Nuclear power is having its moment. After decades of post-Fukushima decline, political hostility, and investor indifference, the atom is suddenly fashionable again. Governments from Washington to Beijing are extending reactor lifetimes, approving new builds, and declaring nuclear essential to decarbonization targets. Tech giants are signing power purchase agreements with nuclear plants to feed their AI data centers. Even Germany — which shut down its last reactor in 2023 — is debating a reversal.

But there’s a problem nobody at the policy conferences wants to talk about: there isn’t enough uranium.

Spot uranium is trading at $78/lb U₃O₈ as of late March 2026 — up 180% from the $28 lows of 2020, but still, remarkably, 40% below the estimated incentive price needed to bring enough new mine supply online to meet projected demand. The nuclear renaissance is real. The fuel to power it is not ready.

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The Nuclear Renaissance by the Numbers

The global nuclear fleet consists of 440 operational reactors with a combined capacity of approximately 395 GW. These reactors generate about 10% of global electricity — the largest source of low-carbon baseload power on the planet.

What’s changed in the past three years is the pipeline:

Reactors Under Construction

As of March 2026, 58 reactors are under construction globally, with a combined capacity of 62 GW. This is the highest number of concurrent builds since the late 1980s.

Country	Reactors Under Construction	Capacity (GW)	Expected Online
China	24	25.6	2026-2032
India	8	6.2	2027-2033
Turkey	4	4.8	2028-2030
Egypt	4	4.8	2029-2031
South Korea	4	5.6	2027-2030
Russia	3	3.3	2027-2029
Bangladesh	2	2.4	2028-2030
UK	2	3.3	2029-2031
Others	7	6.0	Various

China alone is adding reactor capacity faster than the rest of the world combined. The country’s 14th Five-Year Plan targets 70 GW of nuclear capacity by 2028 (from 57 GW today), with a longer-term goal of 150 GW by 2035. At the current build rate, China will surpass France as the world’s second-largest nuclear power generator by 2028 and could challenge the US for the top position by 2035.

Lifetime Extensions

Perhaps more significant than new builds: existing reactors are staying online longer. The United States has extended operating licenses for 86 of its 93 operational reactors from 40 to 60 years. Several are now applying for 80-year licenses — which, if approved, would keep reactors operating that were originally designed for decommissioning in the 2020s running through the 2050s.

France extended the lifetime of its 56 reactors from 40 to 50 years in 2025, with 60-year extensions under review. Japan has restarted 12 of its 33 operable reactors, with more restarts expected.

Each lifetime extension or restart adds uranium demand without the multi-year construction lag of new builds. The demand impact is immediate.

Small Modular Reactors (SMRs)

The wildcard is SMRs. While no commercial SMR has yet been deployed in the West, the pipeline is accelerating:

• NuScale: First plant at Idaho National Lab targeted for 2030. DOE-certified design.
• GE Hitachi BWRX-300: Ontario Power Generation signed for 4 units. First expected 2029.
• X-energy Xe-100: Dow Chemical signed for deployment at an industrial facility.
• Rolls-Royce SMR: UK government approved with £400 million in funding. First unit ~2031.
• China’s HTR-PM: Already operational — the world’s first commercial pebble-bed reactor, online since 2023.
• Russia’s RITM-200: Deployed on icebreakers, with land-based version under development.

The World Nuclear Association estimates SMRs could add 21-30 GW of capacity by 2035. While each individual SMR is small (50-300 MW), the aggregate demand for uranium is material.

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The Supply Side: 15 Years of Neglect

While nuclear demand was stagnating post-Fukushima, uranium mining went through a devastating contraction that hollowed out the supply base.

Mine Production History

Year	Global Mine Production (Mlb U₃O₈)	% of Reactor Requirements
2016	163	90%
2018	143	79%
2020	123	69%
2022	130	72%
2024	142	74%
2025	148	75%

Global uranium mine production has been below reactor requirements every year since 2016. In 2025, mines produced approximately 148 million pounds — about 75% of the ~197 million pounds consumed by reactors. The deficit has been filled by secondary supply sources (discussed below), but these sources are finite and declining.

