The nuclear industry has spent the past decade focused on technology.

Reactor designs, safety systems, fuel types, modular construction methods, passive cooling architectures, the engineering conversation around Small Modular Reactors has become increasingly sophisticated and increasingly crowded. While over 80 SMR designs and concepts are currently under development worldwide, the commercial conversation has not kept pace.

How SMRs will actually be financed, contracted, deployed, and scaled remains one of the least resolved questions in the market today. That gap, between technological ambition and commercial architecture, is rapidly becoming the defining challenge of the sector.

The reality is straightforward: an SMR does not become economically transformative simply because it is smaller. It becomes transformative only if it can be deployed repeatedly, predictably, and at industrial scale.

And today, the market structure required to achieve that scale is still largely missing.

Why SMR economics work differently

The economic logic behind SMRs is frequently misunderstood.

Smaller reactors are not inherently cheaper on a per-megawatt basis. In many cases, first-of-a-kind SMRs are expected to be more expensive than large conventional reactors when measured against installed capacity.

What changes the equation is repetition.

The commercial promise of SMRs is built on the same industrial logic that transformed sectors such as commercial aviation and offshore wind: factory manufacturing, standardised designs, serial production, and learning curve effects generated across fleets rather than individual projects.

The OECD Nuclear Energy Agency has repeatedly highlighted this dynamic in its work on SMR deployment pathways. The competitiveness of SMRs depends fundamentally on volume. The difference between a first-of-a-kind unit and a fleet-deployed nth-of-a-kind reactor is not marginal but structural.

This has major implications for deployment strategy.

An SMR developed as a one-off infrastructure project, however technically credible, is unlikely to achieve the economics that justify the model in the first place. The commercial viability of SMRs depends on repeatability, manufacturing continuity, and deployment pipelines large enough to drive cost reductions over time.

The challenge is that current procurement and financing structures are still largely designed around traditional project-by-project nuclear development.

The NuScale lesson

The clearest illustration of this challenge remains the 2023 cancellation of NuScale’s Carbon Free Power Project in the United States.

The project was the most advanced SMR programme in the Western market and the first SMR design to receive approval from the US Nuclear Regulatory Commission. Technically, it represented a major milestone for the industry.

Commercially, it exposed the fragility of the current model.

The project had been structured around a subscriber framework in which a group of municipal utilities would collectively purchase electricity output under long-term agreements. As development costs increased, rising from initial estimates of approximately $5.3 billion to roughly $9.3 billion at the time of cancellation, participating utilities progressively withdrew from the project.

Ultimately, the issue was not reactor performance but cost absorption.

The commercial structure was unable to manage the uncertainty associated with the economics of first-of-a-kind deployment. By the time the project was cancelled, 23 of the original 35 subscriber utilities had exited.

The lesson was significant precisely because NuScale was one of the industry’s most mature programmes. It demonstrated that even a technically credible, regulatory-approved SMR can fail commercially if the deployment model does not adequately distribute FOAK risk.

The structural Catch-22

This reveals the central contradiction at the heart of the SMR market.

SMRs require scale to become economically competitive. But the conditions required to achieve that scale, lower costs, established supply chains, and proven operational performance, only emerge after scale already exists.

Every industrial technology faces some version of this problem. SMRs face it at nuclear scale.

The combination of high capital needs, long development timelines, and highly risk-sensitive customers creates a difficult commercial environment for early deployment. Utilities and governments generally prefer proven technologies with predictable cost structures. Yet the economics of SMRs improve only after repeated deployment has already taken place.

The result is a market where almost every stakeholder believes in the long-term potential, but relatively few are positioned to absorb the commercial premium associated with being first.

Without mechanisms capable of distributing that early-stage risk, deployment stalls precisely when commercial momentum is most important.

The commercial architecture is the real product

This is why the future of SMRs may depend less on reactor innovation alone and more on commercial architecture.

Fleet deployment models are central to this shift. Developers need deployment pipelines that span multiple units and sites, allowing manufacturing investment, supply chain development, and learning-curve efficiencies to compound over time. The economics of serial production cannot emerge from isolated procurement decisions.

At the same time, a new category of customer is beginning to reshape the market.

Large technology companies and hyperscalers are increasingly emerging as long-term nuclear counterparties, seeking stable, low-carbon electricity supply for data centres and digital infrastructure. Microsoft’s agreement linked to the restart of Three Mile Island and Amazon’s nuclear-related energy partnerships, and broader hyperscaler interest in advanced nuclear are important not only because of the electricity demand involved, but because they introduce highly creditworthy, long-duration customers capable of underwriting deployment risk in ways traditional utility procurement often cannot.

Government participation also remains essential.

The UK’s shift from the Contract for Difference model used for Hinkley Point C towards a RAB approach for Sizewell C reflects a broader recognition that financing structures matter as much as technology. By reducing financing costs and sharing construction risk more effectively, the RAB model seeks to address one of the fundamental barriers facing large-scale nuclear investment.

Similar mechanisms adapted to the realities of SMR deployment, including FOAK risk-sharing frameworks, revenue stabilisation mechanisms, and public-private financing partnerships, are likely to play a critical role in enabling early projects and building the foundations for future fleet deployment.

At the same time, supply chains themselves require forward visibility. Qualified manufacturers, specialised components, and skilled labour pools do not appear automatically once orders are signed. They require investment well in advance of demand. Without credible deployment pipelines, industrial capacity will remain constrained regardless of reactor readiness.

In other words, the challenge is no longer simply technological but also industrial and financial.

From engineering challenge to market design challenge

Political momentum around nuclear is clearly accelerating.

At COP28, 31 countries endorsed the goal of tripling nuclear capacity by 2050. SMR programmes are advancing across the United States, Canada, the United Kingdom, Central Europe, and the Gulf.

But political support alone does not create commercially viable deployment models.

The industry risks repeating a familiar pattern: developing technically credible reactors, attracting early-stage enthusiasm, and then struggling at the point where commercial deployment requires stable procurement frameworks, long-term financing structures, and coordinated industrial planning.

The next phase of the SMR market will not be defined solely by reactor performance.
It will be defined by whether the industry can build commercial structures capable of supporting serial deployment at scale.

Because the central challenge facing SMRs is no longer purely an engineering challenge.

It is increasingly a market design challenge.

The post The SMR commercial model problem appeared first on Damona | Strategy consulting | Nuclear industry.

Wind, solar, and storage dominate the public conversation around the energy transition. They attract the majority of political attention, investment flows, and infrastructure planning.

They are necessary. They are not sufficient. Because electricity is only part of the challenge.

Heat, the energy used to forge steel, fire cement kilns, refine chemicals, and process industrial feedstocks, accounts for nearly half of global final energy consumption, according to the International Energy Agency. In industry specifically, heat remains the dominant energy input, and the vast majority of it is still generated by burning fossil fuels directly.

This is one of the most structurally difficult problems in the energy transition. And it is one that nuclear may be uniquely positioned to help solve.

Industrial decarbonization has a heat problem

Industry remains the largest source of direct carbon emissions globally, accounting for approximately 37% of total CO₂ emissions when direct combustion and indirect electricity-related emissions are combined.

Within that total, a small number of sectors drive a disproportionate share of the challenge.

Steel production alone contributes roughly 7% of global CO₂ emissions, with blast furnace processes requiring temperatures above 1,000°C. Cement production typically requires kiln temperatures of 1,400–1,500°C and generates unavoidable process emissions from limestone calcination. Chemical manufacturing spans a wide range of heat-intensive applications, many of which require continuous, high-temperature energy across highly integrated process chains.

These are not peripheral sectors. They are foundational to the global economy — and among the hardest to decarbonize.

