Romania is not the first country that comes to mind when you think about nuclear ambition. The country runs two aging CANDU reactors at Cernavodă, operates on a grid that still leans heavily on fossil fuels, and has spent the better part of two decades in failed negotiations with one foreign partner after another over its energy future. European partners tried in 2009 and quit. China tried in 2015 and got booted in 2020. Now the Americans are in, and unlike every arrangement before this one, something appears to actually be moving.

On February 12, 2026, shareholders of Romanian state nuclear operator Nuclearelectrica approved the Final Investment Decision for a 462-megawatt SMR plant at a former coal site in Doicești, about 90 kilometers northwest of Bucharest. The technology: six NuScale Power Modules at 77 MW each, designed and certified in the United States. The project company, RoPower Nuclear, describes this as the most advanced SMR project at the European level. Romania’s Energy Minister Bogdan Ivan called it “the transition from the analysis phase to the implementation phase.”

That is the good news. The rest of the story is more complicated, and it is worth understanding precisely, because Romania’s bet on American nuclear technology is not just a construction story. It is a strategic statement that carries implications well beyond a single plant on a de-industrialized river valley in Dâmbovița County.

How Romania stopped trusting Beijing and started calling Washington

The Doicești project did not happen in a vacuum. To understand why Romania chose American SMR technology, you have to understand what it chose instead, and why. 🌍

Romania’s only nuclear plant, Cernavodă, uses Canadian CANDU technology — pressurized heavy water reactors commissioned in 1996 and 2007. Plans to build two more units at Cernavodă (Units 3 and 4) stalled for years. By 2013, China General Nuclear Power Corporation (CGN) had signed a memorandum of understanding to build them. Six years of negotiations followed. They went nowhere. In January 2020, Romanian Prime Minister Ludovic Orban announced the partnership with CGN was not going to work. By May 2020, Romania formally terminated the agreement.

The timing was not coincidental. In August 2019, the US Justice Department had placed CGN and several subsidiaries on a trade blacklist, accusing them of acquiring advanced American technology for military use. And in that same month, Romanian President Klaus Iohannis and then-US President Trump had signed a joint statement in Washington that, reading between the lines, left very little ambiguity about what Romania’s “strategic partners” wanted to see happen to CGN’s involvement in Romanian nuclear infrastructure.

This sequence matters for the Doicești story:

• Romania removed a Chinese state company from its most sensitive energy infrastructure under American pressure

• Within months, it signed an intergovernmental agreement with the US on nuclear cooperation

• The NuScale MOU with Nuclearelectrica began in March 2019, the same month the geopolitical winds changed

• The US Export-Import Bank eventually issued letters of interest for up to $3 billion in project financing

What looks like a commercial technology choice is also a geopolitical alignment, and no one on either side is pretending otherwise. The US Embassy in Romania explicitly calls the country “a key partner to support regional energy security” in its December 2025 strategic dialogue statement. The Heritage Foundation described SMR cooperation as an opportunity to counter “the malign political influence of Russia” in Central and Eastern Europe. Romania is on NATO’s eastern flank, neighbors Ukraine, and has zero interest in energy infrastructure controlled by Moscow or Beijing. American nuclear technology, with American financing, is therefore not just a power source. It is a strategic anchor. ⚛️

Think about that the next time someone tells you SMR contracts are purely about megawatt economics.

What the Doicești project actually involves

Setting aside the geopolitics for a moment, what is Romania actually building? 🔬

The site is the former Doicești coal-fired power plant, which has already had its old infrastructure removed. The plan is to build six NuScale VOYGR-6 modules on that footprint, with a combined output of 462 megawatts electric. That is enough to power roughly 400,000 Romanian homes and meaningfully reduce the country’s remaining coal dependence.

The engineering team is substantial:

• Fluor Corporation, the US engineering giant, serves as main contractor for the FEED (Front-End Engineering and Design) work

• NuScale Power is a subcontractor to Fluor, which is an interesting reversal of what you might expect from the technology licensor

• Samsung C&T, the South Korean construction and engineering conglomerate, is also involved in the FEED phases

• Studsvik Scandpower from Sweden has been contracted for nuclear fuel analysis software (CMS5), bringing in a fourth country’s industrial base

The construction timeline targets the first module in commercial operation in 2033, with subsequent units following. The FEED Phase 2 study was completed in late 2025, producing what NuScale CEO John Hopkins described as the data needed for the final investment decision: an updated cost estimate, schedule, and the safety analyses required for licensing.

Romania’s nuclear tech director Dan Șerbănescu noted that NuScale’s technology builds on half a century of light-water reactor experience, which matters more than it might seem — regulators and operators working with a technology that shares DNA with existing fleet designs start from a more solid knowledge base than a genuinely novel reactor type. What the plant adds on top of that familiar foundation is passive safety systems: the NuScale module does not require external power or active cooling intervention to prevent meltdown, a characteristic that significantly reduces the complexity of the emergency planning zone. That has implications for where you can put these things, and in a densely populated European country with strong public opinion on nuclear safety, it matters a lot. 🛡️

The FID and what it does, and does not, mean

Here is where a dose of realism is useful, because the FID announcement made headlines across Europe, and some of that coverage was rosier than the situation warrants.

The Nuclearelectrica shareholder approval on February 12, 2026 is explicitly conditional. The official documents describe a set of conditions whose fulfillment is mandatory for the project’s feasibility. Romanian Prime Minister Ilie Bolojan was admirably blunt about this at the announcement: “Given the very large amount of money, the complexity of such projects and the technology being in early days, I estimate we will not see the investment immediately.” 📋

The financial picture makes his caution understandable:

• Total project cost is estimated at up to $7 billion by the Romanian government

• The US government commitment is reported to cover approximately $4 billion of that — through a combination of EXIM Bank financing and DFC support

• The remaining financing gap requires Romanian government support, private investors, and potentially EU funds

• The pre-EPC phase, expected to last about 15 months, will nail down the Class 2 budget estimate and the contractual structure before any major construction begins

There is also an ownership complexity worth noting. RoPower Nuclear is currently owned 50/50 by Nuclearelectrica and Nova Power & Gas (part of E-Infra). Reports as of late 2025 suggest a restructuring in which South Korean firm DS Private Equity (DSPE) may take a stake, with Nuclearelectrica’s share dropping to 46.5%. Whether that restructuring closes cleanly will affect the financing timeline.

What the FID genuinely does is move the project past a critical decision point that previous proposals to Romania never reached. All those European partners in 2009? They never got here. China never got here. The fact that a formal, shareholder-approved investment decision exists, with a detailed engineering basis from a completed FEED study, is real progress. It does not guarantee construction starts on schedule, but it is not nothing. 💡

Does Romania’s conditional FID represent the model other European countries should follow, or is it a cautionary tale about how political alignment can move faster than project economics?

Why the rest of Europe is paying close attention

Romania may seem like an unlikely lead actor in Europe’s nuclear future, but that framing underestimates the country’s role in a specific regional dynamic. Romania is a member of the Three Seas Initiative, the grouping of Central and Eastern European countries sitting between the Baltic, Adriatic, and Black seas, many of whom are urgently looking for energy infrastructure that does not depend on Russian gas or Chinese capital. 🌍

The stakes are clear:

• Poland is building its first nuclear program, also with American technology (Westinghouse)

• Czech Republic is proceeding with a Westinghouse PWR at Dukovany

• Bulgaria, Slovenia, and Slovakia are all in various stages of nuclear expansion or extension discussions

• None of these countries wants to be the second one to commit to a new technology before someone else has proven it

Romania, if Doicești actually gets built and operates as designed, becomes the proof of concept for the entire region. Energy Minister Bogdan Ivan was direct about this: the shareholder meeting documents frame the FID as consolidating Romania’s position “at the forefront of the new European nuclear industry.” That framing is deliberate. Romania wants to be first, and being first comes with serious strategic benefits — preferred supplier relationships, accumulated regulatory expertise, and the geopolitical prestige of showing the region how to build energy independence on American technology.

This is also, it bears saying, exactly what US energy diplomacy has been seeking for years. The US-Romania Strategic Dialogue statement from December 2025 commits both countries to continued cooperation on SMR deployment, Cernavodă Units 3 and 4, and Black Sea energy development with American companies. The whole package, taken together, describes a country that has comprehensively reoriented its energy infrastructure around a Western technological and financial framework. That did not happen by accident.

The question Romania’s nuclear bet ultimately raises is this: if Doicești operates on schedule in 2033 and delivers power at the projected cost, how quickly do the other Three Seas countries sign their own NuScale agreements, and what does that mean for the global nuclear supply chain that will have to build all of them?

The moment Sam Altman merged his SPAC with a nuclear startup named Oklo, it was clear something had shifted. Not just in who was funding nuclear energy, but in how these companies think about selling it. Nuclear used to be built by utilities for utilities, financed by regulated ratepayers, blessed by governments, and measured in decades. Then a group of engineers who grew up watching Tesla tear apart the car industry decided to apply the same logic to atoms.

The comparison is not just a slide deck flourish. The specific strategic moves that made Tesla successful — selling direct to customers, owning the supply chain end to end, building iteratively and learning in public, and securing early adopters wealthy enough to absorb first-generation premiums — are playing out in nuclear right now. Some of it is working. Some of it still needs to survive contact with a regulatory body that does not operate on Silicon Valley timelines. But the intent is unmistakable, and it is worth understanding precisely.

The direct model: skipping the utility altogether

Tesla did not sell cars through dealerships. It sold them directly to drivers, cutting out the middleman and controlling the full customer relationship. Oklo is attempting the same move in nuclear energy. Instead of building reactors and handing them to a utility, Oklo builds, owns, and operates its reactors, then sells power directly to customers under long-term contracts — what the company calls a “power-as-a-service” model. 💡

The implications are significant:

• Utilities are not in the transaction at all

• Oklo captures the margin from electricity sales rather than a one-time reactor sale

• Customers like data centers get a predictable, locked-in power price for decades

• Oklo can co-locate its Aurora Powerhouse directly on a customer’s site, eliminating grid interconnection costs

As of early 2026, Oklo has a customer pipeline of roughly 14 GW, including a supply agreement with data center giant Switch and a deal with Meta to supply 1.2 gigawatts to AI operations in Ohio. These are not letters of intent. They are structured agreements that include upfront funding from customers to accelerate construction.

This is, pretty explicitly, the Tesla pre-order model. Early adopters commit capital before the product ships, which funds the factory, which proves the concept for the next wave of buyers. It worked for cars. Whether it works for reactors, which have a dramatically longer build cycle and a much more complex regulatory environment, is the actual bet being placed here.

Think about what this means for the traditional nuclear industry: the assumption that utilities are the only viable customer for nuclear power has not just been questioned. It has been discarded. 🔬

Is this model genuinely viable, or is a 12-GW pipeline of signed contracts just optimism dressed in legal formatting?

Vertical integration: owning the supply chain like Apple owns its chips

Tesla builds its own battery cells, its own motors, its own software, and as of recently, its own chips. The point is not just cost control. It is speed. Every time you depend on an external supplier, you introduce a schedule risk you cannot manage. Kairos Power, the California nuclear startup that just became the only US company actively building an advanced SMR, understood this early. 🏭

According to E&E News reporting from July 2025, Kairos argues that vertically integrating its supply chain, doing everything from fuel fabrication to welding reactor vessels internally, gives it a better shot at staying on schedule. That is not a boast. It is a lesson learned from watching every other nuclear project fall apart when a single specialty subcontractor missed a deadline and the whole critical path unraveled.

Kairos’s vertical integration list is striking:

• Fuel fabrication from its proprietary TRISO pebble fuel in-house

• Reactor vessel welding performed internally rather than contracted out

• Iterative reactor designs built at the same Oak Ridge, Tennessee, site, so infrastructure and personnel carry forward between projects

• A direct revenue agreement with Google locked in before the first commercial reactor operates, providing financial certainty while construction advances

Oklo takes vertical integration a step further by closing the fuel cycle entirely. In March 2025, Oklo acquired Atomic Alchemy and subsequently announced plans for a $1.68 billion nuclear fuel recycling facility in Oak Ridge, Tennessee. The plan: convert the 80,000+ tons of spent nuclear fuel sitting at US reactor sites into HALEU to power its own Aurora reactors. That is not just vertical integration. That is turning a waste liability into a feedstock. Tesla wished it could recycle old cars into new battery cells this cleanly. ⚡

The strategic logic is identical in both industries: when you own the whole stack, you control your cost trajectory, and you build institutional knowledge that competitors cannot easily replicate.

Big Tech as the early adopter: who plays the role of the tech crowd that bought Teslas first

Tesla’s first customers were wealthy early adopters who could absorb a $100,000 price tag for a car that proved the concept for everyone who came after. SMR startups have found a customer base that is even more strategically useful: technology companies with virtually unlimited energy appetite, strong balance sheets, genuine carbon commitments, and the patience to fund first-of-a-kind builds. 🚀

The deal-making here has been extraordinary in scale:

• Google and Kairos Power signed what Google described as the world’s first corporate agreement to purchase nuclear energy from multiple SMRs, targeting 500 MW by 2035, with Hermes 2 targeted for 2030 at the Tennessee Valley Authority grid

• Meta announced agreements for 6.6 GW of nuclear energy projects in 2026, including the Oklo partnership

• Oracle announced a gigawatt-scale data center powered by three SMRs, with CEO Larry Ellison stating construction permits were already secured

• Microsoft signed a 20-year agreement to restart Three Mile Island at 835 MW, while also backing Oklo

These deals change the economics in a specific way. The tech companies are not just buying power. They are, as Google’s head of data center energy Amanda Peterson Corio said to CNBC, actively trying to help commercialize the technology: “We want to see how we can take this from something small to something bigger that we can deploy at scale.” That is a customer funding your learning curve. No nuclear company in history has had that.

It is also worth noting what kind of customer this is. A data center operator running on nuclear does not vary its load the way a grid operator does. It runs at near-constant draw, 24 hours a day, 365 days a year. That is the ideal customer for a baseload nuclear reactor, and it is exactly the profile that makes nuclear competitive against wind and solar in this specific application. The alignment between what SMRs produce and what AI infrastructure needs is probably the most consequential commercial development in nuclear’s history.

The iterative build strategy: failing fast, then failing less

Here is something Tesla did that is deeply unfamiliar in nuclear: it built cars that were not quite right, sold them to customers, used the feedback, and built better ones. The original Roadster was barely viable. The Model S was the first real product. The Model 3 was the one that changed the world. Each generation funded the next and taught lessons the previous one could not.

Kairos Power has adopted this strategy more explicitly than any other SMR developer. Its Hermes 1 reactor in Oak Ridge is a 35-megawatt thermal demonstration plant, deliberately non-power-producing, designed purely to prove the fluoride salt cooling technology and stress-test the supply chain. The Nuclear Regulatory Commission issued a construction permit for Hermes 1 in December 2023, the first non-water-cooled reactor approved for construction in over 50 years. 🔩 Then in November 2024, the NRC approved Hermes 2, a two-unit power-producing plant at the same site.

Kairos CEO Mike Laufer told CNBC that Hermes 2’s core purpose is to create a standardized reactor design that drives down the cost of future deployments. Each iteration is a learning vehicle, not a revenue vehicle. The Google deal is structured the same way — Google and Kairos bear the financial risk of the first-of-a-kind build, while TVA provides the revenue stream through a power purchase agreement. Future customers inherit a cheaper, better-proven design.

This is genuinely novel in nuclear. The traditional approach was to design everything perfectly on paper, then build it once and hope. Kairos builds small, learns expensively, and applies those lessons to the next build. The risk of the approach is that each build still takes years and costs hundreds of millions of dollars. This is not software iteration. You cannot ship a patch to a reactor. But the principle of structured learning across a product line, rather than treating every build as a unique custom project, is real progress.

Where the Tesla playbook could still break down

None of this means the outcome is guaranteed. And I think it is worth saying clearly where the analogy strains under pressure. 📈

Tesla’s most powerful advantage was speed. A car takes roughly 30 hours of manufacturing labor to build. A reactor takes years of construction and a regulatory process that the NRC measures not in sprint cycles but in 18-month review windows. The iterative model that works beautifully in software, and even in automotive, faces a different physics in nuclear:

• Regulatory review of a new reactor design cannot be accelerated just because your customer has deep pockets

• HALEU fuel, required by Kairos, Oklo, and TerraPower’s Natrium reactor, is still not available at commercial scale in the United States, and no tech company checkbook can manufacture that supply chain overnight

• First-of-a-kind construction costs are genuinely high; Kairos’s first commercial units will not benefit from learning-curve cost reductions until multiple reactors are built

• The NRC’s licensing process, even on an accelerated timeline, still requires years that Tesla’s product cycles simply do not

The Bloomberg feature on Oklo from October 2025 noted that critics worry Oklo’s political connections and fast-moving ethos could pressure the NRC to approve designs before they are fully proven. That is a real concern. The nuclear safety record is excellent precisely because the regulatory process is slow and rigorous. The goal is not to remove oversight. It is to rationalize it for new reactor types that have fundamentally different risk profiles than the 1970s designs the current framework was built around.

The SMR startups that will succeed are probably the ones that internalize both sides of this. Move fast where you can: supply chain, factory setup, customer agreements, software. Move carefully where you must: safety case, regulatory submission quality, fuel cycle planning. Kairos, which got its Hermes 1 permit in 18 months after submitting what the NRC described as a thorough application, seems to understand this distinction. Others that assume the Tesla playbook transfers wholesale to a nuclear regulator may find the analogy has limits.

The question worth sitting with is this: when the first American SMR actually produces commercial power, which company will own that moment, and will their approach look more like Silicon Valley’s or more like the traditional nuclear industry’s?

Ask most people what makes a small modular reactor small, and they’ll point to the output numbers. Under 300 megawatts electric, roughly one-third the size of a conventional plant. Fine. That part is easy. But ask what makes it modular, and you’ll get a lot of hand-waving. “Built in a factory!” someone says. “Shipped on a truck!” says another. The answers are not wrong — they’re just incomplete. And the gap between “sort of right” and “fully understood” is exactly where the most important question in nuclear construction lives.

Because “modular” is not just a design philosophy. It is a direct attack on the single biggest reason nuclear energy keeps losing the argument: it costs too much and takes too long to build. Traditional nuclear has a construction problem that is almost comically bad. Fixing it is worth understanding precisely.

The scale of the problem that “modular” is trying to solve

If you want to understand why the word “modular” carries so much weight, start with Vogtle Units 3 and 4 in Georgia. Completed in 2024, the project came in at $35 billion, more than double its original estimate. It took over a decade. And that was a project using modern designs, with experienced contractors, in the United States. 😬

Conventional large reactors typically take 10 to 15 years to build, and they routinely blow past their budgets. The reasons are structural, not accidental:

• Every large plant is essentially custom-designed for its specific site

• Most of the assembly happens outdoors, subject to weather and workforce variability

• The sheer complexity of coordinating thousands of workers and subcontractors on-site creates cascading delays

• Any design change discovered mid-build ripples backward through months of completed work

This is not a new problem. It is the same problem nuclear has had since the 1970s. 🔬 The industry, to its credit, eventually started asking a different question: what if we stopped building power plants the way we build cathedrals, and started building them the way we build submarines?

The answer to that question is, basically, SMRs.

What “modular” actually means — unpacked

The U.S. Department of Energy defines “modular” in a specific way: the ability to fabricate major components of the nuclear steam supply system in a factory environment and ship them to the point of use. That is the baseline definition. But the most ambitious SMR designs go considerably further.

The World Nuclear Association breaks SMR modularity into four distinct concepts: 🏭

• Factory fabrication: components, or entire reactor modules, built in controlled factory conditions rather than assembled in the field

• Serial production: the same design built again and again, driving down costs through repetition, the way aerospace manufacturers improve every successive aircraft off the production line

• On-site assembly: factory-built modules shipped and bolted together at the location, dramatically cutting the time workers spend in a nuclear-licensed construction environment

• Scalability: the ability to add modules incrementally as demand grows, rather than committing upfront to a single enormous capital bet

Some designs treat these as aspirations. Others treat them as engineering requirements baked into the reactor architecture from day one. NuScale Power is perhaps the most aggressive example. In its Q1 2026 earnings call, NuScale described each NuScale Power Module as a fully integrated, self-contained unit that includes the reactor vessel, steam generators, pressurizer, and the high-pressure steel containment vessel, all built in a factory and shipped to the site with virtually no nuclear-grade field construction required. That is a meaningful distinction. Most competitors use factory techniques for parts of their reactor. NuScale ships the whole thing. ⚡

This is worth pausing on. The containment barrier, which is the last line of defense against a radiation release, typically requires the most stringent on-site quality control. Doing that work in a factory, under controlled conditions with dedicated tooling, is a genuinely different proposition.

How the factory changes everything about quality and cost

The reason factories matter so much is not just speed. It is consistency. 🔩

Construction on a nuclear site is hard, expensive, and variable. Workers operate in complex safety environments, exposed to weather, constantly context-switching between trades. The probability of a weld failing inspection, a component being mis-installed, or a critical measurement being taken incorrectly is higher on a muddy site in November than on a climate-controlled factory floor with laser alignment tools and dedicated quality control staff.

Consider how this plays out in practice. GE Hitachi’s BWRX-300, a 300 MWe SMR, targets a construction timeline of just 24 to 36 months, compared to the decade-plus timelines of large conventional builds. The design achieves this partly by slashing material inputs — GE Hitachi claims the BWRX-300 uses roughly 50% less concrete and steel than traditional reactor designs — and partly through modular assembly techniques that move work off-site where it can be performed faster and better.

The IAEA formally defines SMRs as “factory shop built and transported to site”, which is a tighter, more specific definition than many people realize. The factory is not incidental to the concept. It is the concept. Key advantages of factory production include:

• Standardized tooling and jigs that eliminate measurement variation between builds

• A stable, trained workforce that builds expertise with each successive module

• Consistent supply chains that are not disrupted by on-site scheduling conflicts

• Parallel construction — site preparation can happen simultaneously with factory module production, rather than sequentially

The last point is underappreciated. With conventional construction, you cannot pour the foundation until you have approved drawings. You cannot install systems until the civil structure is complete. Everything is sequential. With factory-built modules arriving at a prepared site, you collapse that critical path significantly.

Have you ever watched a house being built versus a manufactured home being assembled? The manufactured home is on a foundation and weathertight in days. The stick-built house is a skeleton in the rain for months. The analogy is imperfect but the intuition is exactly right. 🏗️

The learning curve: why the 50th reactor is cheaper than the first

There is a reason the SMR industry keeps invoking the aerospace comparison, and it is not just marketing. The economics of serial production are genuinely powerful, and they are the logical endpoint of the modular approach.

Idaho National Laboratory projects that in a high-case scenario, SMRs achieve a learning rate of 15% per cumulative doubling of units built. Run that number forward and the deployment of 32 SMR units could cut overnight construction costs by 55.6%. That is not a trivial number. That is the difference between a technology that is economically marginal and one that competes on cost with combined-cycle gas.

Think about what this means in practical terms: 🚀

• The first SMR off a production line carries all the design and tooling costs

• The second is cheaper because the factory is already configured

• By the tenth, workers have built a deep mental model of the assembly process

• By the thirtieth, defect rates are lower, schedules are tighter, and supply chains are optimized

This is exactly how the commercial aviation industry worked. The first Boeing 737 was an expensive, uncertain bet. The ten-thousandth is assembled with extraordinary efficiency by workers who have done the job thousands of times. SMR developers are, in effect, betting that nuclear construction can follow a similar trajectory if they can get to meaningful production volumes.