Why Mine Supply Can’t Scale

The uranium mining industry has been starved of investment for 15 years. Consider:

Exploration spending: Global uranium exploration budgets peaked at $2.1 billion in 2007. By 2020, they had fallen to $250 million — an 88% decline. Even with the recent price recovery, 2025 exploration spending was only $620 million. The pipeline of discovered but undeveloped deposits has barely grown in a decade.

Mine closures and curtailments: Between 2012 and 2022, approximately 20 uranium mines were closed or placed on care-and-maintenance globally. These include:

• Ranger (Australia): Closed 2021 after 40 years. No replacement.
• Cominak (Niger): Closed 2021 after 43 years.
• Langer Heinrich (Namibia): Restarting under Paladin Energy, but slowly. Production expected to ramp to 5.5 Mlb/year by 2027.
• McArthur River (Canada): Cameco’s flagship mine was shut from 2018-2022 due to low prices. Restarted, but full ramp has been slower than planned — 2025 production was 15 Mlb vs. nameplate capacity of 18 Mlb.

New project timelines: The journey from discovery to production for a uranium mine is typically 10-15 years, reflecting the unique regulatory requirements around radioactive materials:

• Environmental impact assessment: 2-3 years
• Regulatory/licensing review: 3-5 years
• Construction: 2-4 years
• Ramp-up: 1-2 years

There is no shortcut. A uranium mine approved today won’t produce at full capacity until the mid-2030s.

The Kazatomprom Question

Kazatomprom — Kazakhstan’s state uranium company — is the world’s largest uranium producer, responsible for approximately 43% of global mine output. Kazakhstan’s ISL (in-situ leach) mines have the lowest production costs in the industry ($15-$20/lb), giving Kazatomprom enormous pricing power.

But Kazatomprom is facing its own challenges:

1. Sulfuric acid shortage: ISL mining requires large quantities of sulfuric acid to dissolve uranium from sandstone formations. Kazakhstan’s acid supply — much of it sourced from domestic copper smelters — has been insufficient. Kazatomprom reduced its 2025 production guidance by 10% (3 Mlb) specifically due to acid availability.

2. Geological maturity: Kazakhstan’s most productive wellfields (at the giant Inkai, Budenovskoye, and Karatau deposits) are maturing. Head grades are declining, and well productivity is falling. New wellfields require 2-3 years of development before reaching design capacity.

3. Government revenue maximization: Kazakhstan has signaled it may impose higher royalties or restrict exports to capture more value from rising uranium prices. A proposed “strategic mineral” designation could limit Kazatomprom’s ability to increase production even if economics warrant it.

Kazatomprom’s 2025 production was approximately 62 million pounds — roughly flat with 2024 despite higher prices. The company’s medium-term guidance calls for 65-68 Mlb by 2028. The market was expecting 75+.

Cameco: The Canadian Stalwart

Cameco operates McArthur River/Key Lake (the world’s largest high-grade uranium mine) and Cigar Lake in Saskatchewan. Combined production capacity is approximately 30 Mlb/year.

Cameco’s strategy has shifted from “produce at any price” to “sell forward at premium prices.” The company has signed long-term contracts at prices above $70/lb — prices that were unthinkable three years ago. This is rational behavior but it limits Cameco’s ability (and willingness) to increase production rapidly.

Cameco’s joint venture with Kazatomprom on the Inkai project in Kazakhstan adds complexity. Production sharing agreements and Kazakhstan’s regulatory environment create operational friction.

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Secondary Supply: The Buffer Is Draining

Historically, the gap between mine production and reactor demand has been filled by secondary supply sources. These sources are now depleting:

Utility Inventories

Nuclear utilities typically hold 2-3 years of fuel inventory. Post-Fukushima, many utilities built up to 4-5 years of strategic inventory. Over the past decade, they’ve been drawing down these inventories rather than purchasing in the spot market. Average utility inventory cover has now fallen to approximately 2.0 years — the lowest since the early 2000s.

With inventories at minimum operating levels, utilities must return to the primary market for procurement. This structural shift from destocking to restocking adds approximately 20-30 Mlb/year of incremental demand.

Enrichment Underfeeding

When enrichment capacity exceeds demand, enrichers can “underfeed” — using extra separative work to extract more U-235 from the uranium feed, effectively creating secondary supply. During the post-Fukushima period, Russian and European enrichment facilities generated an estimated 15-25 Mlb/year of equivalent uranium supply through underfeeding.