Why existing pathways leave a gap

Most industrial decarbonization strategies currently rely on three pathways: electrification, hydrogen, and carbon capture.

Each has a role to play. None fully solve the heat challenge on their own.

Direct electrification is effective for lower-temperature industrial applications and will remain an important part of the transition. But for many continuous, high-temperature processes, scaling electric heat economically remains challenging.

Green hydrogen holds significant long-term promise, particularly in steelmaking and chemicals. Yet cost, infrastructure requirements, electrolyser deployment, and renewable power availability continue to constrain large-scale deployment. For many industrial operators, hydrogen remains a medium- to long-term pathway rather than an immediate solution.

Carbon capture can reduce emissions from existing fossil-fired processes, but it does not eliminate dependence on combustible fuels. It reduces the carbon intensity of the system without fundamentally changing its underlying energy architecture.

The result is a persistent gap in the industrial decarbonization toolkit:
a shortage of scalable, clean, continuous high-temperature heat solutions.

Why nuclear deserves greater attention

Nuclear reactors produce heat first and electricity second. That matters.

Conventional light water reactors already generate steam at approximately 300°C, suitable for district heating and a range of lower-temperature industrial applications. But the more significant strategic opportunity lies in advanced reactor technologies designed specifically for higher-temperature output.

High-Temperature Gas-cooled Reactors and Very High Temperature Reactors are designed to deliver outlet temperatures in the 700–950°C range, making them relevant for a far broader range of industrial applications. At the upper end of that spectrum, they also enable more efficient hydrogen production pathways than conventional electrolysis.

This is not theoretical physics but an engineering and deployment challenge.

Nuclear process heat has already been demonstrated across multiple non-electric applications, and high-temperature industrial integration is increasingly moving from conceptual design toward commercial demonstration.

The market is beginning to move

Momentum is building.

China’s HTR-PM at Shidaowan became the world’s first commercial high-temperature gas-cooled reactor in 2023, establishing a critical proof point for advanced nuclear heat technologies. In the United States, the Department of Energy’s Industrial Decarbonization Roadmap identifies advanced nuclear as a strategic option for industrial heat supply, while national laboratories continue developing integration models for nuclear-industrial thermal systems.

At the same time, several advanced reactor developers such as Jimmy are explicitly designing their commercial offerings around industrial heat applications rather than grid-only electricity supply.

The emerging model is clear:
co-located nuclear and industrial assets, linked through long-term thermal offtake arrangements.

For industrial operators, this creates the possibility of securing stable, low-carbon heat directly at source while reducing exposure to grid congestion, transmission losses, and power market volatility.

Why this matters strategically

For many industrial operators, energy is not just an emissions issue. It is a competitiveness issue.

Steel, cement, and chemicals are globally traded commodities produced in margin-sensitive environments. Energy price volatility directly impacts operating margins and long-term investment decisions.

The European energy crisis of 2022–2023 exposed the vulnerability of industrial sectors reliant on gas-fired heat. Meanwhile, mechanisms such as the EU’s Carbon Border Adjustment Mechanism are turning carbon intensity into an increasingly explicit financial variable for exporters into European markets.

In this context, decarbonized industrial heat is no longer simply an ESG consideration.
It is becoming a strategic determinant of industrial competitiveness.

Nuclear process heat offers a pathway to address that challenge structurally: delivering continuous, carbon-free thermal energy with long-term pricing stability and limited fuel cost exposure.

The window for strategic positioning is open now

High-temperature nuclear heat is not yet available at broad commercial scale.

But industrial decarbonization decisions are not made on deployment timelines alone. They are shaped by long asset cycles, infrastructure planning horizons, and regulatory lead times.

Industrial assets commissioned today may operate for 30 to 50 years. Energy infrastructure decisions made in this decade will shape competitiveness and emissions trajectories well beyond 2050.

The companies that begin assessing nuclear heat pathways now, evaluating site compatibility, technology readiness, regulatory implications, and commercial structures, will be better positioned when deployment reaches maturity.

Those that wait for the technology to become fully commoditized may find that the strategic window has already narrowed.

A strategic reframing

The industrial heat challenge remains one of the least discussed, and most consequential, bottlenecks in the energy transition.

Nuclear may not be the answer for every industrial application.
But for many hard-to-abate sectors, it is one of the few scalable pathways to address the problem at its source.

The question is no longer whether industrial heat must decarbonize.

It is which technologies, and which operators, will move early enough to shape that transition rather than react to it.

The post Nuclear energy and the industrial decarbonization imperative appeared first on Damona | Strategy consulting | Nuclear industry.

That asymmetry is becoming difficult to justify.

Water stress already affects large parts of the Middle East, North Africa, South Asia, and southern Europe. According to the World Resources Institute’s Aqueduct Water Risk Atlas, 25 countries currently face extremely high water stress, consuming more than 80% of their available renewable freshwater supply each year. The UN World Water Development Report projects that global water demand will continue to outpace supply growth, with climate change further intensifying pressure in already-vulnerable regions.

For the countries of the Gulf Cooperation Council, this is not a future risk but a structural reality.

The GCC’s water security model is energy-intensive by design

The Arabian Peninsula is among the most water-scarce regions on earth. Rainfall is minimal, aquifers are in sustained depletion, and per capita renewable freshwater resources remain far below global averages.

As a result, desalination is not supplementary infrastructure in the GCC.
It is core to the region’s water supply.

The Middle East and North Africa account for roughly half of global installed desalination capacity, with GCC states leading both in total deployment and per-capita consumption. Major urban centres such as Riyadh, Abu Dhabi, and Kuwait City rely on desalinated water for the overwhelming majority of their municipal supply.

That dependence is set to deepen as populations grow, urbanisation accelerates, and climate conditions worsen.

The strategic question is therefore not whether desalination will remain central to the region’s water model. It is what powers it, and for how long.

Desalination’s carbon and cost exposure

Today, desalination across the GCC remains overwhelmingly powered by fossil fuels.

This creates an increasingly visible contradiction.

Governments across the region have announced ambitious decarbonisation agendas, from the UAE’s Net Zero 2050 strategy to Saudi Arabia’s Vision 2030 and renewable deployment targets. Yet the infrastructure underpinning regional water security remains among the most carbon-intensive utility systems in operation.

Energy accounts for 30% to 60% of the total cost of desalinated water, depending on the process and local energy pricing. This makes water production not only emission-intensive, but structurally exposed to fuel price volatility and long-term hydrocarbon dependency.

In practical terms, the decarbonisation of desalination is no longer optional. It is necessary for the internal coherence of the GCC’s own sustainability and energy diversification strategies.

Nuclear desalination offers structural advantages

Nuclear desalination is not a novel concept. It is a mature and technically proven application of existing nuclear technology.

Reactors can be coupled to desalination through either electrical supply to reverse osmosis systems or direct thermal integration with heat-based desalination processes such as multi-effect distillation. In both configurations, nuclear provides a combination of characteristics that align closely with the GCC’s structural requirements.

First, desalination requires continuous operation. A region dependent on desalinated water for the majority of its supply cannot rely on intermittent generation without substantial backup or storage. Nuclear’s consistently high capacity factors make it structurally well-suited to support critical water infrastructure.

Second, the scale of GCC desalination demand is substantial. Large coastal desalination facilities require significant and sustained energy input, often concentrated near dense urban populations. Nuclear’s energy density and compact footprint allows it to deliver that output efficiently at utility scale.

Third, nuclear offers long-term cost stability. Fuel costs represent a relatively small share of total operating expenditure and are less exposed to commodity price swings than gas-fired generation. For governments planning strategic infrastructure over 30- to 50-year horizons, this predictability is a material advantage.

