Cameco Corp 6-K, filed Jul 31, 2025
Cameco Corp (CCJ)
About this 6-K
Cameco Corp filed this 6-K on July 31, 2025.
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549
FORM 6-K
Report of Foreign Private Issuer
Pursuant to Rule 13a-16 or 15d-16
Under the Securities Exchange Act of 1934
For the month of July, 2025
Cameco Corporation
(Commission file No. 1-14228)
2121-11th Street West
Saskatoon, Saskatchewan, Canada S7M 1J3
(Address of Principal Executive Offices)
Indicate by check mark whether the registrant files or will file annual reports under cover Form 20-F or Form 40-F.
Form 20-F ☐ Form 40-F ☑
Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2(b) under the Securities Exchange Act of 1934.
Yes ☐ No ☑
If “Yes” is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b):
Exhibit Index
| 1 | Exhibit 99.1 to this Form 6-K shall not be deemed incorporated by reference into any registration statement (or any prospectus that forms a part thereof) or other filing made by Cameco Corporation with the U.S. Securities and Exchange Commission. |
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| Date: July 31, 2025 | Cameco Corporation | |||||
| By: | /s/ Sean A. Quinn | |||||
| Sean A. Quinn | ||||||
| Senior Vice-President, Chief Legal Officer and Corporate Secretary | ||||||
Exhibit 99.1
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| NEWS RELEASE | www.cameco.com | Saskatoon | ||
| All amounts in Canadian dollars unless specified otherwise |
Saskatchewan Canada |
Cameco Q2 results: strong financial performance reflecting positive momentum for nuclear power; uranium average realized price benefitting from long-term contracting strategy; Westinghouse opportunities driving improved 2025 outlook
July 31, 2025
Cameco (TSX: CCO; NYSE: CCJ) today reported its consolidated financial and operating results for the second quarter ended June 30, 2025, in accordance with International Financial Reporting Standards (IFRS).
“The solid second quarter and first-half financial performance across our uranium, fuel services, and Westinghouse segments demonstrates the resilience of our strategy and the constructive outlook for nuclear power, significantly improving our overall 2025 expectations,” said Tim Gitzel, Cameco’s president and CEO. “Despite the uncertainty-driven volatility throughout the capital markets during the first half of the year, the need for clean electrons has remained on the critical path to addressing global energy security, national security, and climate security concerns. As a result, we believe nuclear energy, and in turn Cameco, with our tier-one assets in stable jurisdictions and strategic investments across the entire nuclear fuel cycle, is on the critical path to global energy security.
“Our integrated strategy that aligns our marketing, operational, and financial decisions continues to serve us well in a market that is shifting its focus toward security of supply. From a marketing perspective, we are capturing value with continued patience and discipline as we layer-in long-term contracts for both uranium and conversion services – contracts that protect us from weaker market conditions while retaining exposure to the price improvements needed to support investments in future supply. That portfolio informs our operational plans, ensuring the timing of our supply is aligned with market demand because history has shown us that the overhang created by unencumbered supply – or even an expectation of supply, credible or not –hinders contracting momentum. So, in addition to having a contract book to underpin the coordinated marketing and operational aspects of our strategy, we also maintain a strong balance sheet and the financial discipline that allows us to confidently invest where required and be patient as the market evolves, ensuring our actions are deliberate and our decisions add value.
“As expected, the second quarter timing of planned maintenance at the Key Lake mill this year resulted in lower uranium production and higher unit cost of sales compared to the second quarter and first six months of last year. However, aside from a slight increase in our expected annual average realized price thanks to a rise in market prices, the only other notable shift in our full-year expectations is from our Westinghouse investment. We now expect our 49% share of Westinghouse’s adjusted EBITDA to be between $525 million (US) and $580 million (US), driven by the $170 million (US) increase in our share of Westinghouse’s second quarter revenue, tied to its participation in a construction project for two nuclear reactors at the Dukovany power plant in the Czech Republic. We believe that the Czech project, which was announced in June, evidences the growing support for nuclear power, support that is expected to have a positive impact on our uranium and fuel services businesses while creating significant future growth opportunities for Westinghouse.
“We believe that supportive government policies, the tangible actions of energy-intensive industries, and positive public conversations are all pointing to a global convergence: nuclear energy is a critical solution for providing clean, constant, secure and reliable power to electrify global economies. As a proven and reliable supplier with decades of experience, Cameco, along with Westinghouse, is uniquely positioned to power a safe, secure energy future.”
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Second Quarter Highlights
| • | Strong consolidated financial performance in Q2 and for the first six months of 2025: Net earnings of $321 million, adjusted net earnings of $308 million, and adjusted EBITDA of $673 million were all significantly higher than in the second quarter of 2024, largely due to increased equity earnings from our investment in Westinghouse and strong performance in our uranium and fuel services segments. During the first half of the year, net earnings of $391 million, adjusted net earnings of $378 million and adjusted EBITDA of $1.0 billion were also significantly higher than the first six months of 2024 for the same reasons. Quarterly results are impacted by normal quarterly variations in the timing of contract deliveries in our uranium and fuel services segments, and the timing of customer-driven reactor life cycle activities in the Westinghouse segment. |
| • | Uranium: In our core uranium segment, second quarter earnings before income taxes and adjusted EBITDA increased by 46% and 43% respectively compared to the same period in 2024; earnings before income taxes and adjusted EBITDA for the first half of the year increased by 14% and 17% respectively compared to the first six months of 2024, all mainly as a result of higher sales volumes and average realized prices. Average realized price continued to show improvements as prices from fixed price contracts increased and the US dollar was stronger than in the second quarter of 2024. Total cost of sales (including depreciation and amortization (D&A)) increased due to an increase in the average unit cost of sales and an increase in sales volume. In addition, cost of sales was higher than in the second quarter of 2024 due to the costs of the planned annual maintenance shutdown at the Key Lake mill which were expensed directly to cost of sales. The shutdown took place in the second quarter compared to the third quarter in 2024. See Financial results by segment – Uranium in our second quarter MD&A for more information. Cash cost per pound is a non-IFRS measure, see page 5. |
| • | Fuel Services: In our fuel services segment, second quarter earnings before income taxes and adjusted EBITDA increased by 33% and 36% respectively compared to the same period in 2024 mainly due to higher sales and a decrease in cost of sales. Earnings before income taxes for the first half of the year increased by over 100% while adjusted EBITDA increased 97% compared to the first six months of 2024 due to higher sales, a higher average realized price and a decrease in cost of sales. See Financial results by segment – Fuel services in our second quarter MD&A for more information. |
| • | Westinghouse: Westinghouse reported net earnings of $126 million (our share) for the second quarter and $64 million (our share) for the first six months, improving considerably from net losses in comparable periods in 2024. The improvement over last year is primarily due to Westinghouse’s participation in the construction project for two nuclear reactors at the Dukovany power plant in Czech Republic, which, as previously disclosed, resulted in a $170 million (US) increase in our share of Westinghouse’s 2025 second quarter revenue. We use adjusted EBITDA as a performance measure for Westinghouse and in the second quarter and first six months of 2025, adjusted EBITDA increased to $352 million and $445 million respectively, compared to the same periods in 2024, which was mainly the result of the increased revenue in the second quarter as noted above. Once Westinghouse receives the cash associated with the increased revenue, it will be considered, by the partners, in determining distributions payable. Westinghouse is expected to receive the cash in the fourth quarter of 2025. See Our outlook for 2025 and Our earnings from Westinghouse in our first quarter MD&A for more information. Adjusted net earnings and adjusted EBITDA are non-IFRS measures, see page 5. |
| • | Improved 2025 financial outlook: Our annual expectations for consolidated financial metrics remain unchanged. However, the outlook for our Westinghouse segment has improved significantly. |
| • | Uranium and Fuel Services production outlook: In our uranium segment, we continue to expect 18 million pounds of production (100% basis) at each of McArthur River/Key Lake and Cigar Lake operations in 2025. However, potential risks to our 2025 production outlook at McArthur River/Key Lake include the expected timing of ground freezing and development schedules in new mining areas, access to adequate skilled labour, and the timing of new equipment commissioning. We now expect our uranium average realized price to be approximately $87.00 per pound (previously $84.00 per pound) due to the higher uranium spot price. In our Fuel Services segment, our annual production expectation, which includes UF6 conversion, UO2 conversion, and heavy water reactor fuel bundles, remains between 13 million and 14 million kgU of combined fuel services products. |
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| • | Westinghouse outlook: We now expect our share of adjusted EBITDA from our equity investment in Westinghouse to be between $525 million and $580 million (US) (previously $355 million to 405 million (US)) due to the approximately $170 million (US) increase in our share of Westinghouse’s 2025 second quarter revenue tied to Westinghouse’s participation in the Dukovany construction project in the Czech Republic. Over the next five years, we expect our share of adjusted EBITDA, excluding the impact of the $170 million (US) increase in the second quarter of 2025, will grow at a compound annual growth rate of 6% to 10%. The 2025 outlook for our share of Westinghouse’s net earnings is also impacted by the increased revenue net of income taxes and is now $30 million to $80 million (US) (previously a net loss of $20 million to $70 million (US)). Adjusted EBITDA attributable to Westinghouse is a non-IFRS measure, see page 5. |
| • | Joint Venture Inkai (JV Inkai) production: JV Inkai continues to target 2025 production of 8.3 million pounds (100% basis) of uranium of which our purchase allocation is 3.7 million pounds. We expect shipments of our remaining share of 2024 production (approximately 900,000 pounds) and the majority of our share of 2025 production from JV Inkai to begin in the second half of 2025. |
| • | Disciplined long-term contracting: As of June 30, 2025, we had commitments requiring delivery of an average of about 28 million pounds per year, from 2025 through 2029, which includes deliveries made year to date in 2025, with commitment levels higher than the average in 2025 through 2027, and lower than the average in 2028 through 2029. Long-term uranium contracting slowed during the first half of the year due to global macro-economic uncertainty related to trade policy issues, and customers’ focus on downstream services, driven by continuing geopolitical tensions. However, we continue to have a large and growing pipeline of business under discussion, and as the pace of contracting improves, we expect to selectively continue layering in long-term volumes that capture greater future upside and downside protection using market-related pricing mechanisms. |
| • | Maintaining financial discipline and balanced liquidity to execute on strategy: |
| • | Strong balance sheet: As of June 30, 2025, we had $716 million in cash and cash equivalents and $1.0 billion in total debt. In addition, we have a $1.0 billion undrawn revolving credit facility. |
| • | Additional financial flexibility: To broaden the ratings coverage on our debt and provide a tool for future flexibility, we initiated a public rating with Moody’s, which has assigned an issuer rating of Baa2 with a stable outlook (effective July 30, 2025). Obtaining a rating from Moody’s allows us to engage with an additional rating agency about the dynamics in our market at a time when our industry is in the headlines on a regular basis, demonstrating the supply and demand fundamentals that differ from others in the mining sector. |
| • | Dividend from JV Inkai: In April, we received a cash dividend of $87 million (US), net of withholdings, from JV Inkai based on its 2024 financial performance. From a cash flow perspective, we expect to realize the benefit from JV Inkai’s 2025 financial performance in 2026 once the dividend for 2025 is declared and paid. |
| • | Changes to the executive team: consistent with prudent succession planning and with Cameco’s ongoing commitment to execution of its balanced and disciplined strategy, effective September 1, 2025, the following changes will be made to the executive team: |
| • | Tim Gitzel will continue in his role as chief executive officer |
| • | Grant Isaac will be appointed president and chief operating officer |
| • | Heidi Shockey will be appointed senior vice-president and chief financial officer |
| • | Liam Mooney will be appointed senior vice-president and chief legal officer |
| • | Sean Quinn will assume the role of senior advisor, special projects until March 31, 2026, at which time he is retiring |
| • | Brian Reilly will assume the role of senior advisor, operations until March 31, 2026, at which time he is retiring |
With these changes in the senior leadership team, we expect to continue to have the right people in the right positions, with the appropriate experience to help the company achieve its vision of powering a secure energy future.
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Consolidated financial results
| THREE MONTHS ENDED | SIX MONTHS ENDED | |||||||||||||||||||||||
| HIGHLIGHTS | JUNE 30 | JUNE 30 | ||||||||||||||||||||||
| ($ MILLIONS EXCEPT WHERE INDICATED) |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||
| Revenue |
877 | 598 | 47 | % | 1,666 | 1,232 | 35 | % | ||||||||||||||||
| Gross profit |
257 | 175 | 47 | % | 527 | 362 | 46 | % | ||||||||||||||||
| Net earnings attributable to equity holders |
321 | 36 | >100 | % | 391 | 29 | >100 | % | ||||||||||||||||
| $ per common share (basic) |
0.74 | 0.08 | >100 | % | 0.90 | 0.07 | >100 | % | ||||||||||||||||
| $ per common share (diluted) |
0.74 | 0.08 | >100 | % | 0.90 | 0.07 | >100 | % | ||||||||||||||||
| Adjusted net earnings (ANE) (non-IFRS, see page 5) |
308 | 65 | >100 | % | 378 | 111 | >100 | % | ||||||||||||||||
| $ per common share (adjusted and diluted) |
0.71 | 0.15 | >100 | % | 0.87 | 0.25 | >100 | % | ||||||||||||||||
| Adjusted EBITDA (non-IFRS, see page 5) 1 |
673 | 343 | 96 | % | 1,029 | 677 | 52 | % | ||||||||||||||||
| Cash provided by operations |
465 | 260 | 79 | % | 575 | 323 | 78 | % | ||||||||||||||||
| 1 | In the fourth quarter of 2024, we revised our calculation of adjusted net earnings and adjusted EBITDA to adjust for unrealized foreign exchange gains and losses as well as for share-based compensation because it better reflects how we assess our operational performance. We have restated comparative periods to reflect this change. |
The financial information presented for the three months and six months ended June 30, 2024, and June 30, 2025, is unaudited.
Selected segment highlights
| THREE MONTHS ENDED | SIX MONTHS ENDED | |||||||||||||||||||||||||||
| JUNE 30 | JUNE 30 | |||||||||||||||||||||||||||
| HIGHLIGHTS |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||||||
| Uranium |
Production volume (million lb) | 4.6 | 7.1 | (35 | )% | 10.6 | 12.9 | (18 | )% | |||||||||||||||||||
| Sales volume (million lb) | 8.7 | 6.2 | 40 | % | 15.6 | 13.5 | 16 | % | ||||||||||||||||||||
| Average realized price1 | ($US/lb) | 57.35 | 56.43 | 2 | % | 59.66 | 57.04 | 5 | % | |||||||||||||||||||
| ($Cdn/lb) | 81.03 | 76.93 | 5 | % | 84.62 | 77.15 | 10 | % | ||||||||||||||||||||
| Revenue | 705 | 481 | 47 | % | 1,324 | 1,042 | 27 | % | ||||||||||||||||||||
| Gross profit | 217 | 144 | 51 | % | 420 | 313 | 34 | % | ||||||||||||||||||||
| Earnings before income taxes | 281 | 192 | 46 | % | 509 | 445 | 14 | % | ||||||||||||||||||||
| Adjusted EBITDA2 | 352 | 246 | 43 | % | 641 | 548 | 17 | % | ||||||||||||||||||||
| Fuel services |
Production volume (million kgU) | 3.2 | 2.9 | 10 | % | 7.1 | 6.7 | 6 | % | |||||||||||||||||||
| Sales volume (million kgU) | 4.4 | 2.9 | 52 | % | 6.8 | 4.4 | 55 | % | ||||||||||||||||||||
| Average realized price3 | ($Cdn/kgU) | 36.79 | 39.98 | (8 | )% | 43.75 | 42.80 | 2 | % | |||||||||||||||||||
| Revenue | 162 | 118 | 37 | % | 297 | 190 | 56 | % | ||||||||||||||||||||
| Earnings before income taxes | 44 | 33 | 33 | % | 112 | 53 | >100 | % | ||||||||||||||||||||
| Adjusted EBITDA2 | 57 | 42 | 36 | % | 132 | 67 | 97 | % | ||||||||||||||||||||
| Adjusted EBITDA margin (%)2 | 35 | 36 | (3 | )% | 44 | 35 | 26 | % | ||||||||||||||||||||
| Westinghouse |
Adjusted free cash flow2 | 306 | 89 | >100 | % | 356 | 132 | >100 | % | |||||||||||||||||||
| (our share) |
Net earnings (loss) | 126 | (47 | ) | >(100 | )% | 64 | (170 | ) | >(100 | )% | |||||||||||||||||
| Adjusted EBITDA2 | 352 | 121 | >100 | % | 445 | 197 | >100 | % | ||||||||||||||||||||
| 1 | Uranium average realized price is calculated as the revenue from sales of uranium concentrate, transportation and storage fees divided by the volume of uranium concentrates sold. |
| 2 | Non-IFRS measure, see page 5. |
| 3 | Fuel services average realized price is calculated as revenue from the sale of conversion and fabrication services, including fuel bundles and reactor components, transportation and storage fees divided by the volumes sold. |
The table on the following page shows the costs of produced and purchased uranium incurred in the reporting periods (see non-IFRS measures starting on page 5). These costs do not include care and maintenance costs, selling costs such as royalties, transportation and commissions, nor do they reflect the impact of opening inventories on our reported cost of sales.
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| THREE MONTHS ENDED | SIX MONTHS ENDED | |||||||||||||||||||||||
| JUNE 30 | JUNE 30 | |||||||||||||||||||||||
| ($CDN/LB) |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||
| Produced |
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| Cash cost |
26.19 | 16.96 | 54 | % | 24.05 | 18.11 | 33 | % | ||||||||||||||||
| Non-cash cost |
11.66 | 9.10 | 28 | % | 10.90 | 9.41 | 16 | % | ||||||||||||||||
| Total production cost1 |
37.85 | 26.06 | 45 | % | 34.95 | 27.52 | 27 | % | ||||||||||||||||
| Quantity produced (million lb)1 |
4.6 | 7.1 | (35 | )% | 10.6 | 12.9 | (18 | )% | ||||||||||||||||
| Purchased |
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| Cash cost |
97.00 | 109.11 | (11 | )% | 102.74 | 96.25 | 7 | % | ||||||||||||||||
| Quantity purchased (million lb)1 |
0.7 | 1.7 | (59 | )% | 1.9 | 4.4 | (57 | )% | ||||||||||||||||
| Totals |
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| Produced and purchased costs |
45.66 | 42.10 | 8 | % | 45.25 | 45.00 | 1 | % | ||||||||||||||||
| Quantities produced and purchased (million lb) |
5.3 | 8.8 | (40 | )% | 12.5 | 17.3 | (28 | )% | ||||||||||||||||
| 1 | Due to equity accounting, our share of production from JV Inkai is shown as a purchase at the time of delivery. These purchases will fluctuate during the quarters and timing of purchases will not match production. There were no purchases during the second quarter or in the first six months of 2025. |
Non-IFRS measures
The non-IFRS measures referenced in this document are supplemental measures, which are used as indicators of our financial performance. Management believes that these non-IFRS measures provide useful supplemental information to investors, securities analysts, lenders and other interested parties in assessing our operational performance and our ability to generate cash flows to meet our cash requirements. These measures are not recognized measures under IFRS, do not have standardized meanings, and are therefore may not be comparable to similarly titled measures presented by other companies. Accordingly, these measures should not be considered in isolation or as a substitute for the financial information reported under IFRS. We are not able to reconcile our forward-looking non-IFRS guidance because we cannot predict the timing and amounts of discrete items, which could significantly impact our IFRS results.
The following are the non-IFRS measures used in this document.
ADJUSTED NET EARNINGS
Adjusted net earnings is our net earnings attributable to equity holders, adjusted for non-operating or non-cash items such as gains and losses on derivatives and adjustments to reclamation provisions flowing through other operating expenses, that we believe do not reflect the underlying financial performance for the reporting period. Other items may also be adjusted from time to time. We adjust this measure for certain of the items that our equity-accounted investees make in arriving at other non-IFRS measures. Adjusted net earnings is one of the targets that we measure to form the basis for a portion of annual employee and executive compensation (see Measuring our results in our 2024 annual MD&A).
In calculating ANE we adjust for derivatives. We do not use hedge accounting under IFRS and, therefore, we are required to report gains and losses on all hedging activity, both for contracts that close in the period and those that remain outstanding at the end of the period. For the contracts that remain outstanding, we must treat them as though they were settled at the end of the reporting period (mark-to-market). However, we do not believe the gains and losses that we are required to report under IFRS appropriately reflect the intent of our hedging activities, so we make adjustments in calculating our ANE to better reflect the impact of our hedging program in the applicable reporting period. See Foreign exchange in our 2024 annual MD&A for more information.
We also adjust for changes to our reclamation provisions that flow directly through earnings. Every quarter we are required to update the reclamation provisions for all operations based on new cash flow estimates, discount and inflation rates. This normally results in an adjustment to an asset retirement obligation asset in addition to the provision balance. When the assets of an operation have been written off due to an impairment, as is the case with our Rabbit Lake and US ISR operations, the adjustment is recorded directly to the statement of earnings as “other operating expense (income)”. See note 9 of our interim financial statements for more information. This amount has been excluded from our ANE measure.
As a result of the change in ownership of Westinghouse when it was acquired by Cameco and Brookfield, Westinghouse’s inventories at the acquisition date were revalued based on the market price at that date. As these quantities are sold, Westinghouse’s cost of products and services sold reflect these market values, regardless of their historic costs. Our share of these costs is included in earnings from equity-accounted investees and recorded in cost of products and services sold in the investee information (see note 6 to the financial statements). Since this expense is non-cash, outside of the normal course of business and only occurred due to the change in ownership, we have excluded our share from our ANE measure.
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Westinghouse has also expensed some non-operating acquisition-related transition costs that the acquiring parties agreed to pay for, which resulted in a reduction in the purchase price paid. Our share of these costs is included in earnings from equity-accounted investees and recorded in other expenses in the investee information (see note 6 to the financial statements). Since this expense is outside of the normal course of business and only occurred due to the change in ownership, we have excluded our share from our ANE measure.
To facilitate a better understanding of these measures, the table below reconciles adjusted net earnings with our net earnings for the second quarter and first six months of 2025 and compares it to the same periods in 2024.
| THREE MONTHS ENDED | SIX MONTHS ENDED | |||||||||||||||
| JUNE 30 | JUNE 30 | |||||||||||||||
| ($ MILLIONS) |
2025 | 2024 | 2025 | 2024 | ||||||||||||
| Adjustments |
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| Adjustments on derivatives |
(163 | ) | 14 | (175 | ) | 47 | ||||||||||
| Unrealized foreign exchange losses (gains) |
71 | (7 | ) | 67 | (25 | ) | ||||||||||
| Share-based compensation |
39 | 15 | 37 | 23 | ||||||||||||
| Adjustments on other operating expense (income) |
(8 | ) | (2 | ) | (7 | ) | (17 | ) | ||||||||
| Income taxes on adjustments |
35 | (7 | ) | 39 | (16 | ) | ||||||||||
| Adjustments on equity investees (net of tax): |
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| Inventory purchase accounting |
4 | 12 | 4 | 50 | ||||||||||||
| Acquisition-related transition costs |
— | 5 | — | 19 | ||||||||||||
| Unrealized foreign exchange losses (gains) |
(2 | ) | (2 | ) | 5 | (2 | ) | |||||||||
| Other expenses1 |
11 | 1 | 17 | 3 | ||||||||||||
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| Adjusted net earnings |
308 | 65 | 378 | 111 | ||||||||||||
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| 1 | Other expenses includes Westinghouse’s unrealized foreign exchange losses (gains) and costs related to long-term incentive plans. |
The following table shows what contributed to the change in adjusted net earnings (non-IFRS measure, see above) for the second quarter and first six months of 2025 compared to the same periods in 2024.
| THREE MONTHS ENDED | SIX MONTHS ENDED | |||||||||||||||||
| JUNE 30 | JUNE 30 | |||||||||||||||||
| ($ MILLIONS) |
IFRS | ADJUSTED | IFRS | ADJUSTED | ||||||||||||||
| Net earnings – 2024 |
36 | 65 | 29 | 111 | ||||||||||||||
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| Change in gross profit by segment |
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| (We calculate gross profit by deducting from revenue the cost of products and services sold, and depreciation and amortization (D&A), net of hedging benefits) |
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| Uranium |
Impact from sales volume changes |
57 | 57 | 50 | 50 | |||||||||||||
| Higher realized prices ($US) |
11 | 11 | 55 | 55 | ||||||||||||||
| Foreign exchange impact on realized prices |
24 | 24 | 61 | 61 | ||||||||||||||
| Higher costs |
(19 | ) | (19 | ) | (59 | ) | (58 | ) | ||||||||||
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| Change – uranium |
73 | 73 | 107 | 108 | ||||||||||||||
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| Fuel services |
Impact from sales volume changes |
16 | 16 | 27 | 27 | |||||||||||||
| Higher (lower) realized prices ($Cdn) |
(14 | ) | (14 | ) | 6 | 6 | ||||||||||||
| Lower costs |
7 | 7 | 26 | 26 | ||||||||||||||
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| Change – fuel services |
9 | 9 | 59 | 59 | ||||||||||||||
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| Other changes |
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| Higher administration expenditures |
(30 | ) | (6 | ) | (29 | ) | (16 | ) | ||||||||||
| Lower exploration and research and development expenditures |
6 | 6 | — | — | ||||||||||||||
| Change in reclamation provisions |
8 | 2 | (11 | ) | (1 | ) | ||||||||||||
| Higher earnings from equity-accounted investees |
187 | 184 | 207 | 163 | ||||||||||||||
| Change in gains or losses on derivatives |
167 | (10 | ) | 199 | (23 | ) | ||||||||||||
| Change in foreign exchange gains or losses |
(94 | ) | (16 | ) | (112 | ) | (20 | ) | ||||||||||
| Lower finance income |
(3 | ) | (3 | ) | (5 | ) | (5 | ) | ||||||||||
| Lower finance costs |
16 | 16 | 25 | 25 | ||||||||||||||
| Change in income tax recovery or expense |
(53 | ) | (11 | ) | (75 | ) | (20 | ) | ||||||||||
| Other |
(1 | ) | (1 | ) | (3 | ) | (3 | ) | ||||||||||
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| Net earnings – 2025 |
321 | 308 | 391 | 378 | ||||||||||||||
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EBITDA
EBITDA is defined as net earnings attributable to equity holders, adjusted for the costs related to the impact of the company’s capital and tax structure including depreciation and amortization, finance income, finance costs (including accretion) and income taxes. Included in EBITDA is our share of equity-accounted investees.
ADJUSTED EBITDA
Adjusted EBITDA is defined as EBITDA, as further adjusted for the impact of certain costs or benefits incurred in the period which are either not indicative of the underlying business performance or that impact the ability to assess the operating performance of the business. These adjustments include the amounts noted in the ANE definition.
In calculating adjusted EBITDA, we also adjust for items included in the results of our equity-accounted investees that are not adjustments to arrive at our ANE measure. These items are reported as part of other expenses within the investee financial information and are not representative of the underlying operations. These primarily include transaction, integration and restructuring costs related to acquisitions.
The company may realize similar gains or incur similar expenditures in the future.
ADJUSTED EBITDA MARGIN
Adjusted EBITDA margin is defined as adjusted EBITDA divided by revenue for the appropriate period.
EBITDA, adjusted EBITDA and adjusted EBITDA margin are non-IFRS measures which allow us and other users to assess results of operations from a management perspective without regard for our capital structure.
To facilitate a better understanding of these measures, the tables below reconcile net earnings with EBITDA and adjusted EBITDA for the second quarter and first six months of 2025 and 2024.
