When the Czech government announced in July 2024 that it had chosen South Korea’s Korea Hydro & Nuclear Power (KHNP) to build new reactors at the Dukovany site, it marked the first time in decades that a mid-sized European Union member state had committed to large-scale nuclear construction from scratch. The decision was not made in isolation. Across the continent, a policy consensus has been forming around an uncomfortable reality: wind and solar power, no matter how rapidly deployed, cannot on their own keep the lights on when the weather does not cooperate.
By June 2026, that consensus has hardened into law, procurement contracts, and billions of euros in grid-stabilization costs that European taxpayers are already paying.
The Czech bet on new nuclear
The Dukovany expansion is the clearest single signal of Europe’s nuclear pivot. The Czech government’s official announcement confirmed that Prague intends to negotiate the construction of two reactor units, with options for additional capacity at the same site. KHNP beat out France’s EDF and the U.S.-based Westinghouse for the contract, a geopolitical outcome that drew attention from Washington, Paris, and Seoul alike.
This is not a feasibility study or a political pledge. It is a procurement decision backed by government authority, placing the Czech Republic alongside France, Poland, and the United Kingdom in a small but growing club of European nations actively contracting new nuclear builds. For a country that already draws roughly one-third of its electricity from nuclear plants, the expansion represents a doubling down on a technology that much of Western Europe spent the past two decades trying to phase out.
Why renewables forced the conversation
The policy logic behind the nuclear revival is rooted in a number that rarely makes headlines but shapes every electricity bill in Europe: EUR 7.4 billion. That is how much EU member states spent on capacity mechanisms in 2023, according to the Agency for the Cooperation of Energy Regulators (ACER). Capacity mechanisms are payments made to power plants, often gas-fired, to stand ready to generate electricity during periods when wind and solar output drops. As renewable penetration has deepened across European grids, the cost of maintaining that backup has climbed sharply.
The EU’s own legislative response confirms the scale of the problem. In May 2024, the Council of the European Union finalized updated electricity market rules that explicitly reference capacity mechanisms as tools to ensure supply adequacy. The reform also addresses the need for greater grid flexibility as intermittent generation grows. In plain terms, the EU’s own market redesign acknowledges that a power system dominated by weather-dependent sources needs dispatchable generation standing by for the moments when the wind dies and clouds roll in.
No EU institution has used the blunt phrase “renewables alone cannot stabilize the grid.” But the legislative architecture tells the story clearly enough. When a continent redesigns its electricity market specifically to pay for backup power that renewables cannot provide, the policy implication is hard to miss.
Nuclear gets the same policy backing as solar
The European Commission’s Net-Zero Industry Act, adopted in 2024, went a step further. The law lists advanced nuclear technologies and small modular reactors (SMRs) among the strategic decarbonization technologies eligible for streamlined permitting, procurement support, and industrial policy backing. That classification places nuclear on the same regulatory footing as solar panels, wind turbines, and battery storage in the EU’s green industrial strategy.
For nuclear advocates, the inclusion was a watershed. For years, atomic energy occupied an awkward position in European climate policy: tolerated in some capitals, actively dismantled in others, and largely excluded from the green finance frameworks that channeled investment toward renewables. The Net-Zero Industry Act changed that calculus by treating nuclear as a tool for reaching net-zero emissions, not an obstacle to it.
The International Energy Agency’s assessment of global nuclear trends reinforces the European pattern. The IEA has framed atomic energy as critical for both decarbonization and energy security, noting that governments facing volatile fuel prices and binding climate targets are revisiting nuclear options they had previously sidelined. While the IEA’s analysis is global rather than EU-specific, it provides the broader context in which European decisions are being made.
The gap between policy and poured concrete
Europe’s nuclear ambitions come with a track record that should temper expectations. The continent’s two most recent large reactor projects, Finland’s Olkiluoto 3 and France’s Flamanville EPR, both ran more than a decade behind schedule and billions of euros over budget. Olkiluoto 3, originally expected to begin commercial operation in 2009, did not reach full power until 2023. Flamanville, initially slated for 2012, faced repeated delays tied to welding defects, regulatory reviews, and supply-chain problems.
Whether the Dukovany expansion can avoid a similar fate remains an open question. The Czech government has announced supplier selection and the intent to negotiate, but detailed construction schedules, binding cost estimates, and firm commissioning dates have not appeared in publicly available documentation as of June 2026. KHNP’s track record in South Korea, where it has built reactors closer to schedule than European counterparts, offers some grounds for optimism, but exporting that performance to a different regulatory and industrial environment is far from guaranteed.
Small modular reactors present a separate uncertainty. The Net-Zero Industry Act supports SMRs in principle, but no SMR design has received full regulatory approval for commercial deployment anywhere in Europe. The gap between policy endorsement and an operating reactor could prove wide. Eastern European countries with smaller grids and deep existing nuclear expertise may be well positioned for early SMR adoption, but that possibility depends on engineering and licensing milestones that have not yet been reached.
Germany’s exit looms as a counterpoint
Europe’s nuclear story is not monolithic. Germany completed the shutdown of its last three reactors in April 2023, ending decades of atomic power generation in the EU’s largest economy. The decision, rooted in political commitments that predate the current energy crisis, removed roughly 4 gigawatts of low-carbon baseload capacity from the European grid. Critics argue that Germany’s exit increased the continent’s reliance on natural gas for backup generation, precisely the dynamic that capacity mechanisms are designed to address.
The contrast between Berlin and Prague illustrates the political fault lines that still run through European energy policy. While a growing coalition of EU member states, including France, the Czech Republic, Poland, the Netherlands, and Sweden, has pushed for nuclear-friendly policies at the EU level, opposition remains entrenched in parts of Western Europe. How that tension resolves will shape not just energy policy but the EU’s ability to meet its 2050 climate neutrality target without relying heavily on fossil gas as a bridge fuel.
What the EUR 7.4 billion bill really means
The financial argument for nuclear may ultimately prove more persuasive than the environmental one. Capacity mechanisms exist because electricity markets, as currently designed, do not adequately compensate power plants for simply being available. When renewable output is high, wholesale prices drop, sometimes to zero or below, making it uneconomical for gas plants to run. But those same gas plants must remain operational for the hours and days when renewable output collapses. Someone has to pay them to wait, and that someone is the European electricity consumer.
Nuclear plants, once built, can run at capacity factors above 90 percent for decades. They do not depend on weather, and their fuel costs are a small fraction of total operating expenses. If new reactors at Dukovany or elsewhere can deliver power reliably over 40- to 60-year lifespans, they could displace a significant share of the fossil backup that capacity mechanisms currently fund. The upfront capital cost is enormous, but the long-run economics may favor nuclear over perpetually paying gas plants to idle.
That calculation is what European policymakers appear to be making. The verified facts, a Czech procurement contract, EU market reform legislation, industrial policy support for nuclear, and a EUR 7.4 billion annual backup bill, point in a consistent direction. Whether the policy architecture translates into reactors that are built on time, on budget, and connected to the grid is the question that the next decade will answer. For now, Europe has placed its bet.
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*This article was researched with the help of AI, with human editors creating the final content.