The honest caveat, which the Information Technology and Innovation Foundation noted in its 2025 analysis, is that we do not yet know how these theoretical advantages translate to real-world first-of-a-kind builds. Optimistic SMR companies project delivery timelines of 2 to 4 years. The realistic baseline for conventional new nuclear, at best, is 7 to 10 years. The gap between those numbers is the entire SMR value proposition. Whether the gap survives contact with actual construction is the question the industry has to answer in the next five years.

What is your read — do you think the factory-production model can actually survive the regulatory and supply chain realities of nuclear construction, or is this an elegant theory waiting to meet an ugly world?

Scalability: the option value that large reactors cannot offer

There is a fourth dimension to modularity that gets less attention than it deserves, and it might be the most commercially compelling. Scalability — the ability to start small and grow. 🌱

A conventional 1,000+ MWe reactor commits you to an enormous capital outlay before a single kilowatt-hour is produced. You need the full plant to generate any power. There is no partial credit. For utilities navigating uncertain demand growth, or industrial customers trying to match power generation to a specific load profile, that is a genuinely uncomfortable bet.

A modular SMR plant changes that math entirely:

• A customer can deploy a single 77 MWe module and generate revenue while subsequent modules are still being built

• As load grows — say, a data center expanding its server capacity — additional modules can be added without shutting down the operating units

• If demand projections prove wrong, the customer has not overcommitted to capacity they do not need

• The financial risk is distributed across time, not front-loaded into a single massive construction event

This is what NuScale calls “plug-and-play scalability,” and it is not just a marketing phrase. The Wikipedia overview of SMR development notes that as of early 2026, over 127 modular reactor designs exist worldwide, with seven either operating or under construction. The designs that are gaining traction in commercial negotiations — including NuScale’s discussions with the Tennessee Valley Authority for up to 6 gigawatts of capacity — are precisely the ones that can offer this incremental deployment model.

$30 billion in total announced investment flowed into SMR technology between 2020 and 2025, according to the Sustainability Atlas. That capital is not betting on a concept. It is betting on a production model. 💡

The word “modular” is short. The idea behind it is not. It is a complete reimagining of how nuclear plants get built, financed, and operated. Whether that reimagining succeeds will depend less on physics, which is well understood, and more on execution: supply chains, factory capacity, regulatory timelines, and the slow accumulation of serial production experience.

Nuclear’s history is full of technologies that were supposed to change everything and then didn’t. But the modular approach is not asking for a breakthrough. It is asking to be allowed to learn, the way every other complex manufacturing industry has learned. That is a much more tractable problem than fusion or flying cars. The real question is whether the industry can string together enough first builds to actually start climbing that learning curve — and whether the customers waiting to see “proof” will still be there when it arrives.

There is a particular kind of embarrassment that comes from rediscovering something you already knew. Britain opened the world’s first commercial nuclear power station at Calder Hall in 1956, beat everyone to the technology, then spent the following decades making a series of expensive, politically convenient, and deeply consequential decisions that gutted its own industry. By 2015, the last surviving Magnox reactor shut down at Wylfa in North Wales. By 2023, several of the Advanced Gas-cooled Reactor units that followed had quietly closed too. For a country that once powered 26% of its electricity from nuclear at its 1997 peak, the retreat was remarkable.

Now the same site at Wylfa is at the center of Britain’s nuclear comeback. In April 2026, Great British Energy Nuclear and Rolls-Royce SMR signed a contract formally beginning technology design work for three small modular reactors on the island of Anglesey. In July 2025, the government made a final investment decision on Sizewell C, committing £38 billion to build two large EPR reactors in Suffolk. And in November 2025, Prime Minister Keir Starmer stood up and admitted, with unusual directness for a politician, that “years of neglect and inertia” had let the country down.

That is not a bad summary of the last thirty years. Understanding how Britain got here requires understanding why it stopped building in the first place, and what has changed enough to make nuclear politically survivable again.

The long retreat: how Britain walked away from an industry it invented

The UK’s nuclear history is, depending on your tolerance for irony, either darkly comic or genuinely sad. According to Wikipedia’s detailed account of UK nuclear power, Britain launched 26 Magnox reactors between 1956 and 1971, followed by 14 Advanced Gas-cooled Reactors (AGRs), and finally a single pressurised water reactor at Sizewell B, which opened in 1995. Then nothing for thirty years. 🏚️

The reasons layer on top of each other like geological strata:

• Privatisation in the late 1980s exposed nuclear’s true economics. When auditors scrutinized the books ahead of privatisation, decommissioning liabilities ballooned from £10.4 billion to somewhere between £22 and £36 billion at current prices. Investors recoiled. The nuclear assets ended up in public hands anyway.

• The AGR program was a repeated fiasco. A Works in Progress investigation found that Dungeness B, the first AGR ordered, was awarded to a company that hadn’t expected to win the tender and had no real plan to deliver it. Nine years into the program, Britain still had no operational AGRs, and costs had escalated 50% on average. 😬

• Lack of standardization meant each reactor was essentially custom-built. France built a fleet of nearly identical PWRs and drove costs down through repetition. Britain built bespoke reactors at different sites by different contractors, each learning the same hard lessons independently.

• Political consensus collapsed in the 1990s. Without a clear energy policy, new nuclear was effectively ruled out until a government review reversed that position in 2006. By then, the industrial skills, the supply chain, and the institutional memory had largely evaporated.

The last Magnox reactor — the original Wylfa unit — finally stopped generating electricity in December 2015. It had been running for 44 years, twice its original design life. That’s a remarkable machine, even if the story around it is painful. Britain’s nuclear fleet is now mostly EDF-owned aging AGRs, several of which have already closed, and Sizewell B, the only PWR, which is currently seeking a 20-year life extension to 2055. ⚛️

The Hinkley Point C education, delivered at great expense

Before discussing what Britain is now building, it is worth spending a moment on what it has been building, because the lesson is central to understanding the SMR push.

Hinkley Point C in Somerset is the UK’s first genuinely new nuclear plant in a generation. EDF began construction in 2017 with expectations of completing the first reactor by 2025. The project now targets 2030 at the earliest for Unit 1, with Unit 2 probably in the early 2030s. Initial costs were estimated at £18 billion. Engineering and Technology Magazine reports total costs have risen to approximately £46 billion at today’s prices. That is not a rounding error. That is the GDP of a small country. 💸

EDF blamed British regulations for requiring 7,000 design changes, including 35% more steel and 25% more concrete. The Office for Nuclear Regulation tersely replied that it did not recognize its requirements as “the principal factor” in the cost increases. Both parties have a point, which is one of the depressing things about this story.

A government-commissioned Nuclear Regulatory Review in 2025 was characteristically blunt: the UK had become “the most expensive place in the world to build nuclear projects.” The review listed the causes:

• Complex, risk-averse regulation that has accumulated restrictions without ever pruning them

• Loss of nuclear skills and supply chain during the 30-year building gap

• No standardization, so each project essentially starts from scratch

• Brexit and COVID, which hurt labour supply and materials costs for Hinkley specifically

• A planning system that treats each nuclear project as novel regardless of precedent

The uncomfortable truth is that Hinkley Point C is simultaneously a disaster and a necessary disaster. Stuart Crooks, Hinkley’s managing director, described it as “relearning nuclear skills, creating a new supply chain, and training a workforce,” which is an honest acknowledgment that Britain had to pay to rebuild knowledge it once had for free. Whether that knowledge transfer justifies £46 billion is a fair question, and I’m not sure anyone has a satisfying answer. 🔬

Sizewell C and the government’s biggest nuclear bet

In July 2025, Energy Secretary Ed Miliband signed the final investment decision for Sizewell C, committing a project estimated at £38 billion, with the UK government holding 44.9% of equity as the largest shareholder. The other investors are La Caisse, the Canadian pension fund (20%), Centrica (15%), and EDF (12.5%). The National Wealth Fund is providing the majority of debt finance. 🏗️

What makes Sizewell C different from yet another announcement about a nuclear project that might eventually happen is the actual money attached. The government has committed £14.2 billion through the Spending Review and taken on the role of lead investor. That is a meaningful change in how the UK is approaching nuclear: not leaving it to the private sector to figure out, but treating it as infrastructure the state needs to own and build.

Sizewell C is essentially a copy of Hinkley Point C. The government claims it will cost around 20% less because of lessons learned from Hinkley, which implies they have learned something, and also implies the optimism that always precedes nuclear construction. The expected operational date is 2039 at the earliest. Things to know:

• The two EPR reactors at Sizewell would each generate 1,630 megawatts, together powering the equivalent of six million homes

• China was originally an investor in Sizewell C but was bought out due to “security concerns”

• 10,000 jobs at peak construction, with 1,500 apprenticeships

• 70% of construction value is targeted to go to UK suppliers

The government has been consistent in calling this a “golden age of nuclear,” which is the kind of phrase that either ages well or doesn’t age at all. 📋

Wylfa, Rolls-Royce, and the SMR wager

If Sizewell C is the big, expensive, established bet, Wylfa is the more interesting one.

The island of Anglesey in North Wales has a nuclear history that mirrors the country’s own: the original Wylfa Magnox station opened in 1971 and finally closed in 2015. Hitachi then spent years planning to build a £20 billion advanced boiling water reactor there under the name Wylfa Newydd, before formally canceling the project in January 2021, citing economics and the absence of a government financing commitment. The UK government bought the site back from Hitachi for £160 million in 2024. 🏝️

In November 2025, Wylfa was designated as the site for Britain’s first small modular reactors. In June 2025, Rolls-Royce SMR had been selected as the preferred technology after a two-year competition against GE-Hitachi, Holtec Britain, and Westinghouse. The plan is for three 470-megawatt units, which together would produce roughly the same output as one large EPR — around 1.4 gigawatts total.

The Rolls-Royce design is a pressurised water reactor drawing on established PWR technology. Whether it qualifies as truly “small” is a matter of some debate — critics point out that at 470 MW, it is larger than many historical reactors and requires full nuclear safety provisions including exclusion zones and aircraft crash protection. Calling it an SMR, some observers suggest, is more brand positioning than strict taxonomy. The nuclear industry has a complicated relationship with its own vocabulary.

The financial structure is worth noting:

• £2.5 billion committed by the government via the 2025 Spending Review for the GBE-N SMR programme 💰

• £599 million from the National Wealth Fund directly to Rolls-Royce SMR for reactor development

• A final investment decision on the Wylfa project is expected in 2029

• First grid connection targeted for the mid-2030s

• US firm Amentum selected in January 2026 as programme delivery partner

On 13 April 2026, GBE-N and Rolls-Royce SMR signed the contract that formally commenced design work. Engineers are now conducting geoseismic studies at the site, mapping cooling water availability from the sea, and routing grid connections. It is real work, not just announcements.

If you follow UK energy policy, the question worth asking yourself is: does Britain have the political will to stay the course for the decade-plus it takes to complete these projects? That will isn’t always guaranteed. ⚡

The honest assessment: it’s not a done deal

Anyone who has watched British nuclear policy cycle through promise and disappointment is right to be cautious. The ambitions are real. The obstacles are equally real.

The regulatory system is still the same one the 2025 review called “the most expensive in the world.” Reforms have been promised, but nuclear regulation reform takes years to implement even when everyone agrees it is needed — which they don’t entirely. The planning system adds further friction, and the nuclear skills gap hasn’t been closed; it’s been slightly narrowed.

Key things to watch:

• Whether Hinkley Point C actually reaches first power in 2030 or slips again, because every delay feeds skepticism about the whole programme

• Whether Rolls-Royce’s licensing process (Step 3 of the Generic Design Assessment) completes on schedule in late 2026, enabling first concrete at Wylfa potentially in 2027

• Whether supply chain capacity proves adequate for running Hinkley C, Sizewell C, and Wylfa simultaneously, since all are competing for the same nuclear engineers, specialist contractors, and specialist components

• The 2029 final investment decision for Wylfa, which is where the financial commitments either get made or don’t 🔍

There is also the honest question of cost. Stephen Thomas, emeritus professor of energy policy at the University of Greenwich, has argued that Rolls-Royce’s 470-MW design will not deliver the economies of scale that make SMRs attractive in theory — it’s large enough to require all the safety and security infrastructure of a big reactor, without being large enough to benefit from full-scale economies. That’s a criticism worth taking seriously rather than dismissing.

What Britain has, at last, is something it lacked for thirty years: a government that has made actual financial commitments rather than just expressions of interest, a site selection process that has produced a decision, and contracts with real money attached. The country that opened the world’s first commercial nuclear power station in 1956 is not starting over — it’s trying to rebuild a capability it let rust. Whether it can do so at the pace and cost the government is projecting is a different question entirely, and Hinkley Point C’s long shadow makes anyone’s projections look at least a little optimistic.

The Rolls-Royce contract at Wylfa is the most concrete signal yet that Britain is serious this time. If those three reactors begin generating power in the mid-2030s roughly on schedule, the whole programme becomes more credible and the export ambitions — starting with the Czech Republic — become realistic. If they don’t, Britain will have paid a very expensive tuition fee for another lesson it already learned once.

What do you think is the bigger risk: that Britain repeats its AGR-era cost disasters with the new SMR programme, or that it ends up with too little nuclear capacity to replace the aging fleet before the gap becomes a genuine grid problem?

For most of the past four decades, asking a utility executive about nuclear power was a bit like asking someone who once burned their hand to describe their love of bonfires. The instinct was to back away slowly. Three Mile Island in 1979. Chernobyl in 1986. The spectacular, soul-crushing cost implosions at plants that took decades to build and billions more than promised. Utilities learned a brutal lesson: nuclear is the kind of technology that sounds great until the bill arrives. So they built gas plants instead, signed wind contracts, and left nuclear to the governments and the dreamers.

That calculation is changing. Not dramatically, not overnight, but with the kind of deliberate, unmistakable momentum that tends to precede a genuine shift in a multi-trillion-dollar industry. The Tennessee Valley Authority became the first American utility to file a construction permit application for a small modular reactor in May 2025. Duke Energy is partnering with GE Vernova Hitachi to advance the BWRX-300 design for its Carolinas footprint. And Constellation Energy is literally flipping the lights back on at Three Mile Island — arguably the most famous symbol of nuclear’s failure — to sell power to Microsoft. You probably want to sit with that irony for a moment.

Something real is happening. But why now, after so many false starts? The answer involves artificial intelligence, a hard economics lesson the industry finally absorbed, and a new generation of reactor designs that actually seem designed with utilities’ nightmares in mind.

The long winter, and why utilities froze

It is worth being honest about how bad it got. Nuclear’s collapse in the United States wasn’t just a PR problem — it was a financial catastrophe that nearly swallowed several utilities whole.

The most recent cautionary tale is still fresh. Georgia Power spent $30 billion and eleven years building two new reactors at Plant Vogtle, completing them in 2023 and 2024. That sounds like progress until you notice the 25% rate increase that landed on Georgia customers’ doorsteps, and the two public service commissioners who subsequently lost their jobs at the ballot box. The political fallout was real. As Utility Dive reported, elected officials discovered that voters do not reward nuclear enthusiasm — they punish the electricity bills that come with it. ⚠️

Before Vogtle, there was the SCANA disaster in South Carolina, where the utility and Westinghouse made false claims of progress on twin reactors, eventually resulting in criminal charges and the project’s abandonment after billions were already spent. The wound from that one still hasn’t fully healed in the industry.

The deeper history is more damaging still. Three Mile Island’s partial meltdown in 1979 triggered a regulatory crackdown that made new nuclear almost impossible to approve economically. Then Chernobyl in 1986 turned the public mood to permafrost. By the 1990s:

• 129 nuclear plants had been approved for construction before TMI; fewer than half were ever completed 🚫

• No new utility-scale reactors broke ground in the U.S. for over 30 years

• Construction costs ballooned as safety regulations multiplied, layering complexity onto complexity

• Gas plants, by comparison, could be built in two or three years at a fraction of the upfront cost

Utilities are rational creatures. They respond to incentives and fear losses. For forty years, nuclear offered more of the latter. So they walked away. 🚶

The electricity demand earthquake changed everything

Ask a utility executive today what’s keeping them up at night, and the answer isn’t climate policy or fuel prices. It’s load growth — specifically, the absolutely staggering electricity appetite of AI data centers. ⚡

The numbers are almost surreal. OpenAI has suggested it may need 20 gigawatts of power to accommodate ChatGPT’s 700 million weekly users. Amazon signed a deal with Talen Energy for 1,920 megawatts of nuclear power from the Susquehanna plant through 2042 to support its AWS data centers. Google committed to buying power from Kairos Power’s small modular reactors, targeting 500 MW online by 2030. Microsoft is funding the restart of Three Mile Island for the same reason. These aren’t press releases — they’re power purchase agreements worth billions. 💰

The reason these companies are chasing nuclear specifically, rather than just buying more solar, comes down to one word: firmness. Data centers can’t run on weather. They need electrons at 3 a.m. on a cloudy Tuesday in January, not just on sunny summer afternoons. Renewables are wonderful and cheap, but they require storage backup to be truly dispatchable — and grid-scale storage at the terawatt-hour scale isn’t commercially available yet. Nuclear runs around the clock at 90%+ capacity factors, regardless of what the wind is doing. For hyperscale computing, that reliability isn’t a nice-to-have. It’s the whole point.

Think about it this way: utilities suddenly have customers — very large, very solvent customers — who want nuclear power and will sign 20-year purchase agreements to get it. That changes the financial math fundamentally. The old problem was that utilities had to take all the risk of building an expensive plant and hope ratepayers would eventually benefit. Now there are corporate buyers who will essentially pre-purchase the output, de-risking the investment before the first shovel breaks ground.

Does the current AI energy boom feel durable to you, or does it seem like a hype cycle that might cool? The utilities are clearly betting on the former, but it’s a question worth asking. 🤔

Small modular reactors rewrite the utility risk model

Here’s where the technology story intersects with the business story. Traditional large reactors — the 1,000-plus-megawatt behemoths like Vogtle — require massive upfront capital, take a decade to build, and carry enormous financial risk if anything goes wrong. That profile is almost perfectly designed to terrify a utility’s board of directors.

Small modular reactors are engineered to fix exactly those problems. The World Nuclear Association describes SMRs as representing “a rebalancing of historic economies of scale towards economies of series production” — factory-built, modular components that get shipped to site and assembled rather than constructed from scratch over years. The leading designs include:

• BWRX-300 (GE Vernova Hitachi): 300 megawatts, targeting coal plant replacement sites, uses 60% less concrete and steel than traditional reactors, with a claimed 24-36 month construction timeline 🏗️

• SMR-300 (Holtec): Two units planned for Michigan’s Palisades site, pursuing an unusual “one-stop-shop” model where Holtec acts as vendor, constructor, and operator

• Xe-100 (X-energy): An 80-megawatt module typically packaged in groups of four, backed by Amazon’s $500 million investment

For utilities, the appeal is structural. Lower capital per unit means less financial catastrophe if a project runs over budget. A 300-megawatt plant going wrong is painful; a 1,400-megawatt plant going wrong is existential. TVA understood this, which is why it structured its advanced nuclear deals explicitly “to make sure that risk isn’t on our balance sheet,” according to CEO Don Moul. That sentence is doing a lot of work. It signals a new era of utility engagement with nuclear: interested, but insisting on better risk allocation. And that’s probably healthy. 🔬

The policy environment finally caught up

Nuclear has struggled for decades not just with economics but with regulatory timelines that add years — and billions — to project costs. The U.S. Energy Information Administration notes that SMR licensing is now advancing in 15 countries, with a 65% increase in pre-licensing activities since 2023. America is part of that wave, and its policy framework has finally started to reflect that.

Two successive administrations, Biden and Trump, have taken steps in the same direction:

• The ADVANCE Act, passed with bipartisan support, is designed to streamline Nuclear Regulatory Commission approvals and reduce duplicative review

• Trump signed four executive orders in May 2025 targeting 400 gigawatts of nuclear by 2050 — nearly four times current capacity 🚀

• The Department of Energy launched a $900 million funding program for SMR deployment, awarding $400 million to TVA for the BWRX-300 at Clinch River and $400 million to Holtec for its Michigan project

• TVA signed the first U.S. utility power purchase agreement for a Generation IV reactor in August 2025, a three-way deal with Kairos Power and Google for the Hermes 2 pilot plant 📋

The IEA’s path to a new era for nuclear projects that SMR deployment could reach 190 gigawatts globally by 2050 if construction costs come down to parity with large-scale reactors. That’s a big if. But the policy infrastructure to support that trajectory — tax credits, loan guarantees, production tax credits set at $30 per megawatt-hour — is now in place in a way it simply wasn’t five years ago.

The bipartisan nature of this shift is worth noting. Nuclear energy is one of the very few policy areas where you can get both parties to show up and agree. That doesn’t happen unless the underlying incentives are genuinely compelling. ✅

It’s still not a sure thing

Anyone writing a triumphalist piece about nuclear’s comeback is probably getting ahead of the evidence. The skeptics have legitimate points, and a serious article owes them some space.

NuScale — the only SMR company to win full NRC design approval — canceled its flagship Idaho project in 2023 after subscribers couldn’t absorb the projected costs. That was a genuine gut-punch to the industry’s credibility. The ITIF’s realist assessment of SMRs makes clear that power purchase agreements will likely be mandatory for every first-of-a-kind project, because no lender will take the risk without a committed buyer. Right now, the buyers are largely Big Tech — and if that demand ever softens, the financial scaffolding gets shakier. 🏗️

There are also genuine questions about how much the “small” in SMR reduces costs versus just reduces output. Factory fabrication sounds efficient in theory, but the industry hasn’t actually demonstrated it at scale yet. Only two commercial SMRs are operating anywhere in the world as of now. The global pipeline of 74 designs in development is exciting; the two that are actually running electricity into a grid are a more sober number.

The Vogtle cautionary tale also hasn’t faded. Customers got a 25% rate increase. Elected officials lost their seats. If the first few SMR projects run significantly over budget — which first-of-a-kind nuclear projects historically do — utilities will face the same political backlash all over again. The technology may be modular; the politics are not.

If you’re tracking the SMR sector, the next 18 months will be telling. Watch TVA’s Clinch River construction permit process, the Holtec Palisades restart, and whether Kairos Power’s Hermes plant actually generates power on schedule. Those are the real tests. 🔍

The reasons utilities are warming to nuclear are real, structural, and driven by genuine demand signals rather than ideology. But “warming up” is not the same as “problem solved.” The industry still needs to deliver on its promises, on something approaching on time and on budget, for the current enthusiasm to compound rather than collapse.

The question worth sitting with: is this the generation of utility executives who finally cracked the nuclear problem — or are we watching the early stages of a familiar cycle of optimism that the first cost overrun will deflate?

If you follow nuclear energy closely, you’ve probably noticed something frustrating: the words “fission” and “fusion” get swapped, blurred, or casually conflated in headlines all the time. A politician promises “nuclear power” and means a uranium reactor. A tech CEO announces fusion investment and Twitter/X loses its mind. Meanwhile, the rest of us are left wondering: are these even related? Are they different? And what does any of it mean for the small modular reactor boom happening right now?

The short answer is yes, they’re related. And no, they’re not the same. And the distinction matters enormously, especially as billions of dollars pour into SMR development and a handful of fusion startups race to rewrite the rules entirely.

Let’s break it down properly.

What fission actually is

Fission is the process that powers every nuclear reactor on Earth right now. 🔬 It’s also the process that powered the first atomic bomb. These two facts live in awkward proximity to each other, which is part of why public opinion on nuclear energy has been complicated for decades.

The physics is elegant in a violent sort of way. A neutron slams into a heavy, unstable atom — almost always uranium-235 or plutonium-239 — and the nucleus can’t hold itself together. It splits. The split releases energy and kicks out two or three more neutrons, which then hit neighboring atoms, which then split, releasing more neutrons. This is a chain reaction, and if you let it run unchecked, you get a bomb. But in a reactor, you control it. Engineers insert control rods that absorb excess neutrons, keeping the reaction at a steady, manageable rate.