For the quarter ended June 30, 2025:
| ($ MILLIONS) |
URANIUM1 | FUEL SERVICES |
WESTINGHOUSE | OTHER | TOTAL | |||||||||||||||
| Net earnings (loss) before income taxes2 |
281 | 44 | 126 | (130 | ) | 321 | ||||||||||||||
| Depreciation and amortization |
71 | 13 | — | 2 | 86 | |||||||||||||||
| Finance income |
— | — | — | (5 | ) | (5 | ) | |||||||||||||
| Finance costs |
— | — | — | 27 | 27 | |||||||||||||||
| Income taxes |
— | — | — | 71 | 71 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 352 | 57 | 126 | (35 | ) | 500 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Depreciation and amortization |
4 | — | 95 | — | 99 | |||||||||||||||
| Finance income |
(1 | ) | — | (1 | ) | — | (2 | ) | ||||||||||||
| Finance expense |
— | — | 51 | — | 51 | |||||||||||||||
| Income taxes |
7 | — | 46 | — | 53 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
10 | — | 191 | — | 201 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| EBITDA |
362 | 57 | 317 | (35 | ) | 701 | ||||||||||||||
| Loss on derivatives |
— | — | — | (163 | ) | (163 | ) | |||||||||||||
| Other operating income |
(8 | ) | — | — | — | (8 | ) | |||||||||||||
| Share-based compensation |
— | — | — | 39 | 39 | |||||||||||||||
| Unrealized foreign exchange losses |
— | — | — | 71 | 71 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 354 | 57 | 317 | (88 | ) | 640 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Inventory purchase accounting |
— | — | 5 | — | 5 | |||||||||||||||
| Restructuring costs |
— | — | 14 | — | 14 | |||||||||||||||
| Other expenses |
— | — | 16 | — | 16 | |||||||||||||||
| Unrealized foreign exchange gains |
(2 | ) | — | — | — | (2 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
(2 | ) | — | 35 | — | 33 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Adjusted EBITDA |
352 | 57 | 352 | (88 | ) | 673 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 1 | JV Inkai adjusted EBITDA of $70 million is included in the uranium segment. See Financial results by segment - Uranium for reconciliation. |
| 2 | Westinghouse earnings are after income taxes. |
- 7 -
For the quarter ended June 30, 2024:
| ($ MILLIONS) |
URANIUM1 | FUEL SERVICES |
WESTINGHOUSE | OTHER | TOTAL | |||||||||||||||
| Net earnings (loss) before income taxes2 |
192 | 33 | (47 | ) | (142 | ) | 36 | |||||||||||||
| Depreciation and amortization |
52 | 9 | — | 1 | 62 | |||||||||||||||
| Finance income |
— | — | — | (8 | ) | (8 | ) | |||||||||||||
| Finance costs |
— | — | — | 43 | 43 | |||||||||||||||
| Income taxes |
— | — | — | 18 | 18 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 244 | 42 | (47 | ) | (88 | ) | 151 | ||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Depreciation and amortization |
2 | — | 89 | — | 91 | |||||||||||||||
| Finance income |
— | — | (1 | ) | — | (1 | ) | |||||||||||||
| Finance expense |
— | — | 54 | — | 54 | |||||||||||||||
| Income taxes |
4 | — | (11 | ) | — | (7 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
6 | — | 131 | — | 137 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| EBITDA |
250 | 42 | 84 | (88 | ) | 288 | ||||||||||||||
| Gain on derivatives |
— | — | — | 14 | 14 | |||||||||||||||
| Other operating income |
(2 | ) | — | — | — | (2 | ) | |||||||||||||
| Share-based compensation |
— | — | — | 15 | 15 | |||||||||||||||
| Unrealized foreign exchange gains |
— | — | — | (7 | ) | (7 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 248 | 42 | 84 | (66 | ) | 308 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Acquisition-related transition costs |
— | — | 6 | — | 6 | |||||||||||||||
| Inventory purchase accounting |
— | — | 17 | — | 17 | |||||||||||||||
| Restructuring costs |
— | — | 11 | — | 11 | |||||||||||||||
| Other expenses |
— | — | 3 | — | 3 | |||||||||||||||
| Unrealized foreign exchange gains |
(2 | ) | — | — | — | (2 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
(2 | ) | — | 37 | — | 35 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Adjusted EBITDA |
246 | 42 | 121 | (66 | ) | 343 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 1 | JV Inkai adjusted EBITDA of $52 million is included in the uranium segment. See Financial results by segment - Uranium for reconciliation. |
| 2 | Westinghouse earnings are after income taxes. |
For the six months ended June 30, 2025:
| ($ MILLIONS) |
URANIUM1 | FUEL SERVICES |
WESTINGHOUSE | OTHER | TOTAL | |||||||||||||||
| Net earnings (loss) before income taxes2 |
509 | 112 | 64 | (294 | ) | 391 | ||||||||||||||
| Depreciation and amortization |
123 | 20 | — | 4 | 147 | |||||||||||||||
| Finance income |
— | — | — | (9 | ) | (9 | ) | |||||||||||||
| Finance costs |
— | — | — | 57 | 57 | |||||||||||||||
| Income taxes |
— | — | — | 124 | 124 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 632 | 132 | 64 | (118 | ) | 710 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Depreciation and amortization |
4 | — | 192 | — | 196 | |||||||||||||||
| Finance income |
(1 | ) | — | (1 | ) | — | (2 | ) | ||||||||||||
| Finance expense |
— | — | 100 | — | 100 | |||||||||||||||
| Income taxes |
8 | — | 29 | — | 37 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
11 | — | 320 | — | 331 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| EBITDA |
643 | 132 | 384 | (118 | ) | 1,041 | ||||||||||||||
| Loss on derivatives |
— | — | — | (175 | ) | (175 | ) | |||||||||||||
| Other operating income |
(7 | ) | — | — | — | (7 | ) | |||||||||||||
| Share-based compensation |
— | — | — | 37 | 37 | |||||||||||||||
| Unrealized foreign exchange losses |
— | — | — | 67 | 67 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 636 | 132 | 384 | (189 | ) | 963 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Inventory purchase accounting |
— | — | 5 | — | 5 | |||||||||||||||
| Restructuring costs |
— | — | 26 | — | 26 | |||||||||||||||
| Other expenses |
— | — | 30 | — | 30 | |||||||||||||||
| Unrealized foreign exchange losses |
5 | — | — | — | 5 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
5 | — | 61 | — | 66 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Adjusted EBITDA |
641 | 132 | 445 | (189 | ) | 1,029 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 1 | JV Inkai adjusted EBITDA of $114 million is included in the uranium segment. See Financial results by segment - Uranium for reconciliation. |
| 2 | Westinghouse earnings are after income taxes. |
- 8 -
For the six months ended June 30, 2024:
| ($ MILLIONS) |
URANIUM1 | FUEL SERVICES |
WESTINGHOUSE | OTHER | TOTAL | |||||||||||||||
| Net earnings (loss) before income taxes2 |
445 | 53 | (170 | ) | (299 | ) | 29 | |||||||||||||
| Depreciation and amortization |
88 | 14 | — | 2 | 104 | |||||||||||||||
| Finance income |
— | — | — | (14 | ) | (14 | ) | |||||||||||||
| Finance costs |
— | — | — | 82 | 82 | |||||||||||||||
| Income taxes |
— | — | — | 49 | 49 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 533 | 67 | (170 | ) | (180 | ) | 250 | ||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Depreciation and amortization |
10 | — | 173 | — | 183 | |||||||||||||||
| Finance income |
— | — | (3 | ) | — | (3 | ) | |||||||||||||
| Finance expense |
— | — | 118 | — | 118 | |||||||||||||||
| Income taxes |
24 | — | (48 | ) | — | (24 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
34 | — | 240 | — | 274 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| EBITDA |
567 | 67 | 70 | (180 | ) | 524 | ||||||||||||||
| Gain on derivatives |
— | — | — | 47 | 47 | |||||||||||||||
| Other operating income |
(17 | ) | — | — | — | (17 | ) | |||||||||||||
| Share-based compensation |
— | — | — | 23 | 23 | |||||||||||||||
| Unrealized foreign exchange gains |
— | — | — | (25 | ) | (25 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 550 | 67 | 70 | (135 | ) | 552 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Acquisition-related transition costs |
— | — | 24 | — | 24 | |||||||||||||||
| Inventory purchase accounting |
— | — | 66 | — | 66 | |||||||||||||||
| Restructuring costs |
— | — | 22 | — | 22 | |||||||||||||||
| Other expenses |
— | — | 15 | — | 15 | |||||||||||||||
| Unrealized foreign exchange gains |
(2 | ) | — | — | — | (2 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
(2 | ) | — | 127 | — | 125 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Adjusted EBITDA |
548 | 67 | 197 | (135 | ) | 677 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 1 | JV Inkai adjusted EBITDA of $52 million is included in the uranium segment. See Financial results by segment - Uranium for reconciliation. |
| 2 | Westinghouse earnings are after income taxes. |
CASH COST PER POUND, NON-CASH COST PER POUND AND TOTAL COST PER POUND FOR PRODUCED AND PURCHASED URANIUM
Cash cost per pound, non-cash cost per pound and total cost per pound for produced and purchased uranium are non-IFRS measures. We use these measures in our assessment of the performance of our uranium business. These measures are not necessarily indicative of operating profit or cash flow from operations as determined under IFRS.
To facilitate a better understanding of these measures, the table below reconciles these measures to cost of product sold and depreciation and amortization for the second quarter and first six months of 2025 and 2024.
| THREE MONTHS ENDED | SIX MONTHS ENDED | |||||||||||||||
| JUNE 30 | JUNE 30 | |||||||||||||||
| ($ MILLIONS) |
2025 | 2024 | 2025 | 2024 | ||||||||||||
| Cost of product sold |
417.1 | 284.7 | 781.1 | 640.5 | ||||||||||||
| Add / (subtract) |
||||||||||||||||
| Royalties |
(56.4 | ) | (32.2 | ) | (93.8 | ) | (50.0 | ) | ||||||||
| Care and maintenance costs1 |
(26.2 | ) | (11.7 | ) | (39.8 | ) | (23.8 | ) | ||||||||
| Other selling costs |
(2.8 | ) | (4.5 | ) | (6.3 | ) | (9.4 | ) | ||||||||
| Change in inventories |
(143.3 | ) | 69.6 | (191.1 | ) | 99.8 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Cash costs of production (a) |
188.4 | 305.9 | 450.1 | 657.1 | ||||||||||||
| Add / (subtract) |
||||||||||||||||
| Depreciation and amortization |
71.3 | 51.5 | 122.8 | 88.2 | ||||||||||||
| Care and maintenance costs1 |
(1.6 | ) | (0.2 | ) | (1.7 | ) | (0.4 | ) | ||||||||
| Change in inventories |
(16.1 | ) | 13.3 | (5.6 | ) | 33.6 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total production costs (b) |
242.0 | 370.5 | 565.6 | 778.5 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Uranium produced & purchased (million lb) (c) |
5.3 | 8.8 | 12.5 | 17.3 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Cash costs per pound (a ÷ c) |
35.55 | 34.76 | 36.01 | 37.98 | ||||||||||||
| Total costs per pound (b ÷ c) |
45.66 | 42.10 | 45.25 | 45.00 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| 1 | Care and maintenance costs include costs associated with Rabbit Lake and the US operations, as well as the annual maintenance shutdown at Key Lake mill which were expensed directly to cost of sales in the quarter. In 2024, the shutdown occurred in the third quarter. |
- 9 -
Management’s discussion and analysis (MD&A) and financial statements
The second quarter MD&A and unaudited condensed consolidated interim financial statements provide a detailed explanation of our operating results for the three and six months ended June 30, 2025, as compared to the same periods last year. This news release should be read in conjunction with these documents, as well as our audited consolidated financial statements and notes for the year ended December 31, 2024, first quarter and annual MD&A, 2025 first quarter and our most recent annual information form, all of which are available on our website at cameco.com, on SEDAR+ at sedarplus.ca, and on EDGAR at sec.gov/edgar.shtml.
Qualified persons
The technical and scientific information discussed in this document for our material properties McArthur River/Key Lake, Cigar Lake and Inkai was approved by the following individuals who are qualified persons for the purposes of NI 43-101:
| MCARTHUR RIVER/KEY LAKE | CIGAR LAKE | |
| • Greg Murdock, general manager, McArthur River, Cameco |
• Kirk Lamont, general manager, Cigar Lake, Cameco | |
| • Daley McIntyre, general manager, Key Lake, Cameco |
INKAI | |
| • Sergey Ivanov, deputy director general, technical services, Cameco Kazakhstan LLP | ||
Caution about forward-looking information
This news release includes statements and information about our expectations for the future, which we refer to as forward-looking information. Forward-looking information is based on our current views, which can change significantly, and actual results and events may be significantly different from what we currently expect. Examples of forward-looking information in this news release include: our perception of the constructive outlook for nuclear power and its impact on our 2025 expectations; our view that nuclear energy is on the critical path to addressing global energy security, national security and climate security; our expectation that our long-term contracts will protect us from weaker market conditions while retaining our exposure to the price improvements needed to support investments in future supply, ensuring the timing of our supply is aligned with market demand; our belief that maintaining a strong balance sheet and having financial discipline will allow us to confidently make deliberate value-adding investments as the market evolves; our view that the Dukovany power plant project reflects the growing support for nuclear power, and that such support which will have a positive impact on our uranium and fuel services businesses while creating significant future growth opportunities for Westinghouse; our view that the continued support visible in government policies, energy-intensive industries and public discourse reflects that nuclear energy is a critical solution for providing clean, constant, secure and reliable power, and that Cameco and Westinghouse are uniquely positioned to contribute to this future; our 2025 outlook for our uranium and fuel services segments; our expectations regarding our share of Westinghouse’s adjusted EBITDA and net earnings for 2025; our expectations regarding Westinghouse’s participation in the Dukovany power plant project and the associated increase in revenue; Westinghouse’s expected adjusted EBITDA growth rate over the next five years; our expectations regarding production levels and deliveries from JV Inkai; our expectations regarding our long-term contract portfolio and uranium commitment levels; our intention to broaden the ratings coverage on our debt and provide for future flexibility by obtaining a public issuer rating from Moody’s; our expectation that we will realize the benefit for JV Inkai’s 2025 financial performance in 2026 once the dividend for 2025 is declared and paid; and the expected date of the announcement of our 2025 third quarter results.
Material risks that could lead to different results include: unexpected changes in uranium supply, demand, long-term contracting, and prices; changes in consumer demand for nuclear power and uranium as a result of changing societal views and objectives regarding nuclear power, electrification and decarbonization; the risk that our views regarding nuclear power, its growth profile, and benefits, may prove to be incorrect; the risk that we may not be able to achieve planned production levels within the expected timeframes, or that the costs involved in doing so exceed our expectations; risks related to JV Inkai’s development or production, including the risk that JV Inkai is unable to transport and deliver its production; risks to Westinghouse’s business associated with potential production disruptions, the implementation of its business objectives, compliance with licensing or quality assurance requirements, or that it may otherwise be unable to achieve expected growth; the risk that we may not be able to meet sales commitments for any reason; the risks to our business associated with potential production disruptions, including those related to global supply chain disruptions, global economic uncertainty, political volatility, labour relations issues, and operating risks; the risk that we may not be able to implement our business objectives in a manner consistent with our environmental, social, governance and other values; the risk that the strategy we are pursuing may prove unsuccessful, or that we may not be able to execute it successfully; the risk that Westinghouse may not be able to implement its business objectives in a manner consistent with its or our environmental, social, governance and other values; the risk that we are adversely affected by the imposition of tariffs on Canadian energy products; the risk that the Dukovany power plant project does not result in the expected financial benefits for Westinghouse; and the risk that we may be delayed in announcing our future financial results.
- 10 -
In presenting the forward-looking information, we have made material assumptions which may prove incorrect about: uranium demand, supply, consumption, long-term contracting, growth in the demand for and global public acceptance of nuclear energy, and prices; our production, purchases, sales, deliveries and costs; the market conditions and other factors upon which we have based our future plans and forecasts; our contract pipeline discussions; JV Inkai production and our allocation of planned production and timing of deliveries; assumptions about Westinghouse’s production, purchases, sales, deliveries and costs, the absence of business disruptions, and the success of its plans and strategies; the success of our plans and strategies, including planned production; the absence of new and adverse government regulations, policies or decisions; that there will not be any significant adverse consequences to our business resulting from production disruptions, including those relating to supply disruptions, economic or political uncertainty and volatility, labour relations issues, aging infrastructure, and operating risks; the assumptions relating to Westinghouse’s adjusted EBITDA and net income; the assumption that we would not be adversely affected by the imposition of tariffs on Canadian energy products; the financial benefits of the Dukovany power plant project for Westinghouse; and our ability to announce future financial results when expected.
Please also review the discussion in our 2024 annual MD&A, our 2025 first quarter MD&A and our most recent annual information form for other material risks that could cause actual results to differ significantly from our current expectations, and other material assumptions we have made. Forward-looking information is designed to help you understand management’s current views of our near-term and longer-term prospects, and it may not be appropriate for other purposes. We will not necessarily update this information unless we are required to by securities laws.
Conference call
We invite you to join our second quarter conference call on Thursday, July 31, 2025, at 8:00 a.m. Eastern.
The call will be open to all investors and the media. To join the call, please dial please dial (833) 821-3311 (Canada and US) or (647) 846-2607. An operator will put your call through. The slides and a live webcast of the conference call will be available from a link at cameco.com. See the link on our home page on the day of the call.
A recorded version of the proceedings will be available:
| • | on our website, cameco.com, shortly after the call |
| • | on post view until midnight, Eastern, August 31, 2025, by calling (855) 669-9658 (Canada/ USA toll-free) or (412) 317-0088 (International toll) (Passcode 3789618) |
2025 third quarter report release date
We plan to announce our 2025 third quarter results before markets open on Wednesday, November 5, 2025.
Profile
Cameco is one of the largest global providers of the uranium fuel needed to power a secure energy future. Our competitive position is based on our controlling ownership of the world’s largest high-grade reserves and low-cost operations, as well as significant investments across the nuclear fuel cycle, including ownership interests in Westinghouse Electric Company and Global Laser Enrichment. Utilities around the world rely on Cameco to provide global nuclear fuel solutions for the generation of safe, reliable, carbon-free nuclear power. Our shares trade on the Toronto and New York stock exchanges. Our head office is in Saskatoon, Saskatchewan, Canada.
As used in this news release, the terms we, us, our, the Company and Cameco mean Cameco Corporation and its subsidiaries unless otherwise indicated.
- End -
| Investor inquiries | Media inquiries | |
| Cory Kos | Veronica Baker | |
| 306-716-6782 | 306-385-5541 | |
| cory_kos@cameco.com | veronica_baker@cameco.com |
- 11 -
Exhibit 99.2
Management’s discussion and analysis
for the quarter ended June 30, 2025
| 6 | SECOND QUARTER MARKET UPDATE | |
| 9 | OUR STRATEGY | |
| 12 | CONSOLIDATED FINANCIAL RESULTS | |
| 16 | OUTLOOK FOR 2025 | |
| 21 | LIQUIDITY AND CAPITAL RESOURCES | |
| 24 | FINANCIAL RESULTS BY SEGMENT | |
| 28 | OUR OPERATIONS - SECOND QUARTER UPDATES | |
| 30 | QUALIFIED PERSONS | |
| 30 | NON-IFRS MEASURES | |
| 36 | ADDITIONAL INFORMATION | |
This management’s discussion and analysis (MD&A) includes information that will help you understand management’s perspective of our unaudited condensed consolidated interim financial statements and notes for the quarter ended June 30, 2025 (interim financial statements). The information is based on what we knew as of and through July 30, 2025, and updates our first quarter and annual MD&A included in our 2024 annual report.
As you review this MD&A, we encourage you to read our interim financial statements as well as our audited consolidated financial statements and notes for the year ended December 31, 2024, and annual MD&A. You can find more information about Cameco, including our audited consolidated financial statements and our most recent annual information form, on our website at cameco.com, on SEDAR+ at sedarplus.ca or on EDGAR at sec.gov. You should also read our annual information form before making an investment decision about our securities.
The financial information in this MD&A and in our financial statements and notes are prepared according to International Financial Reporting Standards (IFRS), unless otherwise indicated.
Unless we have specified otherwise, all dollar amounts are in Canadian dollars.
Throughout this document, the terms we, us, our and Cameco mean Cameco Corporation and its subsidiaries unless otherwise indicated.
Caution about forward-looking information
Our MD&A includes statements and information about our expectations for the future. When we discuss our strategy, plans, future financial and operating performance, or other things that have not yet taken place, we are making statements considered to be forward-looking information or forward-looking statements under Canadian and United States (US) securities laws. We refer to them in this MD&A as forward-looking information.
Key things to understand about the forward-looking information in this MD&A:
| • | It typically includes words and phrases about the future, such as: anticipate, believe, estimate, expect, forecast, goal, intend, outlook, plan, project, strategy, target, vision, and will (see examples below). |
| • | It represents our current views and can change significantly. |
| • | It is based on a number of material assumptions, including those we have listed starting on page 4, which may prove to be incorrect. |
| • | Actual results and events may be significantly different from what we currently expect, due to the risks associated with our business. We list a number of these material risks below. We recommend you also review our most recent annual information form and annual MD&A, which includes a discussion of other material risks that could cause actual results to differ significantly from our current expectations. |
| • | Forward-looking information is designed to help you understand management’s current views of our near-term and longer-term prospects, and it may not be appropriate for other purposes. We will not necessarily update this information unless we are required to by applicable securities laws. |
Examples of forward-looking information in this MD&A
| • | our expectations regarding 2025 and future uranium supply, demand, contracting, geopolitical issues, and the market, including the discussion under the heading Second quarter market update |
| • | the discussion under the heading Our strategy, including the role of nuclear energy in the world’s shift to a low-carbon, climate-resilient economy, our expectation that our strategy will allow us to increase long-term value, our intention to execute our strategy with an emphasis on safety, people and the environment, our aim to expand global nuclear capacity and help support energy growth, national security objectives and the transition to a low-carbon economy through our strategic initiatives, our belief that we have the right strategy to achieve our vision and will do so in a manner that reflects our values, our intention to be transparent with our stakeholders regarding risks and opportunities that may impact our strategic plan and our expected financial capacity to execute our strategy, invest in new opportunities and self-manage risk |
| • | the discussion under the heading Strategy in action, including expected Westinghouse Electric Company (Westinghouse) segment performance, our expectations regarding Westinghouse’s participation in the Dukovany power plant project and the associated increase in revenue, our expectations regarding uranium contracting, our contract portfolio and market conditions, our expectation regarding uranium production levels, our expectations regarding production levels and deliveries from JV Inkai, our annual production expectation for our fuel services division, and our expectation that we will maintain the financial strength and flexibility necessary to execute our strategy |
| • | our expectation that Westinghouse’s second quarter performance will be its strongest quarter of 2025 due to its participation in the Dukovany power plant project, and our expectation regarding Westinghouse’s cash flows for the fourth quarter of 2025 |
| • | our expectation that the imposition of tariffs would not materially impact our 2025 financial results |
| • | the discussion of our expectations relating to our Canada Revenue Agency (CRA) transfer pricing dispute, our confidence that the courts would reject any attempt by CRA to utilize the same position and arguments for tax years 2007 through 2014 or the alternate position advanced for tax years 2014 through 2017, or the new reassessing position for 2018, and our belief that CRA should return the full amount of cash and security that has been paid or otherwise secured by us |
| • | the discussion under the heading Outlook for 2025, including our production plan, our planned production levels, our expectation of strong financial performance in 2025, our expectation that our cash balance could increase if there are further distributions from Westinghouse in 2025, expected care and maintenance costs for our tier-two assets, our cost of sales in our uranium and fuel services segments, and other information in the table under the heading 2025 Financial Outlook, our revenue, adjusted net earnings, and cash flow sensitivity analysis, our price sensitivity analysis for our uranium segment, our expected share of adjusted EBITDA, net earnings and income tax expense from our equity investment in Westinghouse, Westinghouse’s expected adjusted EBITDA in 2025 and compound annual adjusted EBITDA growth rate over the next five years, and our intention to update the table under the heading Expected realized uranium price sensitivity under various spot price assumptions at June 30, 2025 each quarter to reflect deliveries made and changes to our contract portfolio |
| • | the discussion under the heading Liquidity and capital resources, including our available alternatives to fund future capital requirements, our intention of broadening the ratings coverage on our debt and providing future flexibility by obtaining a third public issuer rating, our expectation that the low-cost production from our tier one assets will generate strong cash flows which will meet our capital requirements during 2025, our belief that we have sufficient borrowing capacity, and our expectations regarding our contract portfolio and uranium commitment levels |
2 CAMECO CORPORATION
| • | our expectation that our operating and investment activities for the remainder of 2025 will not be constrained by the covenants in our credit agreements, including the financial covenants, and our intention to update the table under the heading Purchase commitments to reflect material changes to our purchase commitments and changes in the prices used to estimate our commitments under market-related contracts |
| • | the discussion of the impact of potential disruptions to JV Inkai’s operations, and the expectation that the benefit from JV Inkai’s 2025 financial performance will be realized later in 2026 once the dividend for 2025 from JV Inkai is paid |
| • | our future plans and expectations for our uranium operating properties including the expected timing of the annual maintenance shutdowns for Cigar Lake, expected production levels for McArthur River/Key Lake, Cigar Lake and JV Inkai, the potential impact of development delays at McArthur River on our packaged production, the expectation that the impact of any labour dispute with United Steelworkers Local 8914 would be minimal in 2025, our expectations regarding the timing of the delivery of our share of JV Inkai’s 2024 and 2025 production, the potential impact of delays in our expected JV Inkai deliveries, and our ability to draw upon inventory, long-term purchase agreements and loan arrangements to mitigate the risks of further delays in JV Inkai deliveries |
| • | the expected care and maintenance costs for our US ISR operations and Rabbit Lake for 2025 |
| • | our future plans and expectations for our fuel services operating sites, including our annual production expectation, and our continued work to achieve and maintain an ongoing production rate which satisfies long-term commitments and the demand for conversion services |
Material Risks
| • | actual sales volumes or market prices for any of our products or services are lower than we expect, or cost of sales is higher than we expect, for any reason, including changes in market prices, loss of market share to a competitor, trade restrictions, or geopolitical issues |
| • | we are adversely affected by changes in currency exchange rates, interest rates, royalty rates, tax rates or inflation |
| • | our production costs are higher than planned, or necessary supplies are not available, or not available on commercially reasonable terms |
| • | our strategies may change, be unsuccessful or have unanticipated consequences, or we may not be able to achieve anticipated operational flexibility and efficiency |
| • | changing views of governments regarding the pursuit of carbon reduction strategies or that our view on the role of nuclear power in pursuit of those strategies may prove to be inaccurate |
| • | our estimates and forecasts prove to be inaccurate, including production, purchases, deliveries, cash flow, revenue, costs, decommissioning, reclamation expenses, or the receipt of future dividends from JV Inkai |
| • | that we may not realize expected benefits from the Westinghouse acquisition |
| • | that Westinghouse fails to generate sufficient cash flow to fund its approved annual operating budget or make distributions to the partners |
| • | the risk that we and Westinghouse may not be able to meet sales commitments for any reason |
| • | the risk that Westinghouse may not achieve the expected growth in its business |
| • | the risk to Westinghouse’s business associated with potential production disruptions, including those related to global supply chain disruptions, global economic uncertainty, political |
| volatility, labour relations issues, and operating risks |
| • | the risk that Westinghouse may not be able to implement its business objectives in a manner consistent with its or our environmental, social, governance and other values |
| • | the risk that Westinghouse’s strategies may change, be unsuccessful, or have unanticipated consequences |
| • | the risk that Westinghouse may be unsuccessful in respect of its new business |
| • | the risk that Westinghouse may fail to comply with nuclear licence and quality assurance requirements at its facilities |
| • | the risk that Westinghouse may lose protections against liability for nuclear damage, including discontinuation of global nuclear liability regimes and indemnities |
| • | the risk that increased trade barriers may adversely impact Westinghouse’s business |
| • | the risk that Westinghouse may default under its credit facilities, adversely impacting Westinghouse’s ability to fund its ongoing operations and to make distributions |
| • | the risk that liabilities of Westinghouse may exceed our estimates and the discovery of unknown or undisclosed liabilities |
| • | the risk that occupational health and safety issues may arise at Westinghouse’s operations |
| • | the risk that there may be disputes between us and Brookfield Renewable Partners and its institutional partners (collectively, Brookfield) regarding our strategic partnership |
| • | the risk that we may default under the governance agreement with Brookfield, including the potential loss of some or all of our interest in Westinghouse |
| • | the risk that we are unable to enforce our legal rights under our agreements, permits or licences |
| • | disruption or delay in the transportation of our products |
| • | that we are subject to litigation or arbitration that has an adverse outcome |
| • | that the courts may accept the same, similar or different positions and arguments advanced by CRA to reach decisions that are adverse to us for other tax years |
2025 SECOND QUARTER REPORT 3
| • | the possibility of a materially different outcome in disputes with CRA for other tax years |
| • | that CRA does not agree that the court rulings for the years that have been resolved in our favour should apply to subsequent tax years |
| • | that CRA will not return all or substantially all of the cash and security that has been paid or otherwise secured in a timely manner, or at all |
| • | there are defects in, or challenges to title, to our properties |
| • | our mineral reserve and resource estimates are not reliable, or there are unexpected or challenging geological, hydrological or mining conditions |
| • | we are affected by environmental, safety and regulatory risks, including workforce health and safety or increased regulatory burdens or delays |
| • | necessary permits or approvals from government authorities cannot be obtained or maintained |
| • | we are affected by political risks, including unrest in Kazakhstan, and geopolitical events, including the Russian invasion of Ukraine |
| • | operations are disrupted due to problems with our own or our joint venture partners’, suppliers’ or customers’ facilities, the unavailability of reagents, equipment, operating parts and supplies critical to production, equipment failure, lack of tailings capacity, labour shortages, labour relations issues, strikes or lockouts, fires, underground floods, cave-ins, ground movements, tailings dam failures, tariffs, transportation disruptions or accidents, aging infrastructure, or other development and operating risks |
| • | we are affected by war, terrorism, cyber-attacks, sabotage, blockades, civil unrest, social or political activism, outbreak of illness (such as a pandemic like COVID-19), accident or a deterioration in political support for, or demand for, nuclear energy |
| • | a major accident at a nuclear power plant |
| • | we are impacted by changes in the regulation or public perception of the safety of nuclear power plants, which adversely affect the construction of new plants, the relicensing of existing plants and the demand for uranium |
| • | government laws, regulations, policies or decisions that adversely affect us, including tax and trade laws and sanctions on nuclear fuel exports and imports |
| • | our uranium suppliers or purchasers fail to fulfil their commitments |
| • | our McArthur River development, mining or production plans are delayed or do not succeed for any reason |
| • | our Key Lake mill production plan is delayed or does not succeed for any reason |
| • | our Cigar Lake development, mining or production plans are delayed or do not succeed for any reason |
| • | JV Inkai’s development, mining or production plans are delayed or do not succeed for any reason, JV Inkai is unable to transport and deliver its production, or JV Inkai is unable to successfully manage several ongoing risks, including the availability of sulfuric acid, procurement and supply chain issues, transportation challenges, construction delays and inflationary pressures on its production costs |
| • | our production plan for our Port Hope UF6 conversion facility is delayed or does not succeed for any reason, including due to the availability of production supplies |
| • | our expectations relating to care and maintenance costs prove to be inaccurate |
| • | we are affected by natural phenomena, such as forest fires, floods and earthquakes as well as shifts in temperature, precipitation, and the impact of more frequent severe weather conditions on our operations as a result of climate change |
| • | natural uranium, UF6, and enriched uranium are no longer excluded from potential tariffs on Canadian energy products, and we and Westinghouse are adversely affected by the imposition of tariffs |
| • | the Dukovany power plant project does not result in the expected financial benefits for Westinghouse |
Material Assumptions
| • | our expectations regarding sales and purchase volumes and prices for uranium and fuel services, cost of sales, trade restrictions, inflation, and that counterparties to our sales and purchase agreements will honour their commitments |
| • | our expectations for the nuclear industry, including its growth profile, market conditions, geopolitical issues, and the demand for and supply of uranium |
| • | the continuing pursuit of energy, national and climate security strategies by governments and the role of nuclear in the pursuit of those strategies |
| • | the assumptions discussed under the heading 2025 Financial Outlook, including the assumptions used to prepare the outlook table and assumptions relating to growth in Westinghouse adjusted EBITDA |
| • | our expectations regarding spot prices and realized prices for uranium, and other factors discussed under the heading Price sensitivity analysis: uranium segment |
| • | that the construction of new nuclear power plants and the relicensing of existing nuclear power plants will not be adversely affected by changes in regulation or in the public perception of the safety of nuclear power plants |
| • | our ability to continue to supply our products and services in the expected quantities and at the expected times |
| • | our expected production levels for Cigar Lake, McArthur River/Key Lake, JV Inkai and our fuel services operating sites |
| • | plans to transport our products succeed, including the shipment of our share of JV Inkai’s production |
| • | our ability to mitigate adverse consequences of production shortfalls or delays in the shipment of our share of JV Inkai production |
| • | our cost expectations, including production costs, operating costs, and capital costs |
| • | our expectations regarding tax payments, tax rates, royalty rates, currency exchange rates, interest rates and inflation |
4 CAMECO CORPORATION
| • | in our dispute with CRA that courts will reach consistent decisions for other tax years that are based upon similar positions and arguments |
| • | that CRA will not successfully advance different positions and arguments that may lead to different outcomes for other tax years |
| • | our expectation that we will recover all or substantially all of the amounts paid or secured in respect of the CRA dispute to date |
| • | our decommissioning and reclamation estimates, including the assumptions upon which they are based, are reliable |
| • | our mineral reserve and resource estimates, and the assumptions upon which they are based, are reliable |
| • | our understanding of the geological, hydrological and other conditions at our uranium properties |
| • | our McArthur River and Cigar Lake development, mining and production plans succeed |
| • | our Key Lake mill production plans succeed |
| • | JV Inkai’s development, mining and production plans succeed, that JV Inkai will be able to deliver its production, and that JV Inkai is able to successfully manage several ongoing risks, including the availability of sulfuric acid, procurement and supply chain issues, transportation challenges, construction delays and inflationary pressures on its production costs |
| • | the ability of JV Inkai to pay dividends |
| • | our production plan for our Port Hope UF6 conversion facility succeeds |
| • | that care and maintenance costs will be as expected |
| • | our and our contractors’ ability to comply with current and future environmental, safety and other regulatory requirements and to obtain and maintain required regulatory approvals |
| • | neither our operations, nor those of our joint venture partners, suppliers or customers, are significantly disrupted as a result of political instability, nationalization, terrorism, sabotage, blockades, civil unrest, breakdown, climate change, natural disasters, aging infrastructure, forest or other fires, outbreak of illness (such as a pandemic like COVID-19), governmental, political or regulatory actions, litigation or arbitration proceedings, cyber-attacks, the unavailability of reagents, equipment, operating parts and supplies critical to production, labour shortages, labour relations issues, strikes or lockouts, health and safety issues, underground floods, increased loadings into the environment, cave-ins, ground movements, tailings dam failure, lack of tailings capacity, improper air emission or treated water releases, transportation disruptions or accidents, tariffs, aging infrastructure, or other development or operating risks |
| • | Westinghouse’s ability to generate cash flow and fund its approved annual operating budget and make distributions to the partners |
| • | our ability to compete for additional business opportunities so as to generate additional revenue for us as a result of the Westinghouse acquisition |
| • | the success of our plans and strategies related to Westinghouse |
| • | Westinghouse’s production, purchases, sales, deliveries, and costs |
| • | the assumptions and discussion set out under the heading Outlook for 2025 |
| • | the market conditions and other factors upon which we have based Westinghouse’s future plans and forecasts |
| • | Westinghouse’s ability to mitigate adverse consequences of delays in production and construction |
| • | the success of Westinghouse’s plans and strategies |
| • | the absence of new and adverse government regulations, policies or decisions |
| • | that there will not be any significant adverse consequences to Westinghouse’s business resulting from business disruptions, including those relating to supply disruptions, economic or trade policy decisions, political uncertainty and volatility, labour relation issues, and operating risks |
| • | Westinghouse will comply with the covenants in its credit agreement |
| • | Westinghouse will comply with nuclear licence and quality assurance requirements at its facilities |
| • | Westinghouse maintaining protections against liability for nuclear damage, including continuation of global nuclear liability regimes and indemnities |
| • | that known and unknown liabilities at Westinghouse will not materially exceed our estimates |
| • | natural uranium, UF6, and enriched uranium will remain excluded from potential tariffs on Canadian energy products, and that we and Westinghouse would not be adversely affected by the imposition of tariffs |
| • | the financial benefits of the Dukovany power plant project for Westinghouse |
2025 SECOND QUARTER REPORT 5
Second quarter market update
Geopolitical uncertainty and heightened concerns about energy security, national security, and climate security continue to improve the demand fundamentals for the nuclear power industry in the face of increasing risk to the long-term fuel cycle supplies that are required to support it.