The technology is proven

Operational nuclear desalination is already in use globally.

India has operated a nuclear desalination demonstration plant at Kalpakkam since 2004, validating both reverse osmosis and thermal desalination integration. Pakistan has operated nuclear-linked desalination capacity in Karachi. Russia’s floating nuclear power unit, Akademik Lomonosov, includes desalination among its design functions.

South Korea’s SMART reactor was specifically conceived as a dual-purpose electricity and desalination platform, and has been evaluated for deployment in multiple Middle Eastern markets.

In other words, the technology adaptation is not speculative.
Its core technical principles have already been demonstrated across multiple reactor and desalination configurations.

The remaining challenge is not feasibility. It is deployment strategy.

Why the GCC is strategically positioned

The GCC is uniquely well placed to lead in this area.

The UAE’s Barakah Nuclear Energy Plant has already established the Arab world’s first operational commercial nuclear programme, creating not only generation capacity but also regulatory infrastructure, operational expertise, and public institutional familiarity with nuclear deployment.

That matters.

Because once a nuclear ecosystem is established, extending its application beyond electricity generation becomes significantly more credible.

For the UAE, nuclear-powered desalination would represent a logical next step: leveraging an existing nuclear platform to address a second strategic dependency through the same infrastructure base.

Saudi Arabia presents a similarly compelling case. The Kingdom is simultaneously pursuing nuclear development and major desalination expansion under Vision 2030. The convergence of those two agendas creates a natural strategic overlap.

More broadly, the GCC’s structural characteristics – high reliance on desalination, coastal urban density, long planning horizons, and strong state-led infrastructure models – make it one of the most favourable global environments for nuclear desalination deployment.

A strategic reframing

In much of the world, nuclear energy is discussed primarily as an electricity solution.

In the GCC, that framing may be too narrow.

Where water scarcity is structural and desalination is existential, nuclear’s most strategic long-term contribution may lie not only in megawatts delivered to the grid, but in cubic metres delivered to national water systems.

The question is no longer whether desalination will expand. It will.

The question is whether the infrastructure powering it remains tied to hydrocarbons — or evolves into a strategic pillar of long-term resilience, decarbonisation, and sovereign resource security.

More broadly, the relationship between nuclear and water security is becoming increasingly strategic in both directions. In water-scarce regions, nuclear can help secure freshwater supply through desalination. In other markets, where electricity systems remain heavily dependent on hydropower, growing hydric stress is exposing the vulnerability of water-dependent generation itself — as seen in countries such as Colombia, where hydropower still provides more than 70% of electricity generation and drought conditions continue to test system resilience.

As climate pressures intensify, nuclear’s role in the water-energy nexus may extend well beyond desalination alone.

For governments and investors shaping long-term infrastructure strategies, that broader connection deserves far greater attention.

The post Why nuclear desalination is the GCC’s most overlooked strategic asset appeared first on Damona | Strategy consulting | Nuclear industry.

As energy systems decarbonise, the challenge is no longer to choose between technologies. It is to make them work together.

Nuclear now operates alongside renewables, storage, hydrogen production, electrified demand, and increasingly, large-scale digital infrastructure such as data centres. Each of these assets behaves differently — technically, economically, and operationally.

The complexity is no longer in individual technologies. It is in the system design that connects them.

From competition to coexistence

Energy debates have long been structured around competition: nuclear versus renewables, baseload versus flexibility, centralised versus distributed systems.

In reality, decarbonised grids require all of these elements simultaneously.

Renewables provide low-cost, variable generation. Storage absorbs short-term fluctuations. Electrification reshapes demand profiles and increases total consumption. Hydrogen introduces flexible demand and new storage dynamics. Data centres add continuous, high-density loads that require reliability.

Within this evolving system, nuclear plays a distinct role. It provides stable, low-carbon generation at scale, independent of weather conditions. But its value is no longer defined solely by its ability to generate electricity. It is defined by how effectively it integrates with the rest of the system.

The question is not whether nuclear competes with other technologies.
It is how it performs alongside them.

The integration challenge

Integrating nuclear into a multi-technology system introduces a different level of complexity.

Highly renewable grids generate volatility in both supply and pricing. Market structures, often based on marginal pricing, were not designed for assets with high capital costs and long operational lifetimes. At the same time, industrial demand is becoming more complex, with clusters requiring combinations of power, heat, and hydrogen. Infrastructure decisions increasingly span sectors that were historically managed separately.

In this environment, nuclear cannot be treated as a standalone asset.

Its role must be defined in relation to the broader system, variable renewable generation, flexible demand sources such as hydrogen electrolysis, storage operating across different time horizons, and the physical constraints of transmission networks.

Without this system-level perspective, integration becomes inefficient, and in some cases, structurally constrained.

Market design as an enabler

One of the most significant barriers to effective integration lies in market design.

Electricity markets in many regions are structured around short-term marginal pricing. This model efficiently dispatches low-cost generation but does not fully capture the value of firm, low-carbon capacity over time.

As a result, nuclear assets can be undervalued relative to the stability they provide to the system.

Addressing this misalignment does not require abandoning market mechanisms. It requires adapting them so that they reflect system needs more accurately. Long-term contracts, capacity remuneration mechanisms, and hybrid pricing structures are increasingly being used to align revenue streams with the role that different assets play.

Certainty, in this context, comes from ensuring that revenue models are consistent with system value.

Infrastructure must be co-optimised

Integration is not only a question of markets. It is also a question of physical infrastructure.

Energy systems are becoming increasingly interconnected. Nuclear plants can supply electricity to the grid, heat to industrial processes, and energy to hydrogen production. Data centres are seeking stable, low-carbon baseload supply. Industrial clusters are evolving into multi-energy hubs where electricity, heat, and fuels are interconnected.

These interactions create significant opportunities, but only when infrastructure is planned coherently.

Co-optimisation requires aligning generation assets with grid capacity, industrial demand with energy availability, and new uses such as hydrogen production with existing infrastructure constraints. Decisions taken in isolation risk creating inefficiencies that persist for decades. Integrated planning, by contrast, allows multiple systems to reinforce each other.

Defining the role of each asset

A multi-technology system only functions when each component is clearly positioned.

Nuclear is not designed to deliver short-term flexibility like batteries. Storage cannot provide long-duration resilience at the same scale as baseload generation. Hydrogen introduces flexibility, but also new infrastructure requirements. Renewables provide low-cost energy but are inherently variable.

System performance depends on assigning each asset a role that matches its characteristics.

For nuclear, this means operating where its strengths are most valuable. It provides stability in systems with high renewable penetration, supports industrial processes that require continuous energy, enables high-utilisation hydrogen production, and anchors supply for energy-intensive digital infrastructure.

Clarity at this level reduces inefficiencies and improves the overall performance of the system.

Certainty comes from system clarity

In a multi-technology energy system, uncertainty does not come from individual technologies. It comes from how they interact.

Certainty is therefore not achieved by focusing on nuclear alone. It emerges from coherent market design, regulatory frameworks that enable integration, infrastructure planning that spans sectors, and clear definitions of roles across the system.

When these elements are aligned, nuclear can operate effectively alongside other technologies, contributing to a system that is both resilient and decarbonised.

A system perspective

The transition to low-carbon energy systems is not a technology race. It is a system challenge.

Nuclear’s value lies not only in what it produces, but in how it interacts with the broader ecosystem of generation, demand, and infrastructure.

Because nuclear does not compete in isolation.
It performs in systems.

The post Nuclear in a multi-technology energy system appeared first on Damona | Strategy consulting | Nuclear industry.

That framework is no longer sufficient.

What is increasingly reshaping nuclear today is geography, where critical materials originate, who controls key stages of the fuel cycle, and which industrial partners can realistically be relied upon over the lifetime of a project.