That heat — and there is a lot of it — boils water into steam. The steam spins a turbine. The turbine generates electricity. It’s basically the same process as a coal plant, except the heat comes from nuclear splitting rather than burning carbon.

Here’s what fission gives you:

• Proven, deployable technology that’s been generating electricity since the 1950s

• A reliable, carbon-free power source that runs 24/7 regardless of weather

• Long-lived radioactive waste, some of which remains hazardous for thousands of years

• A chain reaction that, if the control systems fail, can spiral badly — as Chernobyl and Fukushima proved

• Fuel (uranium-235) that requires mining, enrichment, and careful handling before it’s usable

⚡ Every SMR currently in development or operation runs on fission. The NuScale VOYGR, TerraPower’s Natrium, GE Hitachi’s BWRX-300, Rolls-Royce’s UK SMR — all of them. Fission is the technology of the nuclear present.

Do you already have a clear mental model of fission and fusion? Or has the terminology always felt a bit slippery? Either way, stick with me — the contrast coming next is the key to understanding what the nuclear industry might look like in 2035.

What fusion actually is

Fusion is the opposite process. Literally the opposite. 🌞 Instead of breaking a heavy atom apart, fusion pushes two light atoms together until they merge into a heavier one. The sun does this every second of every day, fusing hydrogen into helium at temperatures of around 15 million degrees Celsius at its core. No one engineered the sun; gravity handled the confinement problem.

On Earth, the preferred fuel combination is deuterium and tritium — both isotopes of hydrogen. Deuterium is remarkably abundant; it’s in ordinary seawater. Tritium is rarer and slightly radioactive, but it has a short half-life and can be produced inside a fusion reactor itself. When deuterium and tritium fuse, they produce helium and a fast-moving neutron, and they release roughly four times more energy per unit of mass than uranium-235 fission, according to nuclear physicist analyses.

What fusion doesn’t produce is a long-lived radioactive nightmare. The primary byproduct is helium — the same inert gas that makes balloons float. The reactor walls get activated by neutron bombardment over time, but this material is low-level radioactive waste that decays in decades, not millennia.

The inherent safety case for fusion is also genuinely different from fission. Because fusion is:

• Not based on a chain reaction, there’s no runaway cascading meltdown risk

• Extremely sensitive to plasma conditions — too cold, too hot, wrong magnetic field, and the reaction simply stops

• Described by the IAEA as self-terminating if something goes wrong

• Reliant on continuous external heating and magnetic confinement, which must be actively maintained

🧪 The challenge isn’t making fusion safe — it already is. The challenge is making it work at all, and then making it economically viable. Plasma at 100 million degrees Celsius needs to be held in place by magnetic fields in a machine we’ve only recently gotten good at building. That’s an engineering problem of staggering complexity.

The key differences that actually matter

Okay, so fission splits, fusion joins. Got it. But for anyone thinking seriously about nuclear energy’s trajectory, the differences worth paying attention to go beyond the basic physics. 🔑

Energy density is the first big one. Fusion reactions, per kilogram of fuel, produce far more energy than fission. The Fusion Industry Association notes that fusion produces an enormous amount of energy relative to the tiny quantity of fuel consumed. Less fuel in, more energy out.

Fuel supply is the second. Uranium-235 — the fission fuel that actually works in reactors — is rare. It makes up less than 1% of natural uranium, so the rest has to be enriched, which requires special centrifuge facilities and careful international oversight. Deuterium, fusion’s primary fuel, is effectively inexhaustible; it’s found in every litre of ocean water on the planet.

Waste is the third and arguably most politically charged difference:

• Fission generates high-level radioactive waste that must be safely stored for up to one million years — a fact that no country has fully solved yet

• Fusion produces low-level activated materials from the reactor walls, which decay in decades and can potentially be recycled

• Fusion’s main output is helium, which isn’t radioactive at all

Safety profile is the fourth. Fission’s chain reaction means a real, if manageable, risk of runaway events. Modern third-generation reactors — and SMRs in particular — use passive safety systems that rely on gravity and natural convection rather than active operator intervention. That’s a genuine improvement. But it’s not the same as fusion’s physics-based safety, where the reaction self-terminates the moment conditions slip even slightly.

None of this means fission is bad technology. It’s produced carbon-free electricity for 70 years. The point is that fusion, if and when it arrives, changes the entire calculus.

Why every SMR today is a fission machine — and what that means

Here’s something the breathless fusion coverage often glosses over: no commercial fusion reactor exists anywhere on Earth. Not one. The SMR industry — which is attracting record investment, regulatory attention, and Big Tech partnerships right now — is 100% fission. 🏭

According to the U.S. Energy Information Administration, SMRs are defined as nuclear fission reactors with a power output below 300 megawatts electric, built using modular factory-fabricated components. The modularity is the innovation. The fission is not.

What makes fission SMRs genuinely interesting, despite the familiar physics, is what they do differently from large conventional reactors:

• Factory-built modules reduce construction time from the decade-plus typical of large plants to potentially 24 to 36 months

• Passive safety features — like NuScale’s natural convection cooling — eliminate the need for operator action during emergencies

• Smaller footprints allow SMRs to replace retiring coal plants, power AI data centers, or serve remote communities

• Modular scaling lets operators add capacity incrementally, rather than committing to a single enormous build

In June 2025, TerraPower broke ground on its Natrium reactor in Kemmerer, Wyoming. X-energy closed a $700 million funding round to advance its Xe-100 gas-cooled reactor. NuScale announced a deal with the Tennessee Valley Authority for up to 6 gigawatts of SMR capacity. The industry is real, moving, and entirely powered by uranium splitting.

For now.

Fusion SMRs are coming — but “coming” is doing a lot of work in that sentence

The fusion industry insists it is not perpetually 20 years away anymore. They may be right, or they may be saying what venture capitalists need to hear. 🚀 The truth is probably somewhere in between.

Commonwealth Fusion Systems, spun out of MIT and backed by Google, Nvidia, and Bill Gates, has raised over $2 billion and signed a power purchase agreement with Google for 200 megawatts from its first ARC plant in Virginia. That plant, targeting 400 megawatts of total capacity, is projected to deliver electricity in the early 2030s. The company’s key innovation is high-temperature superconducting magnets, which allow for smaller, stronger tokamaks than anything built before.

TAE Technologies, the oldest private fusion company at 27 years old, has raised $1.3 billion and is constructing its Copernicus reactor to demonstrate net energy gain before 2030. Its commercial plant, Da Vinci, targets grid delivery in the early 2030s. In early 2025, TAE unveiled a simplified plasma control method that its team said brings commercial fusion materially closer.

Helion Energy, backed by Sam Altman, has already signed a power purchase agreement with Microsoft and targets its first fusion generator deployment in 2028 — which would make it the first commercial fusion plant in history, if the timeline holds.

Are these projections reliable? That’s the honest question. Here’s what the Fusion Industry Association’s 2025 Global Fusion Industry Report says, based on data from 53 companies across more than a dozen countries: fusion is being engineered, tested, and piloted for commercialization in this decade. That’s a shift in tone from where the industry was five years ago. It doesn’t guarantee success, but it’s not science fiction either.

What would a fusion SMR actually offer, compared to a fission SMR? The list is attractive:

• No long-lived radioactive waste — a genuine political and practical relief

• Effectively unlimited fuel from seawater

• Physics-based safety with no chain reaction to contain

• Potentially even smaller and more modular designs as the technology matures

The gap between today’s fission SMRs and tomorrow’s fusion plants is not just a technology gap. It’s a gap in what we mean when we say “nuclear energy.” Fission gives us a tool we already know how to use, getting smaller and smarter. Fusion offers something categorically different — if the engineering holds.

Given the trillions of dollars at stake in the global energy transition, and the specific pressure from AI data centers demanding clean, always-on power, the question isn’t whether fusion will arrive. It’s whether it arrives in time to matter for the decisions being made right now about which fission SMRs to build, where, and how many.

What’s your read on the timeline? Do you think fusion plants will be operating at commercial scale before the first wave of fission SMRs reaches the end of their operating lives — or will fission own the nuclear century?

Here is a country with 1.4 billion people, the world’s fastest-growing major economy, a coal dependency so entrenched it produces 75% of its electricity from burning the stuff, a net-zero commitment it can’t realistically meet with renewables alone, and — sitting quietly under its soil — roughly 25% of the world’s known thorium reserves. That combination of problems and resources doesn’t point to solar panels. It points to nuclear reactors. Lots of them.

India has been circling nuclear energy as a serious solution for seven decades. The physicist Homi Bhabha laid out a three-stage nuclear program in 1954 that was visionary for its time and remains technically sophisticated today. What the country has lacked, repeatedly, is the legal framework, the financing model, and the political appetite to turn ambition into gigawatts at speed. In late 2025, something shifted. Really shifted. And the SMR industry should be paying very close attention.

Why India’s energy problem is unlike anyone else’s

Scale is the starting point for understanding India ☀️. The country currently generates about 2,060 terawatt-hours of electricity annually, making it the world’s third-largest producer. That sounds substantial until you realize that per capita electricity consumption in India remains well below the global average, and the economy is still growing at a pace that will roughly require doubling total electricity capacity by 2030, then doubling it again to reach the kind of energy density needed for the “Viksit Bharat” (developed India) vision of 2047.

The World Nuclear Association’s country profile for India states plainly that energy demand is expected to grow more in India than any other country over the next decade. By 2040, according to the Observer Research Foundation, India is projected to account for nearly 25% of growth in global energy demand. That’s not a rounding error in someone’s forecast model. That’s a structural feature of the world economy.

Coal is what currently fills that demand, and it does so at serious cost:

• Coal plants generate roughly 75% of India’s electricity, with over 280 gigawatts of installed coal capacity

• Coal India, the state-owned miner, produces over 600 million tonnes annually, making it the world’s largest coal producer by volume

• Indian coal plants are estimated to cause 100,000+ premature deaths per year from air pollution

• India pledged net-zero emissions by 2070, but coal remains entrenched well beyond 2050 under current planning

India’s renewable expansion is real. Installed renewable capacity reached 220 gigawatts by 2025. But renewables alone can’t deliver baseload power at the scale India needs, especially not to the remote industrial zones, retiring coal plant sites, and off-grid communities that make up a significant chunk of the country’s energy geography. That’s the gap that nuclear, and specifically SMRs, is positioned to fill.

The three-stage plan: ambition in slow motion

India doesn’t come to nuclear energy as a newcomer 🔬. The three-stage nuclear program Bhabha designed in the 1950s is a long-term scheme to use India’s limited uranium reserves as a launching pad, breed plutonium through fast reactors, and ultimately tap the country’s enormous thorium reserves as the endgame fuel. In theory, it’s brilliant. India holds 846,000 tonnes of thorium, and Indian scientists estimate the country could produce 500 gigawatts of electricity for four centuries from its economically extractable thorium alone.

In practice, the program has moved at a pace that might generously be called deliberate:

• Stage 1, natural uranium-fueled pressurized heavy water reactors (PHWRs), has genuinely worked. India has 22 operational reactors and a genuine indigenous manufacturing capability in PHWR technology

• Stage 2, plutonium-fueled fast breeder reactors, was supposed to be well underway by now. The 500 MW Prototype Fast Breeder Reactor (PFBR) at Kalpakkam finally achieved criticality in April 2026, roughly two decades behind original projections

• Stage 3, the thorium cycle, remains a future ambition rather than a current program

Nuclear power contributes just 3.1% of India’s electricity today, after more than 60 years of development. That number tells you something important: India knows how to build nuclear reactors, but not yet how to build them fast enough or cheaply enough to matter at scale.

Here’s the thing, though. That PHWR expertise is directly relevant to SMRs. The 200 MWe Bharat Small Modular Reactor (BSMR-200) that India’s Bhabha Atomic Research Centre is now developing uses the same pressurized heavy water reactor technology India has been refining since the 1980s. This isn’t speculative science. It’s a known physics platform in a smaller box.

The legislation that changed everything

For the better part of six decades, India’s Atomic Energy Act of 1962 barred private companies from any meaningful participation in nuclear power generation. Only government-owned entities, principally the Nuclear Power Corporation of India Limited (NPCIL), could build or operate reactors. That structure made India’s nuclear program insulated but also slow, capital-constrained, and cut off from the global supply chains and technology transfers that other countries used to build nuclear capacity faster ⚡.

The SHANTI Bill, passed by both houses of India’s parliament on December 18, 2025, changed that structure entirely. The Sustainable Harnessing and Advancement of Nuclear Energy for Transforming India Act repeals both the 1962 Act and the Civil Liability for Nuclear Damage Act of 2010. The liability law change matters enormously: the 2010 law’s supplier liability provisions had blocked international companies, including EDF and Westinghouse, from entering the Indian market for 15 years, because they faced unlimited legal exposure for any nuclear incident caused by their equipment.

What the SHANTI Act does specifically:

• Private Indian companies and joint ventures can now build, own, operate, and decommission nuclear power plants

• The government retains control over sensitive fuel-cycle activities (uranium mining, enrichment above a threshold, heavy water production, high-level waste management)

• A tiered liability cap structure replaces unlimited supplier liability, with maximum overall liability set at 300 million Special Drawing Rights (approximately $430 million) per incident

• The Atomic Energy Regulatory Board receives full statutory independence, aligning India’s oversight model with the US and other Western nuclear markets

• A dedicated Atomic Energy Redressal Advisory Council handles disputes, with appeal rights up to the Supreme Court

The Asia Group’s analysis of the bill called this “a new era of commercial partnerships” between Indian private firms and US companies. Holtec International’s founder Kris Singh called India “likely to be the largest nuclear market in the world in the foreseeable future.” Rolls-Royce SMR, Westinghouse, and GE Hitachi have all been watching the SHANTI process closely. The legal logjam that held up France’s EDF for years on the Jaitapur project appears to be genuinely cleared.

Have you been watching how quickly the Indian regulatory environment has shifted in 2025? The pace of legislative change in this space is accelerating in ways that weren’t predictable even two years ago.

The SMR program taking shape

India’s 2025-26 Union Budget launched the Nuclear Energy Mission with an allocation of INR 20,000 crore (roughly $2.5 billion) specifically for SMR research and development 🚀. The target is blunt: at least five indigenously designed and operational SMRs by 2033.

Three reactor designs are under active development by BARC:

• BSMR-200: A 200 MWe pressurized heavy water reactor using slightly enriched uranium. Cabinet-level financial approval cleared. Lead unit proposed for Tarapur in Maharashtra. Estimated project cost: INR 5,960 crore

• SMR-55: A 55 MWe reactor designed specifically for off-grid deployment in remote locations, including operation in “isolated mode” without grid connectivity. Lead twin units planned for Tarapur by 2033. Estimated cost: INR 7,000 crore for two units

• 5 MWt High-Temperature Gas-Cooled Reactor: Not a power reactor at all, but a hydrogen production system, planned for BARC’s Vizag campus in Andhra Pradesh. Budget: INR 320 crore

These aren’t just drawings on someone’s whiteboard. In-principle approval for construction has been obtained for all three demonstration designs. Tata Consulting Engineers has said the plan is to deploy 40-50 SMRs across India. Tata Power and the Naveen Jindal Group have both expressed interest in becoming early private owners.

The off-grid application of the SMR-55 is worth particular attention. India has four retired coal plant sites that the Central Electricity Authority identified in September 2025 as potential nuclear repowering locations. Several more are expected to retire before 2040. Replacing a retiring 500 MW coal plant with a cluster of SMR-55 units on the same industrial site, using existing grid connections, workers, and cooling infrastructure, is the kind of application that makes theoretical SMR advantages suddenly very concrete.

What makes India different from every other market

India is not just another country with nuclear ambitions. The combination of factors here is unlike anything in Western Europe, North America, or even China 🌏:

• India has domestic PHWR expertise that directly translates to the BSMR-200 design. This isn’t importing foreign technology — it’s packaging existing capability in a new format

• The three-stage nuclear plan means India has a strategic and ideological commitment to nuclear that goes beyond energy policy. It’s national identity

• India’s 25% share of world thorium reserves means that the long-term fuel story for Indian nuclear is fundamentally different from countries that depend on imported uranium

• The country’s AI and data center sector is growing explosively. A Deloitte report in May 2025 highlighted “doubling of global electricity demand from data centres and AI by 2026,” and the Observer Research Foundation notes India’s government is exploring SMRs specifically for captive data center power supply

• The SHANTI Act removes the supplier liability barrier that cost the nuclear industry 15 years of lost deals in India. That problem is now structurally resolved

There’s a counterargument worth taking seriously. India’s nuclear targets have been consistently optimistic and consistently missed. The 100 GW by 2047 goal requires building more nuclear capacity in 22 years than India has built in 70. The regulatory and financing ecosystem for private nuclear is brand new. The BSMR-200 is still a demonstration project with a 7-year commissioning timeline from financial approval. And, as Karthik Ganesan at the Council on Energy, Environment and Water noted to Physics World, SMRs “are still to demonstrate that they can supply electricity at scale.”

All of that is fair. But the legal transformation of December 2025 is real, the funding allocation is committed, the reactor designs are in detailed engineering, and the demand signal from a rapidly industrializing 1.4-billion-person economy isn’t going anywhere.

If the Bharat Small Modular Reactor program reaches commercial deployment by the mid-2030s, India won’t just be a customer for someone else’s technology. It will be a reactor exporter. A country with India’s manufacturing scale, engineering talent, and cost structure could produce PHWR-derived SMRs at a price point that makes Western designs look expensive. That possibility should be on the radar of every SMR developer currently pitching to Southeast Asian and African markets.

Here’s the question the global SMR industry should be actively debating: if India successfully deploys its indigenous Bharat SMR design at scale, does that accelerate the global SMR market by proving the concept in the world’s largest energy growth market — or does it become a formidable competitor that undercuts everyone else on price?

Money is the reason most nuclear plants never get built. Not physics. Not public opposition. Not even regulation, though that certainly doesn’t help. The fundamental problem with nuclear energy has always been that the people who benefit from a reactor, over 60 years of operation, are not the people who have to pay for it up front, in a lump sum, before a single electron flows. That mismatch between when money goes in and when it comes back out has killed more nuclear projects than Chernobyl ever did.

Small modular reactors are, among other things, an attempt to fix that mismatch. Whether they actually succeed depends on how the business model gets structured, who absorbs the cost overruns when things go wrong, and whether a new class of buyers, mainly Big Tech companies desperate for always-on clean power, can provide the demand signal the industry has always lacked. This is not a simple story. But it’s one worth understanding, because the business model matters at least as much as the reactor design.

The traditional nuclear money problem

Every energy project has capital costs and operating costs. What makes nuclear unusual is the ratio between them 💡. A natural gas plant is cheap to build and expensive to fuel. A nuclear plant is expensive to build and almost free to operate once it’s running. The fuel costs for nuclear amount to roughly $24 per megawatt-hour in the United States according to data from the Nuclear Energy Institute, a fraction of what gas or coal plants pay.

That sounds like a good deal. The catch is the upfront cost. According to the International Energy Agency’s 2025 estimates, building an SMR in Western countries currently runs about $10,000 per kilowatt of capacity. Build a 100 MW SMR and you’re looking at roughly $1 billion before the reactor has produced a single kilowatt-hour of electricity. For comparison, a standard 1,000 MW conventional nuclear plant can cost $10 billion or more. Lower total bill, same punishing upfront structure.

And here’s what makes lenders nervous 😬:

• Nuclear projects have a decades-long history of cost overruns, averaging 117% over initial budget in a study of 180 projects published by academic researchers

• Construction timelines routinely run 64% longer than projected

• Interest accumulates throughout construction, so delays compound costs exponentially

• A reactor that takes 15 years to build at a 5% financing rate ends up dramatically more expensive than a reactor that takes 5 years, even if the overnight cost is higher

The GLOBSEC think tank ran the numbers on exactly this point: an SMR costing $10,000 per kilowatt with a 5-year build can end up cheaper in total than a conventional plant at $6,600 per kilowatt with a 15-year build, once you account for the interest that stacks up during construction. The SMR’s shorter build time does real financial work, even before any economies of series production kick in. But if that 5-year timeline slips to 7 years, the advantage evaporates.

Who actually writes the checks

The Information Technology & Innovation Foundation’s 2025 analysis lists the stakeholders in a typical SMR deal and it reads like the cast of a very stressful ensemble drama 📋:

• Vendors: the reactor designers and manufacturers (NuScale, GE Hitachi, Kairos Power, X-energy, Rolls-Royce SMR, and roughly 80 others globally)

• Constructors: the EPC firms that actually build the thing on site

• Utilities: the traditional owners and operators of power plants

• Lenders: banks and institutional investors providing debt financing

• Large end users: tech companies, industrial buyers, military customers

• Government bodies: national energy departments, loan guarantee programs, grant-making agencies

• Ratepayers: the ordinary electricity customers who ultimately pay for regulated utility investments

In the current US model, federal money arrives mainly through three channels. First, R&D grants that help developers get their designs through the regulatory process. Second, tax credits, including a Production Tax Credit set at $30 per megawatt-hour for qualifying nuclear electricity. Third, loan guarantees from the Department of Energy’s Loan Programs Office, which lower borrowing costs by reducing lender risk. The UK has taken a somewhat different approach, committing £210 million in direct grant funding to Rolls-Royce SMR to reduce private investor exposure.

None of this is charity. It’s risk transfer. The government absorbs some of the early-stage uncertainty so that private capital feels safe enough to move. The question is whether the risk transfer is designed well, and the NuScale experience suggests it sometimes isn’t.

The FOAK problem: why the first reactor is always the hardest sell

“FOAK” stands for first-of-a-kind, and it’s the industry’s polite term for “we don’t know what this will actually cost.” Every novel reactor design faces a FOAK build, and FOAK builds are expensive because nothing is optimized yet, supply chains don’t exist at scale, regulators are examining an unfamiliar design, and workers are learning procedures for the first time ⚠️. After the FOAK, subsequent “NOAK” (nth-of-a-kind) builds should be faster and cheaper. The whole SMR business thesis depends on reaching NOAK territory.

NuScale’s Carbon Free Power Project collapse in November 2023 is the FOAK problem made viscerally concrete. The Utah Associated Municipal Power Systems project was supposed to deliver electricity at $55 per megawatt-hour. By cancellation, the projected cost had risen to $89 per megawatt-hour, a 62% increase, driven by inflation, design revisions, and the inherent costs of doing something for the first time. The DOE had committed $1.4 billion in cost-sharing support. None of it was enough.

The Clean Air Task Force’s post-mortem identified several compounding problems:

• UAMPS was a collection of small municipal utilities with no experience in nuclear procurement and no capacity to absorb cost overruns on behalf of their ratepayers

• The project was structured around a single customer base, so when utilities started dropping out, there was no fallback

• NuScale’s pool-based design required large fixed civil works regardless of module count, undermining the “pay for what you need” modularity argument

• The project was launched in 2015, well before NRC design certification, meaning customers were committing to a design that hadn’t been approved yet

What this tells us is that the business model failed at least as much as the economics did. The right customer for a FOAK reactor is someone who can absorb cost uncertainty, needs reliable clean power regardless of price, and has a long enough time horizon to wait. Small municipal utilities in competitive electricity markets are essentially the opposite of that customer profile.

Big Tech as the new nuclear buyer

If you need a buyer who has deep pockets, doesn’t flinch at long timelines, needs 24/7 clean power regardless of price, and has a strategic reason to care about energy security, you are describing the AI data center business in 2025 💰. That alignment is not a coincidence. It’s why the past 18 months have produced more nuclear power purchase agreements than the previous decade combined.