In the second quarter of 2025, the long-term uranium price held at $80 (US), remaining near its highest level since 2012 (in 2025 constant dollars), while the uranium spot price ended the quarter at $78.50 (US). Over the past two years, fuel buyers have continued to focus on securing their long-term requirements for downstream conversion and enrichment services amid uncertain market access and global trade policies, which has resulted in higher prices across the fuel cycle. The uncertainty has delayed a return to the procurement of the uranium required to feed into those services – a return that we believe is unavoidable. A similar focus on security of supply is expected to move upstream to uranium, driven by requests for proposals from utilities and traditional demand entering the market, alongside inbound requests for direct long-term off-market negotiations. Requests for proposals from non-utility, non-traditional customers in energy intensive sectors that are examining long-term nuclear fuel supplies may also add pressure to future uranium supply.
Some of the more significant developments affecting supply in the quarter and to date include:
| • | The Sprott Physical Uranium Trust’s (SPUT) at-the-market offering structure only allows it to raise funds to purchase uranium by selling units into the market when trading at a premium to its net asset value. However, volatility in equity markets has kept SPUT at a discount to its net asset value for most of 2025. SPUT raised $25.6 million (US) through a private placement in May, followed by an additional $200 million (US) bought deal financing raise in June. As a result, SPUT was able to acquire over 2 million pounds of U3O8, bringing total purchases since inception to nearly 50 million pounds U3O8. |
| • | In June, Niger announced plans to nationalize the SOMAIR mine, which was operated under a joint venture between Orano and the Office National des Ressources Minieres du Niger. Previously, in October 2024, Orano announced a temporary suspension of operations at SOMAIR due to financial strain from the 2023 coup and supply route closures, later confirming in December that Nigerien authorities had assumed control amid escalating tensions with the ruling junta. |
| • | In June, Peninsula Energy Ltd. announced a ‘Reset Plan,’ which decreased its 2026 and 2027 production outlook for the Lance ISR uranium project in Wyoming. Peninsula also announced the mutual termination of three uranium supply contracts with global power utility companies that totaled 1.95 million pounds of U3O8 over eight years. |
| • | In May, the European Commission (EC) outlined an initiative to phase out Russian energy imports, including nuclear materials, across the European Union (EU), through a roadmap that restricts new supply contracts co-signed by the Euratom Supply Agency for uranium, enriched uranium and other nuclear materials derived from Russia. The EC is working on diversifying nuclear fuel supplies and creating strategic stockpiles of critical minerals, including nuclear fuel, in response to escalating geopolitical tensions and climate related risks. |
| • | In May, Global Laser Enrichment, LLC (GLE) announced the commencement of its Technology Readiness Level 6 demonstration testing at its Test Loop facility in Wilmington, North Carolina. Additionally, in July, GLE announced the submission of its Safety Analysis Report to the US Nuclear Regulatory Commission (NRC), completing the company’s full licence application for the planned Paducah Laser Enrichment Facility in Kentucky. GLE (jointly owned by Silex Systems Limited and Cameco) expects to begin production in 2030. |
According to the International Atomic Energy Agency (IAEA), globally, there are currently 439 operable reactors and 62 reactors under construction. Demand-related developments continue to suggest growing support for the nuclear industry, with 31 countries pledging to triple their nuclear power capacity by 2050. Many nations are reaffirming their commitment to existing nuclear and/or reversing policies to phase out nuclear, non-nuclear countries are emerging as candidates for new nuclear capacity, improvements are being made in global sustainable financing policies to include nuclear energy, and opinion polls indicate improving public support. With several reactors being saved from early retirement, life-extensions to existing reactors being sought and approved, and new build construction projects underway and many more planned, demand for uranium fuel continues to improve in the near-, medium- and long-term.
The more significant developments in the quarter affecting current and future demand include:
| • | The World Bank lifted its long-standing ban on nuclear financing in June, marking a major policy shift and opening the door for collaboration with the IAEA and focusing on financing life extensions and potential new builds in developing countries. |
6 CAMECO CORPORATION
| • | In June, the China Nuclear Energy Authority reported that China is on track to double its current nuclear capacity (operating and under construction) and reach 200 GWe of nuclear capacity by 2040. This strategy requires shifting away from coal and would increase nuclear energy’s share of China’s energy mix from about 2% today, to approximately 10% in 2040. |
| • | In May, Sweden’s parliament approved funding for up to four new large-scale reactors (5 GWe total) by 2045 to meet the country’s 2045 net zero target, with plans for half the capacity to be online by 2035. |
| • | In the Czech Republic, Korea Hydro & Nuclear Power (KHNP) signed an engineering, procurement and construction contract to build two APR-1000 reactors at the Dukovany site, marking a diversification from the country’s six operating Russian VVER reactors. This is KHNP’s first nuclear project in Europe and first major overseas project since the Barakah project in the UAE. |
| • | In the UK, the construction of Sizewell-C’s two EPR reactors, totaling 3.2 GWe of capacity, received a final investment on the £38 billion project. The UK government will be the largest shareholder at 44.9%, alongside Canadian investment fund La Caisse (20%), British multinational energy and services company Centrica (15%), EDF (12.5%), and Amber Infrastructure (7.6%). |
| • | In Spain, the Spanish People’s Party announced it would present a bill to congress proposing to reverse the country’s 2035 nuclear phase-out following severe power blackouts in the country in April. |
| • | The French Lower House of Parliament approved a sweeping legislative measure outlining to raise nuclear capacity by 27 GWe by 2050. |
| • | In the US, Constellation signed a milestone 20-year power purchase agreement (PPA) with Meta to supply 1.1 GWe of carbon-free electricity starting in mid-2027. As a result, Constellation’s Clinton Clean Energy Center, which had been slated to potentially close after 2027 due to the loss of the zero-emissions credit program, will now continue to operate through 2047. Additionally, Constellation’s restart of Unit 1 at the Crane Clean Energy Centre under a 20-year PPA with Microsoft, is reported to be ahead of schedule and now expected to recommence operations in 2027 (previously 2028). |
| • | Talen Energy and Amazon announced a major expansion to their existing agreement to have Talen Energy supply up to 1.9 GWe of nuclear power through at least 2042. Alongside this agreement, Talen Energy and Amazon plan to explore the possibility of building small modular reactors (SMR) in Pennsylvania. |
| • | Governor Hochul of New York State directed the New York Power Authority and Department of Public Service to begin the development of at least 1 GWe of new nuclear capacity in upstate New York, hinting at broader fleet-style deployment. |
| • | On May 23, US President Trump signed four executive orders to reshape the federal government’s role in nuclear energy by coordinating agency efforts, accelerating advanced reactor deployment, and reinforcing US global leadership in the sector. The orders aim to support quadrupling US nuclear capacity to 400 GWe by 2050, focusing on reform of the NRC, deploying advanced nuclear reactor technologies for national security, reinvigorating the nuclear industrial base, and reforming nuclear research and development at the US DOE. In addition, in June the US Budget Bill was released, proposing sweeping energy-related changes from those approved in the Inflation Reduction Act (IRA), although it preserves key nuclear tax credits, supporting existing and restarting reactors, while cutting other clean energy incentives for solar, wind, and hydrogen. Finally, the US DOE announced a new pilot program to test advanced reactors outside of national labs, aiming for three reactors to reach criticality by July 2026. |
| • | On July 25, the Emirates Nuclear Energy Company and Westinghouse signed a Memorandum of Understanding (MOU) to explore collaborative opportunities for the deployment of advanced nuclear solutions in the US. Under the MOU, the companies will look to accelerate the deployment of AP1000 reactors in the US to meet the US’ goals of quadrupling nuclear power by 2050 and having 10 large scale nuclear reactors under construction by 2030 |
| • | In Canada, the Ontario government approved four GE-Hitachi BWRX-300 SMRs at Ontario Power Group’s Darlington site in May, at an estimated total cost of $20.6 billion, marking Canada’s first major nuclear expansion in over 30 years. The first of the four units is slated to enter service at the end of 2030, at which time it would be the first commercial SMR in North America. In June, the Ontario government launched its “Energy for Generations” – the province’s first integrated energy plan to power Canada. It notes to meet growing electricity demand, Ontario will invest in the largest nuclear buildout on the continent. |
Caution about forward-looking information relating to the nuclear industry
This discussion of our expectations for the nuclear industry, including its growth profile, uranium supply and demand, and reactor growth is forward-looking information that is based upon the assumptions and subject to the material risks discussed under the heading Caution about forward-looking information beginning on page 2.
2025 SECOND QUARTER REPORT 7
Industry prices at quarter end
| JUN 30 | MAR 31 | DEC 31 | SEP 30 | JUN 30 | MAR 31 | |||||||||||||||||||
| 2025 | 2025 | 2024 | 2024 | 2024 | 2024 | |||||||||||||||||||
| Uranium ($US/lb U3O8)1 |
||||||||||||||||||||||||
| Average spot market price |
78.50 | 64.23 | 72.63 | 82.00 | 84.25 | 87.75 | ||||||||||||||||||
| Average long-term price |
80.00 | 80.00 | 80.50 | 81.50 | 79.50 | 77.50 | ||||||||||||||||||
| Fuel services ($US/kgU as UF6)1 |
||||||||||||||||||||||||
| Average spot market price |
||||||||||||||||||||||||
| North America |
69.00 | 81.00 | 97.00 | 72.00 | 60.00 | 58.00 | ||||||||||||||||||
| Europe |
69.00 | 81.00 | 96.00 | 72.00 | 60.00 | 58.00 | ||||||||||||||||||
| Average long-term price |
||||||||||||||||||||||||
| North America |
50.50 | 50.00 | 50.00 | 43.25 | 38.00 | 35.50 | ||||||||||||||||||
| Europe |
50.00 | 49.50 | 49.50 | 43.25 | 38.00 | 35.50 | ||||||||||||||||||
Note: the industry does not publish UO2 prices.
| 1 | Average of prices reported by TradeTech and UxC |
On the spot market, where purchases call for delivery within one year, the volume reported by UxC for the second quarter of 2025 was 15 million pounds U3O8 equivalent, compared to 13 million pounds U3O8 equivalent over the same period in 2024. As of June 30, 2025, the average reported spot price was $78.50 (US) per pound U3O8 equivalent, an increase of $14.27 (US) per pound from the previous quarter.
Long-term contracts generally call for deliveries to begin more than two years after the contract is finalized, and use a number of pricing formulas, including base-escalated prices set at time of contracting and escalated over the term of the contract, and market-related prices, which reference spot and/or long-term indicators and are generally set a month or more prior to delivery, typically including floor prices and ceiling prices that are also escalated to time of delivery. Long-term contracting reported by UxC through the first six months to June 30, 2025, totaled about 27 million pounds U3O8 equivalent, down from about 32 million pounds U3O8 equivalent reported over the same period in 2024. Long-term uranium contracting remains moderate, due to global macro-economic uncertainty, and customers’ focus on downstream services driven by continuing geopolitical tensions.
The average reported long-term price at the end of the quarter was $80.00 (US) per pound U3O8 equivalent, which remains unchanged from the previous quarter.
With consistent demand for western conversion services, pricing in both North America and Europe continues to be strong, despite the downward price trend. At the end of the second quarter, the average reported spot price for conversion was $69.00 (US) per kilogram uranium (kgU) as UF6, down $12.00 (US) from the previous quarter. The average long-term UF6 conversion price for North America finished the quarter at $50.50 (US) per kgU as UF6, an increase of $0.50 (US) from the previous quarter.
8 CAMECO CORPORATION
Our strategy
We are a pure-play investment in the growing demand for nuclear energy, focused on taking advantage of the near-, medium- and long-term growth occurring in our industry. We provide nuclear fuel and nuclear power products, services and technologies across the fuel and reactor life cycles, augmented by our investment in Westinghouse, that supports the generation of carbon-free, reliable, secure and affordable energy. Our strategy is set within the context of what we believe is a transitioning market environment. Increasing populations, a growing focus on electrification and decarbonization, and concerns about energy security and affordability are driving a global focus on tripling nuclear power capacity by 2050, which is expected to durably strengthen long-term fundamentals for our industry. Nuclear energy must be a central part of the solution to achieving energy growth and national security objectives, and helping the world shift to a low-carbon, climate resilient economy. It is an option that can provide the necessary power in a carbon-free, reliable and affordable manner.
Our strategy is to capture full-cycle value by:
| • | remaining disciplined in our contracting activity, building a balanced portfolio in accordance with our contracting framework |
| • | profitably producing from our tier-one assets and aligning our production decisions in all segments of our business with our contract portfolio and customer needs |
| • | being financially disciplined to allow us to |
| • | execute on our strategy |
| • | invest in new opportunities that are expected to add long-term value |
| • | self-manage risk |
| • | exploring other emerging opportunities within the nuclear power value chain that align with our commitment to manage our business responsibly and sustainably, contribute to decarbonization, and help to provide secure and affordable energy |
We expect our strategy will allow us to increase long-term value, and we will execute it with an emphasis on safety, people and the environment.
Our vision – “Powering a secure energy future” – recognizes that we have an important role to play in achieving energy security, national security and climate security. Our uranium and fuel services are used around the world in the generation of safe, reliable, carbon-free, baseload nuclear power, which is crucial to energy security. In times of geopolitical uncertainty, a secure source of nuclear fuel is more important than ever as it also supports national security objectives. Additionally, Cameco supports climate security by enabling the generation of carbon-free nuclear power, helping to reduce greenhouse gas emissions and combat climate change. Cameco’s strategic initiatives, such as its partnership with Net Zero Nuclear, aim to expand global nuclear capacity and support the transition to a low-carbon economy.
We believe we have the right strategy to achieve our vision, and we will do so in a manner that reflects our values. For more than 35 years, we have been committed to operating and delivering our products responsibly and profitably. We integrate sustainability principles and practices into every aspect of our business, from our corporate objectives and approach to compensation to our overall corporate strategy, risk management, and day-to-day operations, and they align with our values. We seek to be transparent with our stakeholders, keeping them updated on the risks and opportunities that we believe may have a significant impact on our ability to achieve our strategic plan and add long-term value. We recognize the importance of integrating certain sustainability factors, such as safety performance, a clean environment and supportive communities, into our executive compensation strategy as we see success in these areas as critical to the long-term success of the company.
You can read more about our strategy in our 2024 annual MD&A and our approach to sustainability in our 2024 Sustainability Report.
Strategy in action
With the ongoing transition and improvements in the nuclear fuel market, our three-pillar strategy is guiding our disciplined contracting, supply and financial decisions.
Results in the second quarter were strong with net earnings of $321 million, adjusted net earnings of $308 million, and adjusted EBITDA of $673 million, all significantly higher than in the second quarter of 2024. Both net earnings and adjusted net earnings were up by over 100% compared to the same period in 2024 largely due to stronger equity earnings from our investment in Westinghouse and strong performance in our uranium and fuel services segments. During the first half of the year, net earnings of $391 million, adjusted net earnings of $378 million and adjusted EBITDA of $1.0 billion were also significantly higher than in 2024.
2025 SECOND QUARTER REPORT 9
In our core uranium segment, net earnings were $281 million and adjusted EBITDA was $352 million compared to $192 million and $246 million in 2024, respectively, mainly as a result of higher sales volume and average realized prices. Average realized price continued to show improvements as prices from fixed price contracts increased and the US dollar was stronger than in the second quarter of 2024. See Outlook on page 16 and Financial results by segment – Uranium on page 24 for more information.
Westinghouse reported net earnings of $126 million (our share) for the second quarter, up from a loss of $47 million (our share) in the second quarter of 2024. The improvement over the last year is primarily due to Westinghouse’s participation in the construction project for two nuclear reactors at the Dukovany power plant in the Czech Republic, which resulted in approximately $170 million (US) increase in our share of Westinghouse’s 2025 second quarter revenue. In addition to the increased revenue in the second quarter, we expect significant future financial benefits for Westinghouse, as a subcontractor, over the term of the construction project and related to the provision of the fuel fabrication services for both reactors for a specified period of time. Also, Westinghouse’s net earnings for the comparative 2024 period were impacted by the sale of inventories held at the time of acquisition, which, due to purchase accounting, required revaluation based on market prices at time of acquisition and expensing as the acquired inventory was sold. The impact of this was largely isolated to the first half of 2024. To better reflect the underlying operating performance, we use adjusted EBITDA as a performance measure for Westinghouse. In the second quarter of 2025, our share of Westinghouse’s adjusted EBITDA was $352 million, compared to $121 million in the second quarter of 2024, mainly as a result of the increased revenue in the second quarter noted above. In June, we updated our 2025 outlook for Westinghouse to reflect this second quarter increase in revenue; once Westinghouse receives the cash associated with the increased revenue, it will be considered, by the partners, in determining distributions payable. Westinghouse is expected to receive the cash in the fourth quarter of 2025. See Our outlook for 2025 starting on page 16 and Our earnings from Westinghouse, starting on page 27 for more information. Adjusted net earnings and adjusted EBITDA are non-IFRS measures, see the information starting on page 30.
We continue to responsibly manage our supply in accordance with our customers’ needs. As a proven and reliable commercial supplier with assets in geopolitically stable jurisdictions across all segments of the nuclear fuel cycle, we are being selective in committing our unencumbered, in-ground uranium inventory and UF6 conversion capacity under long-term contracts. To support the long-term operation of our productive capacity, our contracting is focused on maintaining exposure to future improvements in the market while retaining downside protection. In our uranium segment, over the next five years, we have contracts in place for average annual deliveries of 28 million pounds of U3O8 per year, with commitments higher than the average in 2025 through 2027, and lower than the average in the years 2028 and 2029. We also have contracts in both our uranium and fuel services segments that have deliveries spanning more than a decade. In our uranium segment, many of those contracts incorporate market-related pricing mechanisms that are expected to benefit from the improving market conditions.
To advance our strategy in step with the positive market momentum and long-term contracts we have put in place, we expect to produce 36 million pounds (22.4 million pounds our share) of uranium in 2025. Our 2025 production outlook assumes ground freezing and development in new mining areas advance as planned, that we maintain access to adequate skilled labour, and that new equipment is commissioned on time. In addition, JV Inkai is targeting 2025 production of 8.3 million pounds (100% basis) of uranium which our purchase allocation is 3.7 million pounds. We expect shipments of our remaining share of 2024 production and the majority of our share of 2025 production from JV Inkai to begin in the second half of 2025. The achievement of JV Inkai’s 2025 production target requires it to successfully manage several ongoing risks, including issues of availability of sulfuric acid, other procurement and supply chain issues, transportation challenges, construction delays and inflationary pressures on its production costs.
At our Fuel Services division, our annual production expectation, which includes UF6 conversion, UO2 conversion, and heavy water reactor fuel bundles, remains between 13 million and 14 million kgU of combined fuel services products. At Port Hope, we continue to work towards achieving a UF6 production rate of 12,000 tonnes per year, closely aligned with our licensed capacity, in order to satisfy our book of long-term commitments and demand for conversion services.
10 CAMECO CORPORATION
With our operationally flexible and disciplined approach to supply, we continue to meet our sales commitments through a combination of production, inventory, product loans and purchases. In the second quarter, we produced 4.6 million pounds of uranium (our share), and we purchased 0.7 million pounds (purchased at an average unit cost of $97.00 per pound ($69.30 (US) per pound)). See Financial results by segment – Uranium starting on page 24 for more information. After delivering 8.7 million pounds in the second quarter, our uranium inventory was 7.6 million pounds on June 30, 2025, with an average inventory cost of $47.88 per pound.
We expect to maintain the financial strength and flexibility necessary to execute our strategy by planning production in coordination with contracting success and market opportunities.
Thanks to our risk-managed financial discipline, our balance sheet remains strong. As of June 30, 2025, we had $716 million in cash and cash equivalents, and $1.0 billion in total debt and a $1.0 billion undrawn revolving credit facility.
2025 SECOND QUARTER REPORT 11
Financial results
This section of our MD&A discusses our performance, financial condition and outlook for the future.
