements with cost responsibility identified |
The table is a model structure, not a set of universal cost values. The cited NEA material does not supply project-specific capital cost, financing terms, tariffs, fuel arrangements or schedule inputs for the project described by this title. Obtain them from current project documents, relevant counterparties and jurisdictional records; do not fill the gaps with invented numbers.
Separate first-of-a-kind from repeat-build assumptions
Mark which cost and schedule assumptions apply to the first project of its kind and which depend on future repeat construction. The NEA’s 2016 market assessment discusses possible cost advantages in the context of serial production, optimized supply chains and smaller financing costs. Those conditions are assumptions to test, not guaranteed savings. Show the procurement, production and financing mechanism that would make each claimed benefit achievable for this project.
Model financing timing explicitly. Delays can change how long capital is tied up before operation and may affect contractual obligations and the date revenue starts. The model should make financing during construction responsive to the schedule scenario rather than hiding it inside a cost figure that never changes.
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Treat deployment readiness as schedule and commercial risk
Technical feasibility alone does not establish that a project can be licensed, financed, supplied and brought into operation on the date assumed. The NEA Small Modular Reactor Dashboard’s readiness framework tracks six dimensions: licensing, siting, financing, supply chain, engagement and fuel. Use those dimensions to structure a project risk register, not to assign unsupported scores.
| Dimension | Questions for the model team | How it can affect the case |
|---|---|---|
| Licensing | What approvals apply, what steps remain, and what current evidence supports the assumed sequence? | Changes the credible path to operation and revenue start |
| Siting | What site permissions, infrastructure and location-specific requirements remain unresolved? | Can affect development scope, connection needs and timing |
| Financing | Is the capital structure identified, and which financing terms are evidenced rather than assumed? | Can change capital requirements and the cost of delays |
| Supply chain | Are critical suppliers, components and delivery assumptions identified for the project? | Can affect procurement, construction sequence and cost exposure |
| Engagement | Which stakeholders must be engaged, and what evidence supports the project’s engagement plan? | Can affect development progress and the credibility of schedule assumptions |
| Fuel | Is a project-relevant fuel supply arrangement established or still an open dependency? | Can affect operating readiness and the ability to deliver the modeled product |
For each milestone, record the responsible party, evidence, dependency, expected date and consequence if it slips. Build schedule cases from credible project evidence; do not assign probabilities or readiness scores without current project-specific support. Where timing is uncertain, show how a later operating date changes revenue, financing during construction, contract exposure and any costs that continue before operation.
The NEA Dashboard’s 2023 Volume II tracks an additional 21 SMRs, while its publication page describes Volume I as assessing 21 designs. These are counts within those report editions and scopes, not a current total of all designs in development. The Dashboard’s underlying readiness information is time-sensitive, so a model should rely on current records for the specific project rather than treating a report edition as proof of present status.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.Compare the SMR with alternatives on common terms
A market case is stronger when it shows what the customer or system would do instead. Compare only alternatives relevant to the site and use case: they may include grid supply, renewables with storage, other firm generation, efficiency or industrial process changes. The cited sources support system-aware comparison; they do not establish a single winning technology.
| Comparison axis | What to compare consistently |
|---|---|
| Delivered cost and financing exposure | Cost of the same service, with financing assumptions and cost boundaries made explicit |
| Customer fit | Ability to match the load, reliability and product requirements actually documented |
| Construction and connection timing | Credible schedule to deliver service, including required connections and interfaces |
| Licensing and siting | Jurisdiction- and site-relevant readiness rather than generic technology claims |
| Supply chain and fuel | Evidence that necessary inputs can be procured and made available for the project |
| System interaction | Effects alongside renewables, storage and demand-side management where relevant |
| Contractability | Whether the output and its value can be covered by a credible customer or market arrangement |
| Other site impacts | Emissions, land and infrastructure needs, and exposure to fuel or market-price risk |
Use the same service definition, demand period, delivery point and financing basis across options. If one alternative is compared as a fully delivered service while another is represented only by a plant-level cost, the comparison is not decision-ready. Record material differences that cannot be normalized instead of concealing them in a single cost metric.
Build scenarios, sensitivities and break-even tests
SMR economics are dependent on market development, financing and supply-chain conditions. A single-point estimate can conceal which assumptions must hold for a project to work. Use a reference case plus conservative and upside cases, and show the evidence status behind each change.
Minimum variables to test
- Demand volume, demand shape and utilization
- Realized capital cost and the extent to which repeat-build assumptions apply
- Financing rate, financing structure and time during construction
- Schedule, including delay and the resulting revenue start date
- Fuel and operating costs
- Market prices, contract terms and contracted volume
- Availability, duration and eligibility of policy support
Test these inputs individually to see which ones drive the result, then test combinations that can plausibly occur together. For instance, a schedule delay may coincide with a change in financing exposure and a missed contractual delivery obligation. Avoid treating such variables as independent if project evidence shows they are linked.
Calculate break-even conditions in terms decision-makers can act on: the demand or utilization needed to support the case, the cost or price boundary at which the project ceases to meet its objective, and the latest viable delivery date under the relevant contract. The exact metrics depend on the project’s decision and market rules; state definitions and assumptions so readers can reproduce them. Do not present an unsupported project IRR or levelized cost as though it were a forecast.
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Identify whether each material input is a sponsor assumption, vendor statement, third-party forecast, counterparty term or published historical scenario. Preserve the date, geography, scope and status of the input. In particular, the NEA’s 2016 report included a high-case scenario of up to 21 GWe of SMRs globally by 2035, approximately 3% of installed nuclear capacity in that report’s framing. This is a historical scenario from a 2016 publication, not an observed total or a current forecast; it cannot establish demand for a specific site.
Keep an evidence register and report the decision
A usable model makes uncertainty visible. Maintain an evidence register alongside the calculations so a reviewer can trace each major input to its source and understand what remains unverified.
- Input and unit: state what the number or assumption represents and how it is measured.
- Source and date: record the originating project document, counterparty information, market record or forecast and when it was issued.
- Scope: identify the geography, design, product, period and project boundary to which it applies.
- Status: distinguish observed data, executed contract, estimate, forecast, sponsor assumption and upside case.
- Owner and next evidence: identify who can validate an open assumption and what information would resolve it.
Report the decision in a compact structure: the addressable demand supported by evidence, the credible offtake route, the relevant competing supply, the project’s delivery readiness, economics across scenarios, and the next evidence needed to decide whether to proceed. Tie every conclusion to the scenario and input set that supports it.
At minimum, do not let a global deployment scenario stand in for local demand; do not count uncontracted upside as secured revenue; do not treat prospective serial production benefits as realized project savings; and do not report a single cost or return without its assumptions, range and date. OECD/NEA material can frame market conditions and dependencies, but the location, design, customer, demand profile, alternatives, tariff, cost, financing, schedule and fuel arrangement must come from current project-specific evidence.
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