Nuclear programmes are no longer assessed solely as electricity generation assets. They are increasingly treated as strategic infrastructure, embedded within complex industrial networks that span continents and operate across decades. As a result, the resilience of those networks is becoming just as important as reactor design or construction cost.

In today’s geopolitical landscape, nuclear energy cannot be separated from the supply chains that sustain it.

The fuel cycle reveals strategic dependencies

The nuclear fuel cycle illustrates this shift clearly.

Uranium mining is only the starting point of a long and technically complex process. Conversion, enrichment, fuel fabrication, reactor operation, and spent fuel management each require specialised infrastructures, extensive regulatory oversight, and highly qualified industrial capabilities. These systems are capital-intensive, built over many years, and cannot easily be replicated or relocated.

The result is a global ecosystem in which certain stages of the fuel cycle are concentrated among a limited number of actors.

Enrichment is perhaps the most visible example. Russia roughly controls  40–45% of global enrichment capacity, with other major providers located in Europe, the United States, and China. For many years, this concentration attracted little attention, largely because geopolitical conditions allowed the system to function smoothly.

When those conditions changed, however, the vulnerabilities of that structure became impossible to ignore.

What was once considered a stable commercial arrangement is now increasingly viewed through the lens of strategic dependency.

Nuclear fuel is no longer a routine procurement decision

The implications are significant.

Countries that once approached nuclear fuel services as routine procurement contracts are now reassessing the strategic implications of those arrangements. Governments across North America and Europe are investing in domestic enrichment capabilities, diversifying uranium supply chains, and rebuilding partnerships across the broader fuel cycle.

The underlying logic has shifted.

Nuclear energy is not simply about securing fuel deliveries. It is about maintaining the industrial and technological capacity required to produce reliable electricity for several decades. Ensuring that capacity exists — and remains secure — requires long-term planning that extends well beyond the boundaries of any single power plant.

This reframes nuclear strategy as an issue of industrial capability as much as energy policy.

Partnerships have become strategic instruments

International collaboration has always been a defining feature of nuclear deployment. Large reactor projects routinely involve multinational supply chains, specialised engineering expertise, and regulatory cooperation across borders.

What has changed is the intentionality behind these partnerships.

Governments are increasingly selecting partners not only on the basis of technology performance or project cost, but also on broader strategic considerations: supply chain resilience, long-term industrial cooperation, and geopolitical alignment. The objective is no longer simply to build reactors, but to ensure that the industrial capabilities required to sustain nuclear programmes remain secure over decades.

This shift is visible across the fuel cycle. In the United States, several initiatives aim to rebuild domestic capabilities that had gradually migrated abroad. Companies such as LIS Technologies are working to reinforce enrichment capacity in line with national objectives, while also strengthening the domestic supply chain for both medical and stable isotopes. Similarly, Uranium Energy Corp. (UEC) has announced ambitions to deploy uranium conversion capabilities domestically, complementing efforts to restore key infrastructure such as the Solstice Metropolis conversion facility — formerly Converdyn — which is intended to bring critical fuel cycle processes back onto U.S. soil. Projects such as Orano’s Project IKE, targeting new enrichment capacity, follow the same logic: reinforcing strategic capabilities within national or allied industrial ecosystems.

This trend is not limited to the United States. In Canada and Australia, Cameco’s investments in Silex Systems, which develops laser enrichment technology, and its broader involvement in the fuel cycle through Westinghouse illustrate a similar effort to consolidate capabilities within trusted industrial partnerships. These moves reflect longstanding economic and defence cooperation between the two countries while strengthening resilience across key segments of the nuclear fuel cycle.

The United Kingdom is pursuing comparable objectives. At its Springfields facility in Lancashire, Westinghouse is working — with government backing — to develop new uranium conversion capabilities. The project aims to provide conversion services to utilities seeking diversified supply options while rebuilding domestic fuel cycle expertise that had previously been allowed to decline.

The rapid development of SMRs is reinforcing this trend even further. Many SMR programmes rely on cross-border collaboration between governments, utilities, research institutions, technology developers, and manufacturers. Yet these partnerships are rarely limited to reactor deployment itself. They are increasingly structured to support broader industrial goals such as domestic manufacturing capacity, workforce development, and supply chain diversification.

As a result, the boundary between nuclear deployment and industrial strategy is becoming increasingly blurred. Nuclear partnerships today are not only technical collaborations — they are instruments of industrial policy and long-term strategic positioning.

Supply chains are now a strategic variable

At the same time, nuclear technologies are drawing from an industrial base that is under growing pressure.

Advanced reactors, next-generation enrichment technologies, and fuel cycle infrastructure rely on specialised materials, advanced manufacturing capabilities, and high-precision engineering expertise. Many of these capabilities are simultaneously in high demand across other sectors — including battery production, grid infrastructure, and digital technologies.

This convergence places additional strain on supply chains that were already limited in scale.

For nuclear projects, the implication is clear. Multi-decade infrastructure programmes cannot rely on reactive procurement strategies. Supply chain development must occur well in advance of project delivery, often requiring coordinated investment across industry, government, and research institutions.

Waiting until construction begins is simply too late.

Aligning energy policy with industrial strategy

Countries that have succeeded in deploying nuclear energy at scale tend to share a common approach: they treat nuclear programmes as ecosystems rather than isolated projects.

Investment extends beyond the power plant itself to include the supporting infrastructure required to sustain the sector over time. This includes fuel cycle capabilities, engineering and manufacturing capacity, regulatory institutions, and long-term workforce development.

In other words, the reactor is only one component of a much larger system.

Traditional debates about safety, cost, and electricity pricing remain important. But they now exist within a broader strategic framework that includes industrial resilience, geopolitical stability, and long-term supply chain security.

These factors increasingly shape national decisions about nuclear energy — whether or not they appear explicitly on project balance sheets.

Certainty has become a strategic asset

In a fragmented geopolitical environment, certainty has become one of the most valuable assets a nuclear programme can possess.

Certainty about fuel supply. Certainty about industrial partners. Certainty about the regulatory and institutional framework that will remain stable throughout the lifetime of a reactor.

This kind of certainty cannot be created through a single contract or policy measure. It emerges from a deep understanding of how the entire nuclear ecosystem functions — where dependencies exist, where vulnerabilities may arise, and what is required to sustain the system over several decades.

Nuclear energy has always demanded long-term thinking.

What is new is the extent to which that thinking must now extend beyond the power plant itself, into supply chains, industrial strategy, and the evolving geography of global energy systems.

Because in today’s nuclear landscape, success is no longer defined solely by building reactors. It is defined by the resilience of the ecosystem that surrounds them.

The post The new geography of nuclear: energy security, supply chains and strategic autonomy appeared first on Damona | Strategy consulting | Nuclear industry.

What is emerging is not simply a question of “how to power AI”, but a broader challenge: how to align long-term, capital-intensive nuclear assets with a form of electricity demand that is growing fast, operating continuously, and increasingly strategic for national economies.

For nuclear stakeholders, this moment calls for strategic clarity rather than technological debate.

When digital growth becomes baseload demand

AI is often framed as a software revolution. In reality, it is a physical one. Large-scale model training and inference rely on vast data-centre infrastructures that operate around the clock. These facilities are not flexible loads. They require continuous power, extremely high reliability, and predictable long-term supply.

Energy system planners are now confronting projections that show global data-centre electricity consumption approaching twice today’s levels by the end of the decade, driven by AI. In several advanced economies, expected growth in data centre demand alone rivals or exceeds historical annual increases in total electricity consumption.