Consolidated financial results
| THREE MONTHS | SIX MONTHS | |||||||||||||||||||||||
| HIGHLIGHTS | ENDED JUNE 30 | ENDED JUNE 30 | ||||||||||||||||||||||
| ($ MILLIONS EXCEPT WHERE INDICATED) |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||
| Revenue |
877 | 598 | 47 | % | 1,666 | 1,232 | 35 | % | ||||||||||||||||
| Gross profit |
257 | 175 | 47 | % | 527 | 362 | 46 | % | ||||||||||||||||
| Net earnings attributable to equity holders |
321 | 36 | >100 | % | 391 | 29 | >100 | % | ||||||||||||||||
| $ per common share (basic) |
0.74 | 0.08 | >100 | % | 0.90 | 0.07 | >100 | % | ||||||||||||||||
| $ per common share (diluted) |
0.74 | 0.08 | >100 | % | 0.90 | 0.07 | >100 | % | ||||||||||||||||
| Adjusted net earnings (ANE) (non-IFRS, see page 30)1 |
308 | 65 | >100 | % | 378 | 111 | >100 | % | ||||||||||||||||
| $ per common share (adjusted and diluted) |
0.71 | 0.15 | >100 | % | 0.87 | 0.25 | >100 | % | ||||||||||||||||
| Adjusted EBITDA (non-IFRS, see page 30)1 |
673 | 343 | 96 | % | 1,029 | 677 | 52 | % | ||||||||||||||||
| Cash provided by operations |
465 | 260 | 79 | % | 575 | 323 | 78 | % | ||||||||||||||||
| 1 | In the fourth quarter of 2024, we revised our calculation of adjusted net earnings and adjusted EBITDA to adjust for unrealized foreign exchange gains and losses as well as for share-based compensation because it better reflects how we assess our operational performance. We have restated comparative periods to reflect this change. |
Quarterly trends
| HIGHLIGHTS | 2025 | 2024 | 2023 | |||||||||||||||||||||||||||||
| ($ MILLIONS EXCEPT PER SHARE AMOUNTS) |
Q2 | Q1 | Q4 | Q3 | Q2 | Q1 | Q4 | Q3 | ||||||||||||||||||||||||
| Revenue |
877 | 789 | 1,183 | 721 | 598 | 634 | 844 | 575 | ||||||||||||||||||||||||
| Net earnings (loss) attributable to equity holders |
321 | 70 | 135 | 7 | 36 | (7 | ) | 80 | 148 | |||||||||||||||||||||||
| $ per common share (basic) |
0.74 | 0.16 | 0.31 | 0.02 | 0.08 | (0.02 | ) | 0.18 | 0.34 | |||||||||||||||||||||||
| $ per common share (diluted) |
0.74 | 0.16 | 0.31 | 0.02 | 0.08 | (0.02 | ) | 0.18 | 0.34 | |||||||||||||||||||||||
| Adjusted net earnings (non-IFRS, see page 30) |
308 | 70 | 157 | 24 | 65 | 46 | 108 | 96 | ||||||||||||||||||||||||
| $ per common share (adjusted and diluted) |
0.71 | 0.16 | 0.36 | 0.06 | 0.15 | 0.11 | 0.25 | 0.22 | ||||||||||||||||||||||||
| Cash provided by operations |
465 | 110 | 530 | 52 | 260 | 63 | 201 | 185 | ||||||||||||||||||||||||
Key things to note:
| • | The timing of customer requirements, which tend to vary from quarter to quarter, drives revenue in the uranium and fuel services segments, meaning quarterly results are not necessarily a good indication of annual results due to the variability in customer requirements. |
| • | Net earnings do not trend directly with revenue due to unusual items and transactions that occur from time to time. We use adjusted net earnings, a non-IFRS measure, as a more meaningful way to compare our results from period to period (see page 30 for more information). |
| • | Cash provided by operations tends to fluctuate as a result of the timing of deliveries and product purchases in our uranium and fuel services segments. |
| • | Our quarterly results are impacted by variability in the timing of Westinghouse’s customer requirements, deliveries, and outage schedules. In 2025, the first half of the year was expected to be weaker, with stronger performance and higher quarterly cash flows expected in the fourth quarter. We now expect its second quarter performance to be the strongest this year, due to the $170 million (US) increase in our share of Westinghouse’s revenue in the quarter tied to its participation in the Dukovany construction project. Higher quarterly cash flows continue to be expected in the fourth quarter of 2025. In 2024, the revaluation of Westinghouse’s inventory, due to purchase accounting, had a significant impact on Westinghouse’s quarterly results in the first half of the year. See Our earnings from Westinghouse, starting on page 27 for more information. |
12 CAMECO CORPORATION
The following table compares the net earnings (loss) and adjusted net earnings for the second quarter to the previous seven quarters.
| HIGHLIGHTS | 2025 | 2024 | 2023 | |||||||||||||||||||||||||||||
| ($ MILLIONS EXCEPT PER SHARE AMOUNTS) |
Q2 | Q1 | Q4 | Q3 | Q2 | Q1 | Q4 | Q3 | ||||||||||||||||||||||||
| Net earnings (loss) attributable to equity holders |
321 | 70 | 135 | 7 | 36 | (7 | ) | 80 | 148 | |||||||||||||||||||||||
| Adjustments |
||||||||||||||||||||||||||||||||
| Adjustments on derivatives |
(163 | ) | (12 | ) | 133 | (28 | ) | 14 | 33 | (59 | ) | 41 | ||||||||||||||||||||
| Unrealized foreign exchange losses (gains) |
71 | (4 | ) | (56 | ) | 15 | (7 | ) | (18 | ) | (1 | ) | (57 | ) | ||||||||||||||||||
| Share-based compensation |
39 | (2 | ) | 17 | 4 | 15 | 8 | 12 | 22 | |||||||||||||||||||||||
| Adjustments on other operating expense (income) |
(8 | ) | 1 | (23 | ) | 5 | (2 | ) | (15 | ) | 40 | (48 | ) | |||||||||||||||||||
| Income taxes on adjustments |
35 | 4 | (37 | ) | 7 | (7 | ) | (9 | ) | 6 | (10 | ) | ||||||||||||||||||||
| Adjustments on equity investees (net of tax): |
||||||||||||||||||||||||||||||||
| Inventory purchase accounting |
4 | — | 3 | — | 12 | 38 | 20 | — | ||||||||||||||||||||||||
| Acquisition-related transition costs |
— | — | — | 4 | 5 | 14 | — | — | ||||||||||||||||||||||||
| Unrealized foreign exchange losses (gains) |
(2 | ) | 7 | (7 | ) | — | (2 | ) | — | 2 | — | |||||||||||||||||||||
| Other expenses2 |
11 | 6 | (8 | ) | 10 | 1 | 2 | 8 | — | |||||||||||||||||||||||
| Adjusted net earnings (non-IFRS, see page 30)1 |
308 | 70 | 157 | 24 | 65 | 46 | 108 | 96 | ||||||||||||||||||||||||
| 1 | In the fourth quarter of 2024, we revised our calculation of adjusted net earnings to adjust for unrealized foreign exchange gains and losses as well as for share-based compensation because it better reflects how we assess our operational performance. We have restated comparative periods to reflect this change. |
| 2 | Other expenses includes Westinghouse’s unrealized foreign exchange losses (gains) and costs related to long-term incentive plans. |
Corporate expenses
ADMINISTRATION
| THREE MONTHS | SIX MONTHS | |||||||||||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||||||||||
| ($ MILLIONS) |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||
| Direct administration |
58 | 52 | 12 | % | 120 | 104 | 15 | % | ||||||||||||||||
| Share-based compensation |
38 | 14 | >100 | % | 35 | 22 | 59 | % | ||||||||||||||||
| Total administration |
96 | 66 | 45 | % | 155 | 126 | 23 | % | ||||||||||||||||
Direct administration costs were $6 million higher for the second quarter of 2025 compared to the same period last year, and $16 million higher for the first six months largely due to the impact of inflation and additional costs associated with digital and community initiatives. Share-based compensation was $24 million higher for the second quarter of 2025 compared to last year, and in the first six months of 2025 was $13 million higher than 2024 due to the increase in our share price during this period compared to a smaller increase in the same period last year. See note 16 to the financial statements.
EXPLORATION AND RESEARCH & DEVELOPMENT
In the second quarter, uranium exploration expenses were $6 million, an increase of $3 million from the second quarter of 2024. Exploration expenses for the first six months of the year increased by $4 million compared to 2024, to $14 million. The increased spending for exploration in the second quarter is in line with the outlook provided for 2025.
Due to the timing of expenditures, research and development expenses in the second quarter of the year decreased by $9 million from the second quarter of 2024 and for the first six months of the year decreased by $4 million compared to 2024, to $13 million. These expenses are mainly related to our investment in Global Laser Enrichment, LLC.
INCOME TAXES
We recorded an income tax expense of $71 million in the second quarter of 2025, compared to an expense of $18 million in the second quarter of 2024.
In the first six months of 2025, we recorded an expense of $124 million compared to an expense of $49 million in 2024.
2025 SECOND QUARTER REPORT 13
| THREE MONTHS | SIX MONTHS | |||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||
| ($ MILLIONS) |
2025 | 2024 | 2025 | 2024 | ||||||||||||
| Net earnings before income taxes |
||||||||||||||||
| Canada |
325 | 90 | 525 | 231 | ||||||||||||
| Foreign |
67 | (36 | ) | (10 | ) | (153 | ) | |||||||||
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| Total net earnings before income taxes |
392 | 54 | 515 | 78 | ||||||||||||
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| Income tax expense |
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| Canada |
70 | 13 | 119 | 44 | ||||||||||||
| Foreign |
1 | 5 | 5 | 5 | ||||||||||||
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|
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| Total income tax expense |
71 | 18 | 124 | 49 | ||||||||||||
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TRANSFER PRICING DISPUTE
Background
Since 2008, Canada Revenue Agency (CRA) has disputed our marketing and trading structure and the related transfer pricing methodology we used for certain intercompany uranium sale and purchase agreements.
For the years 2003 to 2014, CRA shifted Cameco Europe Limited’s income (as recalculated by CRA) back to Canada and applied statutory tax rates, interest and instalment penalties, and, from 2007 to 2011, transfer pricing penalties. In addition, for 2014 to 2017, CRA has advanced an alternate reassessing position. See Reassessments, remittances and next steps below for more information.
In September 2018, the Tax Court of Canada (Tax Court) ruled that our marketing and trading structure involving foreign subsidiaries, as well as the related transfer pricing methodology used for certain intercompany uranium sales and purchasing agreements, were in full compliance with Canadian law for the tax years in question (2003, 2005 and 2006). On June 26, 2020, the Federal Court of Appeal (Court of Appeal) upheld the Tax Court’s decision.
On February 18, 2021, the Supreme Court of Canada (Supreme Court) dismissed CRA’s application for leave to appeal the June 26, 2020 decision of the Court of Appeal. The dismissal means that the dispute for the 2003, 2005 and 2006 tax years is fully and finally resolved in our favour. Although not technically binding, there is nothing in the reasoning of the lower court decisions that should result in a different outcome for the 2007 through 2014 tax years, which were reassessed on the same basis.
Refund and cost award
The Minister of National Revenue issued new reassessments for the 2003 through 2006 tax years in accordance with the decision and, in July 2021, refunded the tax paid for those years. In October 2023, pursuant to a cost award from the courts, we received a payment of approximately $12 million for disbursements, which is in addition to the $10 million we received from CRA in April 2021 as reimbursement for legal fees.
Reassessments, remittances and next steps
The Canadian income tax rules include provisions that generally require larger companies like us to remit or otherwise secure 50% of the cash tax plus related interest and penalties at the time of reassessment. Following the Supreme Court’s dismissal of CRA’s application for leave to appeal, we wrote to CRA requesting reversal of CRA’s transfer pricing adjustments for 2007 through 2013 and the return of the $780 million in cash and letters of credit we paid or provided for those years. Given the strength of the court decisions received, our request was made on the basis that the Tax Court would reject any attempt by CRA to defend its reassessments for the 2007 through 2013 tax years applying the same or similar positions already denied for previous years.
In March 2023, CRA issued revised reassessments for the 2007 through 2013 tax years, which resulted in a refund of $297 million of the $780 million in cash and letters of credit held by CRA at the time. The refund consisted of cash in the amount of $86 million and letters of credit in the amount of $211 million, which were returned in the second quarter.
14 CAMECO CORPORATION
The series of court decisions that were completely and unequivocally in our favour for the 2003, 2005 and 2006 tax years, determined that the income earned by our foreign subsidiary from the sale of non-Canadian produced uranium was not taxable in Canada. In accordance with these decisions, CRA issued reassessments reducing the proposed transfer pricing adjustment from $5.1 billion to $3.3 billion, resulting in a reduction of $1.8 billion in income taxable in Canada compared to the previous reassessments issued to us by CRA for the 2007 through 2013 tax years.
The remaining transfer pricing adjustment of $3.3 billion for the 2007 to 2013 tax years relates to the sale of Canadian-produced uranium by our foreign subsidiary. We maintain that the clear and decisive court decisions described above apply, and that CRA should fully reverse the remaining transfer pricing adjustments for these years and return all cash and security being held. In October 2021, due to a lack of significant progress on our points of contention, we filed a notice of appeal with the Tax Court for the years 2007 through 2013. We have asked the Tax Court to order the complete reversal of CRA’s transfer pricing adjustment for those years and the return of all cash and letters of credit being held, with costs.
In 2020, CRA advanced an alternate reassessing position for the 2014 tax year in the event the basis for its original reassessment, noted above, is unsuccessful. Subsequent to this, we received a reassessment for the 2015, 2016 and 2017 tax years, all reflecting this alternative reassessing position. While CRA did not require additional security for the tax debts they considered owing for 2014 through 2016, CRA did require additional letters of credit related to the tax debts they considered owing for 2017. CRA continues to hold $555 million ($209 million in cash and $346 million in letters of credit) that we have remitted or secured to date. Further, as a result of these reassessments CRA has drawn down the tax pools available to us and we are required to remit cash tax of $32 million for the 2024 taxation year. We expect to recover these amounts held by the CRA. The new basis of reassessment is inconsistent with the methodology CRA has pursued for prior years and we are disputing it separately. Our view is that this alternate methodology will not result in a materially different outcome from our 2014 to 2017 filing positions. We filed appeals with the Tax Court for each year from 2014 through 2017.
In late 2024, we received a reassessment for the 2018 tax year. The reassessment relates to contracts other than those discussed above. CRA has advanced another alternate reassessing position for the 2018 tax year. In the first quarter of 2025, we filed a notice of objection for 2018.
We will not be in a position to determine the definitive outcome of the dispute for any tax year other than 2003 through 2006 until such time as all reassessments have been issued advancing CRA’s arguments and final resolution is reached for that tax year. CRA may also advance alternative reassessment methodologies for years other than 2003 through 2006, such as the alternative reassessing position advanced for 2014 through 2017, or the new reassessing position advanced for 2018.
Caution about forward-looking information relating to our CRA tax dispute
This discussion of our expectations relating to our tax dispute with CRA and future tax reassessments by CRA is forward-looking information that is based upon the assumptions and subject to the material risks discussed under the heading Caution about forward-looking information beginning on page 2.
IMPACT OF TARIFFS
Although the US has threatened the imposition of a 10% tariff on Canadian energy products, CUSMA-compliant products and global nuclear fuel products in general are currently excluded, with natural uranium, UF6, and enriched uranium therefore exempt, preserving the flow of nuclear fuel imports into the US market. To mitigate risk amid unpredictable US policy changes and ongoing uncertainty, we have proactively taken steps to minimize the impact of a potential tariff, should a tariff be imposed, such as positioning material ahead of expected deliveries and adjusting our contract terms. We are also working with both local and international suppliers to minimize the direct and general inflationary cost pressures related to tariffs on products we require for our operations. We currently do not anticipate the impact of potential tariffs to be material on our 2025 financial results.
2025 SECOND QUARTER REPORT 15
FOREIGN EXCHANGE
The exchange rate between the Canadian dollar and US dollar affects the financial results of our uranium and fuel services segments.
We sell the majority of our uranium and fuel services products under long-term sales contracts, which are routinely denominated in US dollars. While our product purchases are largely denominated in US dollars, our production costs are largely denominated in Canadian dollars. To provide cash flow predictability, we hedge a portion of our net US/Cdn exposure (e.g. total US dollar sales less US dollar expenditures and product purchases) to manage shorter term exchange rate volatility. Our results are therefore affected by the movements in the exchange rate on our hedge portfolio, and on the unhedged portion of our net exposure.
Impact of hedging on IFRS earnings
We do not use hedge accounting under IFRS and we are therefore required to report gains and losses on economic hedging activity, both for contracts that close in the period and those that remain outstanding at the end of the period. For the contracts that remain outstanding, we must treat them as though they were settled at the end of the reporting period (mark-to-market).
However, we do not believe the gains and losses that we are required to report under IFRS appropriately reflect the intent of our hedging activities, so we make adjustments in calculating our ANE to better reflect the impact of our hedging program in the applicable reporting period.
Impact of hedging on ANE
We designate contracts for use in particular periods, based on our expected net exposure in that period. Hedge contracts are layered in over time based on this expected net exposure. The result is that our current hedge portfolio is made up of a number of contracts which are currently designated to net exposures we expect in 2025 and future years, and we will recognize the gains and losses in ANE in those periods.
For the purposes of ANE, gains and losses on derivatives are reported based on the difference between the effective hedge rate of the contracts designated for use in the particular period and the exchange rate at the time of settlement. This results in an adjustment to current period IFRS earnings to effectively remove reported gains and losses on derivatives that arise from contracts put in place for use in future periods. The effective hedge rate will lag the market in periods of rapid or significant currency movement. See Non-IFRS measures on page 30.
For more information, see our 2024 annual MD&A.
At June 30, 2025:
| • | The value of the US dollar relative to the Canadian dollar was $1.00 (US) for $1.36 (Cdn), down from $1.00 (US) for $1.44 (Cdn) at March 31, 2025. The exchange rate averaged $1.00 (US) for $1.38 (Cdn) over the quarter. |
| • | The mark-to-market position on all foreign exchange contracts was a $35 million gain compared to a $128 million loss at March 31, 2025. |
Outlook for 2025
Our outlook for 2025 reflects our plan to produce 18 million pounds (100% basis) at each of Cigar Lake and McArthur River/Key Lake, and 13 million to 14 million kgU in our fuel services segment, as well as continued work to extend the mine life at Cigar Lake.
In 2025, we expect strong financial performance, including cash flow generation. Our financial performance and the amount of cash generated will be dependent on sourcing the material required to meet our deliveries as planned, including achieving our production plans. Our cash balance could increase if there are additional distributions from Westinghouse during 2025.
As in prior years, we will incur care and maintenance costs for the ongoing curtailment of our tier-two assets, which are expected to be between $62 million and $67 million.
Based on the increase in the UxC uranium spot price at the end of the quarter, we updated our expected average realized price to approximately $87.00 per pound (previously $84.00 per pound). We have not changed our outlook for revenue because the range still reflects our expectations.
16 CAMECO CORPORATION
2025 FINANCIAL OUTLOOK
| CONSOLIDATED | URANIUM | FUEL SERVICES | WESTINGHOUSE | |||||||||||||
| Production (owned and operated properties) |
— | 22.4 million lb | 13 to 14 million kgU | — | ||||||||||||
| Market purchases |
— | up to 3 million lb | — | — | ||||||||||||
| Committed purchases (including Inkai purchase volumes) |
— | 9 million lb | — | — | ||||||||||||
| Sales/delivery volume |
— | 31 to 34 million lb | 13 to 14 million kgU | — | ||||||||||||
| Revenue |
$ |
3,300 to 3,550 million |
|
$ |
2,800 to 3,000 million |
|
$ | 500-550 million | — | |||||||
| Average realized price |
— | $ | 87.00/lb | 1 | — | — | ||||||||||
| Average unit cost of sales (including D&A) |
— | $ | 59.50-63.00/lb | 2 | $ | 27.00-28.75/kgU | 3 | — | ||||||||
| Direct administration costs |
$ | 220-230 million | — | — | — | |||||||||||
| Exploration costs |
— | $ | 27 million | — | — | |||||||||||
| Research and development |
$ | 47 million | — | — | — | |||||||||||
| Capital expenditures |
$ | 360-400 million | $ | 285-310 million | $ | 70-80 million | — | 4 | ||||||||
| Adjusted EBITDA (non-IFRS, see page 30) (US) |
— | — | — | $ | 525-580 million | |||||||||||
| 1 | Uranium average realized price is calculated as the revenue from sales of uranium concentrates, transportation and storage fees divided by the volume of uranium concentrates sold. |
| 2 | Uranium average unit cost of sales is calculated as the cash and non-cash costs of the product sold, care and maintenance and selling costs, divided by the volume of uranium concentrates sold. |
| 3 | Fuel services average unit cost of sales is calculated as the cash and non-cash costs of the product sold, transportation and weighing and sampling costs, divided by the volume of products sold. |
| 4 | The outlook for Cameco’s share of capital expenditures for Westinghouse is $120 million - $150 million (US). |
We are not providing an outlook for the items in the table that are marked with a dash.
The following assumptions were used to prepare the outlook in the table above:
| • | Market purchases – reflect the market purchases we have made to date and expect to make for the remainder of 2025. Market purchases may vary if planned production varies. In addition, if we decide to increase our working inventory from current levels our market purchases could be higher. Our market purchases could also be lower if, instead of making market purchases, we choose to source the required volumes by temporarily reducing inventory levels, by pulling forward long-term purchase commitments, or by drawing on loan arrangements we have in place. |
| • | Committed purchases are based on the 4.8 million pounds of commitments to acquire under contract in 2025 and our JV Inkai purchases, which we have assumed will be equivalent to our 2024 purchase volume of 4.2 million pounds. If Inkai production and/or deliveries vary, committed purchases will vary and we may have to rely on our other sources of supply described above. We equity account for our minority ownership interest in JV Inkai. We record our share of its production as a purchase. However, this does not reflect our share of the economic benefit. Our share of the economic benefit is based on the difference between our purchase price and JV Inkai’s lower production cost and is reflected in the line item on our statement of earnings called, “share of earnings from equity-accounted investees”. As a result, increases in the spot price increase our cost of purchases from JV Inkai and also our “share of earnings from equity-accounted investees”. The benefit is realized, through receipt of a cash dividend, when declared and paid by JV Inkai. |
| • | Our 2025 outlook for sales/delivery volume does not include sales between our uranium and fuel services segments. |
| • | Sales/delivery volume is based on the volumes we currently have delivered and our remaining commitments to deliver under contract in 2025. |
| • | Uranium revenue and average realized price are calculated based on the terms contained in the base-escalated and market-related contracts under which we have deliveries in 2025. For market-related contracts not yet priced and for delivery in 2025, subject to any floors or ceilings, we used a uranium spot price of $78.50 (US) per pound (the UxC spot price as of June 30, 2025), a long-term price indicator of $80.00 (US) per pound (the UxC long-term indicator on June 30, 2025) and an exchange rate of $1.00 (US) for $1.40 (Cdn). |
2025 SECOND QUARTER REPORT 17
| • | Uranium average unit cost of sales (including D&A) is based on the expected unit cost of sales for produced material and the market purchases and committed purchases made to date and the planned volumes remaining noted in the outlook at an anticipated average purchase price of about $100 (Cdn) per pound and includes care and maintenance costs of between $62 million and $67 million. We expect overall unit cost of sales could vary if there are changes in production and market or committed purchase volumes or the mix of supply sources used to meet our contract deliveries, uranium spot prices, and/or care and maintenance costs in 2025. |
| • | Unit cost of sales and capital expenditures could be impacted by the imposition of tariffs or general inflationary pressures related to tariffs. See Impact of tariff taxes on page 15 for more information. |
| • | The adjusted EBITDA outlook for Westinghouse is based on the assumptions listed later in this section. |
| • | Westinghouse and JV Inkai are accounted for using the equity method for our share. Under equity accounting, Westinghouse and JV Inkai capital expenditures are not presented within our consolidated financial statements and are therefore not included in our outlook for capital expenditures. |
For more information on how changes in the exchange rate or uranium prices can impact our outlook see Revenue, adjusted net earnings, and cash flow sensitivity analysis below, and Foreign exchange on page 16.
In 2025 we expect our share of adjusted EBITDA from our equity investment in Westinghouse to be between $525 million and $580 million (US) (previously between $355 million and 405 million (US)), our share of net earnings to be between $30 million and $80 million (US) (previously net loss of between $20 million and $70 million (US)) and our share of income tax expense to be between $30 million and $70 million (US) (previously between an expense of $5 million and recovery of $10 million (US)). The expected increases are due to the $170 million (US) increase in our share of Westinghouse’s 2025 second quarter revenue tied to Westinghouse’s participation in the Dukovany construction project in the Czech Republic. Over the next five years, we expect our share of adjusted EBITDA, excluding the impact of the $170 million (US) increase in revenue in the second quarter of 2025, will grow at a compound annual growth rate of 6% to 10%.
| $US | ||||
| CAMECO SHARE (49%) |
MILLIONS | |||
| Net earnings |
30-80 | |||
| Depreciation and amortization |
260-275 | |||
| Finance income |
(1-2 | ) | ||
| Finance costs |
120-135 | |||
| Income tax expense |
30-70 | |||
|
|
|
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| EBITDA |
470-530 | |||
| Inventory purchase accounting |
1-5 | |||
| Restructuring costs |
15-30 | |||
| Other expenses |
10-25 | |||
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| Adjusted EBITDA (non-IFRS, see page 30) |
525-580 | |||
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Note: the ranges for 2025 outlook for EBITDA and adjusted EBITDA are not determined using the high and low estimates of the ranges provided for each of the detailed reconciling line items.
Previously, we had expected Westinghouse to have stronger performance in the fourth quarter of 2025. However, we now expect its second quarter performance to be the strongest due to the increase in our share of Westinghouse’s second quarter revenue.
The outlook for adjusted EBITDA for 2025 and its growth rate of Westinghouse over the next five years are based on the following assumptions:
| • | A compound annual growth rate in revenue from Westinghouse’s core business of 6% to 8% (excluding any impact from growth in its new build business), which is slightly higher than the anticipated average growth rate of the nuclear industry based on the World Nuclear Association’s Reference Case. In addition to orders for PWR reactor fuel and services, this includes orders for VVER and BWR fuel and services, and a phase out of advanced gas-cooled reactor fuel. The outlook assumes that work is fulfilled on the timelines and scope expected based on current orders received, and additional work is undertaken based on past trends. The expected margins on this work are aligned with the historic margins of 16% to 19%, with variability expected to come from product mix compared to previous years. |
18 CAMECO CORPORATION
| • | Growth in Westinghouse’s new build business from new AP1000® reactor projects based on agreements that have been signed and announcements where AP1000 technology has been selected. This includes Poland, Bulgaria, Ukraine and Finland, as well as the expected benefit over this period for subcontracted work related to the Dukovany construction project. The 6% to 10% compound annual growth rate in our share of adjusted EBITDA (which excludes the impact of the $170 million (US) increase in revenue in 2025) over the next five-years assumes that work to be done by Westinghouse on announced agreements and announced selections would proceed on the timelines and revenue pattern noted under the New Build Framework in our 2024 Annual MD&A, and that within the five-year timeframe, the AP1000 is the chosen technology for one additional project from the group of planned and proposed projects. A delay in project timelines or cancellation of announced projects could result in a lower growth rate near the bottom of the range. For all AP1000 new build projects, the growth assumes Westinghouse undertakes only the engineering and procurement work required prior to a new reactor project breaking ground, which we believe is a small component of its overall potential. |
| • | Estimates and assumptions, including growth capital timelines, new build development timelines for both announced and potential reactor builds are subject to government and regulatory approval, as well as risks related to the current macro-economic environment, and may differ significantly from those assumed. |
| • | Contributions from new technologies are outside the five-year time frame. Timelines for investment in research and development for new technologies, including the eVinci™ microreactor and AP300™ small modular reactor, may differ from that assumed. |
| • | The outlook for capital expenditures includes growth capex for expansion of fuel fabrication capabilities, as well as work to evaluate cost, timeline and infrastructure required to bring back conversion capacity and consider the potential future opportunities at the Springfields site in the UK. As with Cameco’s other investments, planning for this site will align with market opportunities. |
Caution about forward-looking information relating to our future earnings and adjusted EBITDA from Westinghouse
This discussion of our expectations for Westinghouse’s future earnings and adjusted EBITDA and our share thereof is forward-looking information that is based upon the assumptions and subject to the material risks discussed under the headings Caution about forward-looking information beginning on page 2. Actual results and events may be significantly different from what we currently expect.
REVENUE, ADJUSTED NET EARNINGS, AND CASH FLOW SENSITIVITY ANALYSIS
We have sensitivity to the uranium price through both our sales and purchase commitments. However, at the current price levels, many of the market-related sales contracts we have delivered into or are delivering into this year are subject to ceiling prices and therefore are generally less sensitive than our purchase commitments.
As a result, if the uranium spot price increased by $5 (US) per pound, we expect revenue would increase by $23 million, while ANE would increase by $2 million and cash flow would decrease by $31 million. From a cash flow perspective, the sensitivity does not adequately capture the impact of JV Inkai purchases, which straddle two fiscal reporting periods in light of when dividends are declared and paid by JV Inkai. The cash flow sensitivity includes the cash outflow for the remaining 4.2 million pounds of uranium assumed to be purchased from JV Inkai in 2025 at a 5% discount to the spot price but does not account for an associated inflow due to the cash dividend expected, which will be tied to our agreed to 2025 production purchase entitlement and is expected to be received in 2026. JV Inkai distributes excess cash as dividends to its owners, net of working capital requirements. In the case of a $5 (US) per pound increase in uranium prices, the JV Inkai purchases are responsible for about $28 million of the noted expected decrease in cash flow and we expect the impact of these purchases on the 2025 cash flow will be partially offset by dividends once declared and paid in 2026.
