SMR buyers are now being asked to sign fuel and waste contracts early

TerraPower’s first Natrium small modular reactor (SMR) is being positioned as a coal-to-nuclear replacement in Wyoming. X-energy is lining up a unit for an operating Dow chemical site in Texas. On paper, this looks like a technology story.

For the enterprise operators who might actually buy that power, it’s become a contracting story, and the contracts are getting longer. Fuel and waste assumptions, once treated as “national policy issues,” are sliding into the front pages of RFPs.

The SMR pitch is shifting from megaproject to product supply chain

Electrical Contractor Magazine detailed why Natrium and X-energy are getting so much attention: they try to make nuclear buildouts smaller, repeatable, and more compatible with industrial planning cycles. TerraPower’s Natrium design is built around a 345-megawatt generator that can ramp to 500 MW for more than 5.5 hours using a molten salt-based energy storage system, according to Electrical Contractor Magazine. That “peaking” capability is a direct answer to what many large loads want in 2026: firm power most hours, and extra headroom when the grid is tight.

X-energy’s design is sized differently. Electrical Contractor Magazine reported X-energy’s reactors are 80-MW units intended to be combined into larger plants or deployed individually for industrial applications. The company has a joint development agreement with Dow to supply electricity and process steam to Dow’s Seadrift, Texas site, according to Electrical Contractor Magazine.

Reuters put a sharper frame around what “small modular” is really selling. The appeal is not the smallness. It’s the modularity: moving nuclear from a construction business toward a manufacturing business, where major components are built in factories and assembled on site using standardized designs, Reuters reported on Aug. 19, 2026. That distinction matters to any operations executive who has lived through a late EPC schedule. A factory supply chain can still fail, but it fails in more familiar ways: vendor qualification, quality control, spares strategy, and logistics.

HALEU is the gating item, and timelines are already moving

Most advanced reactor conversations still lead with nameplate capacity and siting. In practice, the hard constraint has been fuel. Reuters reported that many advanced designs rely on high-assay low-enriched uranium (HALEU), and that the U.S. Department of Energy has been working through multiple initiatives to establish enrichment and fuel infrastructure to support commercial deployment.

Electrical Contractor Magazine showed what that looks like in a real project schedule. Natrium was initially targeted to start up in 2028, but the company pushed the target to 2030 because of a lack of HALEU, the magazine reported. Electrical Contractor Magazine also reported that Centrus Energy has been working on a HALEU production facility in Piketon, Ohio, with production expected to begin by the end of 2023, and that both TerraPower and X-energy planned to rely on Centrus for HALEU supply.

For industrial and data center procurement teams, that linkage creates a new diligence requirement. A power contract that assumes “fuel will be available” is now a commercial risk, not an engineering footnote. The operator question is basic: what is the contracted fuel volume, what is the delivery schedule, and what happens to output and price if deliveries slip?

Licensing and waste endpoints are moving into the buyer’s risk file

Regulatory predictability has been improving, at least relative to the last decade’s stop-start momentum. Reuters reported the U.S. ADVANCE Act, signed in 2024, directs the Nuclear Regulatory Commission to streamline licensing reviews and create more efficient pathways for advanced reactor deployment, including encouraging development at former fossil fuel sites. Reuters also reported the NRC’s Part 53 framework is intended as a more technology-inclusive, risk-informed licensing pathway for advanced designs.

That helps financing, but it doesn’t eliminate a second reality that enterprise risk teams have to live with: waste has to go somewhere, and the “somewhere” needs to be more than a slide.

Nature’s August 2026 reporting on nuclear waste disposal highlights how much of the technical work is about engineered barriers and controllable, repeatable handling. Nature described Finland’s Onkalo deep geological repository and the use of large clay blocks, each weighing 8,000 kilograms, placed in underground tunnels as part of a long-term storage approach. The operational takeaway is not that every SMR buyer needs its own repository, but that waste plans are being industrialized, with specialized equipment, packaging standards, and process discipline that look a lot like other regulated industrial supply chains.

A parallel planning issue is cost and financing exposure. An August 2026 paper in Energy Policy argued that nuclear competitiveness hinges on optimistic cost and financing assumptions and that prolonged construction duration increases effective project costs due to extended financing exposure. That academic critique is not a verdict on any one SMR, but it reinforces why “schedule certainty” is the real KPI operators should press vendors on, alongside fuel availability and licensing pathway.

Where this lands in 2027 to 2030 power planning

SMRs are being pulled forward by the same force tightening everything else: load growth. Reuters tied the current SMR momentum to rising electricity demand from AI data centers, industrial reshoring, electrification, and new manufacturing investments. That demand pressure is what turns a “2030 technology” into a 2026 procurement conversation, because long-lead decisions are already being made on interconnects, land, and power purchase structures.

For sites with heavy thermal loads, X-energy’s Dow-linked use case is the clearer starting point: process steam plus electricity, built into an operating facility’s reliability requirements. For facilities that already live and die by peak charges and curtailment events, TerraPower’s Natrium storage-enabled ramp profile is the more distinctive operational hook, per Electrical Contractor Magazine’s description.

Either way, the work is migrating from “should we consider nuclear” to “what must be true for us to sign.” That is a shorter meeting, but a thicker checklist.

Questions to bake into SMR RFPs before sites and megawatts

• Fuel: What is the HALEU supply plan, including supplier, contracted quantities, and schedule protections if deliveries slip? (Reuters on HALEU bottlenecks; Electrical Contractor Magazine on Natrium’s delay.)
• Licensing: Which NRC pathway is the project pursuing, and what is the critical path through the review process under Part 53 versus other frameworks? (Reuters on Part 53 and ADVANCE Act.)
• Operations model: If the vendor is building a fleet, where is the remote monitoring, training, and predictive maintenance function housed, and what access does the site get? (Electrical Contractor Magazine reported X-energy is building a support center with real-time instrumentation and digital twin use.)
• Waste: What is the end-to-end waste handling plan during operations and at end-of-life, and which assumptions are tied to national disposal programs versus on-site storage? (Nature’s reporting on industrialized disposal approaches.)