This matters because it changes the nature of demand. Unlike electrification of transport or heating, which introduces variability and behavioural elasticity, AI-driven data centres behave much more like industrial baseload. They do not follow daily or seasonal cycles. They do not tolerate curtailment. And they increasingly influence where generation assets are built.

For the nuclear industry, this represents a rare alignment between demand characteristics and nuclear power’s core strengths.

Why energy systems are struggling to absorb this shift

Today’s energy systems were not designed for this growth profile. Variable renewables continue to scale rapidly, but their intermittency creates challenges when matched with 24/7, non-interruptible demand. Natural gas offers dispatchability, yet raises long-term questions around emissions exposure, fuel price volatility and geopolitical dependence. Grid reinforcement alone is proving slower and more capital-intensive than many governments and utilities anticipated.

As a result, data centre operators, utilities and policymakers are moving beyond short-term power procurement and into infrastructure strategy. Power supply is no longer treated as a marginal cost of digital expansion, but as a determinant of competitiveness, resilience and sovereignty.

It is in this context that nuclear power is returning to strategic discussions, not as an ideological choice, but as an infrastructure option whose attributes match emerging system needs.

Nuclear power as a strategic infrastructure asset

Nuclear energy’s relevance to data centre growth lies less in innovation narratives than in fundamentals. High capacity factors, long asset lifetimes, low operational emissions and predictable output make nuclear uniquely suited to serve continuous, large-scale demand.

This logic is increasingly reflected in market signals. Nuclear assets are being re-evaluated not only as electricity generators but also as anchors of regional energy systems. Interest from technology companies in long-term nuclear offtake, including through existing plants, life-extension projects, and, prospectively, new builds, reflects a broader recognition: stable power is becoming a strategic input to digital economies.

At the same time, expectations remain realistic. Nuclear alone cannot meet the entire growth in data centre demand, nor can capacity be deployed overnight. Large reactors, small modular reactors and life-extension programmes all come with distinct timelines, regulatory pathways and risk profiles. The strategic question is therefore not whether nuclear “wins”, but how nuclear fits into a diversified, resilient energy system designed for the next thirty to fifty years.

The core issue is not technology but decision architecture

For nuclear stakeholders, the most difficult challenges raised by AI-driven demand are not technical. They are structural.

How should new nuclear capacity be sited when demand is geographically concentrated but grids are constrained? How should ownership and offtake models evolve when customers seek long-term certainty but assets operate over several decades? How do regulators adapt frameworks designed for centralised generation to new configurations such as co-location, dedicated supply or hybrid public-private models?

These questions cut across energy policy, industrial strategy, finance and governance. They require coordination between actors with different incentives, time horizons and risk tolerances. They also demand a level of strategic integration that the nuclear sector, historically segmented between policy, engineering, operations and finance, is still adapting to.

This is where the role of strategic nuclear advisory becomes critical.

What this means for nuclear leaders

For utilities, the rise of AI-driven demand introduces new customer archetypes: fewer in number, larger in scale, and far more strategic than traditional industrial loads. For governments, it reinforces the link between nuclear policy and economic competitiveness. For investors and developers, it reshapes the risk-return profile of long-term nuclear assets.

Responding effectively requires more than incremental optimisation. It requires clear strategic choices, robust operating models, and delivery frameworks capable of performing over long lifecycles in evolving contexts.

At Damona, we work with nuclear stakeholders precisely on these challenges. Our focus is not on promoting technology, but on supporting clarity in complex decisions: aligning strategy with regulatory reality, structuring operating models for long-term performance, shaping industrial and supply-chain strategies, and supporting disciplined capital project delivery.

AI is accelerating change in electricity demand. Nuclear power is increasingly part of the strategic response. The decisive factor, however, will be how well organisations connect ambition to execution.

For the nuclear industry, this is not a disruption to fear. It is a strategic moment to shape the next phase of its role in the global energy system.

The post Why the next wave of electricity demand is a strategic issue for the nuclear industry appeared first on Damona | Strategy consulting | Nuclear industry.

Decisions made today regarding technologies, industrial partnerships, supply chains, workforce development, and delivery models will shape energy systems well into the 2040s and beyond. Nuclear assets are designed today to operate for at least 60 years. Once strategic pathways are chosen, reversing them without significant cost, delay, or loss of credibility is difficult.

Hence, “when decisions are made” matters just as much as “what decisions are made”.

A convergence moment for nuclear

Now, several structural forces are converging. However, this momentum is not indefinite. Energy security has returned to the top of national agendas following geopolitical disruptions and supply shocks. Decarbonisation targets are shifting from long-term aspiration to near-term implementation. Meanwhile, governments are reasserting industrial policy, designating nuclear energy as a strategic sector linked to sovereignty, competitiveness, and skilled employment.

The International Energy Agency reports that global electricity demand is projected to grow at its fastest pace in decades, driven by the electrification of transport, industrial processes, hydrogen production, and the rapid expansion of data centres. These uses require firm, dispatchable, low-carbon power, a requirement variable-only systems struggle to meet at scale.

Nuclear sits precisely at this crossroad. But alignment alone does not guarantee delivery.

Timing matters because nuclear systems are path-dependent

Unlike many energy technologies, nuclear projects are deeply path-dependent. Early strategic decisions, reactor selection, licensing route, contracting approach, supply-chain localisation, and skills strategy, lock in consequences for decades.

Postponing these decisions does not preserve flexibility. It often fragments execution:

• suppliers invest without long-term visibility,
• regulators face evolving or incomplete submissions,
• workforce pipelines develop out of sync with project needs,
• and capital markets apply higher risk premiums.

Analysis from the OECD Nuclear Energy Agency shows that governance quality, industrial readiness, and delivery structures are consistently stronger predictors of project outcomes than reactor technology choice alone. In other words, strategic hesitation increases execution risk.

Energy security and decarbonisation now come in pairs

Historically, countries treated energy security and decarbonisation as parallel objectives. That separation is now disappearing.

Recent European experience demonstrates that reliance on imported fossil fuels exposes economies to volatility, political leverage, and price shocks. At the same time, climate targets require rapid emissions abatement in power, heat, and industry sectors that demand a reliable energy supply.

Nuclear power already provides approximately 9% of global electricity and remains among the lowest-lifecycle-emission sources. Unlike intermittent sources, it delivers a predictable output independent of weather or fuel markets.

The strategic implication is clear: if nuclear decisions are delayed today, countries risk locking themselves into prolonged reliance on fossil fuels or fragile systems that struggle under rising demand.

Industrial policy is reshaping nuclear supply chains

Nuclear deployment is increasingly intertwined with industrial strategy.

The United States’ recent partnerships around Westinghouse, Canada’s reinforcement of fuel cycle capacity, and Central and Eastern Europe’s push to localise SMR supply chains illustrate a shift toward mobilising the nuclear supply chain. Nuclear is no longer treated solely as an energy asset, but as a driver of manufacturing, exports, and high-value employment.

However, nuclear supply chains have long lead times. Heavy forgings, reactor vessels, qualified valves, control systems, and fuel fabrication capacity cannot be scaled overnight. Once lost, industrial capability is difficult to recover.

The World Bank has highlighted that infrastructure sectors with complex supply chains require early and credible demand signals to unlock private investment. Nuclear is no exception.

Timing matters because supply chains invest where long-term clarity exists — not where intentions remain uncertain.

Workforce is emerging as a structural constraint

Across mature nuclear markets, workforce availability is becoming a decisive factor.

In Europe, North America, and parts of Asia, a large share of experienced nuclear professionals is approaching retirement. At the same time, new build, life extension, decommissioning, waste management, and SMR programmes are competing for the same skills.

