U.S. utilities are planning a major expansion of nuclear power, with 21 companies outlining 33.6 gigawatts of new nuclear generation over the next 15 years. At the same time, operators of the current reactor fleet are pushing for longer plant lives, uprates and restarts that could add more than 7 GW from existing assets.
That growth story, however, has not translated into stock market strength. Nuclear-themed exchange-traded funds have posted weak or negative year-to-date returns even as broader energy and equity benchmarks have advanced, underscoring investor skepticism that the long-discussed nuclear renaissance will quickly turn into steel-in-the-ground projects.
The disconnect matters because nuclear power is increasingly being positioned as a strategic answer to rising electricity demand from data centers, domestic manufacturing and electrification. For investors, the key question is no longer whether interest exists, but how much of it will become financeable, permitted and constructed on schedule.
Key Facts
- Utilities surveyed across 95 commercial reactors are planning 33.6 GW of new nuclear generation over the next 15 years.
- More than 97% of surveyed reactor units are considering or pursuing approval to operate for at least 80 years.
- Uprates, restarts and operational improvements could add more than 7 GW from the existing U.S. nuclear fleet over the coming decade.
- About 2.2 GW of that potential increase is tied to restarting Palisades, Three Mile Island and Duane Arnold.
- Nuclear-focused ETFs have struggled in 2026, with URA and NUKZ down roughly 2% to 3% and NLR down about 13% year to date.
Nuclear Renaissance
The latest utility planning data points to a far more ambitious buildout pipeline than the market is currently pricing in. Most of the proposed 33.6 GW is expected later in the period, with roughly 28 GW clustered in 2035 through 2039. That timeline shows both the scale of utility interest and the long lead times still facing the industry.
Utilities are not only looking at new reactors. They are also trying to extract more output and more years from the plants already on the grid. The prospect that more than 97% of surveyed units could seek operations of at least 80 years speaks to nuclear power’s value as a long-duration infrastructure asset. Some owners are even planning around a potential 100-year operating life from initial construction.
Why this matters is straightforward: the demand outlook for firm, carbon-light electricity is strengthening. Large data centers tied to artificial intelligence workloads are emerging as a major source of incremental power demand, and more than a dozen utility respondents are evaluating nuclear supply for those loads. By contrast, utility interest in powering hydrogen production has evaporated after tax-credit changes shortened the runway for that use case, showing how sensitive emerging demand segments remain to policy design.
The U.S. nuclear growth story is becoming easier to model on paper than in equity prices, because investors still want evidence of construction, not just intention.
Why the market is not fully buying the story
Public equities have been far less enthusiastic than utility planners. Broader market benchmarks have advanced in 2026, and the energy sector has outperformed sharply, yet the main nuclear-themed ETFs remain underwater. That divergence reflects concerns over execution risk, capital intensity, licensing timelines and the history of cost overruns attached to large reactor projects.
The market’s caution also follows a sharp reversal in nuclear-linked momentum trades. After outsized gains in 2024 and 2025, several reactor developers and related names have fallen more than 50% in recent months. That suggests investors have shifted from rewarding thematic exposure to demanding proof that announced projects can move through permitting, financing and procurement without major delays.
Implications for Investors
For investors, the nuclear opportunity remains real but highly segmented. Regulated utilities with existing reactor fleets may be better positioned than pure-play developers because they can create value through license extensions, uprates, longer refueling cycles and restarts. Those steps can produce incremental generation faster and with less execution risk than building entirely new gigawatt-scale plants.
Project timing is the main watch-point. With around 28 GW of proposed new capacity concentrated in 2035 to 2039, much of the anticipated growth sits beyond the horizon that many public market investors typically reward. Companies tied to engineering, equipment, fuel supply and grid infrastructure could benefit earlier than developers whose valuations depend on final investment decisions that are still years away.
Investors should also distinguish between large reactors, small modular reactors and microreactors. The utility pipeline is split mainly between large plants and SMRs, while no respondents reported microreactor plans. Yet private capital has shown growing interest in microreactors, with recent funding rounds exceeding $1 billion. That suggests commercialization may first emerge in niche uses such as defense and remote power rather than in traditional utility-scale deployment.
Policy remains another critical variable. The collapse in utility interest for hydrogen-related nuclear supply after tax-credit changes illustrates how quickly project economics can shift. That dynamic is likely to apply across the sector, including advanced reactor deployment, transmission buildout and industrial power contracts for data centers. Investors should pay close attention to licensing progress, state-level incentives, federal support and the structure of long-term power purchase agreements.
The long-term setup for nuclear power is strengthening as electricity demand rises and grid reliability becomes more valuable. The next phase for the sector will be defined by whether planned capacity turns into signed contracts, construction starts and measurable generation growth by the end of the decade.