Google made history in October 2024 by signing the world’s first corporate SMR power purchase agreement, committing to buy 500 megawatts from Kairos Power’s fleet of molten salt reactors, to be delivered between 2030 and 2035. Amazon followed two days later, anchoring a $500 million investment round in X-energy and committing to 5 gigawatts of SMR capacity by 2039. Microsoft signed a 20-year deal with Constellation Energy to restart Three Mile Island’s Unit 1, delivering 835 megawatts of power. In May 2025, Google went further, committing early-stage capital to Elementl Power for three reactor sites totaling 1.8 gigawatts. Meta issued a request for proposals targeting as much as 4 gigawatts of new nuclear generation.

These are not token investments. Big tech companies signed contracts for more than 10 gigawatts of possible new US nuclear capacity in the past year, according to reporting compiled by Introl. That’s a demand signal the nuclear industry has genuinely never seen from private buyers before.

What makes a Power Purchase Agreement the preferred structure here:

• The buyer commits to purchase power at a fixed price for a fixed term, often 20 years, giving lenders the revenue certainty they need to finance construction

• The PPA effectively transfers electricity price risk from the reactor owner to the buyer

• Tech companies are relatively indifferent to this risk because their electricity costs are small compared to their data center construction and compute costs

• Long-term PPAs also help tech companies meet their net-zero commitments with real, always-on generation rather than renewable energy certificates

The honest concern worth naming is that most of these agreements are structured around SMRs that don’t exist yet. Google’s Kairos deal has a first delivery date of 2030. Amazon’s X-energy commitment targets the early 2030s. If those timelines slip, which FOAK history suggests is likely, the tech companies face the choice of absorbing delays or walking away. The PPA structure protects them somewhat, but it doesn’t make the underlying physics of nuclear construction any faster.

The emerging alternatives: own it, lease it, or just buy the steam

The traditional model, where a utility builds, owns, and operates a reactor and sells power on the grid, is only one of several structures now being explored 🔬. The SMR format opens up business models that were simply not practical at gigawatt scale.

The Build-Own-Operate (BOO) model flips the traditional utility structure. Instead of selling the reactor to a customer, the vendor builds it, keeps ownership, and sells electricity or heat as a service. This is how some microreactor developers are positioning themselves, particularly for remote industrial applications. The customer gets clean power without the regulatory burden of owning a nuclear facility. The vendor captures long-term operating revenue. The risk is that the vendor carries all the construction and operational risk on its own balance sheet.

Vendor-financed models are a related variant and, according to market research firm Precedence Research, represent the fastest-growing segment in SMR financing by ownership structure. The vendor finances construction and recoups the cost through long-term service and power contracts. Rolls-Royce SMR’s public positioning leans heavily in this direction: their stated goal is to make their reactors “financeable without the need for government intervention in the long term,” relying on factory-built standardization to make the numbers work for private lenders.

For industrial customers, there’s also a simpler version: just buy the heat. Nuclear reactors produce enormous quantities of process heat, and industries like hydrogen production, aluminum smelting, and semiconductor manufacturing need exactly that kind of continuous, high-temperature energy. An SMR positioned as an industrial heat supplier doesn’t need to touch the electricity grid at all, which sidesteps a range of regulatory complications.

What the EFI Foundation’s 2024 report on SMR bankability makes plain is that no single business model works for all applications. The right structure for powering a remote mine in the Canadian Arctic is completely different from the right structure for supplying a data center campus in Virginia. The industry is still figuring out which models work where, and the next decade of deals will tell us far more than any projection does.

So here’s the question worth actually sitting with: given that FOAK projects in nuclear have historically failed about as often as they’ve succeeded, and given that the entire SMR cost thesis depends on reaching NOAK production volumes, which specific company or country do you think will be the first to deploy a second, third, and fourth identical reactor from the same design — and why?

Most people have a rough mental image of a nuclear reactor: something enormous, vaguely ominous, surrounded by cooling towers breathing white steam into the sky. But what’s actually happening inside? The honest answer is: a chain of events so small it’s invisible, producing heat so intense it could power a city, controlled by a system so precise it has to work perfectly every second of every day. That’s the deal. And once you understand it, you can’t look at a uranium pellet the same way.

The core idea is not complicated. Split an atom, capture the heat, boil water, spin a turbine, make electricity. That’s it. A nuclear power plant is, at its simplest, a very exotic way to boil water. The complexity is in the “split an atom” part, and that’s where things get interesting.

The atom that started it all

The star of the show is uranium-235, a particular variety of uranium with 92 protons and 143 neutrons packed into its nucleus ☢️. It’s not very common. As the U.S. Nuclear Regulatory Commission explains, only about 0.7% of naturally occurring uranium is U-235 — the rest is mostly the heavier and far more stable uranium-238, which simply refuses to cooperate with the process we need. So before uranium can fuel a reactor, it gets enriched — that is, the proportion of U-235 is artificially boosted to around 5%. Not weapons-grade by a long shot, but enough to sustain a reaction.

The enriched uranium is then pressed into small ceramic pellets, roughly the size of a sugar cube 🍬. These pellets get stacked inside sealed metal tubes called fuel rods, and more than 200 of those rods get bundled together into a fuel assembly. A full reactor core holds hundreds of these assemblies. What you’re looking at is thousands upon thousands of tiny ceramic cylinders, each one carrying an almost absurd amount of potential energy:

• A single uranium pellet contains roughly the same energy as one tonne of coal

• A typical reactor needs about 27 tonnes of fresh uranium fuel per year

• A coal plant of comparable size would burn through more than 2.5 million tonnes of coal for the same output

• The fuel pellets themselves are not radioactive in the dangerous, touch-it-and-die sense — they become hazardous only once the fission process begins

Think about that energy density for a second. It’s almost offensive how much power is crammed into something you could hold in your palm. That’s the fundamental promise of nuclear energy.

The chain reaction: a controlled domino effect

Here’s where the physics gets genuinely beautiful ⚡. When a slow-moving neutron strikes a U-235 nucleus, the nucleus absorbs it and becomes briefly, violently unstable. It splits — typically into two smaller atoms like barium and krypton — and in doing so, it releases a burst of heat and two or three additional free neutrons. Those neutrons go on to hit other U-235 atoms, which also split and release more neutrons, which hit more atoms, and so on. This is the nuclear chain reaction.

The U.S. Energy Information Administration puts it clearly: the chain reaction is self-sustaining as long as enough fissile material is present. Left completely uncontrolled, it would be catastrophic. Inside a reactor, it’s kept in a careful, deliberate balance where exactly one neutron from each fission event triggers one more fission event. Engineers call this the critical state, and keeping a reactor in it is the entire point.

The math of criticality:

• If fewer than one neutron per fission causes another fission, the reaction fizzles out (subcritical)

• If exactly one neutron sustains the reaction, you have stable, controlled power generation (critical)

• If more than one neutron triggers further fissions, the reaction accelerates (supercritical, which is what you absolutely don’t want)

This is worth pausing on if you’ve ever worried about a reactor “going off like a bomb.” It can’t. The geometry of the fuel, the concentration of U-235, and the moderator all conspire to make an uncontrolled weapons-grade explosion physically impossible in a commercial reactor. The scenarios that have caused real harm — Three Mile Island, Chernobyl, Fukushima — were runaway heat events, not nuclear explosions. Different problem. Still serious, but categorically different.

The unsung hero: the moderator

Here’s a detail most people never hear about 🔬. The neutrons that fly out of a fission event are fast. Too fast, actually. U-235 atoms don’t readily absorb high-speed neutrons — they prefer the slow, lazy kind. So the reactor includes a moderator, a material whose job is to slow the neutrons down without absorbing them.

The most common moderator is plain water. As the MIT Nuclear Reactor Laboratory explains, when a fast neutron bounces around inside water, it gradually loses energy in collisions with hydrogen atoms until it slows to what engineers call a thermal neutron speed. At that speed, it becomes far more likely to cause fission when it encounters a U-235 nucleus. This is why the reactor core is submerged in water — it’s not just for cooling. The water is doing two separate jobs at once.

The main types of moderators used in reactors worldwide:

• Light water (ordinary H₂O): the most common, used in about 90% of reactors globally

• Heavy water (deuterium oxide, or D₂O): absorbs fewer neutrons, allows natural uranium to be used as fuel without enrichment

• Graphite: used historically in some reactor designs, including the now-infamous RBMK at Chernobyl

The choice of moderator shapes almost everything else about a reactor’s design: fuel type, coolant, operating pressure, and safety characteristics. It’s one of the first design decisions a reactor engineer makes.

Control rods: the brakes on the whole system

So you’ve got neutrons flying around, splitting atoms, releasing heat 🌡️. How do you turn it down? Or off? The answer is control rods, usually made from materials like boron or silver, which are excellent at absorbing neutrons. Insert the control rods deeper into the core, and you’re soaking up neutrons before they can cause further fissions — the reaction slows. Pull them out, and the reaction speeds up. All the way in and the chain reaction stops entirely.

This is, in essence, how an operator controls the output of a nuclear reactor. It sounds almost too simple, and in a way, it is:

• Control rods inserted fully → reactor shuts down (called SCRAM, the term for an emergency shutdown)

• Control rods partially inserted → steady-state power output

• Control rods partially withdrawn → power level increases

• Control rods combined with moderator adjustments → fine-grained power control

What you might find interesting is that modern reactor designs increasingly lean on passive safety systems — mechanisms that work automatically using gravity and natural convection, no operator action required. Small modular reactors, the technology this publication covers closely, are built around this principle. The physics itself provides the safety net, not just the engineering. If you’re curious about how SMR designers are baking passive safety into their reactor concepts, that’s a topic worth exploring in depth.

From heat to electricity: the boring part that matters enormously

Once the reactor core generates heat, the rest of the process is basically a very sophisticated steam engine ♻️. The details differ by reactor type, but the principle is identical across the board.

The IAEA breaks this down cleanly: the heat warms a coolant, typically water, which either directly produces steam or transfers its heat through a steam generator to a separate, non-radioactive water loop that produces steam. That steam drives a turbine, which spins a generator, which produces electricity. The steam then cools back into water and the cycle repeats.

The two dominant reactor types handle this slightly differently:

• Pressurized Water Reactors (PWRs): the water in the reactor stays liquid under high pressure (it never boils), then heats a separate water loop that does boil into steam. As of 2024, PWRs account for 74% of all operating reactors worldwide — around 308 units globally

• Boiling Water Reactors (BWRs): the water boils directly inside the reactor vessel and feeds steam straight to the turbine, cutting out the middleman

Both types sit within a pressure vessel — a thick steel container that houses the fuel assemblies, moderator, and coolant. Surrounding that is the containment structure, typically a reinforced concrete shell designed to contain radioactive material if something goes wrong. And surrounding that is the reactor building. The engineering is layered, deliberately and thoughtfully. Multiple barriers, not just one.

Have you ever wondered why nuclear plants produce so little waste relative to fossil fuels? A reactor generates no carbon dioxide during operation. And while spent nuclear fuel is genuinely challenging to manage, according to the World Nuclear Association the entire global nuclear industry produces a comparatively tiny volume of high-level waste relative to coal, oil, and gas, which dump their waste directly into the atmosphere.

Why any of this matters for SMRs

As of 2025, there are 417 commercial nuclear reactors operating globally, and the physics inside every single one of them is identical to what’s described above 🌍. Uranium-235 splits. Neutrons slow down. Heat transfers. Steam spins turbines. Electricity flows.

What small modular reactors are trying to do is take that same physics and apply it in a more compact, factory-built package — one that can be deployed faster, scaled incrementally, and placed in locations where a conventional gigawatt-scale plant would never fit. The fission process doesn’t care about the size of the container. U-235 splits whether the reactor weighs 10,000 tonnes or 500. That’s the elegance of the approach.

Here’s what distinguishes SMR physics from conventional reactor physics:

• Smaller core volume means inherently lower power output but also simpler thermal management

• Passive cooling is more practical at small scale, since natural convection can do what pumps do in large reactors

• Higher power density in some advanced designs, using fuels like HALEU (high-assay low-enriched uranium) at enrichment levels above the standard 5%

• Alternative coolants — liquid sodium, molten salt, helium gas — are more viable in SMR designs because the engineering challenge scales with reactor size

The next time you read about a new SMR startup promising a reactor that “runs for years without refueling” or “can’t melt down,” the physics above is the underlying story. Sometimes those claims hold up. Sometimes they need scrutiny. Knowing how a reactor actually works is the best tool you have for telling the difference.

So here’s the question worth sitting with: given that the core physics of nuclear power has been understood since the 1940s, why does it still feel so mysterious to most people — and what would it take for public understanding to finally catch up with the technology?

Picture a Wednesday afternoon in 2050. A steel mill in rural Ohio hums at full capacity, powered entirely by a pair of compact reactors sitting on a footprint smaller than a neighborhood park. In northern Finland, a remote town heats its homes and powers its hospital from a single modular unit that was factory-built in South Korea and shipped in three pieces. A cargo ship crosses the Pacific running on hydrogen produced by nuclear heat. None of these images feel far-fetched anymore. They feel, increasingly, like a reasonable bet.

This is not a prediction. Nobody with intellectual honesty claims to know what 2050 will look like. But if the SMR industry clears the very real hurdles in front of it — cost, construction timelines, public acceptance, fuel supply chains — the downstream effects on energy, industry, geopolitics, and daily life are genuinely remarkable. Worth thinking through. Worth mapping out.

The International Energy Agency projects that under ambitious policy support, SMR deployment could reach 190 GW globally by 2050, with cumulative investment approaching $900 billion. The Nuclear Energy Agency has identified 127 SMR technologies currently in development worldwide. Some of these will fail spectacularly. A handful will probably change everything. So: what does the world look like if that handful wins?

The electricity grid gets a proper backbone

The central problem of renewable energy has always been intermittency. The sun sets. The wind stalls. Batteries help at the margin, but they have not solved the dispatchability gap that makes grid operators quietly nervous. SMRs, if they scale, address this directly. They generate 24/7 electricity with no emissions and, in most designs, without the catastrophic failure modes of older large reactors. 🔋

In a world where SMRs succeed, the grid of 2050 probably looks like this:

• Renewables handle most daytime generation in sunny and windy regions

• SMRs provide baseload power and the flexibility to ramp when renewables drop

• Industrial facilities co-locate their own reactors, pulling off the main grid entirely

• Rural and island communities stop depending on diesel generators

Think about what that last point alone means. Right now, remote communities across Canada, Alaska, and parts of Scandinavia pay staggering prices for diesel-generated power. The Wikipedia entry on small modular reactors notes that microreactors under 20 MW are specifically being designed for exactly these markets. If a 10 MW unit can be dropped into a northern Canadian mining town the way a shipping container gets dropped on a dock, the economics of remoteness change fundamentally. ⚡

The data center industry has already figured this out. Microsoft, Google, and Amazon have all signed nuclear power agreements, though most won’t see electrons flowing until the mid-2030s at the earliest. By 2050, if costs have followed the learning curve that solar panels once did, those deals will look like the early adopter bargains that they are. 🌐

Is this utopian? A little. But the ITIF analysis makes a credible case that SMRs, unlike large reactors, genuinely can achieve cost reductions through factory production and serial deployment. The question isn’t whether the physics works. It does. The question is whether the economics and logistics do, too.

Industry finally cleans up its act

The dirty secret of the energy transition is that electricity grids get most of the attention, but hard-to-abate industries are where decarbonization gets genuinely hard. Steel. Cement. Chemicals. Ammonia. These sectors produce roughly a third of global CO₂ emissions, and wind and solar can’t directly reach most of them. They need heat, not just electrons. Really hot heat. 🏭

This is where the SMR story gets interesting in a way that most coverage misses. Several SMR designs — particularly high-temperature gas-cooled reactors like the Xe-100, which X-energy is deploying at Dow’s Seadrift plant in Texas — can produce industrial heat at temperatures high enough to replace fossil fuel combustion in manufacturing processes. According to a 2025 analysis tracked by Nucnet, SMRs could reach 700 GW of capacity by 2050 under a transformation scenario, with five industries alone accounting for over 75% of that opportunity:

• Iron and steel production

• Upstream oil and gas processing

• Chemical manufacturing

• Food and beverage production

• District heating networks

In a world where those deployments happen, the steel mill in rural Ohio mentioned above isn’t a fantasy. It’s a market outcome. Nuclear heat replaces coal-fired blast furnaces. The hydrogen economy, which many analysts see as essential for shipping and aviation, runs on nuclear-produced green hydrogen rather than requiring vast renewable electricity capacity dedicated to electrolysis. 🔬

I think this is the most underappreciated dimension of the SMR story. Everyone talks about electricity. The real prize is heat. If SMR developers can consistently deliver high-temperature output at competitive cost, they unlock decarbonization pathways that simply don’t exist in a solar-and-wind-only world. What do you think the hardest industry to decarbonize actually is? The steel sector, with its ancient blast furnace infrastructure? Cement, where 60% of emissions come from the chemistry of the limestone itself? The answers might shape which SMR designs matter most.

Geopolitics runs on uranium

Here is where the optimistic 2050 scenario gets complicated. Because a world where SMRs succeed globally is also a world where nuclear technology exports become one of the most consequential geopolitical levers on the planet. And right now, two countries have a serious head start. 🌍

Russia and China have both deployed operational SMRs. Russia runs its floating KLT-40S reactors in the Arctic, and China brought its land-based ACP-100 online in late 2025. The United States, despite enormous private sector activity, has zero commercially operating Western-designed SMRs as of today. The CSIS analysis is blunt about the implications: nuclear commerce creates decade-long relationships between supplier and recipient countries. Whoever builds your reactor controls a significant portion of your energy security for a generation.

In a successful SMR world in 2050, the geopolitical map probably looks like one of two things:

• A multipolar nuclear market where US, European, South Korean, and Japanese designs have matched or surpassed Russian and Chinese deployments, creating genuine competition and better terms for recipient countries

• A bifurcated world where authoritarian-backed designs dominate the developing world and democratic designs hold the wealthy nations, with fuel supply chains becoming a permanent geopolitical flashpoint

The European Commission’s March 2026 strategy to deploy the continent’s first SMRs by the early 2030s is a direct response to this risk. The UK’s selection of Rolls-Royce as preferred bidder to build Britain’s first SMRs signals that some Western governments are finally treating this as the strategic competition it is, not just an energy policy question. 🤝

The first scenario is better for almost everyone. But reaching it requires the United States and its allies to move much faster than their current regulatory timelines suggest. The race is not merely commercial. It’s structural.

The communities that finally get left in

Zoom out from the geopolitics and you find a human story that matters just as much. Right now, energy poverty is one of the most stubborn constraints on development. Over 700 million people globally still lack reliable electricity access. The conventional answer, for decades, was to build out grid infrastructure and central generation capacity. That answer is slow, expensive, and has failed large parts of sub-Saharan Africa and South Asia on the timelines that mattered. 💡

A successful SMR world offers a different model. Smaller reactors mean smaller grid requirements. A single 50 MW unit can power a medium-sized city in a developing country without requiring the transmission infrastructure that large plants demand. Countries currently considering SMRs include Vietnam, Thailand, the Philippines, and Poland, according to Washington Quarterly research. Over 30 countries are actively planning or exploring new nuclear programs, many with little prior nuclear experience.

In 2050, if those programs succeeded:

• Grid-connected communities in parts of Africa and Southeast Asia would have reliable, 24/7 power from domestic nuclear generation, not diesel or coal imports

• Small island nations could eliminate their dependence on imported fossil fuels entirely

• The economics of desalination change, because nuclear-powered desalination is already technically viable and becomes competitive at scale

The catch, and it’s a real one, is the waste question. Some studies suggest SMRs could produce two to thirty times the waste volume of large reactors, depending on design. This is not a reason to dismiss the technology, but it is a reason to take waste policy as seriously as deployment policy. A world with 700 GW of SMR capacity that has not solved long-term waste storage is trading one problem for another. 🌱

The reckoning still ahead

Let’s be honest about what a 2050 SMR success story does not solve. Because intellectual honesty matters more here than narrative tidiness.

Cost overruns have haunted nuclear for decades. The NuScale project in Idaho was cancelled in 2023 precisely because projected costs spiraled past what the utilities would absorb. The Arthur D. Little analysis notes that the industry faces a classic chicken-and-egg problem: supply chains won’t develop until demand is clear, and demand won’t materialize until supply chains exist. First-mover economics are brutal.

Regulatory harmonization is still a mess. The US Nuclear Regulatory Commission defines SMRs as only light-water reactors under 300 MWe, while the World Nuclear Association uses a broader definition. Different countries have wildly different licensing timelines, making international deployment far harder than proponents often admit.

Fuel supply chains remain dangerously concentrated. As of 2026, Russia effectively monopolizes the supply of HALEU (high-assay low-enriched uranium), which many advanced SMR designs require. China is the only other country with meaningful production capacity. This is a single point of failure that a successful SMR industry cannot afford to leave unaddressed. ⚠️

And then there is the question that doesn’t get asked enough: who decides where these reactors go, and who benefits from the decisions? The ScienceDirect energy justice research from late 2025 is pointed about the transparency problems already present in nuclear governance, where affected communities are regularly excluded from meaningful decision-making about infrastructure that will operate in their backyard for sixty years.

A world where SMRs succeed technically but fail socially is not a success. It’s a different kind of problem.

The 2050 question, ultimately, is not just can SMRs deliver, but who gets to decide how, and who bears the costs when something goes wrong. Those are political questions as much as engineering ones, and the engineering community has historically been better at the second than the first. If you’re tracking the SMR story closely, which of these barriers do you think is most likely to derail the whole thing: costs, fuel supply, waste policy, or public acceptance? The answer might determine whether that Ohio steel mill and that Finnish town are history or just a very expensive thought experiment.

Before August 2022, nuclear energy was the clean energy sector’s awkward stepchild. Wind and solar got generous federal tax credits. Nuclear got nothing. Existing plants were bleeding cash, facing early retirement, and struggling to compete against cheap natural gas. New reactors were a pipe dream. Then Congress passed the Inflation Reduction Act, and almost overnight, the math on nuclear changed.

The IRA is best known for its roughly $369 billion in climate provisions, the largest climate investment in US history. Most of the headlines went to solar panels and electric vehicles. But buried in the legislation was something that nuclear advocates had wanted for decades: direct federal support, structured not as a grant program or a subsidy, but as a production tax credit available to zero-emission electricity generators. Any zero-emission generator. Including nuclear.

That one word, “any,” rewrote the rules. And for small modular reactors, which were already building momentum on the technology side, it may turn out to be the most consequential sentence in federal energy policy in a generation.

The three credits that actually matter

The IRA created or expanded three distinct mechanisms for nuclear, each solving a different problem. It helps to understand them separately rather than lumping them together.

The first is the Section 45U Zero-Emission Nuclear Power Production Credit, which covers the existing fleet. Before 2022, plants like Quad Cities in Illinois, which had nearly been shut down due to negative electricity prices caused by grid congestion and wind oversupply, had no federal backstop whatsoever. Section 45U changed that. The credit:

• Applies to plants that began supplying electricity before August 16, 2022

• Pays a base rate of 0.3 cents per kilowatt-hour, inflation-adjusted annually

• Scales up to 1.5 cents per kWh if prevailing wage requirements are met

• Runs through the end of 2032

• Is eligible for direct payment or transfer, which matters enormously for nonprofit utilities

The Joint Committee on Taxation projects that Section 45U will reduce federal revenues by $13.1 billion between FY2024 and FY2028, roughly $2.6 billion a year. That is real money going to keep real carbon-free generators running. It is worth pausing on that number. These are operational plants that produce about 20% of US electricity and nearly half of all zero-emission electricity. Keeping them online at a cost of $2.6 billion annually is, by any reasonable measure, a bargain.