Recent national assessments — including in Sweden, France, and the UK — indicate that thousands of additional engineers, technicians, welders, safety specialists, and project managers will be required over the next two decades. Skills pipelines take years to rebuild through education, training, and on-the-job experience.

Without early coordination between governments, industry, and academia, workforce shortages risk becoming a hard bottleneck — regardless of technology readiness.

Timing matters because people are the longest-lead asset in nuclear delivery.

Capital discipline is tightening

Capital is available for nuclear, but it is increasingly selective.

Public lenders, export credit agencies, institutional investors, and corporate offtakers are demanding clarity on delivery pathways, regulatory schedules, risk allocation, and industrial readiness. This trend is visible in revised lending frameworks from multilateral institutions and in the growing emphasis on structured project governance.

Projects that delay strategic structuring often face higher financing costs or extended negotiations. Those who demonstrate readiness early benefit from improved confidence and reduced uncertainty premiums.

This reflects a broader shift: capital is no longer chasing ambition; it is rewarding preparedness.

The next 20 years are being decided now

The nuclear sector is entering a defining phase.

The combination of rising electricity demand, climate constraints, geopolitical pressure, and renewed industrial policy has created a rare window for nuclear to reassert its long-term relevance. But this window is not permanent.

Decisions deferred today will shape outcomes tomorrow, determining which countries secure resilient energy systems, which industries capture value, and which projects ultimately reach construction.

Nuclear’s role in the energy transition will be determined more by the timing and quality of current decisions than by future promises.

Because in nuclear, strategy is not only about direction. It is about when you move and with whom you choose to navigate that moment.

The post Why nuclear strategy decisions made today will define the next 20 years appeared first on Damona | Strategy consulting | Nuclear industry.

If hydrogen is to contribute meaningfully to climate targets, it must be produced at scale, with low or zero emissions, and at costs competitive enough to replace fossil-derived hydrogen. Renewables paired with electrolysis are central to current roadmaps, but they face systemic challenges: intermittency, land-use pressures, and the massive overcapacity required to deliver consistent hydrogen output. This is where nuclear enters the equation. With its ability to provide constant, large-scale, low-carbon electricity and heat, nuclear is uniquely positioned to anchor the hydrogen economy.

The question is no longer whether nuclear can produce hydrogen; it already does at pilot-scale. The challenge is whether nuclear can become a backbone of hydrogen supply chains and how financing, infrastructure, and policy must evolve to unlock that potential.

Comparative economics: nuclear hydrogen vs. renewables + electrolysis

The economics of clean hydrogen depend on three factors: electricity price, electrolyzer efficiency, and utilization rate. Renewable-powered electrolysis can achieve low electricity costs during peak production, but intermittency results in low capacity factors—often below 40%. This dramatically increases the levelized cost of hydrogen, since electrolyzers must be oversized or paired with costly storage to ensure stable output.

By contrast, nuclear power plants operate with capacity factors above 90%, providing constant electricity and heat. When coupled with electrolysis, nuclear can maximize utilization rates, lowering the per-unit cost of hydrogen. According to the OECD-NEA, nuclear-powered electrolysis could achieve costs of $2–3/kg of hydrogen by 2030, particularly when combined with high-temperature electrolysis, compared to current renewable-driven averages of $4–6/kg.

This difference is strategic. In heavy industry, where hydrogen is not just an energy carrier but a raw material, cost competitiveness determines adoption. If nuclear can deliver steady, affordable supply, it has the potential to complement renewables and accelerate hydrogen’s penetration into core industrial processes.

Strategic projects: from France to Eastern Europe to the Gulf

Momentum is building globally around nuclear-hydrogen integration.

• France is leveraging its strong nuclear fleet to explore nuclear electrolysis. EDF and partners are studying the potential of coupling existing reactors with electrolyzers to produce low-carbon hydrogen for refineries, fertilizers, and mobility. This aligns with France’s hydrogen roadmap, which sees hydrogen as critical to achieving net-zero while preserving industrial competitiveness.
  
• Eastern Europe is emerging as a testbed for nuclear-hydrogen synergies. Poland, Romania, and Czechia—all heavily reliant on coal—are evaluating SMR projects that could simultaneously decarbonize power grids and supply hydrogen for industry. Romania’s Nuclearelectrica has explicitly positioned SMRs as dual-purpose assets for electricity and hydrogen production.
  
• The Middle East views hydrogen as both a tool for decarbonization and an export commodity. The UAE, already operating the Barakah nuclear plant, is assessing nuclear-powered hydrogen production as part of its diversification strategy. Saudi Arabia’s Vision 2030 includes ambitions for large-scale hydrogen exports, with nuclear offering a pathway to scale production beyond renewables in desert environments.
  
• The U.S. and Canada are investing heavily in demonstration. The U.S. Department of Energy is funding projects coupling existing reactors with electrolysis, including at the Palo Verde and Nine Mile Point plants. Canada’s CANDU refurbishment program is being linked to future hydrogen production opportunities.
  

These projects suggest a shift: nuclear is no longer seen only as a baseload electricity provider but as a multi-purpose industrial energy hub.

Advanced reactors: unlocking efficiency for hydrogen

Current light-water reactors can power electrolysis, but advanced reactors bring an even more compelling proposition. High-temperature gas-cooled reactors, sodium-cooled fast reactors, and some SMR designs can deliver process heat at 700–900°C, which is precisely in the range required for high-temperature electrolysis or thermochemical cycles such as the sulfur–iodine process.

By using both electricity and heat, advanced reactors can achieve hydrogen production efficiencies far above today’s systems. The IAEA notes that these approaches could reduce hydrogen costs by up to 30–40% compared with conventional electrolysis powered by electricity alone. Demonstration efforts in Japan, with the HTTR project, China with the HTR-PM project, and the U.S. show that advanced nuclear-hydrogen coupling is not just theoretical but increasingly practical.

This technological shift positions nuclear not just as a power generator, but as a cornerstone of integrated industrial decarbonization.

Synergies with district heating and industrial clusters

The strategic value of nuclear hydrogen is amplified when considered alongside other applications. Nuclear plants co-located with district heating networks can simultaneously provide heat to urban centers, hydrogen for industry, and electricity to the grid. This multi-vector approach maximizes asset utilization and strengthens the economic case for investment.

Industrial clusters represent another critical synergy. Steelmaking, cement, and chemical industries require both hydrogen and high-grade heat. Locating nuclear hydrogen projects within or near these clusters reduces transport costs, ensures steady offtake, and enhances competitiveness. Europe’s concept of hydrogen valleys, integrated ecosystems where production, distribution, and use are co-located, could benefit significantly from nuclear, which provides the steady base that renewables alone cannot guarantee.
This integration transforms nuclear from a sectoral solution into a systemic enabler, embedding it into broader industrial strategies.

Policy and investment frameworks: the missing link

Despite the technical potential, nuclear’s role in the hydrogen economy remains underdeveloped in policy frameworks. Most national hydrogen roadmaps focus heavily on renewables, with nuclear often absent from funding and certification schemes. This lack of explicit recognition creates uncertainty for investors and limits the scale of projects.

Momentum is shifting slowly. The OECD-NEA has called for greater integration of nuclear into hydrogen strategies, stressing that energy security and climate goals cannot be achieved without it. The IAEA continues to emphasize nuclear’s role in non-electric applications, including hydrogen.

From an investment perspective, hydrogen projects are capital-intensive and face long lead times. They require patient capital and risk-sharing mechanisms. Instruments such as contracts for difference, green hydrogen certification schemes that include nuclear, and public-private partnerships will be decisive. Investors will also demand robust offtake agreements from industries such as steel and chemicals to de-risk demand.

