Energy · US Production

U.S. Uranium Production Surges, Yet Stock Market Reflects Caution

Despite a threefold increase in U.S. uranium production, the stock market shows a muted response due to the nation's continued heavy reliance on imports and strategic inventory management by utilities.

News AutomationCompiled 01:04 UTC · 1 min read

A uranium mine site, representing the increase in U.S. domestic uranium extraction.

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Why Uranium Stocks Are Falling as U.S. Production Triples

By Charles Kennedy - Sep 02, 2026, 7:00 PM CDT

U.S. uranium production is surging, but domestic output still supplies only a small fraction of the roughly 47 million pounds purchased annually by U.S. nuclear operators.
U.S. utilities face 186 million pounds of uncovered uranium requirements through 2035, although large inventories give them time before signing new contracts.
Uranium stocks have retreated despite strong long-term demand, as high expectations, slow contracting and long-term pricing mean rising uranium prices take time to boost producer earnings.

Uranium mine

U.S. uranium production is climbing from a base so depleted that a threefold increase still leaves America dependent on imports for most of its reactor fuel. Output rose to 2.1 million pounds in 2025, its highest level since 2017, before reaching 2.13 million pounds in the first half of 2026, according to the EIA. Second-quarter production increased 4.7% to 1.09 million pounds.

U.S. nuclear-plant operators purchased 46.9 million pounds of uranium in 2025, more than 22 times the amount produced domestically. Uranium of U.S. origin accounted for 7% of deliveries, while Canada, Kazakhstan and Australia supplied a combined 75%. Domestic output is rising rapidly but still supplies only a small fraction of the uranium used by U.S. reactors.

Higher output has been accompanied by the heaviest drilling and spending campaign in more than a decade. Exploration drilling increased by two-thirds to 1.02 million feet in 2025, and spending on land, drilling, production and reclamation rose 47% to $234.7 million, its highest level since 2014, according to the EIA’s annual production report.

Six facilities produced uranium during the second quarter of 2026: four in Wyoming, one in Texas and one in Utah. Five additional in-situ recovery plants were on standby at the end of last year, while seven proposed plants had combined planned capacity of 10.5 million pounds.

The EIA reported 13.3 million pounds of annual capacity at operating U.S. in-situ recovery plants at the end of 2025, although the domestic industry produced only 2.1 million pounds during the year.

Overall, U.S. utilities expect to require as much as 360 million pounds of uranium through 2035. Existing contracts provided for maximum deliveries of 174 million pounds, leaving 186 million pounds of anticipated requirements without contracts. Utilities already owned 118 million pounds in commercial inventories at the end of 2025, which is enough volume for three years of reactor loading at the 2025 rate. The inventories allow utilities to defer part of their contracting.

Global reactor requirements also exceeded primary mine production last year, with inventories and other secondary supplies covering the difference. Mines produced about 60,000 tonnes, compared with reactor requirements of approximately 70,000 tonnes. The World Nuclear Association estimates that annual requirements would approach 200,000 tonnes by 2040 under its upper nuclear-growth scenario. But that’s only if reactors are completed on schedule.

Why Uranium Stocks Have Retreated

Investors do not appear to be treating U.S. dependence on imported uranium as an immediate earnings event. The Sprott Uranium Miners ETF rose to $84.95 on Jan. 29, fell 45% to $46.82 by July 29 and recovered to $56.81 at the end of August. A 3.8% decline on Sept. 1 left the fund about 36% below its January peak, although it was approximately flat for the year.

The broader Global X Uranium ETF traded near $59 in late April, fell below $38 in July and ended August at $45.51, about 23% below its spring high.

Cameco, Uranium Energy, NexGen Energy and Denison Mines were all 20% to 35% below their 2026 peaks at the beginning of September, even though several remained positive for the year.

Time is of the essence here. The 186 million pounds of uncovered U.S. requirements are spread across a decade, and utilities hold enough inventory to postpone part of their purchasing. Mining companies (especially smaller developers without operating revenue) need long-term contracts to finance construction now.

Uranium shares entered this year with fairly high expectations. URNM had more than tripled from its April 2025 low to its January 2026 peak. The rally priced in expectations of higher uranium prices, stronger utility contracting and successful mine development. But operating results did not move at the same pace.

Most uranium does not sell at the current spot price. Long-term contracts accounted for 87% of the uranium delivered to U.S. operators in 2025, at an average price of $55.91 per pound, while spot purchases averaged $76.01.

Producers receive prices set by agreements that may have been signed years earlier and can include fixed prices, market adjustments, floors and ceilings. Because of that, higher spot prices only reach earnings gradually.

Still, the latest decline in uranium shares was on the heels of a fairly strong August rebound. It wasn’t simply an uninterrupted sell-off. URNM gained about 16% in August, before falling 3.8% on Sept. 1, when higher oil prices and Treasury yields pushed the S&P 500 down 0.7% and the Russell 2000 down 1.2%.

Tripling production is impressive, but it doesn’t mean we are materially much closer to uranium independence. Even if output maintained its first-half pace for the rest of this year, domestic facilities would produce little more than 4 million pounds in a market where U.S. reactors recently loaded about 41 million pounds a year.

The uranium market has ample deposits, ambitious developers and growing reactor demand. But they don’t have a lot of time.

By Charles Kennedy for Oilprice.com

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