If the uranium spot price decreased by $5 (US) per pound, we expect revenue to decrease by $28 million, ANE to decrease by $6 million, and cash flow to increase by $27 million. From a cash flow perspective, the impact of the noted decrease in uranium price on the assumed purchase of uranium from JV Inkai is expected to have the opposite impact from that described above for the noted uranium price increase.
In the case of a $5 (US) increase or decrease in the uranium spot price, the sensitivity for ANE compared to the sensitivity for cash flow is less due to the impact on our net earnings from the inclusion of our share of earnings from our equity-accounted investment in JV Inkai in the reporting period, the rate of inventory turnover, and income taxes.
2025 SECOND QUARTER REPORT 19
The following assumptions were used to prepare the revenue, ANE and cash flow sensitivity analysis above:
| • | 7.8 million pounds of purchases are sourced from the market or are committed purchases (excluding JV Inkai) and include pounds purchased to date. |
| • | Total JV Inkai purchases for the year of 4.2 million pounds. |
| • | For market-related contracts not yet priced and for delivery in 2025, subject to any floors or ceilings, we used a uranium spot price of $78.50 (US) per pound (the UxC spot price as of June 30, 2025), a long-term price indicator of $80.00 (US) per pound (the UxC long-term indicator on June 30, 2025) and an exchange rate of $1.00 (US) for $1.40 (Cdn). |
To the extent that our market purchases or JV Inkai purchases vary, the sensitivity of our ANE and cash flow to changes in the spot and long-term prices may be impacted. In the case of decreased market or JV Inkai purchases, our sensitivity would be reduced. In the case of increased market or JV Inkai purchases, our sensitivity would be greater.
A one cent increase or decrease in the value of the US dollar compared to the Canadian dollar would respectively increase or decrease expected revenue by $11 million, while the impacts on ANE and cash flow would not be significant. The majority of our sales are denominated in US dollars, resulting in sensitivity to foreign exchange rates. Revenue will be recognized at the prevailing foreign exchange rate at the time of the sale. ANE and cash flow are less sensitive to foreign exchange rates as we have layered in foreign exchange hedges to provide cash flow certainty, at an average rate of 1.36 USDCAD. See Foreign exchange starting on page 44 in our annual MD&A for more details.
PRICE SENSITIVITY ANALYSIS: URANIUM SEGMENT
As discussed under Long-term contracting on page 25 of our 2024 annual MD&A, our average realized price is based on pricing terms established in our portfolio of long-term contracts, which includes a mix of base-escalated and market-related contracts that are layered in over time. Each confidential contract is bilaterally negotiated with the customer and delivery generally does not begin until two years or more after signing.
| • | Base-escalated contracts will reflect market conditions and pricing at the time each contract was finalized, with escalation factors applied based on when the material is delivered. |
| • | Market-related contracts reference a pricing mechanism that may be based on the spot price and/or the long-term price, and that price is generally set a month or more prior to delivery, subject to specific terms unique to each contract such as floors and ceilings set relative to market pricing at time of negotiation and typically escalated to time of delivery. |
As a result of these contracting dynamics, changes to our average realized price will generally lag changes in market prices in both rising and falling price conditions. The magnitude and direction of the deviation can vary based on the degree of market price volatility between the time the contract price is set, and the time the product is delivered.
To help understand how the pricing under our current portfolio of commitments is expected to react at various spot prices at June 30, 2025, we have constructed the table that follows.
The table is based on the volumes and pricing terms under the long-term commitments in our contract portfolio that have been finalized as of June 30, 2025. The table does not include volumes and pricing terms in contracts under negotiation or those that have been accepted but are still subject to contract finalization. Based on the terms and volumes under contracts that have been finalized, the table is designed to indicate how our average realized price would react under various spot price assumptions at a point in time. In other words, the prices shown in the table would only be realized if the contract portfolio remained exactly as it was on June 30, 2025, using the following assumptions:
| • | The uranium price remains fixed at a given spot level for each annual period shown. |
| • | Deliveries based on commitments under finalized contracts include best estimates of the expected deliveries and flexibility under contract terms. |
| • | To reflect escalation mechanisms contained in existing contracts the long-term US inflation rate target of 2% is used, for modeling purposes only. |
It is important to note that the table is not a forecast of prices we expect to receive. The prices we actually realize will be different from the prices shown in the table. We intend to update this table each quarter in our MD&A to reflect deliveries made and changes to our contract portfolio. As a result, we expect the table to change from quarter to quarter.
20 CAMECO CORPORATION
Expected realized uranium price sensitivity under various spot price assumptions at June 30, 2025
| (rounded to the nearest $1.00) | ||||||||||||||||||||||||||||
| SPOT PRICES | ||||||||||||||||||||||||||||
| ($US/lb U3O8) |
$20 | $40 | $60 | $80 | $100 | $120 | $140 | |||||||||||||||||||||
| 2025 |
53 | 55 | 59 | 61 | 62 | 63 | 63 | |||||||||||||||||||||
| 2026 |
42 | 45 | 56 | 66 | 69 | 70 | 71 | |||||||||||||||||||||
| 2027 |
42 | 45 | 57 | 69 | 73 | 76 | 78 | |||||||||||||||||||||
| 2028 |
47 | 50 | 59 | 71 | 77 | 80 | 82 | |||||||||||||||||||||
| 2029 |
49 | 52 | 61 | 73 | 82 | 86 | 89 | |||||||||||||||||||||
As of June 30, 2025, we had commitments requiring delivery of an average of about 28 million pounds per year from 2025 through 2029, which included deliveries made year to date in 2025, with commitment levels in 2025 through 2027 being higher than the average, and in 2028 and 2029, lower than the average. As the market continues to improve, we expect to continue layering in volumes that capture greater future upside using market-related pricing mechanisms.
Liquidity and capital resources
Our financial objective is to ensure we have the cash and access to capital to fund our operating activities, investments and other financial obligations in order to execute our strategy, take advantage of opportunities and self-manage risk. We regularly consider our financing options so we can take advantage of favourable market conditions when they arise. We have a number of alternatives to fund future capital requirements, including using our operating cash flow, drawing on our existing credit facilities, entering new credit facilities, and raising additional capital through debt or equity financing, including by conducting a registered offering of securities using our base shelf prospectus or utilizing our at-the-market equity program. In addition, with the intent of broadening the ratings coverage on our debt and providing future flexibility, we initiated a third public rating, which is effective as of July 30, 2025. Obtaining an additional rating allows us to engage with rating agencies about the dynamics in our market at a time when our industry is in the headlines on a regular basis, demonstrating the supply and demand fundamentals that differ from others in the mining sector. The nuclear fuels market does not behave like most other commodity markets. Therefore, we believe that it is prudent to engage with ratings agencies to assist them in understanding the complexities of the industry and our broad participation within the industry as we continue to navigate by an investment grade rating.
As of June 30, 2025, we had cash and cash equivalents of $716 million, while our total debt amounted to approximately $1.0 billion. We have a risk management policy to manage our cash balances and investments, which are largely held in government securities or with banks that are party to our lending facilities. In addition, we have a $1.0 billion revolving credit facility, which remains undrawn.
We expect the low-cost production from our tier one assets will continue to generate strong cash flows, which we expect will meet our capital requirements during 2025. However, cash flow from operations for 2025 will be dependent on our ability to source the material required to meet our deliveries as planned, including achieving our production plans.
We have large, creditworthy customers that continue to need our nuclear fuel products and services even during weak economic conditions, and we expect the contract portfolio we have built will continue to provide a solid revenue stream. In our uranium segment, from 2025 through 2029, including deliveries we have made to date, we have commitments to deliver an average of about 28 million pounds per year, with commitment levels higher than the average in 2025 through 2027 and lower than the average in 2028 and 2029.
With the Supreme Court’s dismissal of CRA’s application for leave, the dispute of the 2003 through 2006 tax years are fully and finally resolved in our favour. Furthermore, we are confident the courts would reject any attempt by CRA to utilize the same position and arguments for tax years 2007 through 2014, or its alternate reassessing position for tax years 2014 through 2017, or its new reassessing position for 2018 and believe CRA should return all cash and letters of credit (to date, $555 million) being held. However, the timing of any further payments is uncertain, and there can be no assurance that the courts will take this position. See Transfer pricing dispute starting on page 14 for more information.
2025 SECOND QUARTER REPORT 21
CASH FROM OPERATIONS
Cash provided by operations was $205 million higher this quarter than in the second quarter of 2024 due primarily to higher earnings and lower working capital requirements.
Cash provided by operations was $252 million higher in the first six months of 2025 compared to the same period in 2024 due primarily to higher earnings, lower working capital requirements and the dividend received from Westinghouse.
FINANCING ACTIVITIES
We use debt to provide additional liquidity. We believe we have sufficient borrowing capacity with unsecured lines of credit of about $2.9 billion at June 30, 2025, a decrease from $3.0 billion at March 31, 2025. The decrease was due to the weakening of the US dollar since March 31. At June 30, 2025, we had approximately $1.5 billion outstanding in financial assurances, which was unchanged from March 31, 2025.
At June 30, 2025, we had no short-term debt outstanding on our $1.0 billion unsecured revolving credit facility, which is unchanged from December 31, 2024. Our revolving credit facility matures October 1, 2028.
Long-term contractual obligations
Since March 31, 2025, there have been no material changes to our long-term contractual obligations. Please see our 2024 annual MD&A for more information.
Debt covenants
As at June 30, 2025, we complied with all covenants in our credit agreements, including the financial covenants. The financial covenants place restrictions on total debt, including guarantees and other financial assurances. We do not expect our operating and investment activities for the remainder of 2025 to be constrained by these covenants.
SHARES AND STOCK OPTIONS OUTSTANDING
At July 29, 2025, we had:
| • | 435,387,448 common shares and one Class B share outstanding |
| • | 184,593 stock options outstanding, with exercise prices ranging from $11.32 to $15.27 |
OFF-BALANCE SHEET ARRANGEMENTS
We had three kinds of off-balance sheet arrangements at June 30, 2025:
| • | purchase commitments |
| • | financial assurances |
| • | other arrangements |
Purchase commitments
We make purchases under long-term contracts where it is beneficial for us to do so and in order to support our long-term contract portfolio. The following table is based on our purchase commitments in our uranium and fuel services segments at June 30, 2025,2 but does not include purchases of our share of JV Inkai production. These commitments include a mix of fixed-price and market-related contracts. Actual payments will be different as a result of changes to our purchase commitments and, in the case of contracts with market-related pricing, the market prices in effect at the time of delivery. We will update this table as required in our MD&A to reflect material changes to our purchase commitments and changes in the prices used to estimate our commitments under market-related contracts.
| 2026 AND | 2028 AND | 2030 AND | ||||||||||||||||||
| JUNE 30 ($ MILLIONS) |
2025 | 2027 | 2029 | BEYOND | TOTAL | |||||||||||||||
| Purchase commitments1,2 |
274 | 251 | 12 | — | 537 | |||||||||||||||
| 1 | Denominated in US dollars and Japanese yen, converted from US dollars to Canadian dollars at the rate of 1.40 and from Japanese yen to Canadian dollars at the rate of $0.01. |
| 2 | These amounts have been adjusted for any additional purchase commitments that we have entered into since June 30, 2025, but does not include deliveries taken under contract since June 30, 2025. |
22 CAMECO CORPORATION
We have purchase commitments of $537 million (Cdn) (previously $617 million (Cdn) at December 31, 2024) for the following:
| • | approximately 7.0 million pounds of U3O8 equivalent (previously 7.8 million at December 31, 2024) from 2025 to 2028 |
| • | approximately 0.1 million kgU as UF6 in conversion services (previously 0.2 million at December 31, 2024) in 2025 |
| • | no commitments for enrichment services (previously 0.3 million SWU at December 31, 2024) |
The suppliers do not have the right to terminate agreements other than pursuant to customary events of default provisions.
Financial assurances
At June 30, 2025, our financial assurances totaled $1.5 billion, unchanged from March 31, 2025.
Other arrangements
We have arranged for standby product loan facilities with various counterparties. The arrangements allow us to borrow up to 2 million kgU of UF6 conversion services and 5.7 million pounds of U3O8 over the period 2020 to 2027 with repayment in-kind up to December 31, 2027 (see note 8 to the financial statements). Under the loan facilities, standby fees of up to 1.5% are payable based on the market value of the facilities and interest is payable on the market value of any amounts drawn at rates ranging from 0.5% to 3.0%. At June 30, 2025, we have 1.5 million kgU of UF6 conversion services and 2.5 million pounds of U3O8 drawn on the loans.
BALANCE SHEET
| ($ MILLIONS) |
JUN 30, 2025 | DEC 31, 2024 | CHANGE | |||||||||
| Cash and cash equivalents |
716 | 600 | 19 | % | ||||||||
| Total debt |
996 | 1,281 | (22 | )% | ||||||||
| Inventory |
587 | 827 | (29 | )% | ||||||||
Total cash and cash equivalents at June 30, 2025 were $716 million, or 19% higher than at December 31, 2024, due mainly to higher earnings and the receipt of $87 million (US) and $49 million (US) of dividend payments from JV Inkai and Westinghouse, partially offset by the repayment of the final $200 million (US) outstanding on our floating-rate term loan. Net debt at June 30, 2025 was approximately $280 million.
Total product inventories are $587 million compared to $827 million at the end of 2024. The average inventory cost for uranium has decreased to $47.88 per pound compared to $59.39 per pound at December 31, 2024. As of June 30, 2025, we held an inventory of 7.6 million pounds of U3O8 equivalent (excluding broken ore) (December 31, 2024 - 11.0 million pounds). Total product inventory value and inventory volume varies from quarter to quarter depending on the inventory cost and the timing of production, purchases and sales deliveries in the year.
2025 SECOND QUARTER REPORT 23
Financial results by segment
Uranium
| THREE MONTHS | SIX MONTHS | |||||||||||||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||||||||||||
| HIGHLIGHTS |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||||
| Production volume (million lb) |
4.6 | 7.1 | (35 | )% | 10.6 | 12.9 | (18 | )% | ||||||||||||||||||
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| Sales volume (million lb) |
8.7 | 6.2 | 40 | % | 15.6 | 13.5 | 16 | % | ||||||||||||||||||
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| Average spot price |
($US/lb) | 72.59 | 87.88 | (17 | )% | 69.38 | 91.10 | (24 | )% | |||||||||||||||||
| Average long-term price |
($US/lb) | 80.00 | 78.50 | 2 | % | 80.17 | 76.67 | 5 | % | |||||||||||||||||
| Average realized price |
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| ($US/lb) | 57.35 | 56.43 | 2 | % | 59.66 | 57.04 | 5 | % | ||||||||||||||||||
| ($Cdn/lb) | 81.03 | 76.93 | 5 | % | 84.62 | 77.15 | 10 | % | ||||||||||||||||||
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| Average unit cost of sales (including D&A) |
($Cdn/lb) | 56.12 | 53.86 | 4 | % | 57.78 | 54.01 | 7 | % | |||||||||||||||||
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| Revenue ($ millions) |
705 | 481 | 47 | % | 1,324 | 1,042 | 27 | % | ||||||||||||||||||
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| Gross profit ($ millions) |
217 | 144 | 51 | % | 420 | 313 | 34 | % | ||||||||||||||||||
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| Gross profit (%) |
31 | 30 | 3 | % | 32 | 30 | 7 | % | ||||||||||||||||||
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| Earnings before income taxes ($ millions) |
281 | 192 | 46 | % | 509 | 445 | 14 | % | ||||||||||||||||||
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| Adjusted EBITDA ($ millions) (non-IFRS, see page 30) |
352 | 246 | 43 | % | 641 | 548 | 17 | % | ||||||||||||||||||
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SECOND QUARTER
Production during the quarter was 4.6 million pounds, 35% lower compared to the second quarter of 2024. See Our Operations starting on page 28 for more information.
Uranium revenues this quarter were up 47% compared to 2024 due to a 40% increase in sales volumes and an increase of 5% in the Canadian dollar average realized price. While the average US dollar spot price for uranium decreased by 17% compared to the same period in 2024, the Canadian dollar average realized price increased by 5% due to the impact of fixed-price contracts on the portfolio. The average realized price was also impacted by a weakening Canadian dollar on US-priced contracts. For more information on the impact of spot price changes on average realized price, see Price sensitivity analysis: uranium segment on page 20. In addition, customers choose when in the year to receive deliveries and as a result, our quarterly delivery patterns and, therefore, our quarterly sales volumes and revenue can vary significantly.
Total cost of sales (including D&A) increased by 45% ($488 million compared to $336 million in 2024) due to an increase of 4% in the average unit cost of sales and a 40% increase in sales volume. In addition, cost of sales was higher than in the second quarter of 2024 due to the costs of the planned annual maintenance shutdown at the Key Lake mill which were expensed directly to cost of sales. The shutdown took place in the second quarter compared to the third quarter in 2024. See table below and Uranium production on page 28.
The net effect was a $73 million increase in gross profit for the quarter.
FIRST SIX MONTHS
Production volumes for the first six months of the year were 18% lower than in the previous year. See Our Operations starting on page 28 for more information.
Uranium revenues increased 27% compared to the first six months of 2024 due to a 16% increase in sales volume and an increase of 10% in the Canadian dollar average realized price. While the average US dollar spot price for uranium decreased by 24% compared to the same period in 2024, the Canadian dollar average realized price increased by 10% due to the impact of fixed-price contracts on the portfolio. The average realized price was also impacted by a weakening Canadian dollar on US-priced contracts. For more information on the impact of spot price changes on average realized price, see Price sensitivity analysis: uranium segment on page 20.
Total cost of sales (including D&A) increased by 24% ($904 million compared to $729 million in 2024) primarily as a result of a 7% increase in the average unit cost of sales and a 16% increase in sales volume compared to the same period last year as well as the costs of the planned shutdown at the Key Lake mill being expensed directly to cost of sales. Unit cost of sales was higher due to the higher cost of purchased material compared to the same period in 2024. See table below and Uranium production on page 28.
24 CAMECO CORPORATION
The net effect was a $107 million increase in gross profit for the first six months.
The table below shows the costs of produced and purchased uranium incurred in the reporting periods (see non-IFRS measures starting on page 30). These costs do not include care and maintenance costs, selling costs such as royalties, transportation and commissions, nor do they reflect the impact of opening inventories on our reported cost of sales.
| THREE MONTHS | SIX MONTHS | |||||||||||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||||||||||
| ($CDN/LB) |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||
| Produced |
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| Cash cost |
26.19 | 16.96 | 54 | % | 24.05 | 18.11 | 33 | % | ||||||||||||||||
| Non-cash cost |
11.66 | 9.10 | 28 | % | 10.90 | 9.41 | 16 | % | ||||||||||||||||
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| Total production cost1 |
37.85 | 26.06 | 45 | % | 34.95 | 27.52 | 27 | % | ||||||||||||||||
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| Quantity produced (million lb)1 |
4.6 | 7.1 | (35 | )% | 10.6 | 12.9 | (18 | )% | ||||||||||||||||
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| Purchased |
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| Cash cost |
97.00 | 109.11 | (11 | )% | 102.74 | 96.25 | 7 | % | ||||||||||||||||
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| Quantity purchased (million lb)1 |
0.7 | 1.7 | (59 | )% | 1.9 | 4.4 | (57 | )% | ||||||||||||||||
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| Totals |
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| Produced and purchased costs |
45.66 | 42.10 | 8 | % | 45.25 | 45.00 | 1 | % | ||||||||||||||||
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| Quantities produced and purchased (million lb) |
5.3 | 8.8 | (40 | )% | 12.5 | 17.3 | (28 | )% | ||||||||||||||||
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| 1 | Due to equity accounting, our share of production from JV Inkai is shown as a purchase at the time of delivery. These purchases will fluctuate during the quarters and timing of purchases will not match production. There were no deliveries during the second quarter, or in the first six months of 2025. |
The average cash cost of production was 54% higher for the quarter compared to the same period in 2024 due to lower production at McArthur River/Key Lake as a result of the timing of the annual planned maintenance shutdown at the Key Lake mill. For the first six months, the average cash cost of production was 33% higher than in the same period in 2024 for the same reason.
The estimated average unit life of mine operating costs reflected in our most recent annual information form are $20.31 per pound at McArthur River/Key Lake and $21.12 per pound at Cigar Lake.
Our purchases in the second quarter of 2025 totaled about $68 million, representing an average cost of $97.00 per pound, about $59.00 per pound higher than our total unit production cost for the quarter. Although purchased pounds are transacted in US dollars, we account for the purchases in Canadian dollars. In the second quarter, the average cash cost of purchased material was $97.00 (Cdn) per pound, or $69.30 (US) per pound, compared to $109.11 (Cdn) per pound, or $80.27 (US) per pound in the second quarter of 2024. As a result, the average cash cost per pound of purchased material in Canadian dollar terms decreased by 11% this quarter compared to the same period last year.
For the first six months of the year, purchases totaled about $195 million, representing an average cost of $102.74 per pound, about $68.00 per pound higher than our total unit production cost for the year. The average cash cost of purchased material for the six-month period was $102.74 (Cdn), or $72.48 (US) per pound, compared to $96.25 (Cdn), or $71.32 (US) per pound in the same period in 2024. As a result, the average cash cost per pound of purchased material in Canadian dollar terms increased by 7% for the six months compared to the same period last year.
We equity account for our share of JV Inkai. As a result, we record our share of its production as a purchase, which under Kazakhstan’s pricing regulations, requires that we purchase the material at a price equal to the uranium spot price, less a 5% discount. Our share of the economic benefit is reflected in the line item on our statement of earnings called, “share of earnings from equity-accounted investee” and is based on the difference between our purchase price and JV Inkai’s lower production cost (estimated average unit life of mine operating cash cost of $12.62 per pound). If there is a significant disruption to JV Inkai’s operations for any reason, it may not achieve its production plans, there may be a delay in production, and it may experience increased costs to produce uranium.
JV Inkai contribution to uranium segment
In the second quarter, included in net earnings attributable to equity holders for the uranium segment is $62 million of equity earnings and included in adjusted EBITDA is $70 million from JV Inkai, compared to $48 million and $52 million respectively in the same period last year.
2025 SECOND QUARTER REPORT 25
For the first six months of the year, $98 million is included in net earnings attributable to equity holders and $114 million is included in adjusted EBITDA from JV Inkai, compared to $125 million and $157 million respectively in the same periods last year.
The increase in JV Inkai’s equity earnings and adjusted EBITDA in the second quarter of 2025 was largely driven by the timing of sales. The decrease in JV Inkai’s equity earnings and adjusted EBITDA for the first six months of the year was driven by the timing of sales, lower uranium prices and increased costs compared to the prior year. In April, we received a cash dividend of $87 million (US), net of withholdings, based on JV Inkai’s 2024 financial performance. From a cash flow perspective, we expect to realize the benefit from JV Inkai’s 2025 financial performance in 2026, once the dividend for 2025 is declared and paid.
The following table reconciles our share of earnings from JV Inkai to adjusted EBITDA:
| THREE MONTHS | SIX MONTHS | |||||||||||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||||||||||
| ($ MILLIONS) |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||
| Share of earnings from equity-accounted investee |
62 | 48 | 29 | % | 98 | 125 | (22 | )% | ||||||||||||||||
| Depreciation and amortization |
4 | 2 | 100 | % | 4 | 10 | (60 | )% | ||||||||||||||||
| Finance income |
(1 | ) | — | >100 | % | (1 | ) | — | >100 | % | ||||||||||||||
| Income tax expense |
7 | 4 | 75 | % | 8 | 24 | (67 | )% | ||||||||||||||||
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| EBITDA (non-IFRS, see page 30) attributable to JV Inkai |
72 | 54 | 33 | % | 109 | 159 | (31 | )% | ||||||||||||||||
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| Unrealized foreign exchange losses (gains) |
(2 | ) | (2 | ) | — | 5 | (2 | ) | >(100 | )% | ||||||||||||||
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| Adjusted EBITDA (non-IFRS, see page 30) |
70 | 52 | 35 | % | 114 | 157 | (27 | )% | ||||||||||||||||
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Fuel services
(includes results for UF6, UO2, UO3 and fuel fabrication)
| THREE MONTHS | SIX MONTHS | |||||||||||||||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||||||||||||||
| HIGHLIGHTS |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||||||
| Production volume (million kgU) |
3.2 | 2.9 | 10 | % | 7.1 | 6.7 | 6 | % | ||||||||||||||||||||
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| Sales volume (million kgU) |
4.4 | 2.9 | 52 | % | 6.8 | 4.4 | 55 | % | ||||||||||||||||||||
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| Average realized price |
($ | Cdn/kgU | ) | 36.79 | 39.98 | (8 | )% | 43.75 | 42.80 | 2 | % | |||||||||||||||||
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| Average unit cost of sales (including D&A) |
($ | Cdn/kgU | ) | 27.32 | 29.05 | (6 | )% | 27.51 | 31.35 | (12 | )% | |||||||||||||||||
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| Revenue ($ millions) |
162 | 118 | 37 | % | 297 | 190 | 56 | % | ||||||||||||||||||||
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| Earnings before income taxes ($ millions) |
44 | 33 | 33 | % | 112 | 53 | >100 | % | ||||||||||||||||||||
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| Adjusted EBITDA ($ millions) (non-IFRS, |
57 | 42 | 36 | % | 132 | 67 | 97 | % | ||||||||||||||||||||
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| Adjusted EBITDA margin (%) (non-IFRS, |
35 | 36 | (3 | )% | 44 | 35 | 26 | % | ||||||||||||||||||||
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SECOND QUARTER
Total revenue for the second quarter of 2025 increased by 37% from $118 million in the same period last year to $162 million. This was due primarily to a 52% increase in sales volume partially offset by an 8% decrease in realized price. The decrease in average realized price was mainly the result of variations in the timing of completion and delivery related to fuel fabrication at Cameco Fuel Manufacturing (CFM). Customers choose when in the year to receive deliveries and as a result, our quarterly delivery patterns and, therefore, our sales volumes and revenue can vary significantly.
The total cost of products and services sold (including D&A) increased 40% ($120 million compared to $86 million in 2024) due to a 52% increase in sales volume, which was partially offset by a decrease of 6% in the average unit cost of sales. Average unit cost of sales decreased due to the mix of products and services sold this year compared to the same period last year.
The net effect was an $11 million increase in net earnings.
FIRST SIX MONTHS
In the first six months of the year, total revenue increased 56% to $297 million from $190 million for the same period last year due to a 2% increase in average realized price and a 55% increase in sales volume. The increase in average realized price was mainly the result of contracts that were entered into in an improved price environment and the impact of a weakening Canadian dollar on US priced contracts. Customers choose when in the year to receive deliveries and as a result, our quarterly delivery patterns and, therefore, our sales volumes and revenue can vary significantly.
26 CAMECO CORPORATION
The total cost of products and services sold (including D&A) increased 35% ($187 million compared to $139 million in 2024) due to a 55% increase in sales volume partially offset by a 12% decrease in the average unit cost of sales. Average unit cost of sales decreased due to the mix of products and services sold this year compared to the same period last year.
The net effect was a $59 million increase in net earnings.