Without these frameworks, nuclear hydrogen risks remaining at the demonstration stage. With them, it could scale rapidly, anchoring the industrial hydrogen economy.

Hydrogen will be indispensable to Europe’s and the world’s decarbonization pathways. But the idea that renewables alone can supply the hydrogen economy is increasingly being challenged by realities of scale, intermittency, and cost. Nuclear provides the stability, efficiency, and industrial integration needed to turn hydrogen from a niche technology into a backbone of industrial transformation.

The question is not whether nuclear can produce hydrogen—it already can. The real question is whether governments, investors, and industries will align the financing, infrastructure, and policy frameworks necessary to make it competitive at scale.

If they do, nuclear will evolve beyond its traditional role of powering homes and cities. It will become a cornerstone of industrial decarbonization—producing hydrogen for steel, heat for communities, and resilience for economies. In short, nuclear could be the enabler that turns hydrogen from aspiration into reality.

The end of the Hydrogen hype, a new opportunity for pink Hydrogen?

Although hydrogen has a lot of potential for decarbonization and heavy investments have been poured into this industry, many projects have been canceled. As of December 2025, more than 60 major hydrogen projects have been canceled.

One of the key reasons is the long adoption process from end users as they do not want to pay a premium price. With only 7% of hydrogen projects having successfully passed the FID – in comparison to higher pass rate in more mature industries, it shows there is still work to reduce prices, secure investors and end users.

This is where nuclear power could play a key part. Retrofitting existing plants, would allow at a reduced CAPEX to produce pink hydrogen while advanced nuclear with its already embedded cogeneration could deliver the molecule from day 1.

Although, we have been talking about the end of the hydrogen bubble for years, now is the time for hydrogen projects, with more mature approaches and a cost spending-discipline, relevant projects for end users will be able to bring their promises.

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As an example of commitment, the US Government and Westinghouse have committed to build AP1000 and AP300 reactors for at least $80 billion. This one-in-a-lifetime partnership will allow the US Government to receive 20% of any cash distributions to the portion above $17.5 billion. But more interestingly, when looking at the details of this agreement, if before 2029, the valuation of Westinghouse is above $30 billion, the US Government can force an IPO and has 5 years to buy up to 20% of the shares at a discounted price. This shows confirmation of a strong renaissance for nuclear, with governments such as in the US particularly bullish.

This surge of demand, however, exposes a growing vulnerability. Nuclear energy depends on complex, highly specialized, and globally interdependent supply chains. In an era defined by geopolitical fragmentation, resource nationalism, and industrial bottlenecks, these supply chains are increasingly under strain. For executives, policymakers, and investors, resilience is no longer a secondary consideration: it is a strategic determinant of whether nuclear’s renaissance can be delivered on time and at scale.

The strategic bottlenecks

Unlike other energy technologies, nuclear relies on a small number of qualified suppliers, with strict standards and long lead times. The most critical bottlenecks include:

• Heavy manufacturing capacity: Large forgings for reactor pressure vessels, steam generators, and pressurizers are manufactured by only a handful of facilities worldwide, many concentrated in East Asia. Lead times can stretch years, and disruptions can cascade across multiple projects. Those equipment are known as long-lead items.
  
• Nuclear-grade materials and components: Pumps, valves, instrumentation, and control systems must meet stringent nuclear qualification standards. Supplier pools are narrow, and substituting components is often impossible without redesign and relicensing.
  
• Fuel cycle dependencies: Europe has long depended on imported uranium and enrichment, with Russia historically supplying about 20% of global enrichment capacity. Alternatives exist in the UK, in the Netherlands, Germany, France, China, and the U.S., but diversifying requires years of investment and coordination.
  
• Workforce and specialist services: Nuclear construction depends on highly skilled welders, inspectors, and project managers, many of whom are approaching retirement. Shortages of qualified personnel are emerging as a bottleneck as critical as physical components.

Geopolitics and fragmentation

Geopolitical dynamics are intensifying supply chain risks. The conflict in Ukraine has triggered an urgent reassessment of fuel dependencies, particularly in Europe. The EU is now moving to phase out reliance on Russian enrichment and conversion services, but building alternative capacity will take years and billions in investment. Alternatives to ROSATOM such as Westinghouse and FRAMATOME are also now offering VVER-compatible fuel to diversify fuel manufacturing options.

Elsewhere, resource nationalism is reshaping uranium markets. Kazakhstan, the world’s largest uranium producer, has signaled its intention to prioritize domestic processing and partnerships with aligned states. The U.S. has introduced incentives to rebuild domestic enrichment capacity and recently awarded six companies with energy contracts, while China is securing long-term supply contracts across Africa and Central Asia. In this fragmented context, uranium and enrichment are no longer commodities traded over the counter but strategic assets embedded in geopolitical competition.

Fragmentation also undermines international collaboration. While organizations such as the IAEA and OECD-NEA promote cooperative approaches, national industrial strategies increasingly emphasize domestic capacity and “friend-shoring.” This reduces economies of scale and creates duplication of effort, raising costs for all players.

The economic consequences of weak supply chains

The economic impact of supply chain weakness is profound. Delays in component delivery or shortages of qualified vendors are among the most common causes of cost overruns in nuclear projects. A single missed delivery of a reactor pressure vessel can delay an entire project by years. For large-scale reactors, such setbacks translate into billions in additional costs. Let alone quality risks such as seen with the vessel of the EPR Flamanville.

For SMRs, which promise faster deployment through modularity, the supply chain is even more critical. Their business model depends on repeatability and standardization, akin to shipbuilding or aerospace. Without industrial capacity to mass-produce modules at scale, SMRs risk becoming boutique projects, losing the very economic advantage that makes them attractive. As the OECD-NEA has highlighted, the path from FOAK to NOAK depends entirely on robust supply chains able to deliver at scale and cost.

The financial sector is increasingly aware of these risks. Investors demand evidence of credible supply chain strategies before committing to multi-billion-dollar projects. For utilities and developers, this means that supply chain resilience is no longer just an operational issue—it is central to financial bankability.

Central and Eastern Europe: a strategic opportunity

While supply chain vulnerability is a challenge, it also creates opportunities for new players. Central and Eastern Europe, where many new nuclear projects are planned, is well-positioned to capture industrial value. The region has a strong base in heavy industry, engineering, and skilled labor, making it a natural candidate to host parts of the nuclear supply chain.

Poland has launched initiatives to attract large scale and SMR developers and is exploring partnerships with Western vendors. The Czech Republic is leveraging its historical expertise in reactor design and manufacturing to secure a role in both large reactor and SMR supply chains. Romania, with its plans for CANDU refurbishment and SMR deployment, is positioning itself as a hub for both construction services and long-term fuel cycle activities.

By integrating nuclear into broader industrial policy, CEE countries could transform nuclear projects from technology imports into engines of domestic industrial renewal. The choice is not only about energy, it is about whether nuclear becomes a strategic lever for reindustrialization, exports, and long-term competitiveness.

Building resilience through strategy

Strengthening nuclear supply chains requires coordinated action at multiple levels. Diversification of suppliers is essential, reducing dependence on single points of failure. Workforce strategies must address demographic challenges, with new pipelines of engineers, welders, and project managers built through apprenticeships and university partnerships.

Standardization of designs is another key factor. The proliferation of bespoke reactor designs fragments demand and weakens supply chains. Consolidating around standardized models enables economies of scale, reduces qualification costs, and creates predictable demand for suppliers. This is particularly important for SMRs, where standardization is central to their economic rationale.

Finally, governments and private firms must collaborate to build industrial resilience. Public funding can support new manufacturing capacity, while export credit agencies and international financing institutions can de-risk investment in supply chains. For private developers, embedding supply chain strategy into project planning is no longer optional—it is a prerequisite for success. Lessons from aerospace and semiconductors are clear: industrial ecosystems do not emerge spontaneously; they are cultivated through sustained investment, policy alignment, and long-term partnerships.

