Spot uranium prices recently reached a peak not witnessed since 2007, standing strong at $101 per pound, per Numerico data.
This upswing signifies a constrained nuclear fuel market, growing expectations for future demand, and the imperative for additional mine restarts and new constructions, according to experts in the uranium industry.
Uranium is Powering Up the Future
The surge in uranium prices aligns with an increased focus on nuclear energy in global climate change mitigation efforts. Furthermore, rising uranium prices have spurred the revival of uranium mining operations previously scaled back following the 2011 Fukushima disaster.
Analysts and industry players anticipate more mine restarts in 2024. Plus, new builds are getting more attractive due to rising prices and anticipated supply deficits over the coming years.
The spot price of uranium surging $100/pound was more than a 100% increase from the 2023 low. It is also a whopping >300% rise from the 2020 low.
Uranium Spot Price USD Per Pound

The 16-year high uranium price, cracking at $101/pound since 2007, is driven by several factors.
For one, shortage in uranium supplies since the Fukushima incident drove prices upward.
Moreover, a U.S. bill seeking to ban nuclear fuel imports from Russia further contributes to the prices’ upward trajectory. The bill was called “NO RUSSIA” – National Opportunity to Restore Uranium Supply Services In America Act of 2022. Put simply, Russia will be out of the U.S. uranium market.
- RELATED: BREAKING: The US House Passed a Bill that just Repatriated the Nuclear Cycle from Russia’s Control
Once the bill passes the Senate, near-term demand for uranium will further surge upward.
What Causes the Unprecedented Rise of Uranium?
But what are the market experts saying about this price breakthrough?
According to a uranium market analyst, Marin Katusa, the 16-year high uranium price reflects the “real” cost of bringing on previously built and permitted facilities to replace uranium exported from Russia and Niger.
Marin also noted that with the US banning Russian imports, the logical investment is exposure to permitted, built out production in the US. The banned imports include Kazakh production owing to Russian enrichment.
Uranium prices have to increase more, Marin further noted, to incentivize new projects like the case with the Athabasca Basin. Building a new mine in North America would need even higher prices than $100.
Highlighting the growing demands for clean energy from data centers, which require more power for new technologies, SMR technologies offer a promising solution.
Small modular reactor development, with under 300 MWe capacity, is taking place in Western countries with increasing private investment. North America, in particular, would be the epicenter of this rapidly growing nuclear resurgence.
Marin also highlighted Japan’s decision to bring on the world’s largest nuclear power plant and its pro-nuclear stance since Fukushima. This and the positive outlook for nuclear technology globally coming out of the recent COP28 climate summit will create new demand for long term supply of uranium in politically stable jurisdictions. After all, Marin said that:
“…no nation wants to experience what France is experiencing in Niger with their uranium supply being completely cut off.”
For Miss America 2023, Grace Stanke, who happens to be a student of nuclear engineering, nuclear energy already plays a big role in the lives of many Americans. As a nuclear champion, Grace particularly noted that:
“From curing my dad’s cancer twice, to powering 20% of America, to helping with agriculture which is so important in my home state of Wisconsin… it really does feel like nuclear does it all.”
Beyond the Price: Uranium’s Ascent and Nuclear Energy Resurgence
As the world strives to reduce carbon emissions, zero-carbon nuclear energy is crucial. This is expected to make the demand for uranium explode much more.
In effect, escalating spot uranium prices may also exert upward pressure on contract prices as sellers seek higher returns. While higher prices may not dissuade utilities for short-term needs, climbing contract prices, covering larger quantities of uranium, could have a more substantial impact.
Some utilities are already experiencing “sticker shock”, as seen below in the S&P Global presentation. Experts also anticipate a widespread increase in nuclear fuel costs in the coming years due to rising market prices.

Notably, higher uranium prices would also drive further restarts in the near term, with industry giants like NAZ Kazatomprom JSC and Cameco restarting idle capacity. Canada-based Cameco will add capacity as needed under long-term contract pricing.
Meanwhile, Kazakhstan-based Kazatomprom, the largest uranium producer, plans to return to full production capacity by 2025. However, given the challenges that the company faces related to the availability of sulphuric acid (a critical operating material), they expect adjustments to their 2024 production plans. They also anticipate delays in finishing construction works at their newly developed deposits. These may affect Kazatomprom’s 2025 production plan, subject to considerable supply chain risks.
For other companies like GoldMining Inc (GLDG), this price increase is great news for their high-value assets. GLDG is one among the companies that’s making waves in the sector.
The surge in uranium prices signifies a resurgence in the nuclear energy sector. Driven by geopolitical shifts, legislative actions, and a growing demand for clean energy, the uranium market is poised for unprecedented growth.
Disclosure: Owners, members, directors and employees of carboncredits.com have/may have stock or option position in any of the companies mentioned: GLDG
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The post Uranium Prices at 16-Year Highs, Breaking $100 Per Pound appeared first on Carbon Credits.
Carbon Footprint
Where should an SME start with a carbon action plan?
More and more small and medium-sized businesses are hearing the same question from their larger customers: What is your carbon footprint? That question now travels down entire supply chains, and it arrives next to tender requirements, certification criteria, and rising customer expectations.
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Carbon Footprint
Insetting vs Offsetting: Which Actually Counts Toward Your Scope 3 Targets
The accounting differences that decide whether your nature investment shows up in inventory, in BVCM, or nowhere at all.