Westinghouse
OUR EARNINGS FROM WESTINGHOUSE
Westinghouse is one of the world’s largest nuclear services businesses owned in a strategic partnership between Cameco and Brookfield, where Cameco owns a 49% interest and Brookfield owns the remaining 51%. Cameco accounts for its interest under the equity method of accounting in Canadian dollars.
| THREE MONTHS | SIX MONTHS | |||||||||||||||||||||||
| CAMECO SHARE | ENDED JUNE 30 | ENDED JUNE 30 | ||||||||||||||||||||||
| ($CAD MILLIONS) |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | ||||||||||||||||||
| Net earnings (loss) |
126 | (47 | ) | >100 | % | 64 | (170 | ) | >100 | % | ||||||||||||||
| Depreciation and amortization |
95 | 89 | 7 | % | 192 | 173 | 11 | % | ||||||||||||||||
| Finance income |
(1 | ) | (1 | ) | — | (1 | ) | (3 | ) | 67 | % | |||||||||||||
| Finance costs |
51 | 54 | (6 | )% | 100 | 118 | (15 | )% | ||||||||||||||||
| Income tax expense (recovery) |
46 | (11 | ) | >100 | % | 29 | (48 | ) | >100 | % | ||||||||||||||
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| EBITDA2 |
317 | 84 | >100 | % | 384 | 70 | >100 | % | ||||||||||||||||
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| Inventory purchase accounting1 |
5 | 17 | (71 | )% | 5 | 66 | (92 | )% | ||||||||||||||||
| Restructuring costs |
14 | 11 | 27 | % | 26 | 22 | 18 | % | ||||||||||||||||
| Other expenses |
16 | 3 | >100 | % | 30 | 15 | 100 | % | ||||||||||||||||
| Acquisition-related transition costs |
— | 6 | (100 | )% | — | 24 | (100 | )% | ||||||||||||||||
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| Adjusted EBITDA2 |
352 | 121 | >100 | % | 445 | 197 | >100 | % | ||||||||||||||||
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| Capital expenditures |
46 | 32 | 44 | % | 89 | 65 | 37 | % | ||||||||||||||||
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| Adjusted free cash flow2 |
306 | 89 | >100 | % | 356 | 132 | >100 | % | ||||||||||||||||
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| Revenue |
1,033 | 670 | 54 | % | 1,803 | 1,325 | 36 | % | ||||||||||||||||
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| Adjusted EBITDA margin2 |
34 | % | 18 | % | 89 | % | 25 | % | 15 | % | 67 | % | ||||||||||||
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| 1 | Net earnings for 2024 and 2025 were impacted by purchase price accounting. Inventories acquired were assigned values based on the market price at the date of acquisition. As these quantities are sold, cost of products and services sold reflects these market values, regardless of Westinghouse’s historic costs. |
| 2 | Non-IFRS measures, see page 30. |
SECOND QUARTER
In the second quarter, adjusted EBITDA was $352 million, compared to $121 million in the same period last year. The improvement over last year is primarily related to the $170 million (US) increase in our share of Westinghouse’s 2025 second quarter revenue tied to Westinghouse’s participation in the construction project for two nuclear reactors at the Dukovany power plant in the Czech Republic.
FIRST SIX MONTHS
In the first six months of the year, adjusted EBITDA was $445 million, compared to $197 million in the same period last year, mainly as a result of the increase in our share of Westinghouse’s second quarter revenue tied to the Dukovany construction project. We use adjusted EBITDA as a performance measure as the impact of the revaluation of Westinghouse’s inventory and assets and the non-operating acquisition-related transition costs do not reflect the underlying performance for the reporting period.
Westinghouse’s quarterly results are not necessarily a good indication of annual results due to variability in timing of customer requirements and delivery and outage schedules. The first half of 2025 was expected to be weaker, with stronger performance and higher quarterly cash flows expected in the fourth quarter. We now expect Westinghouse’s performance in the second quarter of 2025 to be the strongest due to the increase in our share of Westinghouse’s second quarter revenue related to its participation in the Dukovany construction project. Higher quarterly cash flows continue to be expected in the fourth quarter.
2025 SECOND QUARTER REPORT 27
Our operations
Uranium – production overview
We produced 4.6 million pounds of U3O8 (our share) in the second quarter and 10.6 million pounds production (our share) in the first six months of 2025, compared to 7.1 million pounds and 12.9 million pounds in the same periods of 2024.
We continue to evaluate the optimal mix of production, inventory and purchases in order to retain flexibility and deliver long-term value.
URANIUM PRODUCTION
| THREE MONTHS | SIX MONTHS | |||||||||||||||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||||||||||||||
| OUR SHARE (MILLION LB) |
2025 | 2024 | CHANGE | 2025 | 2024 | CHANGE | 2025 PLAN | |||||||||||||||||||||
| Cigar Lake |
2.8 | 2.9 | (3 | )% | 5.5 | 5.1 | 8 | % | 9.8 | |||||||||||||||||||
| McArthur River/Key Lake |
1.8 | 4.2 | (57 | )% | 5.1 | 7.8 | (35 | )% | 12.6 | |||||||||||||||||||
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| Total |
4.6 | 7.1 | (35 | )% | 10.6 | 12.9 | (18 | )% | 22.4 | |||||||||||||||||||
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Inflation, the availability of personnel with the necessary skills and experience, aging infrastructure, and the impact of supply chain challenges on the availability of materials and reagents carry with them the risk that we do not achieve our production plans and/or, experience production delays and increased costs.
At the Key Lake mill, an annual maintenance shutdown took place in the second quarter. There is no planned shutdown of the McArthur River mine in 2025. The annual maintenance outage at Cigar Lake will take place in the third quarter, which is similar timing to previous years.
Uranium 2025 Q2 updates
PRODUCTION UPDATE
McArthur River/Key Lake
In the second quarter of 2025, total packaged production from McArthur River and Key Lake was 2.6 million pounds (1.8 million pounds our share) compared to 6.2 million pounds (4.2 million pounds our share) in the second quarter of 2024. In the first six months of the year, total packaged production from McArthur River and Key Lake was 7.3 million pounds (5.1 million pounds our share) compared to 11.2 million pounds (7.8 million pounds our share) in the first six months of 2024. The lower packaged production is primarily due to the operation’s annual maintenance shutdown occurring in the second quarter of 2025, which occurred during the third quarter of 2024.
We continue to expect production of 18 million pounds (12.6 million pounds our share) in 2025. However, at McArthur River, there have been some development delays, which have increased the potential risks to our 2025 production outlook. The potential risks include the expected timing of ground freezing and development schedules in new mining areas, access to adequate skilled labour, and the timing of commissioning for new equipment. We continue to monitor these risks, and they could have an impact on our packaged production in the second half of 2025 if alternative plans are not successful in offsetting the delays incurred.
The collective agreement with the United Steelworkers Local 8914 expires in December 2025. As such, we expect the impact risk of a labour dispute, if it were to occur, to be minimal in 2025.
Cigar Lake
Total packaged production from Cigar Lake was 5.1 million pounds (2.8 million pounds our share) in the second quarter of 2025 compared to 5.3 million pounds (2.9 million pounds our share) in the second quarter of 2024. In the first six months of the year, total packaged production from Cigar Lake was 10.1 million (5.5 million pounds our share) compared to 9.5 million pounds (5.1 million pounds our share) in the first six months of 2024.
We continue to expect production of 18 million pounds (9.8 million pounds our share) in 2025.
28 CAMECO CORPORATION
Inkai
Production on a 100% basis was 2.3 million pounds for the quarter, and 3.5 million pounds for the first six months of this year, compared to 1.9 million pounds and 3.5 million pounds, respectively in the same period last year. Following the unplanned, temporary production suspension in January 2025, the adjusted mine plan resulted in higher second quarter production to bring production for the first six months back in line with the annual production plan.
JV Inkai is targeting 2025 production of 8.3 million pounds (100% basis) of which our purchase allocation is 3.7 million pounds. The temporary suspension did not have a material impact on JV Inkai’s 2025 outlook. The achievement of JV Inkai’s 2025 production target requires it to successfully manage several ongoing risks, including the availability of sulfuric acid, other procurement and supply chain issues, transportation challenges, construction delays and inflationary pressures on its production costs.
Due to equity accounting, our share of production is shown as a purchase at a 5% discount to the spot price and included in inventory at this value at the time of delivery. We continue to expect shipments of our remaining share of 2024 production (approximately 900,000 pounds) and the majority of our share of 2025 production to be made from JV Inkai in the second half of 2025. Our share of the profits earned by JV Inkai on the sale of its production to the joint venture partners is included in “share of earnings from equity-accounted investee” on our consolidated statement of earnings. Excess cash, net of working capital requirements, is distributed to the partners as dividends once declared.
The geopolitical situation continues to cause transportation risks in the region. We could continue to experience delays in our expected Inkai deliveries. To mitigate this risk, we have inventory, long-term purchase agreements and loan arrangements in place we can utilize. Depending on when we receive shipments of our share of Inkai’s production, our share of earnings from this equity-accounted investee and the timing of the receipt of our share of dividends from the joint venture may be impacted.
TIER-TWO CURTAILED OPERATIONS
US ISR Operations
As a result of our 2016 curtailment decision, commercial production has ceased. As production is suspended, we expect ongoing cash and non-cash care and maintenance costs to range between $14 million (US) and $15 million (US) for 2025.
Rabbit Lake
Rabbit Lake remains in a safe state of care and maintenance following the suspension of production in 2016. We continue to evaluate opportunities to minimize care and maintenance costs while maintaining critical infrastructure and processes. We expect care and maintenance costs to range between $43 million and $47 million for 2025.
Fuel services 2025 Q2 updates
PORT HOPE CONVERSION SERVICES
CAMECO FUEL MANUFACTURING INC. (CFM)
Production update
Fuel services produced 3.2 million kgU in the second quarter of 2025, 10% higher than the second quarter of 2024. Production in the first six months of 2025 was 7.1 million kgU, 6% higher compared to the same period last year.
Our fuel services segment includes the combined production of UO2, UF6, and heavy water reactor fuel bundles. Our annual production expectation for fuel services remains between 13 million and 14 million kgU of combined fuel services products in 2025 (outlook and production results are not disclosed by individual product line).
We continue to work towards achieving a UF6 production rate of 12,000 tonnes per year, closely aligned with our licensed capacity in order to satisfy our book of long-term commitments and demand for conversion services. Inflation, the availability of personnel with the necessary skills and experience, aging infrastructure, and the impact of supply chain challenges on the availability of materials and reagents carry with them the risk that we do not achieve our production plans and/or experience production delays and increased costs.
Labour relations
A new collective agreement with unionized employees at our Port Hope conversion facility was reached in July 2025 for a three-year term, expiring in June 2028.
2025 SECOND QUARTER REPORT 29
Qualified persons
The technical and scientific information discussed in this document for our material properties (McArthur River/Key Lake, Inkai and Cigar Lake) was approved by the following individuals who are qualified persons for the purposes of NI 43-101:
| MCARTHUR RIVER/KEY LAKE
• Greg Murdock, general manager, McArthur River, Cameco
• Daley McIntyre, general manager, Key Lake, Cameco
CIGAR LAKE
• Kirk Lamont, general manager, Cigar Lake, Cameco |
INKAI
• Sergey Ivanov, deputy general director, technical services, Cameco Kazakhstan LLP |
Non-IFRS measures
The non-IFRS measures referenced in this document are supplemental measures, which are used as indicators of our financial performance. Management believes that these non-IFRS measures provide useful supplemental information to investors, securities analysts, lenders and other interested parties in assessing our operational performance and our ability to generate cash flows to meet our cash requirements. These measures are not recognized measures under IFRS, do not have standardized meanings, and are therefore unlikely to be comparable to similarly titled measures presented by other companies. Accordingly, these measures should not be considered in isolation or as a substitute for the financial information reported under IFRS. We are not able to reconcile our forward-looking non-IFRS guidance because we cannot predict the timing and amounts of discrete items, which could significantly impact our IFRS results.
The following are the non-IFRS measures used in this document.
ADJUSTED NET EARNINGS
Adjusted net earnings is our net earnings attributable to equity holders, adjusted for non-operating or non-cash items such as gains and losses on derivatives, unrealized foreign exchange gains and losses, share-based compensation and adjustments to reclamation provisions flowing through other operating expenses, that we believe do not reflect the underlying financial performance for the reporting period. In 2024, we revised our calculation of adjusted net earnings to adjust for unrealized foreign exchange gains and losses as well as for share-based compensation because it better reflects how we assess our operational performance. We have restated comparative periods to reflect this change. Other items may also be adjusted from time to time. We adjust this measure for certain of the items that our equity-accounted investees make in arriving at other non-IFRS measures. Adjusted net earnings is one of the targets that we measure to form the basis for a portion of annual employee and executive compensation (see Measuring our results starting on page 36 of our 2024 annual report).
In calculating ANE we adjust for derivatives. We do not use hedge accounting under IFRS and, therefore, we are required to report gains and losses on all hedging activity, both for contracts that close in the period and those that remain outstanding at the end of the period. For the contracts that remain outstanding, we must treat them as though they were settled at the end of the reporting period (mark-to-market). However, we do not believe the gains and losses that we are required to report under IFRS appropriately reflect the intent of our hedging activities, so we make adjustments in calculating our ANE to better reflect the impact of our hedging program in the applicable reporting period. See Foreign exchange starting on page 16 for more information.
We also adjust for changes to our reclamation provisions that flow directly through earnings. Every quarter we are required to update the reclamation provisions for all operations based on new cash flow estimates, discount and inflation rates. This normally results in an adjustment to an asset retirement obligation asset in addition to the provision balance. When the assets of an operation have been written off due to an impairment, as is the case with our Rabbit Lake and US ISR operations, the adjustment is recorded directly to the statement of earnings as “other operating expense (income)”. See note 9 of our interim financial statements for more information. This amount has been excluded from our ANE measure.
30 CAMECO CORPORATION
As a result of the change in ownership of Westinghouse when it was acquired by Cameco and Brookfield, Westinghouse’s inventories at the acquisition date were revalued based on the market price at that date. As these quantities are sold, Westinghouse’s cost of products and services sold reflect these market values, regardless of their historic costs. Our share of these costs is included in earnings from equity-accounted investees and recorded in cost of products and services sold in the investee information (see note 6 to the financial statements). Since this expense is non-cash, outside of the normal course of business and only occurred due to the change in ownership, we have excluded our share from our ANE measure.
Westinghouse has also expensed some non-operating acquisition-related transition costs that the acquiring parties agreed to pay for, which resulted in a reduction in the purchase price paid. Our share of these costs is included in earnings from equity-accounted investees and recorded in other expenses in the investee information (see note 6 to the financial statements). Since this expense is outside of the normal course of business and only occurred due to the change in ownership, we have excluded our share from our ANE measure.
To facilitate a better understanding of these measures, the table below reconciles adjusted net earnings with our net earnings for the second quarter and first six months of 2025 and compares it to the same periods in 2024.
| THREE MONTHS | SIX MONTHS | |||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||
| ($ MILLIONS) |
2025 | 2024 | 2025 | 2024 | ||||||||||||
| Net earnings attributable to equity holders |
321 | 36 | 391 | 29 | ||||||||||||
|
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|
|
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|
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|
|||||||||
| Adjustments |
||||||||||||||||
| Adjustments on derivatives |
(163 | ) | 14 | (175 | ) | 47 | ||||||||||
| Unrealized foreign exchange losses (gains) |
71 | (7 | ) | 67 | (25 | ) | ||||||||||
| Share-based compensation |
39 | 15 | 37 | 23 | ||||||||||||
| Adjustments on other operating expense (income) |
(8 | ) | (2 | ) | (7 | ) | (17 | ) | ||||||||
| Income taxes on adjustments |
35 | (7 | ) | 39 | (16 | ) | ||||||||||
| Adjustments on equity investees (net of tax): |
||||||||||||||||
| Inventory purchase accounting |
4 | 12 | 4 | 50 | ||||||||||||
| Acquisition-related transition costs |
— | 5 | — | 19 | ||||||||||||
| Unrealized foreign exchange losses (gains) |
(2 | ) | (2 | ) | 5 | (2 | ) | |||||||||
| Other expenses1 |
11 | 1 | 17 | 3 | ||||||||||||
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| Adjusted net earnings |
308 | 65 | 378 | 111 | ||||||||||||
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| 1 | Other expenses includes Westinghouse’s unrealized foreign exchange losses (gains) and costs related to long-term incentive plans. |
2025 SECOND QUARTER REPORT 31
The following table shows what contributed to the change in adjusted net earnings in the second quarter and first six months of 2025 compared to the same periods in 2024.
| THREE MONTHS | SIX MONTHS | |||||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||||
| ($ MILLIONS) |
IFRS | ADJUSTED | IFRS | ADJUSTED | ||||||||||||||
| Net earnings – 2024 |
36 | 65 | 29 | 111 | ||||||||||||||
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| Change in gross profit by segment |
||||||||||||||||||
| (We calculate gross profit by deducting from revenue the cost of products and services sold, and depreciation and amortization (D&A), net of hedging benefits) |
|
|||||||||||||||||
| Uranium |
Impact from sales volume changes |
57 | 57 | 50 | 50 | |||||||||||||
| Higher realized prices ($US) |
11 | 11 | 55 | 55 | ||||||||||||||
| Foreign exchange impact on realized prices |
24 | 24 | 61 | 61 | ||||||||||||||
| Higher costs |
(19 | ) | (19 | ) | (59 | ) | (58 | ) | ||||||||||
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| Change – uranium |
73 | 73 | 107 | 108 | ||||||||||||||
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| Fuel services |
Impact from sales volume changes |
16 | 16 | 27 | 27 | |||||||||||||
| Higher (lower) realized prices ($Cdn) |
(14 | ) | (14 | ) | 6 | 6 | ||||||||||||
| Lower costs |
7 | 7 | 26 | 26 | ||||||||||||||
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| Change – fuel services |
9 | 9 | 59 | 59 | ||||||||||||||
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| Other changes |
||||||||||||||||||
| Higher administration expenditures |
(30 | ) | (6 | ) | (29 | ) | (16 | ) | ||||||||||
| Lower exploration and research and development expenditures |
6 | 6 | — | — | ||||||||||||||
| Change in reclamation provisions |
8 | 2 | (11 | ) | (1 | ) | ||||||||||||
| Higher earnings from equity-accounted investees |
187 | 184 | 207 | 163 | ||||||||||||||
| Change in gains or losses on derivatives |
167 | (10 | ) | 199 | (23 | ) | ||||||||||||
| Change in foreign exchange gains or losses |
(94 | ) | (16 | ) | (112 | ) | (20 | ) | ||||||||||
| Lower finance income |
(3 | ) | (3 | ) | (5 | ) | (5 | ) | ||||||||||
| Lower finance costs |
16 | 16 | 25 | 25 | ||||||||||||||
| Change in income tax recovery or expense |
(53 | ) | (11 | ) | (75 | ) | (20 | ) | ||||||||||
| Other |
(1 | ) | (1 | ) | (3 | ) | (3 | ) | ||||||||||
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| Net earnings - 2025 |
321 | 308 | 391 | 378 | ||||||||||||||
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EBITDA
EBITDA is defined as net earnings attributable to equity holders, adjusted for the costs related to the impact of the company’s capital and tax structure including depreciation and amortization, finance income, finance costs (including accretion) and income taxes.
ADJUSTED EBITDA
Adjusted EBITDA is defined as EBITDA, as further adjusted for the impact of certain costs or benefits incurred in the period which are either not indicative of the underlying business performance or that impact the ability to assess the operating performance of the business. These adjustments include the amounts noted in the ANE definition.
In calculating adjusted EBITDA, we also adjust for items included in the results of our equity-accounted investees that are not adjustments to arrive at our ANE measure. These items are reported as part of other expenses within the investee financial information and are not representative of the underlying operations. These include gains/losses on undesignated hedges, transaction, integration and restructuring costs related to acquisitions and gains/losses on disposition of business.
The company may realize similar gains or incur similar expenditures in the future.
ADJUSTED FREE CASH FLOW
Adjusted free cash flow is defined as adjusted EBITDA less capital expenditures for the period.
ADJUSTED EBITDA MARGIN
Adjusted EBITDA margin is defined as adjusted EBITDA divided by revenue for the appropriate period.
32 CAMECO CORPORATION
EBITDA, adjusted EBITDA, adjusted free cash flow, and adjusted EBITDA margin are non-IFRS measures which allow us and other users to assess results of operations from a management perspective without regard for our capital structure. To facilitate a better understanding of these measures, the tables below reconcile earnings before income taxes with EBITDA and adjusted EBITDA for the first quarter of 2025 and 2024.
For the quarter ended June 30, 2025:
| FUEL | ||||||||||||||||||||
| ($ MILLIONS) |
URANIUM1 | SERVICES | WESTINGHOUSE | OTHER | TOTAL | |||||||||||||||
| Net earnings (loss) before income taxes2 |
281 | 44 | 126 | (130 | ) | 321 | ||||||||||||||
| Depreciation and amortization |
71 | 13 | — | 2 | 86 | |||||||||||||||
| Finance income |
— | — | — | (5 | ) | (5 | ) | |||||||||||||
| Finance costs |
— | — | — | 27 | 27 | |||||||||||||||
| Income taxes |
— | — | — | 71 | 71 | |||||||||||||||
|
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|
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|
|||||||||||
| 352 | 57 | 126 | (35) | 500 | ||||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Depreciation and amortization |
4 | — | 95 | — | 99 | |||||||||||||||
| Finance income |
(1 | ) | — | (1 | ) | — | (2 | ) | ||||||||||||
| Finance expense |
— | — | 51 | — | 51 | |||||||||||||||
| Income taxes |
7 | — | 46 | — | 53 | |||||||||||||||
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| Net adjustments on equity investees |
10 | — | 191 | — | 201 | |||||||||||||||
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| EBITDA |
362 | 57 | 317 | (35 | ) | 701 | ||||||||||||||
| Loss on derivatives |
— | — | — | (163 | ) | (163 | ) | |||||||||||||
| Other operating income |
(8 | ) | — | — | — | (8 | ) | |||||||||||||
| Share-based compensation |
— | — | — | 39 | 39 | |||||||||||||||
| Unrealized foreign exchange losses |
— | — | — | 71 | 71 | |||||||||||||||
|
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|
|||||||||||
| 354 | 57 | 317 | (88) | 640 | ||||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Inventory purchase accounting |
— | — | 5 | — | 5 | |||||||||||||||
| Restructuring costs |
— | — | 14 | — | 14 | |||||||||||||||
| Other expenses |
— | — | 16 | — | 16 | |||||||||||||||
| Unrealized foreign exchange gains |
(2 | ) | — | — | — | (2 | ) | |||||||||||||
|
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| Net adjustments on equity investees |
(2 | ) | — | 35 | — | 33 | ||||||||||||||
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| Adjusted EBITDA |
352 | 57 | 352 | (88 | ) | 673 | ||||||||||||||
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| 1 | JV Inkai adjusted EBITDA of $70 million is included in the uranium segment. See Financial results by segment - Uranium for reconciliation. |
| 2 | Westinghouse earnings are after income taxes. |
2025 SECOND QUARTER REPORT 33
For the quarter ended June 30, 2024:
| FUEL | ||||||||||||||||||||
| ($ MILLIONS) |
URANIUM1 | SERVICES | WESTINGHOUSE | OTHER | TOTAL | |||||||||||||||
| Net earnings (loss) before income taxes2 |
192 | 33 | (47 | ) | (142 | ) | 36 | |||||||||||||
| Depreciation and amortization |
52 | 9 | — | 1 | 62 | |||||||||||||||
| Finance income |
— | — | — | (8 | ) | (8 | ) | |||||||||||||
| Finance costs |
— | — | — | 43 | 43 | |||||||||||||||
| Income taxes |
— | — | — | 18 | 18 | |||||||||||||||
|
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|
|||||||||||
| 244 | 42 | (47 | ) | (88 | ) | 151 | ||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Depreciation and amortization |
2 | — | 89 | — | 91 | |||||||||||||||
| Finance income |
— | — | (1 | ) | — | (1 | ) | |||||||||||||
| Finance expense |
— | — | 54 | — | 54 | |||||||||||||||
| Income taxes |
4 | — | (11 | ) | — | (7 | ) | |||||||||||||
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| Net adjustments on equity investees |
6 | — | 131 | — | 137 | |||||||||||||||
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| EBITDA |
250 | 42 | 84 | (88 | ) | 288 | ||||||||||||||
| Gain on derivatives |
— | — | — | 14 | 14 | |||||||||||||||
| Other operating income |
(2 | ) | — | — | — | (2 | ) | |||||||||||||
| Share-based compensation |
— | — | — | 15 | 15 | |||||||||||||||
| Unrealized foreign exchange gains |
— | — | — | (7 | ) | (7 | ) | |||||||||||||
|
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|
|||||||||||
| 248 | 42 | 84 | (66 | ) | 308 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Acquisition-related transition costs |
— | — | 6 | — | 6 | |||||||||||||||
| Inventory purchase accounting |
— | — | 17 | — | 17 | |||||||||||||||
| Restructuring costs |
— | — | 11 | — | 11 | |||||||||||||||
| Other expenses |
— | — | 3 | — | 3 | |||||||||||||||
| Unrealized foreign exchange gains |
(2 | ) | — | — | — | (2 | ) | |||||||||||||
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| Net adjustments on equity investees |
(2 | ) | — | 37 | — | 35 | ||||||||||||||
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| Adjusted EBITDA |
246 | 42 | 121 | (66 | ) | 343 | ||||||||||||||
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| 1 | JV Inkai adjusted EBITDA of $52 million is included in the uranium segment. See Financial results by segment - Uranium for reconciliation. |
| 2 | Westinghouse earnings are after income taxes. |
For the six months ended June 30, 2025:
| FUEL | ||||||||||||||||||||
| ($ MILLIONS) |
URANIUM1 | SERVICES | WESTINGHOUSE | OTHER | TOTAL | |||||||||||||||
| Net earnings (loss) before income taxes2 |
509 | 112 | 64 | (294 | ) | 391 | ||||||||||||||
| Depreciation and amortization |
123 | 20 | — | 4 | 147 | |||||||||||||||
| Finance income |
— | — | — | (9 | ) | (9 | ) | |||||||||||||
| Finance costs |
— | — | — | 57 | 57 | |||||||||||||||
| Income taxes |
— | — | — | 124 | 124 | |||||||||||||||
|
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|
|||||||||||
| 632 | 132 | 64 | (118 | ) | 710 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Depreciation and amortization |
4 | — | 192 | — | 196 | |||||||||||||||
| Finance income |
(1 | ) | — | (1 | ) | — | (2 | ) | ||||||||||||
| Finance expense |
— | — | 100 | — | 100 | |||||||||||||||
| Income taxes |
8 | — | 29 | — | 37 | |||||||||||||||
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| Net adjustments on equity investees |
11 | — | 320 | — | 331 | |||||||||||||||
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|
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| EBITDA |
643 | 132 | 384 | (118 | ) | 1,041 | ||||||||||||||
| Loss on derivatives |
— | — | — | (175 | ) | (175 | ) | |||||||||||||
| Other operating income |
(7 | ) | — | — | — | (7 | ) | |||||||||||||
| Share-based compensation |
— | — | — | 37 | 37 | |||||||||||||||
| Unrealized foreign exchange losses |
— | — | — | 67 | 67 | |||||||||||||||
|
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|
|||||||||||
| 636 | 132 | 384 | (189 | ) | 963 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Inventory purchase accounting |
— | — | 5 | — | 5 | |||||||||||||||
| Restructuring costs |
— | — | 26 | — | 26 | |||||||||||||||
| Other expenses |
— | — | 30 | — | 30 | |||||||||||||||
| Unrealized foreign exchange losses |
5 | — | — | — | 5 | |||||||||||||||
|
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| Net adjustments on equity investees |
5 | — | 61 | — | 66 | |||||||||||||||
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| Adjusted EBITDA |
641 | 132 | 445 | (189 | ) | 1,029 | ||||||||||||||
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| 1 | JV Inkai adjusted EBITDA of $114 million is included in the uranium segment. See Financial results by segment - Uranium for reconciliation. |
| 2 | Westinghouse earnings are after income taxes. |
34 CAMECO CORPORATION
For the six months ended June 30, 2024:
| FUEL | ||||||||||||||||||||
| ($ MILLIONS) |
URANIUM1 | SERVICES | WESTINGHOUSE | OTHER | TOTAL | |||||||||||||||
| Net earnings (loss) before income taxes2 |
445 | 53 | (170 | ) | (299 | ) | 29 | |||||||||||||
| Depreciation and amortization |
88 | 14 | — | 2 | 104 | |||||||||||||||
| Finance income |
— | — | — | (14 | ) | (14 | ) | |||||||||||||
| Finance costs |
— | — | — | 82 | 82 | |||||||||||||||
| Income taxes |
— | — | — | 49 | 49 | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 533 | 67 | (170 | ) | (180 | ) | 250 | ||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Depreciation and amortization |
10 | — | 173 | — | 183 | |||||||||||||||
| Finance income |
— | — | (3 | ) | — | (3 | ) | |||||||||||||
| Finance expense |
— | — | 118 | — | 118 | |||||||||||||||
| Income taxes |
24 | — | (48 | ) | — | (24 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
34 | — | 240 | — | 274 | |||||||||||||||
|
|
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|
|
|
|
|
|
|
|
|||||||||||
| EBITDA |
567 | 67 | 70 | (180 | ) | 524 | ||||||||||||||
| Gain on derivatives |
— | — | — | 47 | 47 | |||||||||||||||
| Other operating income |
(17 | ) | — | — | — | (17 | ) | |||||||||||||
| Share-based compensation |
— | — | — | 23 | 23 | |||||||||||||||
| Unrealized foreign exchange gains |
— | — | — | (25 | ) | (25 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| 550 | 67 | 70 | (135 | ) | 552 | |||||||||||||||
| Adjustments on equity investees |
||||||||||||||||||||
| Acquisition-related transition costs |
— | — | 24 | — | 24 | |||||||||||||||
| Inventory purchase accounting |
— | — | 66 | — | 66 | |||||||||||||||
| Restructuring costs |
— | — | 22 | — | 22 | |||||||||||||||
| Other expenses |
— | — | 15 | — | 15 | |||||||||||||||
| Unrealized foreign exchange gains |
(2 | ) | — | — | — | (2 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
| Net adjustments on equity investees |
(2 | ) | — | 127 | — | 125 | ||||||||||||||
|
|
|
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|
|
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|
|
|||||||||||
| Adjusted EBITDA |
548 | 67 | 197 | (135 | ) | 677 | ||||||||||||||
|
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|
|||||||||||
| 1 | JV Inkai adjusted EBITDA of $157 million is included in the uranium segment. See Financial results by segment - Uranium for reconciliation. |
| 2 | Westinghouse earnings are after income taxes. |
CASH COST PER POUND, NON-CASH COST PER POUND AND TOTAL COST PER POUND FOR PRODUCED AND PURCHASED URANIUM
Cash cost per pound, non-cash cost per pound and total cost per pound for produced and purchased uranium are non-IFRS measures. We use these measures in our assessment of the performance of our uranium business. These measures are not necessarily indicative of operating profit or cash flow from operations as determined under IFRS.