This source has largely disappeared. Enrichment demand has risen to meet nuclear fleet growth, and the loss of Russian enrichment access for Western utilities (due to sanctions and political pressure) has tightened the enrichment market. SWU (separative work unit) prices have risen from $50 to $175, making underfeeding uneconomical.

Russian HEU/LEU Sales

The “Megatons to Megawatts” program — which converted Russian nuclear warhead material into reactor fuel — provided approximately 24 Mlb/year of secondary supply from 1993 to 2013. This program ended, and while Russia continued commercial uranium sales, US and EU sanctions have progressively restricted Russian uranium purchases.

The US passed legislation in 2024 phasing out Russian uranium imports by 2028 (with limited waivers). The EU is expected to follow. This removes approximately 15-20 Mlb/year of Russian-origin supply from Western markets.

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The Supply-Demand Balance

Aggregating all of the above:

2026 Uranium Demand:

• Existing fleet (440 reactors): 197 Mlb
• New reactors starting operations: +8 Mlb
• Utility restocking (inventory rebuild): +12 Mlb
• Total: ~217 Mlb

2026 Uranium Supply:

• Mine production: ~152 Mlb
• Secondary sources (inventories, underfeeding, recycling): ~40 Mlb
• Total: ~192 Mlb

Deficit: ~25 Mlb

2030 Projected:

• Demand (500+ GW fleet, assuming 50 GW of new additions): ~245 Mlb
• Mine production (committed + probable): ~165-175 Mlb
• Secondary sources (further depleted): ~25-30 Mlb
• Total supply: ~195 Mlb
• Deficit: ~50 Mlb

A deficit of 50 million pounds represents 20% of demand. In a market where the fuel is critical for baseload electricity generation and carries national security implications, this level of deficit is untenable. Prices must rise to the level that incentivizes new production — or governments must intervene to secure supply through strategic reserves, subsidies, or off-take agreements.

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The Incentive Price: $120-$130/lb

The critical question: what uranium price is needed to bring enough new supply online?

Based on analysis of the major undeveloped uranium deposits:

Project	Location	Owner	Capacity (Mlb/yr)	Required Price ($/lb)
Arrow	Canada	NexGen Energy	25	$70-$85
Wheeler River	Canada	Denison Mines	8	$50-$65
Dasa	Niger	Global Atomic	5	$65-$75
Yeelirrie	Australia	Cameco	7	$80-$100
Etango	Namibia	Bannerman Energy	4	$90-$110
Dubrovka	Russia	Rosatom	8	N/A (state-directed)
Various ISL (Kazakhstan)	Kazakhstan	Kazatomprom	10-15	$40-$55
Various greenfield	Multiple	Various juniors	15-25	$100-$150

To bring enough supply online to close the 50 Mlb deficit by 2030, the industry needs:

• Kazatomprom expansion: ~10 Mlb at $40-$55 (most likely)
• Arrow + Wheeler River: ~33 Mlb at $65-$85 (probable)
• Remaining ~7-10 Mlb from Tier 3 projects: $100-$150 (difficult)

The weighted-average incentive price for the marginal supply needed is approximately $120-$130/lb. Spot uranium at $78 is 40% below this level. Either prices rise to incentivize supply, or supply doesn’t come, and prices rise anyway.

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The Tech-Nuclear Nexus

A new demand driver is emerging that wasn’t in anyone’s models two years ago: Big Tech’s appetite for nuclear power.

• Microsoft: Signed a 20-year PPA with Constellation Energy’s Three Mile Island Unit 1 restart. Exploring SMR deployments at data center sites.
• Google: Signed with Kairos Power for advanced reactor deployment. Invested in TAE Technologies (fusion).
• Amazon: Partnered with Energy Northwest for SMR development. Acquired a nuclear-powered data center site in Pennsylvania.
• Oracle: Announced plans for data centers powered by SMRs.
• Meta: Issued RFPs for 1-4 GW of nuclear capacity for AI data centers.

The aggregate: Big Tech has committed to or expressed interest in approximately 12-15 GW of new nuclear capacity specifically for data centers. At 400 tonnes of uranium per GW-year, this adds 5,000-6,000 tonnes — approximately 13-16 Mlb — of annual uranium demand once operational.