The question reaches a procurement team about three weeks before the next sustainability committee meeting. Someone has read about insetting. Someone else has just signed off on an offset purchase. The CSO wants to know if the two are interchangeable. The answer is no, and the GHG Protocol Land Sector and Removals Standard is the reason why.
This article walks through what each term means at audit-grade specificity, what the standards actually say about how each gets counted, and how to decide which tool fits which target. The insetting vs offsetting question is one of the most-searched in corporate climate strategy, and one of the most poorly answered. By the end of this piece, you should be able to brief a committee on the difference without notes.
The two definitions, in plain English
Offsetting means buying carbon credits generated outside your value chain and retiring them against your residual emissions. The reduction happens somewhere else, financed by you, and the credit is the receipt.
Insetting means investing in emission reductions or removals inside your own value chain, typically with suppliers, where the reduction is directly linked to the products and services you buy. The reduction happens inside the boundary of your Scope 3 inventory, and the accounting treatment is fundamentally different.
The shorthand from the University of Oxford’s Nature-based Insetting Initiative is useful: insetting is what you do with the supply chain you have; offsetting is what you do with the supply chain you do not have.
What the GHG Protocol Land Sector Standard actually says
The GHG Protocol Land Sector and Removals Standard, finalised in 2024 after a multi-year pilot, sets the rules for how land-based emission reductions and removals enter corporate inventories. The Standard distinguishes between inventory accounting (Scope 1, 2, and 3) and project or intervention accounting (a separate methodology for crediting).
For insetting, the practical implication is that supplier-level interventions, when properly measured and attributed, can reduce your Scope 3 category 1 (purchased goods and services) emissions in your inventory. The reduction is not a credit retired against the inventory; it is a lower inventory number, period.
For offsetting, the credit is retired separately. It can be reported as a contribution toward a net-zero claim under the SBTi Beyond Value Chain Mitigation framework or as part of a VCMI Carbon Integrity claim, but it does not lower the inventory number.
A practical consequence: if your Science Based Target requires a 50% absolute reduction in Scope 3 emissions by 2030, insetting moves you toward the target. Offsetting does not. This single point of difference reshapes the procurement decision.
When insetting counts toward Scope 3 (and when it does not)
Insetting counts toward Scope 3 only when several conditions are met:
- The intervention must occur with an entity in your value chain.
- The emissions reduction or removal must be measured against a defensible baseline.
- The reduction must be attributed to your share of that supplier’s output, not double-counted with other buyers.
- It must follow the inventory accounting rules in the GHG Protocol Land Sector Standard, not the project accounting rules used to generate credits.
The most common failure mode is double counting. If your supplier sells the same reduction as a credit on the voluntary market and also reports it to you as a Scope 3 reduction, the math breaks. The Standard requires you to address this risk, typically by purchasing and retiring the supplier-issued credit as part of your inventory or by contractual provisions that prevent the supplier from selling the reduction twice.
When insetting does not count toward Scope 3: when the intervention sits with a supplier you do not buy from, when the baseline is not defensible, when the attribution is unclear, or when the documentation does not survive audit. Those cases default to Beyond Value Chain Mitigation, which is still useful but operates on a different ledger.
The procurement and supplier engagement question
Insetting is harder than offsetting. That is the unfashionable truth most buyers eventually confront. Offsetting is a transaction; insetting is a relationship.
To run an insetting program, you need supplier mapping precise enough to know which farms or facilities sit at which Scope 3 boundary. You need an engagement model that gets suppliers to participate, which usually requires multi-year commitments and shared economics. You need an MRV architecture that measures the right things and produces audit-ready documentation. And you need a contractual structure that prevents double counting and protects both sides.
The trade-off you receive in return is significant. Reductions count against your inventory rather than your residual. Supplier relationships deepen, which protects sourcing continuity. Yield and quality improvements often follow regenerative interventions, which reduces your input cost over time. And the regulatory file, under CSRD, CSDDD, EUDR, and the SBTi FLAG Guidance, is materially stronger.
Choosing the right tool for the right target
A practical decision rule. If your target is a science-based Scope 3 reduction and you operate in a FLAG sector or source FLAG commodities, insetting is the structurally correct tool. If your target is a net-zero claim that includes neutralising hard-to-abate residual emissions outside your value chain, BVCM via high-integrity offsets is the structurally correct tool. Most companies with material Scope 3 exposure need both, in different proportions, sequenced over time.
The sequencing matters. Insetting takes longer to stand up but produces a permanent reduction in the inventory. Offsetting can be transacted faster but does not change the inventory and now sits under tighter claim restrictions. Treat them as complementary tools with different jobs, not as substitutes. The Accountability Framework Initiative and the IUCN Global Standard for Nature-based Solutions both provide useful guardrails for the insetting side, with biodiversity, human rights, and benefit-sharing requirements that go beyond carbon math.
If you are mapping a Scope 3 reduction roadmap and need to scope which interventions count toward your inventory versus which sit in Beyond Value Chain Mitigation, the carbon and sustainability experts at Carbon Credit Capital can help you structure a nature-based supply chain investment program that fits your FLAG exposure, your target architecture, and your audit horizon. Schedule a consultation.
Carbon Footprint
Net zero needs nature: a carbon credit guide
Net zero is often described as a balancing act: cut what you can, account for the rest, and reach zero on the ledger. That framing is useful, but it leaves something out. It treats every tonne of carbon as interchangeable and every route to zero as equally sound, while the science tells a more specific story.
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