The nuclear renaissance will be defined not only by technological breakthroughs or political commitments but by the resilience of the supply chains that make them possible. In a fragmented world, nuclear components, fuel cycles, and skilled labor are not just industrial inputs—they are strategic assets.

The companies and countries that recognize this early, investing in diversification, industrial capacity, and workforce renewal, will secure a competitive advantage. They will deliver projects on time, attract investor confidence, and position themselves as leaders in a sector central to energy security and decarbonization. Those who ignore the supply chain challenge may find that their nuclear ambitions are constrained not by technology, but by the weakest link in a fragile global system.

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Yet, behind the optimism lies a stark reality. Most SMR developers today are still startups—lean, engineering-driven ventures with limited resources. The real challenge is not designing reactors on paper or in laboratories, but scaling from R&D entities into fully fledged industrial companies capable of delivering reactors at commercial scale. This transition is proving to be far more difficult than anticipated, defined by what energy analysts call the “valley of death”: the high-risk, capital-intensive gap between proving a concept and deploying a first-of-a-kind facility.

The funding gap between startups and infrastructure

The financing model for SMRs exposes a fundamental tension. Startups typically attract venture or growth equity in their early phases, raising tens or even hundreds of millions to fund design, licensing, and initial prototypes. Recent years have seen several SMR companies successfully expand their capital base, underlining investor enthusiasm for nuclear innovation.

But the leap to actual deployment requires billions, not millions – French government released a study claiming that at least €1b is necessary to reach FOAK deployment. FOAK projects carry the financial profile of large infrastructure assets and require sufficiently large balance sheets. Yet, unlike other industries, SMR startups cannot generate significant revenues until reactors are fully licensed and operational—a process that often spans a decade or more. This creates a prolonged period where capital is consumed but no income is generated, eroding investor confidence. Nuclear projects are uniquely capital-intensive and require patient, long-term financing that few private investors are accustomed to providing. To that effect, decision makers have been trying to counter this challenge that scares away investors through innovative financing structures such as the Regulated Asset Based model (RAB) for Sizewell C.

Without bridging mechanisms, many developers risk being stranded in this financial dead zone. The valley of death is therefore not a metaphor but a structural problem: a stage where enthusiasm is high, technical potential is proven, but funding dries up because the scale of capital required resembles traditional infrastructure rather than high-growth technology.

Policy and licensing as strategic gateways

Scaling SMRs is not just a financial challenge; it is also profoundly shaped by policy and regulation. Licensing remains one of the most significant bottlenecks. Most regulatory frameworks were developed for gigawatt-scale reactors, with little flexibility for modular or novel designs. The result is that many SMR projects face lengthy and uncertain approval processes that extend timelines, inflate costs, and deter investors.

The IAEA has underscored the importance of regulatory innovation, calling for harmonization of standards across countries to avoid duplicative and inconsistent licensing processes. Similarly, the OECD-NEA stresses that governments must adapt existing frameworks to reflect the specific risk profiles of modular reactors. Without more agile regulation, SMRs risk being trapped in a cycle of endless review and delayed deployment. Hence the presidential executives orders and the U.S. DOE pilot programme, aiming at accelerating SMR deployment through simplified regulation.

Policy also directly shapes market appetite. A recent analysis showed that investor confidence is closely correlated with government signals—long-term decarbonization commitments, procurement frameworks that recognize nuclear as a clean energy source, and public funding for FOAK deployments. Where policy is clear and supportive, private capital follows; where it is inconsistent, projects stall.

Industrial supply chains and execution capability

Even if financing and licensing are secured, SMR startups confront the industrial reality of scaling. Building a reactor requires an ecosystem of advanced suppliers: forged steel, precision machining, nuclear-grade materials, modular construction expertise, and digital control systems. Few startups have this capacity internally. To succeed, they must form strategic partnerships with established industrial players or build entirely new supply chains from scratch. Identifying relevant delivery models is essential. Away from the traditional EPC model or Multi-Package, there are collaborative alternatives such as Integrated Project Delivery (IPD) that can bring stakeholders engagement and lower risks.

Some companies are already innovating in this space. Thorcon, for example, leverages the shipbuilding industry, constructing reactors in established shipyards before transporting them to deployment sites. This “shipyard build” approach reduces on-site construction risks, exploits existing industrial expertise, and demonstrates how cross-sector synergies—in this case with shipping—can accelerate nuclear deployment.

Yet the challenge is systemic. Industrialization is the decisive bottleneck. SMRs cannot remain bespoke projects; they must evolve into standardized, replicable products. This requires not just new engineering, but new manufacturing paradigms that treat reactors as products rather than one-off megaprojects.

Organisational scaling and talent pressures

The human capital dimension is equally significant. Most SMR startups today are composed of small teams of engineers, scientists, and business developers. Scaling to become an industrial company means managing thousands of employees, complex vendor networks, and multinational project pipelines. This organizational transformation is as demanding as the technology itself.

The IAEA consistently highlights the need for human resource planning in nuclear programs, noting that gaps in project management and specialized engineering often cause delays. SMR startups must therefore not only attract scarce nuclear talent but also build governance structures, training programs, and cross-generational knowledge systems capable of sustaining long-term industrial operations. In a sector already facing widespread skills shortages, this is no small task.

FOAK to NOAK: the cost curve challenge

Perhaps the most defining test of all is the transition from FOAK to Nth-of-a-Kind reactors. FOAK projects inevitably come with high costs, technical risks, and uncertain schedules. It is only by achieving NOAK deployments—where repetition, learning effects, and standardization drive down costs—that SMRs can become commercially viable and display competitive Levelized costs of Electricity or LCOEs.

FOAK may be as expensive per megawatt as large reactors, but costs decline steeply once manufacturing and deployment routines are standardized. The challenge is ensuring that startups, investors, and governments can sustain commitment through this critical phase. Without reaching NOAK, SMRs risk remaining perpetually experimental.

Investor confidence and the long game

For investors, SMRs present both an opportunity and a dilemma. The potential market is vast—tens of billions in new capacity across developed and emerging economies—but the timelines, risks, and policy uncertainties are daunting. A recent CNBC review of U.S. SMR efforts illustrates the paradox: enthusiasm is high, yet FOAK facilities face cost overruns, regulatory delays, and investor hesitation. Not only seen in the U.S., this is a world-wide situation.

To overcome this, blended financing models are emerging, combining public funding, export credit, institutional capital, and strategic partnerships with large industrial firms. The SMR deployment will succeed not just on technological merit, but on the strength of governance and financing innovation. Investor confidence depends on credible roadmaps, transparent risk-sharing mechanisms, and evidence that lessons from FOAK projects are being systematically applied to subsequent deployments.

From startups to industrial champions

The journey from startup to industrial champion in the SMR space is arduous, but the stakes could not be higher. Developers must secure patient capital that bridges the gap between venture finance and infrastructure-scale funding. They must work with governments to ensure regulatory frameworks are fit for purpose. They must build or integrate into robust industrial supply chains, while simultaneously scaling their own organizations and workforce capacity. Above all, they must prove they can deliver FOAK projects and quickly transition to standardized NOAK deployments.

The challenge is formidable, but the prize is historic. If successful, SMR startups will not only carve out a new industrial niche, they will redefine how nuclear power is delivered—making it more modular, more scalable, and more integrated into the broader energy transition. The companies that manage to cross the valley of death will become the backbone of a new era in nuclear, shaping both climate resilience and industrial competitiveness for decades to come.

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