This demand is particularly significant because:

1. It’s additional — not a substitution from existing nuclear capacity
2. It’s long-term — 15-20 year PPAs provide durable demand visibility
3. It’s price-insensitive — for a tech company spending $15 billion on a data center, uranium fuel costs ($2-3/MWh out of $60-80/MWh total cost of power) are irrelevant
4. It has political backing — governments actively support the tech-nuclear nexus as both an energy security and AI competitiveness measure

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Equity Plays in the Uranium Space

The uranium equity landscape has evolved from a handful of producers to a more complex ecosystem:

Producers:

• Kazatomprom (KAP.L): The lowest-cost producer, but subject to Kazakhstan regulatory risk and acid supply constraints. Trading at 8x EV/EBITDA.
• Cameco (CCJ): The premium uranium stock — best assets, best management, but priced for perfection at 35x forward earnings. Downside risk if prices stall.

Developers (highest upside if prices rise):

• NexGen Energy (NXE): Arrow is potentially the best undeveloped uranium deposit on Earth — 25 Mlb/year at $7/lb cash cost (if built). The stock trades at $8 (C$11) — pricing in significant but not full value of the deposit.
• Denison Mines (DNN): Wheeler River’s Phoenix deposit is the world’s highest-grade undeveloped uranium deposit. ISR mining reduces capital intensity.

Physical trusts:

• Sprott Physical Uranium Trust (U.UN, SRUUF): Holds approximately 66 million pounds of U₃O₈ in physical inventory. Essentially a leveraged bet on the spot price. Trades at a 3-5% premium to NAV.
• Yellow Cake plc (YCA.L): Similar model, London-listed. Holds 21 million pounds with a Kazatomprom supply agreement.

ETFs:

• Global X Uranium ETF (URA): Broad uranium equity exposure. Top holdings include Cameco (24%), Kazatomprom (12%), NexGen (7%).
• Sprott Uranium Miners ETF (URNM): More concentrated in pure-play uranium names. Higher beta.

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Risk Factors

The uranium thesis is not without risks:

1. Nuclear accident: A Fukushima-scale event would set the industry back a decade. While modern reactor designs are significantly safer, the political and psychological impact of a nuclear accident is disproportionate to the actual risk.

2. SMR delays: If SMRs fail to commercialize on the current timeline, a significant portion of projected demand growth evaporates. NuScale’s DOE cost overruns are a cautionary example.

3. Geopolitical supply surprise: If Russia and Kazakhstan fully cooperate and flood the market with cheap uranium (unlikely given current geopolitics but possible), prices could fall.

4. Demand substitution: If renewables + storage become cheaper than nuclear (already the case in some markets), new nuclear builds may be cancelled in favor of solar/wind/batteries.

5. Regulatory reversal: Anti-nuclear political movements in Europe or the US could slow or reverse reactor approvals.

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The CommodityNode View

Uranium’s supply-demand fundamentals are among the most compelling in the entire commodity complex. The nuclear renaissance is policy-backed, climate-driven, and AI-accelerated. The supply deficit is structural, multi-year, and unbridgeable at current prices.

At $78/lb, the spot price is well above the cost of existing production (~$30-$50/lb for Tier 1 producers) but far below the incentive price for new supply (~$120-$130/lb). This creates an unusual dynamic: current producers are highly profitable, but the market cannot solve its deficit without significantly higher prices.

Signal: Strongly Bullish. Uranium is the most fundamentally undervalued commodity in our coverage universe. The 25+ Mlb annual deficit, depleting secondary supply, 15 years of exploration underinvestment, and accelerating demand from both traditional nuclear and the tech-nuclear nexus create a setup where $100+ uranium is not a question of if but when.

The quiet part: 40 new reactors are being built. Hundreds more are planned. And the world’s uranium mines can’t feed the ones that already exist.

That’s not a trade. That’s a crisis in formation.

uranium nuclear energy-transition Kazatomprom Cameco supply-deficit SMR

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Methodology

How to read this Impact Map

CommodityNode Signal Reports combine directional sensitivity, supply-chain structure, category overlap, and linked thematic context. Treat the percentages and correlations as research signals designed to accelerate deeper diligence, not as financial advice. Read our full methodology.