The second mechanism targets new advanced reactors, including SMRs: Sections 45Y and 48E, the technology-neutral clean electricity production and investment credits. This is where things get genuinely interesting. ⚡

• The production tax credit (45Y) pays $15 per megawatt-hour for 10 years after a qualifying zero-emission facility is placed into service, with annual inflation adjustments

• The investment tax credit (48E) covers 30% of construction costs for qualifying facilities placed in service after December 31, 2024

• A 10% bonus applies if the plant is built on a brownfield or fossil-fuel community site 🏭

• A new nuclear-specific energy community adder was added by the One Big Beautiful Bill Act in 2025, rewarding areas with existing nuclear employment

Developers can choose one or the other but not both. For SMRs with very high first-of-a-kind capital costs, the 30% ITC is probably the right pick. As costs fall with subsequent builds and manufacturing scale, the PTC becomes more attractive.

The third piece is the $700 million for HALEU fuel research and production. This matters because most advanced reactor designs, including many SMR concepts, need high-assay low-enriched uranium, which barely exists in commercial quantities in the US right now. Without a domestic HALEU supply chain, no SMR can be built at scale regardless of what the tax code says. The IRA at least started the clock on solving that problem. 🔬

Why SMRs specifically benefit

The technology-neutral framing of 45Y and 48E is the key insight here. Previous nuclear tax credits were narrow, technically complex, and practically useless. Section 45J, the old advanced nuclear credit, has existed since 2005. As of mid-2023, not a single taxpayer had ever received it. Georgia Power’s Vogtle Units 3 and 4 finally claimed 45J credits in late 2023, but that was the first time in 18 years the credit did anything.

The IRA flipped that failure by making nuclear compete alongside wind and solar on the same credit terms, rather than through a separate, harder-to-access regime. According to a 2024 study published in Frontiers in Nuclear Engineering, which modeled IRA credit impacts on a 300 MWe representative SMR in the ERCOT market, the credits meaningfully improve SMR economics across a range of variable operating costs. That is not a guarantee of profitability, but it shifts SMRs from “probably uneconomic” to “competitive with careful project selection.”

The Center for Strategic and International Studies ran the numbers on overall capital costs, using first-of-a-kind estimates of $3.7 billion to $7.7 billion per gigawatt of overnight capital cost. At those price points, the ITC and PTC materially reduce the levelized cost of energy and make nuclear competitive with other generation technologies. For higher-cost projects, the ITC wins. As costs fall, both approaches converge. 📈

The public power angle deserves more attention than it usually gets. Nonprofit utilities, co-ops, rural electric associations: these organizations have historically been locked out of federal tax credit financing because they do not owe federal income tax. The IRA’s direct pay option changes that. Nonprofits can now receive the credit value as a payment, not just as an offset against taxes they do not owe. This matters enormously for SMRs, because small modular reactors are sized to serve the demand profiles of medium-sized utilities, many of which are nonprofits. Have you thought about what this means for rural electric co-ops that have been buying power from coal plants for decades?

The big tech catalyst

The IRA did not just improve nuclear economics in spreadsheets. It triggered a wave of power purchase agreements between tech companies and nuclear developers that probably would not have happened without the policy certainty the credits provided. 💡

Consider what happened in the fall of 2024:

• Google signed an agreement with Kairos Power to build six to seven reactors totaling 500 megawatts, targeting the first unit online by 2030

• Amazon partnered with X-energy to develop a four-unit 320 megawatt project with Energy Northwest, with an option to scale to 12 units and 960 megawatts, plus a broader collaboration targeting more than 5 gigawatts by 2039

• In May 2025, Google and Elementl Power agreed to develop three project sites totaling at least 600 megawatts each

These are not research announcements. They are commercial commitments. According to Third Way’s analysis, these agreements are largely predicated on the existence of the IRA tax credits. Remove the credits, and the risk calculus for tech companies changes significantly.

The AI data center buildout is driving this. Data centers need reliable, around-the-clock baseload power that cannot be provided by solar panels that stop working at night. Nuclear, and specifically SMRs that can be sited close to load centers, is one of the very few technologies that meets that need. The IRA gave developers the financial confidence to start making commitments, and tech companies the assurance that the projects would get built.

What the One Big Beautiful Bill changed, and what it did not

In July 2025, President Trump signed the One Big Beautiful Bill Act, which rewrote large chunks of the IRA’s clean energy framework. For wind and solar, the news was mostly bad. For nuclear, the story is more nuanced.

What the OBBBA did not do is just as important as what it did. Wind and solar faced aggressive timelines: projects must be placed in service by the end of 2027 to qualify for the tech-neutral credits. Nuclear did not face the same accelerated phaseout. According to Arnold & Porter’s analysis, the OBBBA:

• Retains Section 45U for existing nuclear facilities through December 31, 2032

• Maintains transferability provisions for the full credit window

• Preserves the tech-neutral 45Y and 48E credits for nuclear with a 2032 phase-out schedule

• Adds a new nuclear energy community bonus tied to local nuclear employment

• Allocates $125 million specifically for developing small modular reactors for military use

The OBBBA did add one significant new constraint: restrictions on foreign entities of concern, meaning any nuclear project with ties to China, Russia, North Korea, or Iran loses credit eligibility. Given that Russia’s ROSATOM still supplies enriched uranium to several US reactors, the fuel sourcing provision is a live complication, not just a theoretical one. 🌍

The Council on Foreign Relations noted that nuclear’s relative preservation in the bill reflects genuine bipartisan support. No Republican voted for the original IRA. But when the OBBBA’s earlier drafts threatened to accelerate nuclear credit phaseouts, Republican lawmakers from nuclear-heavy districts pushed back hard. Rep. Claudia Tenney of New York made the case directly: her district depends on four nuclear reactors for a substantial share of the state’s electricity.

The political lesson here is real: nuclear has a coalition that wind and solar do not, cutting across party lines in ways that make it more durable in a changing political environment.

The uncertainty that remains

None of this means SMRs are a done deal. The IRA created the financial conditions for nuclear resurgence. It did not actually build any reactors.

First-of-a-kind construction risk is still enormous. The Vogtle Units 3 and 4 in Georgia came in years late and billions over budget. The industry argues, with some justification, that SMRs avoid many of those problems through factory fabrication and modular assembly. But that argument has not yet been stress-tested against actual SMR construction. The Argonne National Laboratory’s modeling, which is the most credible independent analysis of IRA impacts on SMRs, shows that the credits significantly improve SMR economics but do not guarantee competitiveness across all scenarios. Variable operating costs, grid pricing, and local market conditions still matter a lot.

The HALEU fuel supply chain is still not solved. $700 million is a start, not a solution. Commercial quantities of HALEU for a fleet of advanced reactors require years of infrastructure investment that has not fully materialized.

And the credits themselves have a clock. The 45U credit expires in 2032. The tech-neutral credits begin phasing out around the same year. For developers making 20-year investment decisions, a 7-year incentive window is better than nothing, but it is not the same as long-term policy certainty. The Breakthrough Institute makes a strong case that IRA credits are necessary to attract private capital at this stage of development, when first-of-a-kind costs are highest and project risk is greatest. The question is whether the window stays open long enough for SMRs to reach cost reductions that make them self-sustaining without credits.

What does your read on the policy risk look like? Is a decade of credits enough to get SMRs to commercial maturity, or does the industry need longer-term certainty to make the capital commitments required?

The honest answer, as of April 2026, is that we do not know yet. What we do know is that the IRA opened a door that had been effectively closed for 30 years. The nuclear industry is walking through it. Whether SMRs can reach commercial scale before the credits expire is the central question of US energy policy for the rest of this decade. The next few investment decisions by TVA, Kairos Power, X-energy, and others will tell us more than any policy analysis can. Watch those announcements closely.

Picture this: a hospital in rural Nigeria running on a diesel generator that costs three times more per kilowatt-hour than anything its patients can afford. A school in Ethiopia where children do homework by candlelight because the grid, if it exists at all, cuts out for 18 hours a day. A factory in Ghana that could employ a thousand people, but can’t attract investment because power is too unreliable to run a shift.

This is the everyday reality of energy poverty — not an abstraction, not a statistic, but a structural ceiling on human potential that affects roughly 730 million people worldwide as of 2024. Sub-Saharan Africa alone accounts for 80% of the global electricity access gap, with more than 600 million Africans still without power. Nigeria, the Democratic Republic of Congo, and Ethiopia together account for over a third of the world’s unelectrified population.

Against that backdrop, a growing chorus of policymakers, nuclear engineers, and development economists is making a bold argument: small modular reactors — compact, factory-built nuclear plants that can be scaled up module by module — could be exactly the kind of technology the developing world needs. The pitch is seductive. Lower capital costs than traditional reactors. Shorter construction times. The ability to work with small, fragile grids. Baseload power that never depends on whether the sun is shining or the wind is blowing. But whether SMRs can actually deliver on that pitch, in countries where financing is scarce, regulatory capacity is thin, and electricity demand is growing faster than anyone can keep up with, is a genuinely complicated question.

The scale of the problem, and why conventional solutions aren’t enough

The numbers here are worth sitting with. The IEA’s October 2025 data shows that 730 million people lacked electricity access in 2024 — a decline of only 11 million from the year before. That pace is slower than before the pandemic and is nowhere near what’s needed to reach universal access by 2030, which requires progress roughly ten times faster than the current rate. In sub-Saharan Africa, population growth continues to outpace new electricity connections in many countries, meaning the absolute number of people without power is rising even as electrification rates technically improve. 🌍

• Sub-Saharan Africa now accounts for 85% of the global population without electricity, up from 50% in 2010

• Africa’s electricity demand is projected to grow at 4% annually through 2026, the fastest of any region

• 18 of the 20 countries with the largest electricity access deficits are in Sub-Saharan Africa

• The World Bank and African Development Bank’s Mission 300 initiative aims to connect 300 million Africans to electricity by 2030, requiring $90 billion in financing

Solar and wind have made genuine progress — mini-grids and standalone solar systems provided over 50% of new electricity connections in sub-Saharan Africa between 2020 and 2022. That’s real. But here’s the thing renewables advocates sometimes gloss over: intermittency. A solar panel is great until sunset, or until the rainy season, or until the dry-season dust coats it and no one has the equipment to clean it. A continent that needs to power hospitals, cold chains, manufacturing facilities, and data centers cannot run on intermittent power alone. It needs baseload — reliable, dispatchable electricity available 24 hours a day, every day, regardless of weather. ☀️

That’s the gap SMRs are designed to fill. And it’s a real gap.

What SMRs actually offer developing countries

A small modular reactor is, by definition, a nuclear reactor producing up to 300 megawatts electric per unit — roughly a third the output of a conventional plant. The “modular” part matters: these reactors are designed to be factory-built and shipped in standardized components, then assembled on-site, much the way you’d deploy a fleet of identical trucks rather than custom-building each one from scratch. That matters enormously for countries without the deep construction expertise needed for traditional nuclear megaprojects.

The advantages for energy-poor nations are specific and worth stating clearly:

• Smaller footprint: SMRs can work with low-capacity grids that would be overwhelmed by a full-scale 1,000 MW reactor

• Incremental deployment: A country can start with one or two modules and add more as demand and financial capacity grow

• Passive safety: Many designs use gravity and natural convection for cooling, eliminating the need for active backup power systems — critical in places where grid reliability can’t be assumed 🔬

• Site flexibility: SMRs can be sited in remote areas, including repurposed industrial sites, without the extensive infrastructure that large plants require

• Baseload power: Unlike solar and wind, an SMR runs day and night, in any weather, for 60+ years

Ingrid Kirsten and Tony Stott, Senior Research Associates at the Vienna Center for Disarmament and Non-Proliferation, have noted that to equal nuclear’s power output, solar panels would need to cover vast land areas, creating significant environmental challenges of their own. The baseload argument isn’t just a nuclear talking point — it’s an engineering reality that grid planners in Nigeria and Kenya are grappling with every day.

Who’s actually moving on this, and how fast

This is where the story gets interesting. As of 2025, the developing world is not waiting passively for Western countries to figure out SMRs and eventually export the results. Countries across Africa and Asia are actively pursuing deals, feasibility studies, and regulatory frameworks right now. ⚡

Ghana is the most advanced. It has operated a nuclear research reactor since 1994 and in 2024 signed a framework agreement with U.S.-based Regnum Technology Group and NuScale Power to deploy up to 12 NuScale VOYGR-12 SMR modules — a total eventual capacity of nearly 924 MW. Ghana also launched Africa’s first NuScale Energy Exploration Centre in Accra, a regional training hub for operators and regulators across the continent.

Kenya, aiming to commission its first nuclear plant by 2034, hosted Africa’s first IAEA-led SMR School in May 2025 in Nairobi, with officials from Ghana, Niger, Nigeria, Uganda, and Zambia attending. Rwanda is exploring partnerships with NANO Nuclear Energy and Canada’s Dual Fluid for microreactor designs. Uganda has designated Buyende as a potential nuclear power plant site. The Nuclear Business Platform projects that Africa could generate as much as 15,000 MW of nuclear energy by 2035, led by Ghana, Uganda, Kenya, and Rwanda.

The geopolitical dimension here matters a great deal, and I think it’s undersold in most coverage. Russia and China are not waiting for the West to act. Russia’s state nuclear corporation Rosatom is already building a $30 billion, four-reactor plant in Egypt. China and Nigeria inked a nuclear cooperation deal at the 2024 Forum on China-Africa Cooperation. China approved 11 new domestic reactor projects in 2024 alone and is on track to become the world’s top nuclear generator by 2030. The U.S. is scrambling to catch up — the Department of Energy’s FIRST program is backing civil nuclear development across the continent, and the U.S.-Africa Nuclear Energy Summit is now an annual event — but the race is real, and the West does not have a commanding lead.

What does this mean for African nations? They have options, which is power. But it also means they’re navigating competing vendor agendas, financing models with different strings attached, and varying standards for nuclear safety and non-proliferation — all while trying to run a coherent national energy policy. If you think that’s easy, you’ve never tried to build regulatory capacity from scratch in a country where the entire nuclear engineering talent pool fits in one seminar room.

The hard problems no one should paper over

Here’s where honesty matters. The case for SMRs in the developing world is real, but the obstacles are genuinely serious — not just talking points from anti-nuclear activists. 💡

Financing is the biggest wall. A single 100-MW SMR can cost over $200 million, at roughly $2–3 million per megawatt. For context, Ghana’s entire national budget in recent years has been under $15 billion. International development finance institutions have historically been reluctant to back nuclear — partly due to lingering prohibitions, partly due to limited in-house expertise in evaluating nuclear projects. The World Bank recently changed its policy to allow nuclear financing, and regional development banks are following suit, but this evolution is slow relative to the urgency. Energy for Growth Hub research identifies three core barriers:

• Lack of specific projects mature enough for financing

• Limited nuclear expertise within lending institutions themselves

• Lingering explicit or implicit prohibitions on supporting nuclear technology

The timeline problem is uncomfortable. Even optimistic estimates from a 2025 ScienceDirect study suggest SMR deployment takes 7–10 years for newcomer countries on a first-of-a-kind basis. That’s 7–10 years before a single kilowatt-hour flows to a rural household. People are living without power right now. Solar home systems and mini-grids can be deployed in months. The honest answer is that SMRs are not a solution to the access crisis of the 2020s — they’re a potential foundation for the 2030s and beyond. That doesn’t make them wrong. It does mean anyone promising a quick fix is selling something that doesn’t exist.

Climate vulnerability is a real issue, and SIPRI researchers have flagged it clearly: many of the developing countries where electricity access is worst already have high ambient temperatures, which reduce the efficiency of nuclear power generation and can clog cooling water intakes. The Fukushima disaster, triggered by an extreme natural event, is a reminder that even wealthy nations with sophisticated emergency response systems can be blindsided. Designing SMRs for climate resilience, particularly in hot, drought-prone regions, is non-negotiable — and it needs to happen before construction starts, not as an afterthought.

Nuclear waste remains a real and unresolved challenge. Some SMR designs, according to research from Stanford and the University of British Columbia, may generate two to thirty times more radioactive waste per unit of electricity than traditional large reactors. That’s not a reason to abandon SMRs — but it means the waste management question needs to be baked into deployment planning, not kicked down the road.

Are you surprised by any of these challenges? Or do they confirm something you’ve suspected about the gap between the SMR pitch and the SMR reality? Either way, engaging with these questions honestly is the only way to build policy that actually works.

A path forward that takes both the promise and the risk seriously

None of the challenges above are arguments for abandoning SMRs as a development tool. They’re arguments for being smarter about how and where they’re deployed. The technology is real — China’s ACP-100 became the world’s first operational land-based SMR in late 2025. Russia’s floating plant at Pevek has been generating power since 2020. The science works. The question is whether the systems around the technology can be built fast enough and well enough to make deployment in developing countries a genuine success rather than a cautionary tale. 🚀

The IEA estimates that if SMR construction costs reach parity with large reactors by 2040, cost-effective uptake could increase by 60%, with deployment reaching 190 GW by 2050 globally. That trajectory is faster than conservative scenarios but slower than what SMR developers are currently promising. Somewhere in between is probably where reality lands.

What would a credible path actually look like? A few things seem clear:

• Regional cooperation matters more than individual country deals. Robert Lisinge of the UN Economic Commission for Africa has called for regional nuclear projects spanning multiple countries, sharing costs, regulatory capacity, and trained personnel

• The World Bank’s policy shift on nuclear financing needs to translate into actual loans, quickly, with concessional terms that reflect the development premium these projects carry

• Training pipelines need to start now, even where the first reactor is a decade away. Kenya’s IAEA SMR School model is exactly right — you build the human capital before you need it, not after

• Western democracies need to compete on vendor terms, not just on safety rhetoric. If Russia and China are offering financing packages that developing countries can actually access, the U.S. and Europe need equivalent instruments — or they’ll lose this market and the geopolitical relationships that come with it

• Hybrid approaches work. SMRs don’t replace solar and wind in developing countries — they complement them, providing the firm baseload capacity that makes an intermittent-heavy grid stable and reliable

The World Nuclear Association’s SMR Global Project Tracker shows at least 40 countries now taking concrete steps toward SMR deployment. That’s not hype — that’s a genuine shift in how the world thinks about nuclear energy’s role in the energy transition.

Here’s the question I’d invite you to sit with: If an SMR in Ghana in 2034 lights up hospitals, powers factories, and enables a generation of Ghanaian engineers to build and operate nuclear infrastructure — was the decade of preparation worth it? Most people, thinking carefully, would say yes. The real failure would be not to start that preparation now, because the alternative is another thirty years of diesel generators, unreliable grids, and economic ceilings that don’t need to exist.

What’s your read — are SMRs a genuine lifeline for the energy-poor world, or are we getting ahead of the technology again? The answer probably depends on what happens in Ghana over the next ten years. Watch that space.

There is a running joke in the nuclear industry: the countries most enthusiastic about small modular reactors are rarely the ones actually building them. The United States, the UK, France — they have the money, the engineers, and the regulatory frameworks. They are moving cautiously, as rich countries tend to do. But talk to an energy official from Ghana, Kenya, Romania, or Mongolia, and you hear something different. You hear urgency. You hear a specific kind of excitement that comes not from abstract techno-optimism, but from a very concrete problem: their countries need power, they need it soon, and the traditional nuclear playbook was never written for them.

This is not a niche observation. Since COP28 in late 2023, more than 25 countries have explicitly committed to tripling global nuclear capacity by 2050. A striking number of those are nations that have never operated a single reactor. The International Atomic Energy Agency is now coordinating SMR interest from countries including Algeria, Ethiopia, Indonesia, Jordan, Mongolia, Nigeria, Saudi Arabia, and Uzbekistan — a list that reads less like a nuclear club and more like a general assembly of economies that feel they have been left behind by the energy transition. The question worth asking is: why SMRs specifically? And is the excitement justified?

The gigawatt problem: when big power plants are too big

Here is the fundamental mismatch that almost never gets mentioned in Western SMR coverage. A conventional nuclear reactor produces somewhere between 1,000 and 1,700 megawatts of electricity. That is a lot of power. For France or the United States, dropping that kind of output onto a continental-scale grid is routine. For a country like Kenya, which has a total installed electricity capacity of roughly 3,000 MW across its entire national grid, connecting a single traditional reactor would mean managing a single plant that equals a third of your entire power system. One unexpected shutdown and you have a catastrophe. ⚡

The SIPRI analysis from 2024 put it well: 20th-century nuclear plants were, for the most part, enormous beasts that required sizable grids just to absorb their output. SMRs, by contrast, are designed to top out at 300 megawatts per module — about one-third the size of a conventional reactor. More practically, many designs come in even smaller increments. NuScale’s individual power modules, for example, each produce 77 MW, meaning a country can start with one, see how it goes, and add more as demand grows. That is a completely different risk profile than betting several billion dollars on a single monolithic plant.

This sizing logic explains something that pure economics does not. The appeal of SMRs to small-grid nations is not just about cost — it is about manageability. A power plant that can be built in stages, scaled up modularly, and physically sited in locations that would never work for a 1,000 MW behemoth is simply a different kind of technology. Whether the economics ultimately work out is a separate (and genuinely thorny) question. But the fit between SMR design philosophy and small-nation energy reality is not hype — it is structural.

The specific appeal breaks down like this:

• Grid compatibility: Small grids cannot safely absorb a sudden loss of a gigawatt-scale reactor without blackouts; sub-300 MW units are far more manageable

• Upfront capital: Lower per-unit cost means smaller financing ask, which is critical for countries with limited access to international capital markets

• Modular expansion: Nations can add generating capacity incrementally as demand grows, rather than overbuilding from day one

• Siting flexibility: Many SMR designs don’t require the massive water sources that traditional plants need, which matters enormously in arid or landlocked countries 🌍

• Passive safety: Modern SMR designs rely on physics — gravity, natural circulation — rather than human intervention, which is relevant in countries still building out their nuclear workforce

Who is actually signing up

The skeptic’s response to SMR enthusiasm in small nations is: sure, everyone says they want one. Letters of intent are cheap. But look past the press releases and the picture is more substantive than the cynics suggest. 🔬

Ghana is the most concrete African example. In August 2024, at the U.S.-Africa Nuclear Energy Summit in Nairobi, Ghana signed a framework agreement with NuScale Power and Regnum Technology Group to deploy up to 12 NuScale VOYGR-12 SMR modules. Each module initially produces 50 MW, scalable to 77 MW, which means the full deployment would eventually reach nearly 924 MW — a major chunk of new capacity. Through U.S. government support, Ghana also launched the region’s first NuScale Energy Exploration Centre in Accra, a hands-on training facility for future operators. It is not a shovel in the ground, but it is well beyond a vague declaration.

Kenya is moving on a parallel track. The country officially aims to commission its first nuclear plant by 2034 and in May 2025 hosted Africa’s first IAEA-led SMR School — a regional training program for engineers and regulators across the continent. Kenya has launched feasibility studies for 100–300 MW SMR deployment and, perhaps more revealingly, signed an MoU with Russia in 2025 to begin constructing a nuclear plant by 2027. Kenya is not waiting for a single perfect option. It is hedging across partners.

Rwanda is exploring microreactors and SMRs through partnerships with U.S.-based NANO Nuclear Energy and Canada’s Dual Fluid. A demonstration reactor funded by Dual Fluid could, if it materializes, dramatically accelerate Rwanda’s timeline. Then there is Europe’s version of this story. Poland and Romania — both mid-sized economies with significant coal dependence and a strong desire to cut it — are advancing GE Hitachi’s BWRX-300, a 300 MWe SMR designed explicitly as a coal plant replacement. GE Hitachi claims the BWRX-300 cuts capital costs by up to 60% per megawatt compared to traditional reactors, with a construction timeline of 24 to 36 months. Poland and Romania don’t have the nuclear infrastructure of France, but they have the grid scale and the political will. 🚀

What these countries share is instructive:

• Electricity demand growing faster than their current supply

• Limited options for large baseload power that isn’t coal or gas

• Political and economic pressure to hit climate targets

• Insufficient grid capacity for traditional-scale nuclear plants

Have you looked at what your own country’s energy plan looks like for 2035? The countries signing these SMR agreements are the ones that have, and found the answer unsatisfying.