To facilitate a better understanding of these measures, the table below reconciles these measures to cost of product sold and depreciation and amortization for the second quarter and first six months of 2025 and 2024.
| THREE MONTHS | SIX MONTHS | |||||||||||||||
| ENDED JUNE 30 | ENDED JUNE 30 | |||||||||||||||
| ($ MILLIONS) |
2025 | 2024 | 2025 | 2024 | ||||||||||||
| Cost of product sold |
417.1 | 284.7 | 781.1 | 640.5 | ||||||||||||
| Add / (subtract) |
||||||||||||||||
| Royalties |
(56.4 | ) | (32.2 | ) | (93.8 | ) | (50.0 | ) | ||||||||
| Care and maintenance costs1 |
(26.2 | ) | (11.7 | ) | (39.8 | ) | (23.8 | ) | ||||||||
| Other selling costs |
(2.8 | ) | (4.5 | ) | (6.3 | ) | (9.4 | ) | ||||||||
| Change in inventories |
(143.3 | ) | 69.6 | (191.1 | ) | 99.8 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Cash costs of production (a) |
188.4 | 305.9 | 450.1 | 657.1 | ||||||||||||
| Add / (subtract) |
||||||||||||||||
| Depreciation and amortization |
71.3 | 51.5 | 122.8 | 88.2 | ||||||||||||
| Care and maintenance costs1 |
(1.6 | ) | (0.2 | ) | (1.7 | ) | (0.4 | ) | ||||||||
| Change in inventories |
(16.1 | ) | 13.3 | (5.6 | ) | 33.6 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total production costs (b) |
242.0 | 370.5 | 565.6 | 778.5 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Uranium produced & purchased (million lb) (c) |
5.3 | 8.8 | 12.5 | 17.3 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Cash costs per pound (a ÷ c) |
35.55 | 34.76 | 36.01 | 37.98 | ||||||||||||
| Total costs per pound (b ÷ c) |
45.66 | 42.10 | 45.25 | 45.00 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| 1 | Care and maintenance costs include costs associated with Rabbit Lake and the US operations, as well as the annual maintenance shutdown at Key Lake mill which were expensed directly to cost of sales in the quarter. In 2024, the shutdown occurred in the third quarter. |
2025 SECOND QUARTER REPORT 35
Additional information
Critical accounting estimates
Due to the nature of our business, we are required to make estimates that affect the amount of assets and liabilities, revenues and expenses, commitments and contingencies we report. We base our estimates on our experience, our best judgment, guidelines established by the Canadian Institute of Mining, Metallurgy and Petroleum and on assumptions we believe are reasonable.
Purchase prices related to business combinations and asset acquisitions are allocated to the underlying acquired assets and liabilities based on their estimated fair value at the time of acquisition. The determination of fair value requires us to make assumptions, estimates and judgments regarding future events. The allocation process is inherently subjective and impacts the amounts assigned to individually identifiable assets and liabilities. As a result, the purchase price allocation impacts our reported assets and liabilities, future net earnings due to the impact on future depreciation and amortization expense and impairment tests.
Controls and procedures
As of June 30, 2025, we carried out an evaluation under the supervision and with the participation of our management, including our chief executive officer (CEO) and chief financial officer (CFO), of the effectiveness of our disclosure controls and procedures. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives.
Based upon that evaluation and as of June 30, 2025, the CEO and CFO concluded that:
| • | the disclosure controls and procedures were effective to provide reasonable assurance that information required to be disclosed in the reports we file and submit under applicable securities laws is recorded, processed, summarized and reported as and when required; and |
| • | such information is accumulated and communicated to our management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. |
In April 2024, we implemented SAP S/4 HANA, an enterprise resource planning system, across the entire organization. As a result of this implementation, certain existing internal controls were modified, and new controls were implemented. Actions were taken to monitor and maintain appropriate internal controls over financial reporting during the period of change, including additional verifications and analysis to ensure data integrity.
There have been no changes in our internal control over financial reporting during the quarter ended June 30, 2025, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
36 CAMECO CORPORATION
Exhibit 99.3
Cameco Corporation
2025 condensed consolidated interim financial statements
(unaudited)
July 30, 2025
Cameco Corporation
Consolidated statements of earnings
| (Unaudited) | Three months ended | Six months ended | ||||||||||||||||
| ($Cdn thousands, except per share amounts) |
Note | Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Revenue from products and services |
11 | $ | 877,016 | $ | 598,458 | $ | 1,666,448 | $ | 1,232,003 | |||||||||
| Cost of products and services sold |
533,454 | 361,280 | 992,147 | 764,837 | ||||||||||||||
| Depreciation and amortization |
86,472 | 61,858 | 147,073 | 105,025 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Cost of sales |
619,926 | 423,138 | 1,139,220 | 869,862 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Gross profit |
257,090 | 175,320 | 527,228 | 362,141 | ||||||||||||||
| Administration |
96,436 | 65,705 | 155,256 | 125,513 | ||||||||||||||
| Exploration |
6,044 | 2,703 | 13,932 | 10,063 | ||||||||||||||
| Research and development |
(708 | ) | 7,879 | 13,274 | 17,199 | |||||||||||||
| Other operating income |
9 | (10,646 | ) | (3,008 | ) | (9,227 | ) | (19,787 | ) | |||||||||
| Loss on disposal of assets |
13 | 42 | 2,230 | 412 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Earnings from operations |
165,951 | 101,999 | 351,763 | 228,741 | ||||||||||||||
| Finance costs |
12 | (26,977 | ) | (43,383 | ) | (57,075 | ) | (81,527 | ) | |||||||||
| Gain (loss) on derivatives |
17 | 147,732 | (18,762 | ) | 138,804 | (60,040 | ) | |||||||||||
| Finance income |
5,407 | 7,887 | 9,096 | 14,209 | ||||||||||||||
| Share of earnings (loss) from equity-accounted investees |
6 | 188,421 | 1,037 | 161,570 | (45,309 | ) | ||||||||||||
| Foreign exchange gains (losses) |
(88,946 | ) | 5,254 | (89,817 | ) | 21,859 | ||||||||||||
| Other income (expense) |
382 | — | 787 | (3 | ) | |||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Earnings before income taxes |
391,970 | 54,032 | 515,128 | 77,930 | ||||||||||||||
| Income tax expense |
13 | 71,085 | 18,024 | 124,490 | 48,984 | |||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Net earnings |
320,885 | 36,008 | 390,638 | 28,946 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Net earnings (loss) attributable to: |
||||||||||||||||||
| Equity holders |
$ | 320,888 | $ | 36,010 | $ | 390,653 | $ | 28,953 | ||||||||||
| Non-controlling interest |
(3 | ) | (2 | ) | (15 | ) | (7 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Net earnings |
$ | 320,885 | $ | 36,008 | $ | 390,638 | $ | 28,946 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Earnings per common share attributable to equity holders: |
||||||||||||||||||
| Basic |
14 | $ | 0.74 | $ | 0.08 | $ | 0.90 | $ | 0.07 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Diluted |
14 | $ | 0.74 | $ | 0.08 | $ | 0.90 | $ | 0.07 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
See accompanying notes to condensed consolidated interim financial statements.
2 CAMECO CORPORATION
Cameco Corporation
Consolidated statements of comprehensive earnings
| (Unaudited) | Three months ended | Six months ended | ||||||||||||||
| ($Cdn thousands) |
Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | ||||||||||||
| Net earnings |
$ | 320,885 | $ | 36,008 | $ | 390,638 | $ | 28,946 | ||||||||
| Other comprehensive income (loss), net of taxes: |
||||||||||||||||
| Items that will not be reclassified to net earnings: |
||||||||||||||||
| Remeasurements of defined benefit liability - equity-accounted investee1 |
— | — | (37 | ) | (31 | ) | ||||||||||
| Items that are or may be reclassified to net earnings: |
||||||||||||||||
| Exchange differences on translation of foreign operations |
(121,605 | ) | 24,365 | (105,649 | ) | 62,563 | ||||||||||
| Gains (losses) on derivatives designated as cash flow hedges - equity-accounted investee2 |
(29,346 | ) | 11,432 | (42,015 | ) | 15,381 | ||||||||||
| Exchange differences on translation of foreign operations - equity-accounted investee |
76,333 | (5,113 | ) | 136,987 | (17,266 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Other comprehensive income (loss), net of taxes |
(74,618 | ) | 30,684 | (10,714 | ) | 60,647 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total comprehensive income |
$ | 246,267 | $ | 66,692 | 379,924 | 89,593 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Other comprehensive income (loss) attributable to: |
||||||||||||||||
| Equity holders |
$ | (74,617 | ) | $ | 30,684 | $ | (10,713 | ) | $ | 60,647 | ||||||
| Non-controlling interest |
(1 | ) | — | (1 | ) | — | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Other comprehensive income (loss) |
$ | (74,618 | ) | $ | 30,684 | $ | (10,714 | ) | $ | 60,647 | ||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total comprehensive income (loss) attributable to: |
||||||||||||||||
| Equity holders |
$ | 246,271 | $ | 66,694 | $ | 379,940 | $ | 89,600 | ||||||||
| Non-controlling interest |
(4 | ) | (2 | ) | (16 | ) | (7 | ) | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total comprehensive income |
$ | 246,267 | $ | 66,692 | $ | 379,924 | $ | 89,593 | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| 1 | Net of tax (Q2 2025 - $0; 2025 - $13) |
| 2 | Net of tax (Q2 2025 - $7,421; 2025 - $11,994) |
See accompanying notes to condensed consolidated interim financial statements.
2025 SECOND QUARTER REPORT 3
Cameco Corporation
Consolidated statements of financial position
| (Unaudited) | As at | |||||||||
| ($Cdn thousands) |
Note | Jun 30/25 | Dec 31/24 | |||||||
| Assets |
||||||||||
| Current assets |
||||||||||
| Cash and cash equivalents |
$ | 716,292 | $ | 600,462 | ||||||
| Accounts receivable |
291,100 | 346,800 | ||||||||
| Current tax assets |
23,351 | 2,579 | ||||||||
| Inventories |
4 | 586,635 | 826,863 | |||||||
| Supplies and prepaid expenses |
147,527 | 145,390 | ||||||||
| Current portion of long-term receivables, investments and other |
5 | 37,057 | 1,093 | |||||||
|
|
|
|
|
|||||||
| Total current assets |
1,801,962 | 1,923,187 | ||||||||
|
|
|
|
|
|||||||
| Property, plant and equipment |
3,260,169 | 3,286,515 | ||||||||
| Intangible assets |
37,815 | 39,822 | ||||||||
| Long-term receivables, investments and other |
5 | 659,550 | 595,896 | |||||||
| Investment in equity-accounted investees |
6 | 3,106,734 | 3,218,456 | |||||||
| Deferred tax assets |
715,326 | 843,131 | ||||||||
|
|
|
|
|
|||||||
| Total non-current assets |
7,779,594 | 7,983,820 | ||||||||
|
|
|
|
|
|||||||
| Total assets |
$ | 9,581,556 | $ | 9,907,007 | ||||||
|
|
|
|
|
|||||||
| Liabilities and shareholders’ equity |
||||||||||
| Current liabilities |
||||||||||
| Accounts payable and accrued liabilities |
434,871 | 619,035 | ||||||||
| Current tax liabilities |
500 | 21,225 | ||||||||
| Current portion of long-term debt |
7 | — | 285,707 | |||||||
| Current portion of other liabilities |
8 | 127,479 | 221,820 | |||||||
| Current portion of provisions |
9 | 46,044 | 37,974 | |||||||
|
|
|
|
|
|||||||
| Total current liabilities |
608,894 | 1,185,761 | ||||||||
|
|
|
|
|
|||||||
| Long-term debt |
7 | 995,965 | 995,583 | |||||||
| Other liabilities |
8 | 281,477 | 363,497 | |||||||
| Provisions |
9 | 953,737 | 997,833 | |||||||
|
|
|
|
|
|||||||
| Total non-current liabilities |
2,231,179 | 2,356,913 | ||||||||
|
|
|
|
|
|||||||
| Shareholders’ equity |
||||||||||
| Share capital |
10 | 2,936,816 | 2,935,367 | |||||||
| Contributed surplus |
206,553 | 210,784 | ||||||||
| Retained earnings |
3,489,888 | 3,099,264 | ||||||||
| Other components of equity |
108,216 | 118,892 | ||||||||
|
|
|
|
|
|||||||
| Total shareholders’ equity attributable to equity holders |
6,741,473 | 6,364,307 | ||||||||
| Non-controlling interest |
10 | 26 | ||||||||
|
|
|
|
|
|||||||
| Total shareholders’ equity |
6,741,483 | 6,364,333 | ||||||||
|
|
|
|
|
|||||||
| Total liabilities and shareholders’ equity |
$ | 9,581,556 | $ | 9,907,007 | ||||||
|
|
|
|
|
|||||||
Commitments and contingencies [notes 9, 13]
See accompanying notes to condensed consolidated interim financial statements.
4 CAMECO CORPORATION
Cameco Corporation
Consolidated statements of changes in equity
| Attributable to equity holders | ||||||||||||||||||||||||||||||||||||
| (Unaudited) ($Cdn thousands) |
Share capital |
Contributed surplus |
Retained earnings |
Foreign currency translation |
Cash flow hedges |
Equity investments at FVOCI |
Total | Non- controlling interest |
Total equity | |||||||||||||||||||||||||||
| Balance at January 1, 2025 |
$ | 2,935,367 | $ | 210,784 | $ | 3,099,264 | $ | 104,245 | $ | 15,395 | $ | (748 | ) | $ | 6,364,307 | $ | 26 | $ | 6,364,333 | |||||||||||||||||
| Net earnings (loss) |
— | — | 390,653 | — | — | — | 390,653 | (15 | ) | 390,638 | ||||||||||||||||||||||||||
| Other comprehensive income (loss) |
— | — | (37 | ) | 31,339 | (42,015 | ) | — | (10,713 | ) | (1 | ) | (10,714 | ) | ||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||
| Total comprehensive income (loss) for the period |
— | — | 390,616 | 31,339 | (42,015 | ) | — | 379,940 | (16 | ) | 379,924 | |||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||
| Share-based compensation |
— | 4,451 | — | — | — | — | 4,451 | — | 4,451 | |||||||||||||||||||||||||||
| Stock options exercised |
1,449 | (352 | ) | — | — | — | — | 1,097 | — | 1,097 | ||||||||||||||||||||||||||
| Restricted share units settled |
— | (8,330 | ) | — | — | — | — | (8,330 | ) | — | (8,330 | ) | ||||||||||||||||||||||||
| Dividends |
— | — | 8 | — | — | — | 8 | — | 8 | |||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||
| Balance at June 30, 2025 |
$ | 2,936,816 | $ | 206,553 | $ | 3,489,888 | $ | 135,584 | $ | (26,620 | ) | $ | (748 | ) | $ | 6,741,473 | $ | 10 | $ | 6,741,483 | ||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||
| Balance at January 1, 2024 |
$ | 2,914,165 | $ | 215,679 | $ | 2,979,743 | $ | (18,040 | ) | $ | 3,506 | $ | (748 | ) | $ | 6,094,305 | $ | 4 | $ | 6,094,309 | ||||||||||||||||
| Net earnings (loss) |
— | — | 28,953 | — | — | — | 28,953 | (7 | ) | 28,946 | ||||||||||||||||||||||||||
| Other comprehensive income (loss) |
— | — | (31 | ) | 45,297 | 15,381 | — | 60,647 | — | 60,647 | ||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||
| Total comprehensive income (loss) for the period |
— | — | 28,922 | 45,297 | 15,381 | — | 89,600 | (7 | ) | 89,593 | ||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||
| Share-based compensation |
— | 3,004 | — | — | — | — | 3,004 | — | 3,004 | |||||||||||||||||||||||||||
| Stock options exercised |
18,631 | (3,925 | ) | — | — | — | — | 14,706 | — | 14,706 | ||||||||||||||||||||||||||
| Restricted share units settled |
— | (7,124 | ) | — | — | — | — | (7,124 | ) | — | (7,124 | ) | ||||||||||||||||||||||||
| Transactions with owners - contributed equity |
— | — | — | — | — | — | — | 31 | 31 | |||||||||||||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||
| Balance at June 30, 2024 |
$ | 2,932,796 | $ | 207,634 | $ | 3,008,665 | $ | 27,257 | $ | 18,887 | $ | (748 | ) | $ | 6,194,491 | $ | 28 | $ | 6,194,519 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||||||||
See accompanying notes to condensed consolidated interim financial statements.
2025 SECOND QUARTER REPORT 5
Cameco Corporation
Consolidated statements of cash flows
| (Unaudited) | Note | Three months ended | Six months ended | |||||||||||||||
| ($Cdn thousands) |
Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | ||||||||||||||
| Operating activities |
||||||||||||||||||
| Net earnings |
$ | 320,885 | $ | 36,008 | $ | 390,638 | $ | 28,946 | ||||||||||
| Adjustments for: |
||||||||||||||||||
| Depreciation and amortization |
86,472 | 61,858 | 147,073 | 105,025 | ||||||||||||||
| Deferred revenue |
31,524 | 68,412 | (16,925 | ) | 44,130 | |||||||||||||
| Unrealized loss (gain) on derivatives |
(163,537 | ) | 12,510 | (176,550 | ) | 47,154 | ||||||||||||
| Share-based compensation |
16 | 2,383 | 1,716 | 4,451 | 3,004 | |||||||||||||
| Loss on disposal of assets |
13 | 42 | 2,230 | 412 | ||||||||||||||
| Finance costs |
12 | 26,977 | 43,383 | 57,075 | 81,527 | |||||||||||||
| Finance income |
(5,407 | ) | (7,886 | ) | (9,096 | ) | (14,209 | ) | ||||||||||
| Share of loss (earnings) in equity-accounted investees |
(188,421 | ) | (1,037 | ) | (161,570 | ) | 45,309 | |||||||||||
| Foreign exchange losses (gains) |
88,946 | (5,254 | ) | 89,817 | (21,859 | ) | ||||||||||||
| Other operating income |
9 | (10,646 | ) | (3,008 | ) | (9,227 | ) | (19,787 | ) | |||||||||
| Other expense (income) |
(382 | ) | — | (787 | ) | 3 | ||||||||||||
| Income tax expense |
13 | 71,085 | 18,024 | 124,490 | 48,984 | |||||||||||||
| Interest received |
5,407 | 7,886 | 9,096 | 14,209 | ||||||||||||||
| Income taxes paid |
(19,263 | ) | (21,620 | ) | (71,053 | ) | (33,503 | ) | ||||||||||
| Dividends from equity-accounted investees |
136,970 | 185,447 | 206,717 | 185,447 | ||||||||||||||
| Other operating items |
15 | 82,194 | (136,405 | ) | (10,988 | ) | (191,559 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Net cash provided by operations |
465,200 | 260,076 | 575,391 | 323,233 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Investing activities |
||||||||||||||||||
| Additions to property, plant and equipment |
(74,923 | ) | (46,880 | ) | (131,381 | ) | (86,899 | ) | ||||||||||
| Decrease (increase) in long-term receivables, investments and other |
931 | 7,003 | (23 | ) | 7,003 | |||||||||||||
| Proceeds from sale of property, plant and equipment |
56 | 48 | 79 | 48 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Net cash used in investing |
(73,936 | ) | (39,829 | ) | (131,325 | ) | (79,848 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Financing activities |
||||||||||||||||||
| Increase in debt |
— | 497,325 | — | 497,325 | ||||||||||||||
| Decrease in debt |
— | (636,690 | ) | (285,240 | ) | (904,990 | ) | |||||||||||
| Interest paid |
(21,368 | ) | (48,360 | ) | (27,251 | ) | (50,883 | ) | ||||||||||
| Lease principal payments |
(1,129 | ) | (378 | ) | (1,730 | ) | (790 | ) | ||||||||||
| Proceeds from issuance of shares, stock option plan |
1,023 | 14,215 | 1,097 | 14,706 | ||||||||||||||
| Dividends returned |
18 | — | 8 | — | ||||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Net cash used in financing |
(21,456 | ) | (173,888 | ) | (313,116 | ) | (444,632 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Increase (decrease) in cash and cash equivalents, during the period |
369,808 | 46,359 | 130,950 | (201,247 | ) | |||||||||||||
| Exchange rate changes on foreign currency cash balances |
(14,968 | ) | (7,959 | ) | (15,120 | ) | (3,945 | ) | ||||||||||
| Cash and cash equivalents, beginning of period |
361,452 | 323,217 | 600,462 | 566,809 | ||||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Cash and cash equivalents, end of period |
$ | 716,292 | $ | 361,617 | $ | 716,292 | $ | 361,617 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||||
| Cash and cash equivalents is comprised of: |
||||||||||||||||||
| Cash |
452,444 | 232,647 | ||||||||||||||||
| Cash equivalents |
263,848 | 128,970 | ||||||||||||||||
|
|
|
|
|
|||||||||||||||
| Cash and cash equivalents |
$ | 716,292 | $ | 361,617 | ||||||||||||||
|
|
|
|
|
|||||||||||||||
See accompanying notes to condensed consolidated interim financial statements.
6 CAMECO CORPORATION
Cameco Corporation
Notes to condensed consolidated interim financial statements
(Unaudited)
(Cdn$ thousands, except per share amounts and as noted)
| 1. | Cameco Corporation |
Cameco Corporation is incorporated under the Canada Business Corporations Act. The address of its registered office is 2121 11th Street West, Saskatoon, Saskatchewan, S7M 1J3. The condensed consolidated interim financial statements as at and for the period ended June 30, 2025 comprise Cameco Corporation and its subsidiaries (collectively, the Company or Cameco) and the Company’s interests in associates and joint arrangements.
Cameco is one of the world’s largest providers of the uranium needed to generate clean, reliable baseload electricity around the globe. The Company has operations in northern Saskatchewan and the United States, as well as a 40% interest in Joint Venture Inkai LLP (JV Inkai), a joint arrangement with Joint Stock Company National Atomic Company Kazatomprom (Kazatomprom), located in Kazakhstan. Cameco also has a 49% interest in Westinghouse Electric Company (Westinghouse), a joint venture with Brookfield Renewable Partners and its institutional partners (collectively, Brookfield). Westinghouse is one of the world’s largest nuclear services businesses with corporate headquarters in Pennsylvania and operations around the world. Both JV Inkai and Westinghouse are accounted for on an equity basis (see note 6).
Cameco has two operating mines, Cigar Lake and McArthur River as well as a mill at Key Lake. The Rabbit Lake operation was placed in care and maintenance in 2016. Cameco’s operations in the United States, Crow Butte and Smith Ranch-Highland, are also not currently producing as the decision was made in 2016 to curtail production and defer all wellfield development. See note 18 for the financial statement impact.
The Company is also a leading provider of nuclear fuel processing services, supplying much of the world’s reactor fleet with the fuel to generate one of the cleanest sources of electricity available today. It operates the world’s largest commercial refinery in Blind River, Ontario, controls a significant portion of the world UF6 primary conversion capacity in Port Hope, Ontario and is a leading manufacturer of fuel assemblies and reactor components for CANDU reactors at facilities in Port Hope and Cobourg, Ontario.
| 2. | Material accounting policies |
| A. | Statement of compliance |
These condensed consolidated interim financial statements have been prepared in accordance with IAS 34 Interim Financial Reporting. The condensed consolidated interim financial statements do not include all of the information required for full annual financial statements and should be read in conjunction with Cameco’s annual consolidated financial statements as at and for the year ended December 31, 2024.
These condensed consolidated interim financial statements were authorized for issuance by the Company’s board of directors on July 30, 2025.
| B. | Basis of presentation |
These condensed consolidated interim financial statements are presented in Canadian dollars, which is the Company’s functional currency. All financial information is presented in Canadian dollars, unless otherwise noted. Amounts presented in tabular format have been rounded to the nearest thousand except per share amounts and where otherwise noted.
The condensed consolidated interim financial statements have been prepared on the historical cost basis except for the following material items which are measured on an alternative basis at each reporting date:
2025 SECOND QUARTER REPORT 7
| Derivative financial instruments | Fair value through profit or loss (FVTPL) | |
| Equity investments | Fair value through other comprehensive income (FVOCI) | |
| Liabilities for cash-settled share-based payment arrangements | FVTPL | |
| Net defined benefit liability | Fair value of plan assets less the present value of the defined benefit obligation | |
The preparation of the condensed consolidated interim financial statements in conformity with International Financial Reporting Standards (IFRS) requires management to make judgments, estimates and assumptions that affect the application of accounting policies and the reported amounts of assets, liabilities, revenue and expenses. Actual results may vary from these estimates.
In preparing these condensed consolidated interim financial statements, the significant judgments made by management in applying the Company’s accounting policies and key sources of estimation uncertainty were the same as those that applied to the consolidated financial statements as at and for the year ended December 31, 2024.
Estimates and underlying assumptions are reviewed on an ongoing basis. Revisions to accounting estimates are recognized in the period in which the estimates are revised and in any future periods affected. The areas involving a higher degree of judgment or complexity, or areas where assumptions and estimates are significant to the consolidated financial statements are disclosed in note 5 of the December 31, 2024, consolidated financial statements.
| 3. | Accounting standards |
| A. | Changes in accounting policy |
In August 2023, the International Accounting Standards Board (IASB) amended IAS 21 The Effects of Changes in Foreign Exchange Rates, requiring companies to assess whether a currency is exchangeable into another currency and, when it is not, to determine the exchange rate to use and the disclosures to provide. The amendment became effective on January 1, 2025, but it did not have an effect on the Company’s financial statements.
| B. | New standards and interpretations not yet adopted |
A number of new standards and amendments to existing standards are not yet effective for the period ended June 30, 2025 and have not been applied in preparing these condensed consolidated interim financial statements. Cameco does not intend to early adopt any of the standards and amendments and does not expect them to have a material impact on its financial statements. The one new standard that is expected to have an impact on disclosures is described below.
| i. | Financial statement presentation |
In April 2024, the IASB issued IFRS 18, Presentation and Disclosure of Financial Statements (IFRS 18). IFRS 18 is effective for periods beginning on or after January 1, 2027, with early adoption permitted. IFRS 18 is expected to improve the quality of financial reporting by requiring defined subtotals in the statement of profit or loss, requiring disclosure about management-defined performance measures, and adding new principles for aggregation and disaggregation of information. Cameco has not yet determined the impact of this standard on its disclosures.