What small nations actually want — and what they think they’re getting

When researchers Friederike Friess, Maha Siddiqui, and M.V. Ramana analyzed presentations from national representatives at IAEA conferences for their February 2026 paper in PNAS Nexus, they identified three consistent expectations from developing-country officials considering SMRs:

• Low cost electricity — specifically cheaper than what they’re currently paying for diesel or imported gas

• Demonstrated technology — proof that the design works somewhere before they stake their national energy policy on it

• Local manufacturing — the idea that the nuclear project would bring industrial jobs and technology transfer, not just a foreign-built box

These are rational things to want. They are also, unfortunately, things that SMRs currently struggle to promise. The paper is skeptical about all three. ⚡ On cost, the researchers point out that SMRs sacrifice economies of scale by design — smaller output means higher cost per unit of electricity, not lower. On demonstrated technology, only two commercial SMRs are actually operating today: one in Russia (the floating Akademik Lomonosov, operational since 2020) and one in China (the HTR-PM pebble-bed reactor, which came online commercially in December 2023, though at reduced capacity). Every other design is still on paper or in early licensing. And on local manufacturing, the economic model that makes SMRs potentially cheaper — factory mass-production of standardized modules — directly conflicts with local manufacturing. You cannot simultaneously build in a central factory for economies of scale and also build locally in 30 different countries.

None of this means the excitement is irrational. TerraPower, founded by Bill Gates, has been explicit that its Natrium reactor targets “nations that don’t even have nuclear today: nations in sub-Saharan Africa, where there’s tremendous population growth, or in Indonesia where we think Gen IV technology will be ideal.” That is a genuine long-term vision, not a charity pitch. And a Nature Energy study from 2024 found that, technically, micro and small modular reactors could serve 70.9% of the world’s unelectrified population. The physics work. What does not automatically work is the economics, governance, and financing — and those are the pieces that most of the enthusiasm papers over.

The hard math that no press release mentions

It is worth being specific about the economic tension here, because the gap between promise and reality is real and the people signing agreements deserve to understand it. 💡

The PNAS Nexus researchers calculated that even with significant projected cost declines — around 40% between now and 2050 — electricity from SMRs could still run US$180 to US$305 per megawatt-hour. That is two to five times the projected cost of a 90%-renewable energy grid by the end of this decade. For a developing country choosing between those two paths, that premium is not trivial. It is the difference between a viable national energy plan and a budget crisis.

The construction timeline problem compounds this. The IAEA’s own guidance suggests a 7 to 10 year timeline for a first-of-a-kind SMR in a newcomer country. That is the optimistic case. China’s HTR-PM started construction in December 2012 and was not declared commercially operational until December 2023 — 108 months, nearly triple the original estimate. NuScale’s UAMPS project in Idaho, which was supposed to be the landmark American deployment, was canceled in 2024 after costs ballooned. These are not obscure data points. They are the two most prominent recent examples.

The skeptical view is that small nations are being sold a promise calibrated around 2030s or 2040s technology at a price point that has not yet been demonstrated anywhere. The optimistic view is that the first-of-a-kind cost and schedule problem is a real but solvable engineering and manufacturing challenge — and that the countries getting their regulatory frameworks, workforces, and financing structures ready now will be first in line when the technology matures. Both views can be correct simultaneously.

What should a developing country’s energy minister actually do with this tension? Probably something like what Kenya is doing: explore multiple partners, invest in human capital and regulatory capacity, commission feasibility studies, and make no irreversible commitments until at least one design with comparable grid needs has been built somewhere and operated reliably for a few years.

The geopolitical layer that makes this more complicated

Here is a dimension of the small-nations-and-SMRs story that rarely gets the attention it deserves: this is not just an energy question. It is a geopolitical contest being played out through reactor deals. 🌍

Russia’s Rosatom and China’s state nuclear enterprises are not building reactors in Africa and the Middle East purely for commercial reasons. Nuclear power plants create decades-long dependencies — on fuel supply, on maintenance expertise, on technical assistance, on regulatory frameworks modeled on the supplier’s approach. A country that builds its first reactor with Russian help tends to buy its second one from Russia too. The same logic applies to American, French, South Korean, and Chinese vendors. Every SMR agreement signed is also a statement about which bloc a country’s energy infrastructure will align with for the next half-century.

This explains why the U.S.-Africa Nuclear Energy Summit was held in Nairobi with the U.S. Department of Energy’s direct involvement when NuScale signed the Ghana deal. The ITIF’s 2025 analysis puts it plainly: SMR markets will be global, and the U.S. and its allies need to align their regulatory regimes specifically to counter competition from Chinese and Russian state-backed enterprises that can offer financing, construction, and operation as a single package.

For small nations navigating this, it creates leverage as well as risk. Multiple powers actively want to sell you a reactor. That is unusual. Historically, energy infrastructure in developing countries arrived largely on the terms of whoever was willing to finance it. The current competitive landscape — with the U.S., Russia, China, France, South Korea, and Canada all pushing reactor exports — means a country like Kenya or Indonesia can, in principle, shop around. They can demand better financing terms, more technology transfer, and more local content. Whether they have the institutional capacity to negotiate that effectively is a different question. But the leverage is real.

The countries getting in early are not being naive. They are placing considered bets on a technology that, if it matures as its proponents expect, will give them energy options that large plants never could. The bet may not pay off. The technology could stay expensive. The timelines could slip again. But if you are running a grid that adds a million new electricity users every year and you have exhausted the easy renewable sites, the calculus looks different from a ministry in Nairobi than it does from a think tank in Washington. So: is your country’s energy plan accounting for what happens if SMRs actually work at scale — or only for what happens if they don’t?

There’s a scene from 1981 that says everything about how far we’ve come. Singer-songwriter Jackson Browne gets arrested outside Diablo Canyon nuclear power plant in California, surrounded by protesters who are convinced that nuclear energy is the enemy of the natural world. Fast-forward four decades, and a new generation of activists is staging demonstrations at the very same plant — this time begging California not to shut it down.

That’s not irony. That’s arithmetic.

The shift among environmentalists toward nuclear energy is real, meaningful, and — for anyone paying attention to the carbon math — long overdue. It didn’t happen because the nuclear industry ran a clever ad campaign. It happened because the facts changed, or more precisely, because people started taking the full picture of those facts seriously. The question worth asking isn’t “why are some environmentalists changing their minds?” It’s “what took so long?”

The numbers that broke the old consensus

Start with the most basic question: how much carbon does nuclear actually emit? 🔬

The answer surprises most people. On a lifecycle basis, the IPCC puts the median figure for nuclear at about 12 grams of CO2 equivalent per kilowatt-hour — similar to wind and lower than all types of solar. That’s the full cradle-to-grave accounting: mining the uranium, building the plant, operating it for decades, and eventually tearing it down. A separate Yale-led study put the number even lower, at around 4 grams of CO2 equivalent per kWh, comparable to onshore wind.

Coal, for context, sits at roughly 820 grams per kWh. Natural gas is around 490. Nuclear is not just cleaner than fossil fuels — it is almost incomprehensibly cleaner, by two orders of magnitude.

The lifecycle emissions picture also explains why several prominent figures who built careers opposing nuclear have reversed course. Some of the most notable flippers include:

• James Lovelock, originator of the Gaia hypothesis, who argued nuclear was necessary to prevent climate catastrophe

• Patrick Moore, an early Greenpeace member, who said in a 2008 interview that he had been “incorrect in my analysis of nuclear as being some kind of evil plot”

• Stewart Brand, creator of the Whole Earth Catalog, once a bible of the environmental movement

• George Monbiot, the Guardian columnist, who shifted his position after running the numbers on land use and reliability

• Stephen Tindale, former executive director of Greenpeace UK, who became a vocal nuclear advocate

These aren’t fringe defectors. These are the people who built the modern environmental movement. When they change their minds, it’s worth asking why.

The land problem nobody talks about

Here’s the uncomfortable truth that solar and wind boosters rarely want to discuss up front: clean energy is not the same as invisible energy. Every watt of power requires physical space. 🌍

And nuclear wins this comparison so decisively it borders on embarrassing. A nuclear facility requires about 1.3 square miles per 1,000 megawatts of generating capacity. To generate the same electricity, a wind farm would need over 140,000 acres — more than 170 times the land area. According to the UN Economic Commission for Europe, nuclear is the most land-efficient source of electricity by a significant margin, requiring about 18 to 27 times less land than solar PV per unit of electricity generated.

This isn’t an abstract concern. Consider what a 100% renewable grid actually looks like on a map:

• Princeton University’s “Net-Zero America” project modeled the most land-intensive scenario, which eliminated all nuclear plants

• The result: the U.S. energy footprint would roughly quadruple in size

• Wind farms would need to cover an area equivalent to Arkansas, Iowa, Kansas, Missouri, Nebraska, and Oklahoma combined

• Transmission lines would need to more than triple — through forests, wetlands, and rural communities

An environmentalist who cares about habitat preservation, biodiversity, and the integrity of wild spaces has legitimate reasons to find those numbers alarming. Nuclear doesn’t just emit less carbon than renewables — it consumes far less of the planet doing it. 🌱 Barry Brook, Professor of Environmental Sustainability at the University of Tasmania, co-authored an open letter signed by 66 leading conservation scientists from 14 countries arguing the same point: that the environmental community’s anti-nuclear position was never based on objective land-use or biodiversity analysis.

Have you ever actually run the numbers on how much space your favorite clean energy source requires? If not, Our World in Data’s breakdown of land use per energy source is a genuinely eye-opening read.

The grid problem changed everything ⚡

Carbon emissions and land use are important. But there’s a third factor that quietly did more than any study to move environmentalists toward nuclear: the grid itself started failing.

In California, the moment of truth came in 2020, when residents endured a series of rolling power outages. “The state is constantly on the verge of blackouts,” said Michael Shellenberger, an environmentalist and author who supports nuclear. California had spent decades closing nuclear plants and betting on renewables. The bet didn’t hold when the sun went down or the wind died.

This is the capacity factor problem, and it matters enormously. Nuclear runs at roughly 90% capacity, meaning it delivers nearly full output around the clock, every day, through heat waves, winter storms, and cloudy weeks. Wind averages around 35%. Solar around 25%. That gap is real, and filling it without nuclear requires either:

• Enormous battery storage infrastructure (expensive, materials-intensive, not yet built at scale)

• Natural gas backup plants (which emit carbon and undermine the whole project)

• Continental-scale transmission upgrades (politically and financially brutal)

• Or simply accepting that the lights occasionally go out

Nuclear solves the baseload problem cleanly. It produces firm, dispatchable, zero-carbon power — exactly what an increasingly renewable grid needs to stay stable. Judi Greenwald, executive director of the Nuclear Innovation Alliance, makes this point plainly: advanced nuclear technologies can serve hard-to-decarbonize sectors like heavy manufacturing and produce zero-carbon hydrogen. Wind and solar can’t.

The opinion data is clearer than you’d think 📈

Conventional wisdom says the public is divided on nuclear, and that environmentalists are the most hostile bloc. The data says something entirely different.

Research from the Potential Energy Coalition, based on surveys across the U.S., Europe, and Asia, found a striking result: fewer than 15% of people identify as “anti-nuclear” — a small segment that is older, skeptical of innovation, and almost impossible to persuade. The remaining 85% either supports or is willing to support advanced nuclear, and gets more supportive the more they learn.

More striking still: people who self-identify as environmentalists showed support for advanced nuclear that was 5 percentage points higher than self-identified non-environmentalists. And across the U.S., support for advanced nuclear is about 60% or higher across Democrats, Republicans, and Independents alike.

That’s not a country divided on nuclear. That’s a country that already moved on — while the political debate was still stuck arguing about the 1970s.

The ADVANCE Act of 2024, which streamlined nuclear licensing in the United States, was described by energy developer Ryan Pickering as “one of the most bipartisan bills in recent U.S. history.” Elizabeth Warren, who had previously vowed not to support new nuclear development, voted for it. The politics followed the public, which followed the data.

If you’re an environmentalist, ask yourself honestly: when did you last update your nuclear position based on new information, rather than old associations?

What “ecomodernism” actually means 🔬

There’s a name for the movement that’s emerged from this intellectual shift. Environmentalists who now support nuclear often call themselves Ecomodernists — people who believe that human ingenuity and technology, including nuclear energy, can solve environmental problems rather than cause them. The Ecomodernist Manifesto, signed by scientists, ecologists, and engineers, argues that dense, reliable, low-footprint energy sources allow humanity to use less of the planet, not more.

The framing matters. The old environmental paradigm treated energy consumption as inherently destructive — something to be reduced, rationed, and felt guilty about. Ecomodernism treats it as something to be made clean and abundant, because abundant clean energy is what allows the developing world to lift people out of poverty without burning coal.

That’s a genuine philosophical shift, and it’s still contested inside the environmental movement. Groups like the Sierra Club continue to oppose nuclear, partly for substantive reasons and partly, as critics note, because changing position risks dividing their donor base. Opposition to nuclear power in some quarters has become as much a tribal identity as a policy position.

But the arguments on the other side are getting louder and better-evidenced. The carbon math is clear. The land math is clear. The reliability data is clear. What was once a fringe view inside the environmental movement — that nuclear deserves a serious place at the clean energy table — now reads, in 2026, a lot like mainstream sense.

The real question isn’t whether some environmentalists have flipped. It’s whether the institutions that still resist nuclear can explain, with specific numbers and honest comparisons, why they haven’t.

Here is a number worth sitting with for a moment: 10 to 15 years. That is the gap analysts at the Information Technology and Innovation Foundation estimate separates China from the United States when it comes to deploying fourth-generation nuclear reactors at commercial scale. Not designing them, not licensing them — actually building and operating them. If you work in the SMR space, that number should feel bracing, because it is not a projection. It is, increasingly, a description of reality.

By the first half of 2026, China is expected to bring online the Linglong One — also known as the ACP100 — making it the world’s first commercial land-based small modular reactor. 🌏 Meanwhile, America’s most prominent SMR project, NuScale’s UAMPS plant in Idaho, was cancelled in 2023 before a single shovel of dirt was moved. The contrast is not subtle. It is a floodlight pointed directly at a structural problem in Western nuclear development.

This article is not about dunking on the West for sport. It is about understanding, honestly, what China has actually built, how they built it so fast, and what the lead means — or doesn’t mean — for the global SMR race going forward.

What China has already put on the grid

Before the Linglong One even starts up, China can already claim something no other country can: two distinct SMR-class reactor technologies in commercial operation.

The first is the HTR-PM — the High Temperature Gas-Cooled Reactor Pebble-bed Module — at the Shidaowan site in Shandong province. This is a Generation IV design, and it has been commercially operational since December 2023. Two 250 MWt helium-cooled reactors drive a single 210 MWe steam turbine, and the fuel is famously peculiar: more than 400,000 graphite-coated “pebbles” the size of tennis balls, each containing roughly 7 grams of enriched uranium. 🔬

What makes the HTR-PM genuinely remarkable is not just its operation — it’s what it proved. In tests published in the journal Joule in 2024, Tsinghua University researchers shut off external power entirely when the plant was running at full capacity and tracked what happened. The answer: the reactor cooled itself down over two days without any human intervention and without emergency cooling systems. That is inherent safety at commercial scale, demonstrated for the first time in history. Not simulated. Not modeled. Done.

Key facts about the HTR-PM worth knowing:

• Two reactor modules, each 250 MWt, driving one shared turbine

• Helium coolant, graphite moderator — no water in the primary circuit

• TRISO fuel pebbles retain radioactivity even at temperatures up to 1,620°C

• Entered commercial operation December 2023, the first Gen IV plant in the world to do so

• An upgraded version, the HTR-PM600, is planned with six modules and a 650 MWe turbine

Does it face challenges? Absolutely. The specialized fuel supply chain is still thin, and the economics of helium-cooled systems are not trivial. But the physics has been validated at scale. That matters.

Linglong One: the SMR the whole world is watching 🏗️

The second entry is the one getting most of the international attention. The Linglong One — developed by the China National Nuclear Corporation (CNNC) over more than a decade of independent research — is a 125 MWe integrated pressurized water reactor under construction at the Changjiang Nuclear Power Base on Hainan Island.

First concrete was poured on July 13, 2021. The outer containment dome was hoisted into place in February 2025. Cold functional tests — the critical pre-fuel-loading verification that all primary circuit components are sealed and performing correctly — were completed on October 16, 2025. A non-nuclear turbine run test was completed on December 23, 2025. Commercial operation is now targeted for the first half of 2026.

That is a 58-month construction timeline from first concrete to commercial operation. No Western SMR project has come close to that execution speed — many haven’t broken ground at all.

The Linglong One’s stats, in plain terms:

• 125 MWe electrical output per unit

• Can generate 1 billion kWh annually, enough for roughly 526,000 households

• Designed for cogeneration: electricity, district heating, steam supply, and seawater desalination 💧

• 60-year operational life, with a two-year refueling cycle

• Reduces CO₂ emissions by approximately 880,000 tonnes per year

• The first SMR in the world to pass an IAEA general safety review, back in 2016

One detail that deserves more attention than it typically gets: CNNC has stated that the Linglong One relies on a fully domestic industrial supply chain, with no significant dependence on foreign suppliers. That is a degree of manufacturing independence that most Western SMR developers can only aspire to, given how fragmented nuclear supply chains outside of China have become.

Does 2026 seem ambitious? The original target was end of 2025, and it slipped by about six months. But the tests have been completed on sequence, and the Nuclear Energy Agency’s SMR Dashboard now lists the project as “under construction, commissioning 2026.” At this point, the project execution risk is substantially reduced. What’s left is largely operational, not structural.

What do you think — does a six-month slip on the world’s first commercial SMR concern you, or is that basically on-time by nuclear standards? Drop a comment below. 👇

How China built this machine: the structural advantages

It would be tempting to write China’s lead off as purely a product of authoritarian speed — just decree things and they happen. The reality is considerably more nuanced, and understanding it matters if you want to know whether the lead is replicable.

According to analysis from the Breakthrough Institute, China’s nuclear success rests on three structural pillars:

• Industrial supply chain depth. China has built 30+ nuclear plants since 2000, creating a mature, high-volume domestic supply base for reactor components. The workforce knows what it’s doing. Parts arrive on time because the factories making them have been optimized over dozens of builds.

• Top-down policy commitment. Every nuclear plant in China is included in the “national strategy” before it ever enters the licensing pipeline. There is no equivalent of the U.S. system where a private developer must obtain NRC approval before any serious planning can happen, then wait for state utility commissions to act before construction begins.

• Learning-by-doing at scale. China intentionally builds multiple units of the same design in sequence, improving each time. The Hualong One (HPR-1000) has been refined over ten domestic builds. That kind of iterative improvement compresses costs and timelines in ways that one-off projects structurally cannot.

Some of these advantages are not exportable. Direct public financing of reactors and low construction labor costs are features of China’s political economy, not adjustable policy levers for democracies. But others — predictable licensing pathways, co-ordination between regulators and developers, and a serious commitment to modular construction practices — are learnable. The Breakthrough Institute’s Seaver Wang has argued China’s licensing process, while faster partly because it is state-directed, also benefits from formal structures that reduce ambiguity for developers in ways that could be adapted elsewhere.

The U.S. currently has 35 GWe of nuclear capacity under construction in China — more than the rest of the world combined — while America’s Vogtle Units 3 and 4 became cautionary tales of cost overruns and multi-year delays. That divergence is not a natural law. It is the product of decades of different choices.

The export question: who does China sell to next? 🌍

Here is where the stakes get genuinely geopolitical. China is not just building SMRs for its own grid. CNNC is actively marketing the ACP100 internationally, with reported discussions involving Indonesia, Thailand, Malaysia, and Saudi Arabia under the Belt and Road Initiative framework.

Why does this matter beyond nuclear energy? Because whoever sells a country its first reactor also sells it fuel, maintenance contracts, engineering training, regulatory expertise, and in some cases, the safety culture that shapes a nation’s nuclear industry for generations. A nuclear export is not a one-time sale. It is a 40-to-60-year relationship. ⚡

The West understands this calculus, which is why the U.S.-UK Atlantic Partnership for Advanced Nuclear Energy, signed in September 2025, includes commitments to coordinate safety assessments and accelerate SMR deployment, partly as a response to Chinese and Russian export momentum. The UK announced a £2.5 billion package to speed SMR deployment targeting the mid-2030s. The Trump administration unveiled an executive order in May 2025 targeting 400 GW of nuclear capacity by 2050, with SMRs at the center.

These are real commitments. But there is a timeline problem:

• Rolls-Royce SMR: targeting mid-2030s for first UK deployment

• GE-Hitachi BWRX-300: 2030 target for first unit in Canada

• X-energy Xe-100: demonstration in Texas, still years from commercial operation

• NuScale: design certified, but the only major customer withdrew; no construction underway

By the time any of these projects reach commercial operation, the Linglong One will have been running for nearly a decade. China will have accumulated operational data, iterated on costs, and locked in relationships with early adopter nations. That is a compounding advantage, not a static one.

What would genuinely close this gap? Not just money and executive orders — those help — but a serious industrial commitment to building the supply chains, training the workforce, and accepting that some degree of modular standardization requires choosing a design and sticking with it, rather than supporting 20 competing concepts simultaneously.

The honest limitations in China’s lead 🔬

Fairness demands acknowledging what China’s program is not.

The Linglong One, at 125 MWe, is a demonstration project, not yet a production line. The economics of subsequent units — the all-important “Nth-of-a-kind” cost — remain to be seen at scale. CNNC has spoken about modular manufacturing and assembly-line production, and the construction methodology genuinely supports this vision, but it hasn’t been proven across multiple units yet.

The HTR-PM, while operationally impressive, has faced questions about capacity factor performance and the economics of its specialized fuel. Helium-cooled systems are excellent physics; they are harder supply chains.

There is also the data transparency question. China’s nuclear program operates under state ownership and with limited independent external audit. Performance data from the HTR-PM, for example, is reported by operators with commercial and geopolitical interests in positive framing. That is not a reason to dismiss the achievements — the IAEA reviews and the published Joule research carry real credibility — but it is a reason to read China’s own press releases with appropriate skepticism.

And internationally, the financing structures China offers through the Belt and Road — low-interest loans, turnkey construction — come with geopolitical strings that some nations are increasingly wary of. Sri Lanka’s experience with Chinese infrastructure debt has not been forgotten in Southeast Asia. Whether that hesitancy shapes SMR purchasing decisions remains an open question.

The SMR market, according to research published in 2025, was valued at $159.4 million in 2024 and is projected to reach $5.17 billion by 2035 at a compound annual growth rate of 42.31%. That is a market where first-mover credibility matters enormously. China has it right now. Whether it holds it depends partly on whether the Linglong One performs as designed, and partly on whether Western programs can compress their timelines before the export landscape solidifies.

So here is the question worth sitting with: if China’s Linglong One performs flawlessly through 2026 and 2027, and CNNC signs its first export deal by 2028, what exactly is the Western response — and is anyone preparing it seriously enough? That answer will determine whether the 10-to-15-year gap closes, widens, or simply becomes the permanent shape of the global nuclear order.

Nuclear energy has a cost problem that no amount of enthusiasm from Goldman Sachs, Microsoft, or the UK government seems to solve. Pick almost any SMR project from the last decade, follow it for a few years, and watch the budget estimates balloon. It’s almost hypnotic, in a horrifying sort of way. The NuScale flagship project in Idaho went from $5.3 billion to $9.3 billion before collapsing entirely. Argentina’s CAREM reactor has racked up cost overruns of around 700% since construction began in 2013. Russia’s floating reactor, the Akademik Lomonosov, blew its budget by roughly 400%. China’s pebble-bed HTR-PM came in at about 300% over.

These aren’t outliers. They’re the entire dataset.

For an industry promising a cheaper, faster, more manageable alternative to the nuclear megaprojects of the 20th century, this is a genuinely uncomfortable place to be. So why does it keep happening? And — more interestingly — what, if anything, is actually starting to change?

The structural reasons cost overruns happen

Start with something called the iron law of megaprojects. According to research cited in a techno-economic analysis published in Applied Energy, nine out of ten large infrastructure projects go over budget, with cost overruns exceeding 50% not being uncommon. SMRs were supposed to sidestep this trap through their smaller, more manageable scale. That theory makes intuitive sense. What it missed is that being small doesn’t automatically make you simple. 🏗️

The structural cost drivers are stubborn:

• Regulatory complexity: Each reactor design needs its own licensing process, and in the US that process can eat years and hundreds of millions of dollars before a shovel enters the ground. NuScale spent roughly $1.8 billion just getting to the point of design certification — with unresolved safety questions still on the table.

• Supply chain immaturity: You can’t order SMR components the way Boeing orders aircraft parts. The supply chain is thin, bespoke, and expensive. Commodity price swings — steel, concrete, specialized equipment — hit nuclear projects harder than almost any other construction type.

• Workforce gaps: Skilled nuclear construction workers are rare, expensive, and don’t scale quickly. Every first-of-a-kind project trains its workforce essentially from scratch. 👷

• Design churn: Many projects have changed their reactor designs mid-development, which resets timelines and explodes budgets. NuScale’s original 50-megawatt design was upsized to 77 megawatts when the economics of the smaller unit failed to hold up.

• Financing costs: Nuclear projects tie up capital for a decade or more before generating a single watt of electricity. Every year of delay is a year of interest payments on top of construction costs.

According to IEEFA’s May 2024 report, the pattern isn’t improving. The data from the few SMRs that have actually been built shows cost outcomes that look uncomfortably like large-reactor failures, just at a smaller scale.

The FOAK trap — and why it’s real

There’s a concept the nuclear industry uses to explain away first-project failures: FOAK, or First-Of-A-Kind. The argument goes that first plants are always expensive; the savings kick in once you’re building the 5th, 10th, or 20th unit — what engineers call NOAK (Nth-Of-A-Kind). This argument isn’t wrong exactly. But it’s being used to wave away a genuine problem. 🔬

According to the International Energy Agency’s 2025 projections, SMR overnight costs in the EU run around $10,000 per kilowatt, versus $6,600 per kilowatt for conventional nuclear. Research on FOAK-to-NOAK transitions suggests cost reductions of 20–30% are realistic with manufacturing learning curves and supply chain optimization — but only if:

• Designs are standardized across many builds

• Production volumes reach at least 30 to 50 units of the same reactor type

• Supply chains are built and coordinated in advance

• Regulatory processes are streamlined and consistent

Lars Thurmann-Moe of Arthur D. Little, speaking to NucNet in July 2025, put it plainly: “We need a single or small group of standardised designs to reach production volumes of at least 30 to 50 units to fully benefit from economies of scale.” That’s the catch. Right now, the IAEA counts over 80 different SMR designs in various stages of development globally. Eighty designs. For a market that hasn’t yet proven demand for one. The FOAK learning curve only works if you actually build enough reactors of the same design to move past FOAK. With this many competing designs splitting a limited pool of customers, that’s genuinely hard to achieve.

Do you think the proliferation of competing SMR designs helps or hurts the industry’s case for government support? It’s worth thinking through.

The financing trap — where the budget pressure actually lives

Here’s the part that doesn’t get enough attention: the overnight construction cost is only part of the story. Nuclear projects are unique in how brutally they’re punished by financing costs. A project that takes 15 years to complete pays interest on borrowed capital for 15 years. A project that takes 5 years pays for 5. The math is unforgiving. 💰

This is where SMRs have a genuinely real advantage — in theory. Consider the comparison laid out in a June 2025 GLOBSEC analysis: even with a higher overnight cost of $10,000/kW versus $6,600/kW for a conventional plant, an SMR completing in 5 years has a lower all-in cost than a conventional reactor taking 15 years, assuming a 5% financing rate. The numbers work out to roughly $12,763/kW for the SMR versus $13,721/kW for the conventional plant.

But — and this is a very significant but — the same analysis shows that extending the SMR construction timeline by just two years, from 5 to 7 years, is enough to wipe out that advantage entirely. This is why schedule overruns are so damaging. It’s not just the extra construction cost. It’s the compounding interest on every month of delay.

The financing trap has a few distinct components:

• Private capital is scarce: Unlike bridges or pipelines, SMRs don’t generate revenue until fully operational, creating a decade-long cash-negative phase that most private investors won’t accept.

• Cost-of-capital premium: Nuclear projects attract higher discount rates because of their risk profile, making the effective cost of every dollar borrowed even higher.

• Government subsidy dependence: NuScale’s $89/MWh target price would have been significantly higher without $4 billion in federal subsidies, including a $1.4 billion Department of Energy contribution and a $30/MWh Inflation Reduction Act benefit. Strip those out and the economics collapse.

What’s actually changing — and why it’s not nothing

Enough bad news. Something is shifting, even if it’s slower than the press releases suggest. ⚡

The most credible change is the movement toward genuine factory-based manufacturing. GE Hitachi’s BWRX-300, which received construction approval at Ontario Power Generation’s Darlington site in April 2025, is designed with roughly 90% of its components manufactured in factory conditions, with on-site work limited to assembly. BWXT has already been contracted to manufacture the reactor pressure vessel — an early signal that the supply chain is starting to get real. GE Hitachi’s stated price target, if fleet production is achieved, is around $5,000 per kilowatt for the BWRX-300. That would represent a meaningful shift.

Rolls-Royce SMR, selected by the UK government through Great British Energy in June 2025 for domestic deployment, is targeting an LCOE below £70/MWh. The 470-megawatt pressurized water reactor design has a strong factory-manufacturing case, with the UK’s existing engineering base potentially giving it a genuine industrial advantage.

Regulatory reform is also moving, slowly:

• The US Nuclear Regulatory Commission has been under pressure to streamline its licensing processes for advanced reactor designs

• Canada’s CNSC gave formal safety approval for the Darlington BWRX-300 site in April 2025

• The IAEA and OECD-NEA have been pushing for international regulatory harmonization, which would let a reactor certified in one country leverage that work in another

The Darlington project in Ontario is perhaps the most important near-term data point for the whole industry. Its first reactor, projected to cost CAN$6.1 billion (roughly US$4.4 billion), is scheduled for completion in 2030. If it comes in on time and on budget, it will be the first piece of real evidence that factory manufacturing and regulatory improvements can actually deliver what the models predict. If it doesn’t, the skeptics — and there are plenty of them — will have fresh ammunition. 🌱

The honest reckoning

The SMR industry is not facing a public relations problem. It’s facing an engineering and economics problem that no amount of enthusiasm from tech billionaires or government ministers makes easier. The cost overrun pattern is real, it’s documented, and it reflects structural challenges that take years — not quarters — to fix.

But writing off the entire technology because the first few attempts went badly is probably too hasty. Every energy technology goes through a painful first-mover phase. Solar and wind were expensive and unreliable for decades before learning curves and manufacturing scale made them competitive. The difference is that solar and wind didn’t require a decade-long regulatory process for each new installation.

The question the SMR industry has to answer honestly — not in investor decks, but in actual delivered projects — is whether factory manufacturing and standardization can do what advocates have promised for years. Darlington will tell us something. So will Rolls-Royce’s first UK unit, if it gets built. So will whatever comes next in the US, where TVA is expected to apply for a BWRX-300 license.

Watch the actual construction timelines. Watch whether the Darlington FOAK comes in at CAN$6.1 billion or blows past it. That number will tell you more about the future of SMRs than any projection ever will.

The standard pitch for small modular reactors goes something like this: they’re clean, they’re compact, they’re reliable, and they might finally make nuclear energy affordable at scale. That pitch is compelling enough on its own. But it undersells the real story by quite a bit.

The truly interesting thing about SMRs is not that they can replace a coal plant or juice up a grid. It’s that they unlock energy solutions for industries that have been essentially stuck — industries where fossil fuels are deeply embedded not just as fuel, but as part of the production process itself. According to a study by consultancy LucidCatalyst for uranium enrichment company Urenco, SMRs could support the decarbonization of at least 11 industrial sectors, representing a potential market of 700 gigawatts by 2050 and a $0.5 to $1.5 trillion investment opportunity. That is not a niche play. That is a restructuring of how the global economy runs on energy.

Here are six industries where SMRs could cause the most dramatic shifts, and why each one is worth watching closely.

1. Data centers and artificial intelligence 💡

This is the one everybody is already talking about, but the scale of what’s actually happening deserves more attention than it gets. AI workloads do not just need a lot of electricity. They need electricity that is always on, always at the same voltage, and contractually guaranteed for decades. That is not a description of the current grid in most places. It is, however, a perfect description of what a nuclear plant delivers.

Microsoft and Constellation Energy committed $1.6 billion to restart the Three Mile Island Unit 1 plant, now rebranded as the Crane Clean Energy Center, with power targeted for 2028. Amazon signed a large agreement for carbon-free supply from Talen Energy’s Susquehanna nuclear station in Pennsylvania to feed its data center campus there. Google and Amazon have also backed X-Energy’s Xe-100 SMR project with Energy Northwest in Washington state, expandable to 960 megawatts by 2039.

Why SMRs specifically, rather than just plugging into the grid or existing large plants?

• SMRs can be built on-site or co-located with a data center campus, cutting transmission losses and grid dependency

• Their modular nature means capacity can scale in stages as the data center grows

• No combustion byproducts means no carbon accounting headaches

• Factory fabrication offers more predictable construction timelines than custom large-reactor builds

The American Society of Civil Engineers notes that data centers are growing faster than the grid can expand in many regions, creating multi-gigawatt power needs that utilities simply cannot meet on current timelines. OpenAI has suggested it may eventually need 20 gigawatts of power for its operations. No combination of solar panels and battery packs is answering that call at the reliability level AI infrastructure requires. 🔬

Do you think Big Tech’s nuclear spending spree is the most important thing driving SMR commercialization right now? The money certainly seems to think so.

2. Steel and heavy manufacturing ⚡

Steel is one of the most carbon-intensive materials on earth. The traditional blast furnace process uses coking coal not just as a fuel but as a chemical reagent, feeding carbon into the reaction that turns iron ore into iron. Decarbonizing that is genuinely hard. Renewable electricity alone does not fix it.

This is where high-temperature gas-cooled SMRs enter the picture. Reactors of this type can generate heat at temperatures high enough to drive the industrial processes that steel and heavy manufacturing need, not just spin a turbine. The Information Technology and Innovation Foundation’s April 2025 report on SMR economics identifies industrial process heat as one of the most substantial market opportunities for advanced reactor designs, particularly gas-cooled fast reactors and molten salt reactors, which operate at high enough temperatures to be useful across chemicals, petroleum refining, and steelmaking.

The Urenco/LucidCatalyst study pegs iron and steel alone at 33 GW of SMR deployment potential by 2050. That number is probably conservative, given how few realistic alternatives exist for direct-heat industrial decarbonization at scale. The steel industry has been waiting for a credible answer to its carbon problem for a long time. SMRs may be that answer.

Key reasons the steel and manufacturing sector is watching SMRs:

• Process heat above 700°C is achievable with advanced high-temperature gas reactor designs

• Nuclear-generated hydrogen (more on that next) can replace coking coal as a chemical reductant in steelmaking

• Long plant lifespans, potentially 80 years, mean a capital investment that amortizes over an industrial planning horizon that actually makes sense

• Co-location with industrial clusters avoids expensive transmission infrastructure

3. Clean hydrogen production 🌱

Hydrogen is the molecule that climate policy keeps promising will solve everything. The problem is that 95 percent of hydrogen today is produced using natural gas, a process that emits substantial carbon dioxide. “Green hydrogen,” made by splitting water using renewable electricity, is clean but expensive and intermittent by nature.

SMR-powered hydrogen changes that equation in two ways. First, nuclear electricity is available 24 hours a day, 7 days a week, which means the electrolyzers making hydrogen can run continuously, not just when the sun is up or the wind is blowing. Continuous operation is critical to the economics: an electrolyzer sitting idle half the time is a very expensive piece of equipment.

Second, some SMR designs can directly use their heat, rather than first converting it to electricity, to drive thermochemical hydrogen production. NuScale, working with researchers at the Department of Energy’s Pacific Northwest National Laboratory, is developing a hydro-thermal chemical decomposition approach that does not require electrolysis at all, reducing both energy and water consumption. The research was presented at the World Petrochemical Conference in March 2025. ♻️

SMR-generated hydrogen has real advantages over alternatives:

• Hydrogen electrolysis powered by SMRs may reduce green hydrogen costs by up to 40% compared to renewable-powered production, according to analysis from Strategy International

• Baseload reactor operation means no wasted electrolyzer capacity on idle nights or calm days

• High-temperature designs can pursue thermochemical production routes that are fundamentally more efficient than electrolysis

• The same plant can switch between hydrogen production and grid supply based on market prices, acting as a flexible economic hedge

Major corporations including ExxonMobil, Shell, and Mitsubishi are actively exploring SMRs as an alternative to power refineries and industrial processes, according to Strategy International. That is not the behavior of companies that think this is a fringe idea.

4. Water desalination 💧

Fresh water scarcity is one of the most serious resource problems the world faces and one that is getting worse, not better, as populations grow and aquifers deplete. Desalination is an obvious partial solution. It is also extremely energy-intensive, which is why most desalination plants today run on fossil fuels, which makes the water clean but the carbon footprint ugly.

A single NuScale Power Module coupled to a state-of-the-art reverse osmosis desalination system could produce approximately 150 million gallons of clean water per day without emitting any carbon dioxide. A 12-module plant could supply desalinated water for a city of 2.3 million residents, with surplus power left over to supply 400,000 homes with electricity. NuScale notes that when coupled to a desalination plant, a single module can provide all the water needed for a city the size of Cape Town, South Africa.

The ITIF report points out something clever about the economics here: an SMR paired with a desalination plant has a natural buffer against grid price fluctuations. When electricity prices are high, power flows to the grid. When they’re low, it flows to the desalination plant instead. The desalination plant becomes, in effect, an economic battery, storing excess energy as fresh water. That is an elegantly useful design for the water-stressed, hot, and sun-exposed countries in the Middle East, North Africa, and South Asia where both problems hit hardest.

Countries watching this space include:

• Saudi Arabia, the UAE, and Egypt, all exploring SMRs for energy security and nuclear-powered desalination

• Texas, where a consortium is exploring nuclear for desalination at the Texas Tech SMR cluster

• Multiple small island nations where grid size makes large reactors impractical but water stress is severe

🌍 The combination of clean water and clean power from a single compact plant is a different kind of pitch than anything fossil fuels or renewables can currently make in these regions.

5. Chemical refining and petrochemicals 🔬

This one might seem counterintuitive. Aren’t petrochemicals the problem? Not entirely. The chemical industry produces materials that society genuinely needs, from plastics to fertilizers to pharmaceuticals, and much of the carbon it emits comes from the energy used in production, not the products themselves. Swap out that energy source and the emissions profile changes dramatically.

Refineries are particularly interesting targets. A six-module NuScale plant, according to NuScale’s own technical data, coupled to a 230,000 barrels-per-day refinery, can eliminate approximately 40% of overall plant emissions, equivalent to a reduction of 175 metric tons of CO2 per hour. That is a meaningful number for an industry that is not going to stop operating just because we want it to be greener.

Beyond refining, pulp and paper production, chemical manufacturing, and synthetic fuel production all require sustained high-temperature process heat that SMRs may eventually supply. The ITIF report identifies gas-cooled fast reactors and molten salt reactors as the designs most likely to reach the temperatures needed for chemical sector applications. Both are still in development, but both have active programs behind them with real capital.

The industries that stand to benefit in this space share some characteristics:

• They require continuous, not intermittent, energy supply

• Their production processes use heat directly, not just electricity

• They have large enough energy budgets that a nuclear investment pencils out

• They face genuine decarbonization pressure with no obvious renewable alternative

What SMRs offer these industries is not disruption in the Silicon Valley sense. It’s a replacement of one energy supply with a cleaner one, while keeping the production process largely intact. That is an easier sell to an incumbent industry than “rebuild your entire supply chain.”

6. Remote communities and defense installations 🚀

This last sector is different in character from the others, and I think it gets underestimated even by people who follow nuclear closely. The problem of energy access in remote locations is not just a developing-world story. It affects military bases, mining operations, Arctic research stations, island communities, and large industrial sites located far from transmission infrastructure.

The World Nuclear Association notes that SMRs can be deployed on grids too small to accommodate large reactors, and that some designs promise smaller emergency planning zones, allowing deployment near smaller communities. The U.S. Army built eight nuclear reactors about five decades ago, five of them portable or mobile. One, the PM-1, successfully powered a remote air and missile defense radar station on a mountain top in Wyoming for six years. That precedent matters.

Today, the Department of Energy has selected Radiant Industries for its pilot reactor program specifically targeting portable nuclear units for military and remote applications. Alaska’s Eielson Air Force Base plans to build a microreactor as early as 2027. The case for remote and defense applications is different from the case for data centers or steelmaking:

• Energy independence is a military and national security priority, not just an environmental one

• Remote communities often pay extremely high prices for diesel-generated electricity, making nuclear competitive even at higher capital costs

• Microreactors smaller than 20 MW can fit on a semi-truck and be transported to almost any location

• The 14-year refueling cycles on some designs mean deployment in genuinely inaccessible places becomes possible

The Stanford Understand Energy learning hub reports that the Nuclear Energy Agency is currently tracking $15.4 billion in financing toward SMRs globally, with private capital playing an increasingly prominent role. When private investors put that kind of money in, they’re not betting on one application. They’re betting on a platform.

The question worth sitting with now: which of these six sectors do you think will be the first to have an operating SMR on-site at a commercial facility? The timelines are closer than most people expect — and the answer will say a lot about which industry was serious enough about its energy problem to actually solve it.

Nuclear energy has spent the better part of fifty years as a political football, kicked around by people who understood it poorly and feared it deeply. Politicians on the left treated it like a four-letter word. Politicians on the right ignored it in favor of whatever fossil fuel was polling best in their district. And the result? The United States, the country that invented commercial nuclear power, now generates barely 18 percent of its electricity from it, while fossil fuels remain dominant at roughly 60 percent. That is not a policy outcome. That is a slow-motion accident.

The good news — and there really is some, which is not something you say lightly about energy policy — is that the political picture is changing faster than almost anyone predicted. The question worth asking now is not just what went wrong, but whether the corrections happening today are serious or just good-looking theater.

The fear factory: how politicians learned to run against atoms

The political fear of nuclear energy did not materialize from nothing. It has roots in real events, real anxieties, and a genuinely complicated technology that is hard to explain at a campaign rally. But somewhere between legitimate caution and actual policy, something went badly wrong.

Three Mile Island is Exhibit A. The 1979 partial meltdown in Pennsylvania is, according to the Nuclear Regulatory Commission itself, the worst nuclear accident in American history. It killed zero people. It caused zero documented long-term health impacts in the surrounding population. What it did cause was a media firestorm, a wave of political panic, and — combined with the coincidental release of The China Syndrome just twelve days earlier — a cultural moment that politicians exploited for decades.

What followed was a regulatory response so extreme that it effectively strangled the industry. Adam Stein, director of the Nuclear Energy Innovation Program at the Breakthrough Institute, describes the aftermath bluntly: what was considered in the public interest became “just reducing risk to as low as possible,” producing “a huge volume of regulations that anybody who wanted to build a new reactor had to know.” The problem is that risk minimization at any cost is itself a risk. Every year nuclear plants weren’t built was another year coal plants kept running. Coal kills people. Routinely. At scale.

The political calculation, though, was straightforward and cynical:

• Nuclear is scary and invisible

• Accidents make front pages; clean daily operation does not

• Environmental groups were loudly opposed

• Fossil fuel donors were loudly generous

So politicians took the path of least resistance, and the country’s electricity grid paid the price.

The left’s complicated relationship with clean energy ☢️

Here is something that should embarrass progressive politicians when they look at the scoreboard: nuclear power is America’s largest source of clean electricity. Full stop. Not solar. Not wind. Nuclear. It runs at over 90 percent capacity factor, meaning U.S. nuclear plants operate at full power more than 90 percent of the time every year, far outpacing wind and solar, which are weather-dependent by definition.

And yet, for years, many Democratic politicians treated nuclear as a dirty word — sometimes literally bundling it rhetorically with coal and oil in speeches about “dirty energy.” Senator Elizabeth Warren (D-MA) previously vowed not to back the construction of new nuclear plants. California, the self-proclaimed climate leader, still has a nearly 50-year-old ban on new nuclear development, a policy that is difficult to square with the state’s stated climate ambitions.

Part of the blame belongs to environmental organizations that got this badly wrong. As energy developer Ryan Pickering told the Washington Examiner, some groups “have an interest in not dividing their donors” and kept anti-nuclear positions as a fundraising tool. That is what happens when ideology beats data.

The honest accounting looks like this:

• 54 percent of Americans incorrectly believe nuclear contributes to air pollution, according to the American Climate Perspectives Survey

• In reality, nuclear plants emit no greenhouse gases during operation

• Concerns about nuclear safety have been declining steadily since 2018

• 72 percent of Americans now favor nuclear energy, with those who strongly favor it outnumbering strong opponents by 5 to 1

The public got ahead of the politicians on this one. That is embarrassing for a class of people who claim to follow the science. 🔬

The right’s own blind spots 💡

Republicans did not cover themselves in glory either, just in different ways. The conservative political obsession with fossil fuels — driven heavily by donor relationships with oil, gas, and coal industries — meant nuclear was consistently undersupported even when it should have been a natural fit for a party that claims to love energy abundance and American technological dominance.

Trump’s first term paid lip service to nuclear but did relatively little structural reform. The regulatory regime governing the industry remained a labyrinthine holdover from the 1970s, designed around massive light-water reactors and completely unsuited to the new wave of small modular reactor designs that are now the actual future of the sector.

The political right also has a habit of using nuclear as a rhetorical cudgel — promising reactors for political effect without reckoning with what it actually takes to build them. Australia’s opposition leader Peter Dutton promised his first reactor by the mid-2030s if his coalition won power. New South Wales chief engineer Hugh Durrant-Whyte called the timeline “unrealistic”, noting that Australia would need “many decades” to develop the regulatory expertise, fuel supply chains, and workforce to operate a reactor. A politician promising nuclear plants like he’s promising a new highway is not nuclear policy. It is nuclear-flavored election strategy.

The pattern is consistent and frustrating:

• Promise big things about nuclear for political credit

• Do little to fix the regulatory and financing structures that actually block nuclear

• Move on when the news cycle does

• Leave the industry no further forward than before

What’s actually changing — and why it matters 🚀

Now for the part where things get genuinely interesting. Something has shifted in the political world, and it may actually stick this time.

The ADVANCE Act, signed by President Biden in July 2024, is the clearest evidence. The bill passed the Senate 88-2 and the House 393-13 — numbers that are practically science fiction in the current congressional climate. It reformed Nuclear Regulatory Commission licensing fees for advanced reactors, cutting them roughly in half. It created prizes for first-of-a-kind deployments. It streamlined environmental review. It opened the door to foreign investment in U.S. nuclear projects. It even directed the NRC to develop a licensing path specifically for microreactors.

The Harvard Law Review described it as legislation that “strikes a workable balance between maintaining trust in an independent regulator and addressing a clean energy shortage.” That is a measured take. The unfiltered version is that Congress, for one surprising moment, looked at the evidence and acted on it.

State-level politics are shifting too:

• Illinois Governor J.B. Pritzker lifted a long-standing ban on large-scale nuclear construction and plans to bring 2 gigawatts of nuclear power online

• New York Governor Kathy Hochul directed the New York Power Authority to add at least 1 gigawatt of new nuclear capacity

• Even California, the last major Democratic holdout, is at least keeping its existing plant open

Do you think the AI energy crunch is what it finally took to change political minds on nuclear? The timing is hard to ignore. 📈

SMRs: the technology that changes the political math

Part of why the political conversation is evolving is that the technology itself has evolved. Small modular reactors — nuclear plants under 300 megawatts, designed to be factory-built and modular — address almost every objection that politicians have historically used to avoid nuclear.

Too expensive to build? SMRs are designed for factory fabrication, which the Information Technology and Innovation Foundation argues should drive down costs as the technology scales. Too big for smaller grids or remote areas? SMRs can go where large reactors cannot — off-grid, close to industrial sites, on military bases. Too slow to build? The Chinese ACP100, one of the only commercially operating SMRs in the world, went from groundbreaking to grid connection in 58 months.

The Department of Energy has selected 11 companies to participate in a pilot program targeting criticality in at least three test reactors by July 4, 2026. Companies involved include Oklo, TerraPower, Westinghouse, and Kairos Power. Big Tech has jumped in too: Microsoft, Google, and Amazon have all committed to nuclear-backed power purchase agreements, partly because they need the reliable baseload power that intermittent renewables cannot guarantee.

What SMRs do for the political conversation is just as important as what they do for the grid:

• Smaller price tags make it easier to secure project financing without decades-long political debates

• Factory production means construction jobs spread across manufacturing states, not just the reactor site

• Modular deployment lets politicians promise a smaller, faster, more credible first step

• Advanced passive safety features in many designs make the Chernobyl comparison even weaker than it already was

Now here is the real question worth sitting with: if SMRs can deliver on even half their promise, which political party will claim credit for it — and which one will have earned it?

The accountability gap: promises vs. pipelines

Being honest about the progress means being honest about what is still broken. The Trump administration’s executive orders in early 2025 directed the NRC to speed up approvals and rewrite safety rules — goals that many nuclear advocates share, in principle. But ProPublica reported that the rollout has been messy, with NRC staff afraid to voice dissenting opinions, career officials leaving in waves, and lawyers withdrawing from licensing proceedings citing “limited resources.” That is not a nuclear renaissance. That is turbulence that could delay the projects it claims to accelerate.

The Vogtle nuclear plant in Georgia — the only new large reactors built in the U.S. in recent years — came online seven years late and $17 billion over budget against an original estimate of $14 billion. Katy Huff, who ran the DOE’s Office of Nuclear Energy under Biden, told WBUR that to meet net-zero goals by 2050, the country needs nuclear growth “rivaling the fastest rate we’ve ever produced new nuclear power plants.” That is a steep ask from a standing start.

What good nuclear policy actually requires, regardless of which party is delivering it:

• Stable, long-term regulatory frameworks that don’t change with each election

• Off-fee funding for the NRC so it’s not dependent on industry licensing fees

• Public investment in fuel supply chains, especially high-assay low-enriched uranium

• Honest timelines — not reactor promises designed to win a news cycle and forgotten by the next one

Nuclear energy is not automatically the answer to every grid problem. It is a serious tool that requires serious stewardship. The politicians who get that are starting to act like it. The ones who don’t are still performing. The difference matters enormously — and the next decade will sort them into two very clear groups.

What would it take for you to feel confident that your government is making genuinely smart nuclear policy, rather than just smart nuclear politics?

When someone tells you an SMR costs “too much” or a wind farm is “basically free,” they’re usually comparing the wrong numbers. They’re looking at construction costs in isolation, or reciting an LCOE figure they half-understood from a headline, and then acting like the case is closed. It isn’t. The economics of electricity generation are genuinely complicated — not complicated in the way that requires a PhD, but complicated in the way that requires you to slow down, define your terms, and stop treating a single number like scripture.

So let’s do this properly. No hand-waving. No advocacy dressed up as analysis. Just a clear look at what SMRs and wind farms actually cost, what that cost includes, and why the comparison matters a great deal more than either camp wants to admit.

What “cost” actually means here

Before any dollar figures, you need to know about LCOE — Levelized Cost of Energy. It’s the metric the whole industry uses, and for good reason. LCOE captures every cost a power plant incurs over its entire lifetime — construction, financing, fuel, operation, maintenance — and then divides all of that by every megawatt-hour of electricity that plant will ever produce. ⚡ The result is a single number in dollars per MWh: the average price at which the plant needs to sell electricity just to break even.

This is useful because it lets you compare genuinely different technologies on the same playing field. Without it, you’re comparing apples to turbines. But LCOE has real limits, too — and both sides of this debate weaponize those limits constantly. We’ll get to that.

The other number worth knowing is overnight capital cost, which is simply: how much would it cost to build this thing right now, if time had no value? It ignores financing and interest accumulation. Developers love to quote it. Critics love to ignore it. Reality lives somewhere in between.

What SMRs cost right now

Here’s the honest answer: we don’t really know, because very few SMRs have actually been built in the Western world. What we have instead are vendor projections, independent analyses, and a cautionary tale from Utah.

The most instructive recent data point is NuScale’s ill-fated Carbon Free Power Project in Idaho. When Utah Associated Municipal Power Systems (UAMPS) and NuScale first priced the project around 2016, they pegged the target electricity price at $55/MWh. By mid-2021, it had crept to $58/MWh after downsizing from 12 modules to six. By late 2022, after a more detailed cost estimate was completed, the IEEFA reported that the target price had jumped to $89/MWh in 2022 dollars — a 53% increase — and that was before accounting for inflation through to the projected 2030 operational date. Inflation-adjusted, IEEFA estimated ratepayers would actually pay around $102/MWh. UAMPS cancelled the project entirely in November 2023. 💸

Independent techno-economic research tells a similar story:

• A 2024 ScienceDirect analysis of three advanced SMR designs found LCOEs ranging from $80.6 to $89.6/MWh, with overnight capital costs of $3,985–$4,844 per kilowatt

• The IEA’s 2025 estimate puts SMR overnight costs in the EU at around $10,000/kW — significantly higher than the $6,600/kW for conventional large nuclear

• A European review found an average capital cost of €7,031/kW across multiple SMR designs, with capital costs averaging 41% higher than large reactors

The GLOBSEC think tank made a sharp point in a June 2025 analysis: even with SMR’s shorter build times (say, five years versus fifteen for a large conventional plant), the math on financing costs can still favor SMRs — but only barely, and only if construction stays on schedule. If timelines slip from five years to seven, the cost advantage evaporates. 🔬

What gives SMR advocates genuine cause for optimism is the FOAK-to-NOAK transition. First-of-a-kind reactors are expensive. They’re essentially prototypes at commercial scale. Arthur D. Little’s Lars Thurmann-Moe argued in mid-2025 that the real breakthrough will come with next-of-a-kind designs, but only after the industry reaches production volumes of at least 30 to 50 standardized units. That is a long way from where we are today.

Do you think governments should be subsidizing SMR development during this FOAK phase, or is that just throwing good money after uncertain technology? It’s a question worth sitting with.

What a wind farm costs right now

Wind is the established technology in this comparison, and the cost trends are far more settled — though perhaps not as settled as the wind industry would like to claim. 🌬️

Onshore wind is genuinely cheap. The U.S. Energy Information Administration’s Annual Energy Outlook 2025 puts the LCOE for new onshore wind at around $29.58/MWh with tax credits, and roughly $37/MWh without them. Lazard’s 2025 LCOE+ report confirms that unsubsidized renewables remain the most cost-competitive form of new generation. Arthur D. Little’s own LCOE data puts onshore wind at $36.92/MWh — cheaper than virtually everything else on the grid.

Offshore wind is a different story entirely. The costs are:

• Fixed-bottom offshore wind: typically $70–120/MWh in current estimates

• Dominion Energy’s Coastal Virginia Offshore Wind project projected at $91/MWh in 2027 dollars as of February 2025

• The UK’s Arup consultancy found an offshore wind LCOE of 88.5 £/MWh in 2024, roughly double what government estimates had assumed

Twelve offshore wind contracts along the U.S. Atlantic Coast were cancelled between 2019 and 2023 because the prices negotiated years earlier no longer matched the reality of post-inflation, post-supply-chain-chaos construction costs. That’s not a fatal verdict on offshore wind — it’s a market correction — but it does puncture the notion that offshore wind is on an unstoppable cost-reduction curve with no turbulence along the way.

So the honest cost picture for wind right now is:

• Onshore: genuinely very cheap, among the cheapest electricity we know how to make

• Offshore: roughly comparable to or more expensive than projected SMR costs, depending on the project and the assumptions

The number that LCOE ignores

This is where the debate gets genuinely interesting, and where both sides tend to argue past each other. 💡

Capacity factor is the ratio of actual output to maximum possible output. A plant running flat out for every hour of the year has a capacity factor of 100%. Nothing achieves that in practice, but nuclear gets close: the U.S. nuclear fleet averaged a 92.3% capacity factor in 2024, according to the Department of Energy. SMRs, which use the same physics as large reactors, are designed to operate in the same range of 80–95%.

Wind is different. The average capacity factor for U.S. wind farms in 2024 was 34–35%. Offshore wind can reach 40–50% in excellent locations, but the point stands: a wind turbine rated at 1 MW produces about a third of what a 1 MW nuclear plant produces in any given year.

This matters enormously when you try to build equivalent systems:

• To match the annual output of a 1,000 MW nuclear plant, you need between 1,900 MW and 2,800 MW of wind capacity

• That wind capacity would require between 260 and 360 square miles of land, according to the Nuclear Energy Institute’s analysis — compared to about 1.3 square miles for the nuclear facility itself

• The Our World in Data analysis confirms nuclear as the most land-efficient electricity source per unit of output, by a wide margin

Now, the wind industry correctly points out that most of that land between turbines remains usable for farming and ranching. Fair point. But the transmission infrastructure doesn’t disappear: wind and solar require significantly more transmission lines to deliver dispersed power to population centers. Princeton University’s Net-Zero America Project found that under a high-renewables scenario, transmission capacity would need to more than triple.

None of this makes wind bad. It makes the comparison honest.

Who’s right about what

This is the part where both camps would prefer you stop reading, because the answer is “it depends, and both sides are cherry-picking.” 🔎

The case for prioritizing wind right now is strong on cost and speed. Onshore wind is deployable today, at scale, at $30–40/MWh, with no first-of-a-kind risk premium baked in. If your goal is the most decarbonization per dollar in the shortest time, wind and solar win on current numbers — and current numbers are what the grid runs on.

The case for prioritizing SMR development is strong on reliability and strategic optionality. The ITIF’s April 2025 realist assessment put it plainly: SMRs offer reliable baseload power 24/7, a smaller footprint, and deployment flexibility that wind fundamentally cannot match. AI data centers, which Goldman Sachs estimates will more than double their power consumption by 2030, need exactly that: continuous, dispatchable electricity that doesn’t go dark when the wind drops. Microsoft’s decision to restart Three Mile Island and Google’s agreement with Kairos Power aren’t PR moves — they’re engineering decisions made by people who cannot afford intermittency.

Here’s the awkward truth neither side loves to say out loud:

• Wind’s LCOE looks better largely because it’s a mature technology that has already traveled the cost curve SMRs are just starting

• SMR’s value proposition looks better once you factor in the hidden costs of grid balancing, storage, and transmission that LCOE quietly ignores

• Neither technology is a complete solution on its own

• Cost projections for SMRs are not equivalent to actual costs — history shows that nuclear projects nearly always exceed their initial estimates, sometimes dramatically

The IEA’s research framework suggests SMR costs could reach parity with conventional nuclear within 10–15 years under optimistic scenarios. A 2025 analysis in Nuclear Engineering and Design found that over a 100-year time horizon with lifetime extensions, SMR long-term costs could fall to around $53/MWh — competitive with most firm power sources.

What’s your read — do you think the reliability premium that nuclear offers justifies its higher upfront cost, or is that a bet the market should make without government backing?

The bottom line

The simplest version of this comparison: today, at this moment in April 2026, onshore wind is cheaper to build and cheaper per MWh than any SMR you could actually commission. That is not in serious dispute. If you need electricity fast and cheap and you have the right geography, wind wins on cost.

But “cheaper per MWh” and “better for the grid” are not the same sentence. 🌍 The grid needs firm capacity — power that shows up when the wind stops, when demand spikes on a cold dark January morning, when an industrial facility needs heat at 3 a.m. Wind cannot reliably provide that. SMRs, in principle, can. The question is whether we can get their costs down far enough, fast enough, to make that promise real rather than just aspirational.

The honest answer is that we’re in a transition period where the smart play is probably both: build wind and solar aggressively now, because the cost curve is settled and the technology is ready, while simultaneously funding SMR development to give the grid the firm backbone it will eventually need. Treating this as an either/or debate misses the point entirely — and costs us time we don’t have.

The real cost of an SMR isn’t just what it costs to build. It’s the cost of not having it when the wind doesn’t blow.

Ask most people whether nuclear energy is “clean,” and you’ll get one of two reactions: a confident yes from the techno-optimists, or a suspicious eye-roll from the environmentalists. Both camps, it turns out, are partly right. The honest answer sits somewhere in the complicated middle, and getting there requires looking at the whole picture, not just the part that confirms what you already believe.

Here’s the short version: a nuclear power plant produces almost no carbon dioxide while it runs. That’s real. But mining uranium, building the plant, enriching the fuel, and eventually managing the waste all have environmental costs. The question isn’t whether those costs exist. It’s whether they’re large enough to undermine nuclear’s climate credentials. Spoiler: they aren’t, at least not compared to fossil fuels. But the comparison to other clean energy sources is considerably more interesting.

The carbon numbers, honestly

Start with lifecycle emissions, because that’s the only fair way to compare power sources. A lifecycle assessment — or LCA, in the jargon — accounts for everything: raw material extraction, construction, operation, fuel processing, and decommissioning. It answers the question that actually matters: how much CO2 does a technology emit per unit of electricity over its entire life?

The results for nuclear are striking. The IPCC, drawing on peer-reviewed studies, places nuclear’s median lifecycle carbon intensity at 12 grams of CO2 equivalent per kWh, comparable to wind and lower than all types of solar. A 2025 study published in the Journal of Industrial Ecology puts US nuclear plants even lower, at around 3 grams of CO2e per kWh, reflecting newer mining and enrichment technologies. For context: coal clocks in at 820 to 980 grams per kWh, while natural gas sits around 450 to 500 grams per kWh.

That’s not a close race. It’s a rout.

To put it in terms the World Nuclear Association finds worth repeating: nuclear’s lifecycle emission intensity is 7% of natural gas and only 3% of coal, averaged across the published studies. Those figures are consistent whether you look at industry sources, university research, or government analyses — the correlation between the three approaches is 0.95 or higher, which is remarkable agreement for a politically charged topic.

Where the numbers get slippery is in the range of estimates. Published lifecycle GHG values for nuclear power span from a few grams to more than 100 g CO2e/kWh globally, for reasons that are frequently misunderstood when reported by policymakers. The spread isn’t random. It depends heavily on:

• The uranium ore grade being mined (richer ore = less energy to extract per unit of fuel)

• Whether gaseous diffusion or the more efficient centrifuge method is used for enrichment

• The energy grid mix in the country doing the enrichment

• How plant construction materials are accounted for

• Whether waste disposal is included in the calculation

Germany’s official figure, for instance, is 67.8 g CO2e/kWh for nuclear — mostly because their enrichment was historically done using the energy-intensive gaseous diffusion method, now largely retired elsewhere. France, which enriches domestically using a cleaner grid, reports 6 g CO2e/kWh. Same reactor technology, very different upstream choices. 🇫🇷

So when you see a headline claiming nuclear is dirtier than solar, double-check the methodology. It’s probably using an outlier assumption or an outdated enrichment scenario.

How nuclear compares to its clean rivals

The honest comparison isn’t nuclear vs. coal. That debate is over. The more interesting question is: how does nuclear stack up against wind and solar?

Harmonized LCA data from the National Renewable Energy Laboratory shows that lifecycle greenhouse gas emissions from solar, wind, and nuclear are all considerably lower and less variable than emissions from coal or natural gas. But within that low-carbon club, there are differences worth noting.

• Wind onshore: ~11 g CO2e/kWh (IPCC median) 🌬️

• Nuclear: ~12 g CO2e/kWh (IPCC median)

• Solar PV (rooftop): ~41 g CO2e/kWh (IPCC figure)

• Natural gas: ~490 g CO2e/kWh

• Coal: ~820–980 g CO2e/kWh

Nuclear and wind are essentially tied on lifecycle carbon. Solar comes in roughly three to four times higher, mostly because manufacturing solar panels is energy-intensive and often happens in countries running on coal-heavy grids. ☀️

That said, solar’s footprint is falling fast. Manufacturing efficiency has improved dramatically, and more recent studies show solar’s lifecycle emissions dropping significantly over time as production moves toward cleaner grids. Nuclear’s advantage over solar may narrow further.

Where nuclear genuinely stands apart is capacity factor — how often a plant actually generates power relative to its maximum. US nuclear plants operate at a 92.6% capacity factor, compared to coal at 47.8% and natural gas combined-cycle plants at 56.7%. Wind and solar, of course, depend on weather. That reliability is worth something, especially for grid stability, and it’s why the IEA argues nuclear shouldn’t be dismissed as just one more option in the clean energy portfolio.

What I think gets underweighted in most public discussions: nuclear’s sheer output per unit of land and infrastructure is enormous. The fuel density is staggering. One uranium fuel pellet the size of your fingertip contains as much energy as 17,000 cubic feet of natural gas. 🔬

The radioactive waste problem — real, but often overstated

Here’s where nuclear’s critics have a legitimate point, and it’s worth engaging with directly rather than waving away.

A major environmental concern related to nuclear power is the creation of radioactive waste — uranium mill tailings, spent reactor fuel, and other materials that can remain radioactive and dangerous for thousands of years. That’s not nothing. Unlike CO2 emissions, which are genuinely invisible until their effects accumulate, spent nuclear fuel is a physical object you have to store somewhere, and “somewhere” has been a political nightmare for decades in the United States.

The US currently has no permanent disposal site. The proposed Yucca Mountain facility in Nevada has been politically stalled since the Obama administration pulled its funding. In the meantime, highly radioactive waste sits in interim storage at 70 sites across 35 states. That’s not ideal. The good news is that by volume, nuclear waste is genuinely small compared to the waste streams of other energy sources. A single nuclear plant’s annual waste output would fit inside a standard school bus — all the spent fuel ever generated by US nuclear plants could fit inside a football field piled about 30 feet high. The problem isn’t volume. It’s the duration of hazard and the political will to solve the storage question.

The upstream picture — uranium mining — is messier than the nuclear industry typically admits:

• Mining and refining uranium ore requires large amounts of energy, and the emissions from those processes count toward nuclear’s overall footprint.

• Mill tailings contain radium, which decays into radon gas, requiring engineered containment barriers to prevent atmospheric release.

• The White Mesa Mill in Utah has been cited at least 40 times for regulatory violations by state authorities since 1999, with testing wells regularly showing uranium, nitrates, cadmium, and nickel above state limits.

That’s a real-world example, not a hypothetical. Regulations exist, enforcement is imperfect, and communities near mining and milling sites — often Indigenous communities in the American Southwest — bear disproportionate exposure risks. ⚠️

Have you thought about where your electricity actually comes from when you plug in? Most people haven’t — and that invisibility benefits every energy source, nuclear included.

The “clean” label and what it actually means

At this point, it’s worth asking what “clean” even means. The word does a lot of lifting in energy debates, usually more rhetorical than scientific.

If clean means “produces no CO2 or air pollutants during operation,” nuclear is unambiguously clean. It emits no sulfur dioxide, no nitrogen oxides, no particulate matter. Unlike gas or coal plants, nuclear plants are not responsible for the hundreds of thousands of premature deaths that the World Health Organization attributes annually to fossil fuel combustion.

If clean means “has no harmful environmental footprint across its full lifecycle,” nuclear is mostly clean, with real asterisks around uranium mining and long-term waste. The asterisks matter, but they don’t flip the verdict.

If clean means “a net positive choice for climate compared to fossil fuels,” the science is unambiguous. The IEA estimates that over the past 50 years, the use of nuclear power has reduced CO2 emissions by over 60 gigatonnes — nearly two years’ worth of global energy-related emissions. That’s not an abstraction. That’s carbon that didn’t go into the atmosphere because reactors ran instead of coal plants.

The numbers that matter, compared plainly: ☢️

• Nuclear lifecycle emissions are ~98% lower than coal

• Nuclear lifecycle emissions are ~97% lower than natural gas

• Nuclear operates around the clock at 92.6% capacity, unlike weather-dependent sources

• The US has 94 operating reactors generating about 19% of the country’s electricity

None of this means nuclear is without tradeoffs. But framing it as dirty because uranium mining exists, while giving natural gas a pass for its methane leaks and its 490 g CO2e/kWh, isn’t honest analysis. It’s aesthetics masquerading as science.

What SMRs change about the equation

Small Modular Reactors don’t fundamentally change nuclear’s carbon profile — the physics is the same, and the fuel cycle is similar. What they potentially improve is the construction phase, which is where a significant chunk of nuclear’s lifecycle emissions originate. Large reactors require enormous amounts of concrete and steel to build, and that construction can take a decade or more — all of it powered by fossil fuels. 🏗️

SMRs, designed for factory fabrication and modular assembly, could reduce both construction time and the embodied carbon in plant infrastructure. Whether that theoretical advantage translates into measurable lifecycle improvements will depend heavily on:

• The energy source powering the factories that build the modules

• How quickly manufacturing volumes scale up to reduce per-unit material use

• Whether standardized designs reduce the engineering rework that inflates construction costs and timelines

The Trump administration has issued an executive order targeting an expansion of US nuclear capacity from approximately 100 GW in 2024 to 400 GW by 2050, with SMRs as the primary vehicle for that growth. That’s an ambitious number, and it’s worth noting that SMRs haven’t yet proven their cost competitiveness at scale. But the policy direction is clear, and the investment is following.

There’s also a lifecycle benefit that doesn’t get enough attention: SMRs could eventually run on spent nuclear fuel from conventional reactors, as some sodium-cooled fast reactor designs propose. If that technology matures, it would simultaneously address the waste storage problem and reduce the need for new uranium mining. Two birds, one very advanced stone. 🔬

What would it take to convince a skeptic that nuclear — large or small — deserves a serious seat at the clean energy table? Tell us in the comments or send your takes our way. The debate is worth having with real data on the table.

The verdict

Nuclear energy is low-carbon by any honest measurement. Its lifecycle emissions are comparable to wind, lower than solar, and roughly 97–98% below fossil fuels. The radioactive waste problem is real and politically unresolved, but it’s a volume-manageable problem, not an insurmountable one. Uranium mining carries environmental risks that deserve serious regulatory attention, particularly for communities near mining sites.

None of that makes nuclear “clean” in the way a clear mountain stream is clean. Energy production at civilization scale never is. But the IPCC’s own net-zero roadmaps include nuclear as a necessary component of decarbonization — not because the IPCC loves nuclear, but because the math keeps pointing that way. ⚡

The real question isn’t whether nuclear is clean enough. It’s whether we’re willing to be honest about trade-offs across all our energy choices — nuclear, solar, wind, gas, and everything else — rather than applying scrutiny selectively based on which technology we already prefer. If we measured solar and wind by the same standard that nuclear critics apply to uranium mining, the comparison would be more complicated than most clean energy advocates admit.

The carbon math favors nuclear. What comes next is a political and engineering question, not a scientific one.