8 CAMECO CORPORATION
| 4. | Inventories |
| Jun 30/25 | Dec 31/24 | |||||||
| Uranium |
||||||||
| Concentrate |
$ | 363,624 | $ | 651,901 | ||||
| Broken ore |
63,186 | 27,892 | ||||||
|
|
|
|
|
|||||
| 426,810 | 679,793 | |||||||
| Fuel services |
158,841 | 146,612 | ||||||
| Other |
984 | 458 | ||||||
|
|
|
|
|
|||||
| Total |
$ | 586,635 | $ | 826,863 | ||||
|
|
|
|
|
|||||
Cameco expensed $532,691,000 of inventory as cost of sales during the second quarter of 2025 (2024 - $374,113,000). For the six months ended June 30, 2025, Cameco expensed $1,005,183,000 of inventory as cost of sales (2024 - $778,411,000).
| 5. | Long-term receivables, investments and other |
| Jun 30/25 | Dec 31/24 | |||||||
| Deferred charges |
$ | 20,683 | $ | — | ||||
| Derivatives [note 17] |
45,232 | 103 | ||||||
| Investment tax credits |
97,186 | 96,199 | ||||||
| Amounts receivable related to tax dispute [note 13](a) |
209,125 | 209,125 | ||||||
| Income tax receivable(b) |
32,804 | — | ||||||
| Product loan(c) |
288,294 | 288,294 | ||||||
| Other |
3,283 | 3,268 | ||||||
|
|
|
|
|
|||||
| 696,607 | 596,989 | |||||||
| Less current portion |
(37,057 | ) | (1,093 | ) | ||||
|
|
|
|
|
|||||
| Net |
$ | 659,550 | $ | 595,896 | ||||
|
|
|
|
|
|||||
| (a) | Cameco is required to remit or otherwise secure 50% of the cash taxes and transfer pricing penalties, plus related interest and instalment penalties assessed, in relation to its dispute with Canada Revenue Agency (CRA). In light of our view of the likely outcome of the case, Cameco expects to recover the amounts remitted to CRA, including cash taxes, interest and penalties paid. |
| (b) | As a result of Cameco’s dispute with CRA, Cameco has drawn down the tax pools available to us and we were required to remit cash tax for the 2024 taxation year. Cameco expects to recover this amount. |
| (c) | Cameco loaned 5,400,000 pounds of uranium concentrate to its joint venture partner, Orano Canada Inc., (Orano). Orano is obligated to repay the Company in kind with uranium concentrate no later than December 31, 2028. As at June 30, 2025, 3,000,000 pounds have been returned as repayment on this loan (December 31, 2024 - 3,000,000 pounds). |
Cameco also loaned Orano 1,148,200 kgU of conversion supply and an additional 1,200,000 pounds of uranium concentrate during 2022 and 2023. Repayment to Cameco is to be made in kind with U3O8 quantities drawn being repaid by December 31, 2027 and quantities of UF6 conversion supply drawn by December 31, 2035.
As at June 30, 2025, 3,600,000 pounds of U3O8 (December 31, 2024 - 3,600,000 pounds) and 1,148,200 kgU of UF6 conversion supply (December 31, 2024 - 1,148,200 kgU) were drawn on the loans. The values of the loans are recorded at Cameco’s weighted average cost of inventory at the time the loans were drawn.
2025 SECOND QUARTER REPORT 9
| 6. | Equity-accounted investees |
| Jun 30/25 | Dec 31/24 | |||||||
| Interest in Westinghouse |
$ | 2,863,715 | $ | 2,931,746 | ||||
| Interest in JV Inkai |
243,019 | 286,710 | ||||||
| Interest in Global Laser Enrichment (GLE) |
— | — | ||||||
|
|
|
|
|
|||||
| $ | 3,106,734 | $ | 3,218,456 | |||||
|
|
|
|
|
|||||
| A. | Joint ventures |
| i. | Westinghouse |
Westinghouse is a nuclear reactor technology original equipment manufacturer and a global provider of products and services to commercial utilities and government agencies. Cameco holds a 49% interest and Brookfield holds 51%. Cameco has joint control with Brookfield over the strategic operating, investing and financing activities of Westinghouse. The Company determined that the joint arrangement should be classified as a joint venture after concluding that neither the legal form of the separate entity, the terms of the contractual arrangement, or other facts and circumstances would give the Company rights to the assets and obligations for the liabilities relating to the arrangement. As a result, Cameco accounts for Westinghouse on an equity basis.
Westinghouse provides outage and maintenance services, engineering support, instrumentation and controls equipment, plant modification, and components and parts to nuclear reactors. Westinghouse has three fabrication facilities that design and manufacture nuclear fuel supplies for light water reactors. In addition, Westinghouse designs, develops and procures equipment for the build of new nuclear reactor plants.
The following table summarizes the total comprehensive loss of Westinghouse (100%):
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Revenue from products and services |
$ | 2,109,170 | $ | 1,366,594 | $ | 3,679,627 | $ | 2,704,398 | ||||||||
| Cost of products and services sold |
(1,185,247 | ) | (971,329 | ) | (2,358,325 | ) | (2,027,098 | ) | ||||||||
| Depreciation and amortization |
(194,566 | ) | (180,763 | ) | (391,176 | ) | (353,612 | ) | ||||||||
| Marketing, administrative and general expenses |
(216,046 | ) | (180,684 | ) | (427,285 | ) | (410,699 | ) | ||||||||
| Finance income |
1,825 | 1,618 | 2,701 | 5,557 | ||||||||||||
| Finance costs |
(103,939 | ) | (110,813 | ) | (203,871 | ) | (241,665 | ) | ||||||||
| Other expense |
(60,822 | ) | (41,803 | ) | (112,724 | ) | (122,385 | ) | ||||||||
| Income tax recovery (expense) |
(93,359 | ) | 21,831 | (58,564 | ) | 98,163 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Net earnings (loss) |
$ | 257,016 | $ | (95,349 | ) | $ | 130,383 | $ | (347,341 | ) | ||||||
| Other comprehensive income (loss) |
95,892 | 12,895 | 193,745 | (3,910 | ) | |||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total comprehensive income (loss) |
$ | 352,908 | $ | (82,454 | ) | $ | 324,128 | $ | (351,251 | ) | ||||||
|
|
|
|
|
|
|
|
|
|||||||||
10 CAMECO CORPORATION
The following table summarizes the financial information of Westinghouse (100%) and reconciles it to the carrying amount of Cameco’s interest:
| Jun 30/25 | Dec 31/24 | |||||||
| Cash and cash equivalents |
$ | 457,908 | $ | 255,589 | ||||
| Other current assets |
3,214,548 | 2,737,164 | ||||||
| Intangible assets |
7,320,707 | 7,821,802 | ||||||
| Goodwill |
1,655,721 | 1,698,174 | ||||||
| Non-current assets |
3,030,926 | 3,113,031 | ||||||
| Current portion of long-term debt |
(40,089 | ) | (44,576 | ) | ||||
| Other current liabilities |
(3,152,791 | ) | (2,751,396 | ) | ||||
| Long-term debt |
(4,643,723 | ) | (4,924,398 | ) | ||||
| Other non-current liabilities |
(2,144,832 | ) | (2,078,688 | ) | ||||
|
|
|
|
|
|||||
| Net assets |
5,698,375 | 5,826,702 | ||||||
| Net assets attributable to non-controlling interest |
(25,842 | ) | (25,127 | ) | ||||
|
|
|
|
|
|||||
| Net assets attributable to shareholders |
5,672,533 | 5,801,575 | ||||||
| Cameco’s share of net assets attributable to shareholders (49%) |
2,779,541 | 2,842,772 | ||||||
| Acquisition costs(a) |
83,896 | 83,896 | ||||||
| Impact of foreign exchange on acquisition costs(a) |
278 | 5,078 | ||||||
|
|
|
|
|
|||||
| Carrying amount of interest in Westinghouse |
$ | 2,863,715 | $ | 2,931,746 | ||||
|
|
|
|
|
|||||
| (a) | Cameco incurred acquisition costs that were denominated in US dollars. This amount was included in the cost of the investment and is remeasured every period. |
| ii. | Global Laser Enrichment LLC (GLE) |
GLE is the exclusive licensee of the proprietary Separation of Isotopes by Laser Excitation (SILEX) laser enrichment technology, a third-generation uranium enrichment technology. Cameco owns a 49% interest in GLE with an option to attain a majority interest of up to 75% ownership. Cameco has joint control with Silex Systems Limited over the strategic operating, investing and financing activities and as a result, accounts for GLE on an equity basis. In 2014, an impairment charge was recognized for its full carrying value of $183,615,000. Following the impairment, under the equity method of accounting, Cameco discontinued recognizing its share of losses in GLE. Cameco’s contributions to GLE are recorded in earnings as research and development.
| B. | Associate |
| i. | JV Inkai |
JV Inkai is the operator of the Inkai uranium deposit located in Kazakhstan. Cameco holds a 40% interest in JV Inkai and Kazatomprom holds a 60% interest. Cameco does not have control over the joint venture so it accounts for the investment on an equity basis.
JV Inkai is a uranium mining and milling operation that utilizes in-situ recovery (ISR) technology to extract uranium. The participants in JV Inkai purchase uranium from Inkai and, in turn, derive revenue directly from the sale of such product to third-party customers.
2025 SECOND QUARTER REPORT 11
The following tables summarize the total comprehensive earnings of JV Inkai (100%):
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Revenue from products and services |
$ | 157,091 | $ | 90,779 | $ | 157,900 | $ | 404,643 | ||||||||
| Cost of products and services sold |
(39,558 | ) | (25,524 | ) | (39,620 | ) | (63,948 | ) | ||||||||
| Depreciation and amortization |
(11,223 | ) | (5,890 | ) | (11,244 | ) | (26,290 | ) | ||||||||
| Finance income |
1,418 | 1,085 | 3,504 | 1,647 | ||||||||||||
| Finance costs |
(133 | ) | (87 | ) | (269 | ) | (359 | ) | ||||||||
| Other income (expense) |
3,696 | 5,134 | (11,814 | ) | (10,178 | ) | ||||||||||
| Income tax expense |
(18,688 | ) | (11,653 | ) | (19,613 | ) | (61,110 | ) | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Net earnings from continuing operations |
$ | 92,603 | $ | 53,844 | $ | 78,844 | $ | 244,405 | ||||||||
| Other comprehensive income |
— | — | — | — | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total comprehensive income |
$ | 92,603 | $ | 53,844 | $ | 78,844 | $ | 244,405 | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
The following table summarizes the financial information of JV Inkai (100%) and reconciles it to the carrying amount of Cameco’s interest:
| Jun 30/25 | Dec 31/24 | |||||||
| Cash and cash equivalents |
$ | 61,406 | $ | 47,282 | ||||
| Other current assets |
432,869 | 694,041 | ||||||
| Non-current assets |
301,561 | 307,801 | ||||||
| Current liabilities |
(53,849 | ) | (42,368 | ) | ||||
| Non-current liabilities |
(23,365 | ) | (27,802 | ) | ||||
|
|
|
|
|
|||||
| Net assets |
718,622 | 978,954 | ||||||
| Cameco’s share of net assets (40%) |
287,449 | 391,582 | ||||||
| Consolidating adjustments(a) |
(25,547 | ) | (93,365 | ) | ||||
| Fair value increment(b) |
77,352 | 77,992 | ||||||
| Dividends declared but not received |
7,209 | 9,760 | ||||||
| Dividends in excess of ownership percentage(c) |
(109,064 | ) | (107,179 | ) | ||||
| Impact of foreign exchange |
5,620 | 7,920 | ||||||
|
|
|
|
|
|||||
| Carrying amount of interest in JV Inkai |
$ | 243,019 | $ | 286,710 | ||||
|
|
|
|
|
|||||
| (a) | Cameco records certain consolidating adjustments to eliminate unrealized profit, recognize deferred profit and amortize historical differences in accounting policies. The historical differences are amortized to earnings over units of production. |
| (b) | Upon restructuring, Cameco assigned fair values to the assets and liabilities of JV Inkai. This increment is amortized to earnings over units of production. |
| (c) | Cameco’s share of dividends follows its production purchase entitlements which is currently higher than its ownership interest. |
12 CAMECO CORPORATION
| 7. | Long-term debt |
| Jun 30/25 | Dec 31/24 | |||||||
| Unsecured debentures |
||||||||
| Series F - 5.09% debentures due November 14, 2042 |
$ | 99,405 | $ | 99,395 | ||||
| Series H - 2.95% debentures due October 21, 2027 |
399,119 | 398,936 | ||||||
| Series I - 4.94% debentures due May 24, 2031 |
497,441 | 497,252 | ||||||
| Term loans |
— | 285,707 | ||||||
|
|
|
|
|
|||||
| 995,965 | 1,281,290 | |||||||
| Less current portion |
— | (285,707 | ) | |||||
|
|
|
|
|
|||||
| Total |
$ | 995,965 | $ | 995,583 | ||||
|
|
|
|
|
|||||
On November 7, 2023, the Company utilized a term loan for $600,000,000 (US) to finance the 49% acquisition of Westinghouse. The term loan consisted of two $300,000,000 (US) tranches. The first tranche had a floating interest rate of SOFR plus 1.80% and was to mature on November 7, 2025. The second tranche had a floating interest rate of SOFR plus 2.05% and was set to mature on November 7, 2026. The second tranche was fully repaid on June 10, 2024. On September 9, 2024, Cameco repaid $100,000,000 (US) of the first tranche. The remaining $200,000,000 (US) was repaid on January 13, 2025.
| 8. | Other liabilities |
| Jun 30/25 | Dec 31/24 | |||||||
| Deferred sales |
$ | 89,633 | $ | 106,569 | ||||
| Derivatives [note 17] |
12,188 | 143,609 | ||||||
| Accrued pension and post-retirement benefit liability |
81,169 | 78,674 | ||||||
| Lease obligation [note 17] |
11,379 | 9,839 | ||||||
| Product loans(a) |
142,240 | 177,623 | ||||||
| Sales contracts |
2,553 | 4,304 | ||||||
| Other |
69,794 | 64,699 | ||||||
|
|
|
|
|
|||||
| 408,956 | 585,317 | |||||||
| Less current portion |
(127,479 | ) | (221,820 | ) | ||||
|
|
|
|
|
|||||
| Net |
$ | 281,477 | $ | 363,497 | ||||
|
|
|
|
|
|||||
| (a) | Cameco has standby product loan facilities with various counterparties. The arrangements allow us to borrow up to 2,000,000 kgU of UF6 conversion services and 5,680,000 pounds of U3O8 by September 30, 2027 with repayment in kind up to December 31, 2027. Under the facilities, standby fees of up to 1.5% are payable based on the market value of the facilities and interest is payable on the market value of any amounts drawn at rates ranging from 0.5% to 3.0%. At June 30, 2025, we have 1,490,000 kgU of UF6 conversion services (December 31, 2024 - 1,567,000 kgU) drawn on the loans with repayment in the following years: |
| 2025 | 2026 | 2027 | Total | |||||||||||||
| kgU of UF6 |
293,000 | 1,197,000 | — | 1,490,000 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
We also have 2,462,000 pounds of U3O8 (December 31, 2024 - 2,506,000 pounds) drawn with repayment in the following years:
2025 SECOND QUARTER REPORT 13
| 2025 | 2026 | 2027 | Total | |||||||||||||
| lbs of U3O8 |
630,000 | 1,832,000 | — | 2,462,000 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
The loans are recorded at Cameco’s weighted average cost of inventory.
| 9. | Provisions |
| Reclamation | Waste disposal | Total | ||||||||||
| Beginning of year |
$ | 1,025,039 | $ | 10,768 | $ | 1,035,807 | ||||||
| Changes in estimates and discount rates |
||||||||||||
| Capitalized in property, plant, and equipment |
(13,307 | ) | — | (13,307 | ) | |||||||
| Recognized in earnings |
(9,227 | ) | (337 | ) | (9,564 | ) | ||||||
| Provisions used during the period |
(14,249 | ) | (659 | ) | (14,908 | ) | ||||||
| Accretion [note 12] |
19,401 | 164 | 19,565 | |||||||||
| Effects of movements in exchange rates |
(17,812 | ) | — | (17,812 | ) | |||||||
|
|
|
|
|
|
|
|||||||
| End of period |
$ | 989,845 | $ | 9,936 | $ | 999,781 | ||||||
|
|
|
|
|
|
|
|||||||
| Current |
41,557 | 4,487 | 46,044 | |||||||||
| Non-current |
948,288 | 5,449 | 953,737 | |||||||||
|
|
|
|
|
|
|
|||||||
| $ | 989,845 | $ | 9,936 | $ | 999,781 | |||||||
|
|
|
|
|
|
|
|||||||
| 10. | Share capital |
At June 30, 2025, there were 435,387,448 common shares outstanding. Options in respect of 184,593 shares are outstanding under the stock option plan and are exercisable up to 2027. For the quarter ended June 30, 2025, there were 70,530 options that were exercised resulting in the issuance of shares (2024 - 974,820). For the six months ended June 30, 2025, there were 75,365 options exercised that resulted in the issuance of shares (2024 - 1,004,820).
| 11. | Revenue |
Cameco’s uranium and fuel services sales contracts with customers contain both fixed and market-related pricing. Fixed-price contracts are typically based on a term-price indicator at the time the contract is accepted and escalated over the term of the contract. Market-related contracts are based on either the spot price or long-term price, and the price is quoted at the time of delivery rather than at the time the contract is accepted. These contracts often include a floor and/or ceiling prices, which are usually escalated over the term of the contract. Escalation is generally based on a consumer price index. The Company’s contracts contain either one of these pricing mechanisms or a combination of the two. There is no variable consideration in the contracts and therefore no revenue is considered constrained at the time of delivery. Cameco expenses the incremental costs of obtaining a contract as incurred as the amortization period is less than a year.
14 CAMECO CORPORATION
The following tables summarize Cameco’s sales disaggregated by geographical region and contract type and includes a reconciliation to Cameco’s reportable segments (note 18):
For the three months ended June 30, 2025
| Uranium | Fuel services | Other | Total | |||||||||||||
| Customer geographical region |
||||||||||||||||
| Americas |
$ | 398,890 | $ | 120,436 | $ | 9,613 | $ | 528,939 | ||||||||
| Europe |
164,999 | 40,556 | — | 205,555 | ||||||||||||
| Asia |
141,478 | 1,044 | — | 142,522 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| $ | 705,367 | $ | 162,036 | $ | 9,613 | $ | 877,016 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Contract type |
||||||||||||||||
| Fixed-price |
$ | 209,754 | $ | 155,285 | $ | 9,613 | $ | 374,652 | ||||||||
| Market-related |
495,613 | 6,751 | — | 502,364 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| $ | 705,367 | $ | 162,036 | $ | 9,613 | $ | 877,016 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
For the three months ended June 30, 2024
| Uranium | Fuel services | Total | ||||||||||
| Customer geographical region |
||||||||||||
| Americas |
$ | 235,012 | $ | 90,116 | $ | 325,128 | ||||||
| Europe |
112,366 | 22,635 | 135,001 | |||||||||
| Asia |
133,222 | 5,107 | 138,329 | |||||||||
|
|
|
|
|
|
|
|||||||
| $ | 480,600 | $ | 117,858 | $ | 598,458 | |||||||
|
|
|
|
|
|
|
|||||||
| Contract type |
||||||||||||
| Fixed-price |
$ | 199,543 | $ | 115,877 | $ | 315,420 | ||||||
| Market-related |
281,057 | 1,981 | 283,038 | |||||||||
|
|
|
|
|
|
|
|||||||
| $ | 480,600 | $ | 117,858 | $ | 598,458 | |||||||
|
|
|
|
|
|
|
|||||||
For the six months ended June 30, 2025
| Uranium | Fuel services | Other | Total | |||||||||||||
| Customer geographical region |
||||||||||||||||
| Americas |
$ | 743,266 | $ | 210,960 | $ | 45,562 | $ | 999,788 | ||||||||
| Europe |
364,051 | 80,441 | — | 444,492 | ||||||||||||
| Asia |
216,874 | 5,294 | — | 222,168 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| $ | 1,324,191 | $ | 296,695 | $ | 45,562 | $ | 1,666,448 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Contract type |
||||||||||||||||
| Fixed-price |
$ | 441,239 | $ | 274,223 | $ | 45,562 | $ | 761,024 | ||||||||
| Market-related |
882,952 | 22,472 | — | 905,424 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| $ | 1,324,191 | $ | 296,695 | $ | 45,562 | $ | 1,666,448 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
2025 SECOND QUARTER REPORT 15
For the six months ended June 30, 2024
| Uranium | Fuel services | Total | ||||||||||
| Customer geographical region |
||||||||||||
| Americas |
$ | 656,929 | $ | 151,369 | $ | 808,298 | ||||||
| Europe |
179,497 | 33,396 | 212,893 | |||||||||
| Asia |
205,284 | 5,528 | 210,812 | |||||||||
|
|
|
|
|
|
|
|||||||
| $ | 1,041,710 | $ | 190,293 | $ | 1,232,003 | |||||||
|
|
|
|
|
|
|
|||||||
| Contract type |
||||||||||||
| Fixed-price |
$ | 357,470 | $ | 179,491 | $ | 536,961 | ||||||
| Market-related |
684,240 | 10,802 | 695,042 | |||||||||
|
|
|
|
|
|
|
|||||||
| $ | 1,041,710 | $ | 190,293 | $ | 1,232,003 | |||||||
|
|
|
|
|
|
|
|||||||
| 12. | Finance costs |
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Interest on long-term debt |
$ | 12,684 | $ | 28,870 | $ | 28,296 | $ | 53,242 | ||||||||
| Accretion [note 9] |
9,704 | 9,805 | 19,565 | 18,578 | ||||||||||||
| Other charges |
4,589 | 4,708 | 9,214 | 9,707 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total |
$ | 26,977 | $ | 43,383 | $ | 57,075 | $ | 81,527 | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
16 CAMECO CORPORATION
| 13. | Income taxes |
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Earnings (loss) before income taxes |
||||||||||||||||
| Canada |
$ | 324,735 | $ | 90,221 | $ | 524,778 | $ | 230,795 | ||||||||
| Foreign |
67,235 | (36,189 | ) | (9,650 | ) | (152,865 | ) | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| $ | 391,970 | $ | 54,032 | $ | 515,128 | $ | 77,930 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Current income taxes (recovery) |
||||||||||||||||
| Canada |
$ | (2,689 | ) | $ | 6,398 | $ | (5,689 | ) | $ | 17,752 | ||||||
| Foreign |
434 | 2,956 | 2,406 | 4,401 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| $ | (2,255 | ) | $ | 9,354 | $ | (3,283 | ) | $ | 22,153 | |||||||
| Deferred income taxes |
||||||||||||||||
| Canada |
$ | 72,321 | $ | 6,538 | $ | 125,261 | $ | 25,994 | ||||||||
| Foreign |
1,019 | 2,132 | 2,512 | 837 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| $ | 73,340 | $ | 8,670 | $ | 127,773 | $ | 26,831 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Income tax expense |
$ | 71,085 | $ | 18,024 | $ | 124,490 | $ | 48,984 | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
Cameco has recorded $715,326,000 of deferred tax assets (December 31, 2024 - $843,131,000). The realization of these deferred tax assets is dependent upon the generation of future taxable income in certain jurisdictions during the periods in which the Company’s temporary tax differences are available. The Company considers whether it is probable that all or a portion of the deferred tax assets will not be realized. In making this assessment, management considers all available evidence, including recent financial operations, projected future taxable income and tax planning strategies. Based on projections of future taxable income over the periods in which the deferred tax assets are available, realization of these deferred tax assets is probable and consequently the deferred tax assets have been recorded.
Cameco has operations in countries where the global minimum top-up tax has been enacted or substantively enacted effective January 1, 2024, including: Canada, Australia, Barbados, Germany, Luxembourg, Switzerland and the United Kingdom. The exposure is currently only in Switzerland, as all other constituent entities have effective tax rates higher than 15% or the transitional safe harbour rules are expected to be met. As a result of this exposure, additional income tax expense of $920,000 has been recorded relating to the profits earned in Switzerland (2024 - $1,060,000).
Canada
On February 18, 2021, the Supreme Court of Canada (Supreme Court) dismissed Canada Revenue Agency’s (CRA) application for leave to appeal the June 26, 2020 decision of the Federal Court of Appeal (Court of Appeal). The dismissal means that the dispute for the 2003, 2005 and 2006 tax years is fully and finally resolved in the Company’s favour.
In September 2018, the Tax Court of Canada (Tax Court) ruled that the marketing and trading structure involving foreign subsidiaries, as well as the related transfer pricing methodology used for certain intercompany uranium sales and purchasing agreements, were in full compliance with Canadian law for the tax years in question. Management believes the principles in the decision apply to all subsequent tax years, and that the ultimate resolution of those years will not be material to Cameco’s financial position, results of operations or liquidity in the year(s) of resolution.
As CRA continues to pursue reassessments for tax years subsequent to 2006, Cameco is utilizing its appeal rights under Canadian federal and provincial tax rules.
2025 SECOND QUARTER REPORT 17
| 14. | Per share amounts |
Per share amounts have been calculated based on the weighted average number of common shares outstanding during the period.
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Basic earnings per share computation |
||||||||||||||||
| Net earnings attributable to equity holders |
$ | 320,888 | $ | 36,010 | $ | 390,653 | $ | 28,953 | ||||||||
| Weighted average common shares outstanding |
435,331 | 434,875 | 435,322 | 434,530 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Basic earnings per common share |
$ | 0.74 | $ | 0.08 | $ | 0.90 | $ | 0.07 | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Diluted earnings per share computation |
||||||||||||||||
| Net earnings attributable to equity holders |
$ | 320,888 | $ | 36,010 | $ | 390,653 | $ | 28,953 | ||||||||
| Weighted average common shares outstanding |
435,331 | 434,875 | 435,322 | 434,530 | ||||||||||||
| Dilutive effect of stock options |
203 | 1,077 | 205 | 1,077 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Weighted average common shares outstanding, assuming dilution |
435,534 | 435,952 | 435,527 | 435,607 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Diluted earnings per common share |
$ | 0.74 | $ | 0.08 | $ | 0.90 | $ | 0.07 | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| 15. | Statements of cash flows |
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Changes in non-cash working capital: |
||||||||||||||||
| Accounts receivable |
$ | (143,926 | ) | $ | 31,565 | $ | 53,390 | $ | 284,466 | |||||||
| Inventories |
158,308 | (90,561 | ) | 175,266 | (151,329 | ) | ||||||||||
| Supplies and prepaid expenses |
4,475 | 19,359 | (2,326 | ) | 14,833 | |||||||||||
| Accounts payable and accrued liabilities |
88,909 | (109,633 | ) | (198,717 | ) | (337,674 | ) | |||||||||
| Reclamation payments |
(7,396 | ) | (8,301 | ) | (14,908 | ) | (16,109 | ) | ||||||||
| Other |
(18,176 | ) | 21,166 | (23,693 | ) | 14,254 | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Other operating items |
$ | 82,194 | $ | (136,405 | ) | $ | (10,988 | ) | $ | (191,559 | ) | |||||
|
|
|
|
|
|
|
|
|
|||||||||
| 16. | Share-based compensation plans |
| A. | Stock option plan |
The aggregate number of common shares that may be issued pursuant to the Cameco stock option plan shall not exceed 43,017,198 of which 33,407,755 shares have been issued. As of June 30, 2025, the total number of stock options held by the participants was 184,593 (December 31, 2024 - 259,958).
| B. | Executive performance share unit (PSU) |
During the period, the Company granted 183,370 PSUs. The weighted average fair value per unit at the date of issue was $63.70. As of June 30, 2025, the total number of PSUs held by the participants was 583,524 (December 31, 2024 - 636,588).
| C. | Restricted share unit (RSU) |
During the period, the Company granted 327,867 RSUs. The weighted average fair value per unit at the date of issue was $63.70. As of June 30, 2025, the total number of RSUs held by the participants was 762,811 (December 31, 2024 - 734,000).
18 CAMECO CORPORATION
| D. | Deferred share unit (DSU) |
During the period, the Company issued 14,060 DSUs. The weighted average fair value per unit at the date of issue was $72.83. As of June 30, 2025, the total number of DSUs held by participating directors was 324,664 (December 31, 2024 - 310,604).
Equity-settled plans
Cameco records compensation expense under its equity-settled plans with an offsetting credit to contributed surplus, to reflect the estimated fair value of units granted to employees. During the period, the Company recognized the following expenses under these plans:
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Employee share ownership plan(a) |
$ | 1,275 | $ | 1,301 | $ | 2,673 | $ | 2,380 | ||||||||
| Restricted share unit plan |
2,383 | 1,716 | 4,451 | 3,004 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total |
$ | 3,658 | $ | 3,017 | $ | 7,124 | $ | 5,384 | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| (a) | The total number of shares purchased in 2025 with Company contributions was 38,551 (2024 - 37,246). |
Cash-settled plans
During the period, the Company recognized the following expenses under these plans:
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Performance share unit plan |
$ | 11,937 | $ | 3,840 | $ | 14,515 | $ | 7,361 | ||||||||
| Deferred share unit plan |
13,428 | 4,862 | 8,852 | 5,723 | ||||||||||||
| Restricted share unit plan |
9,532 | 3,705 | 7,952 | 6,515 | ||||||||||||
| Phantom stock option plan |
1,065 | 460 | 541 | 530 | ||||||||||||
| Phantom restricted share unit plan |
579 | 243 | 504 | 409 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| $ | 36,541 | $ | 13,110 | $ | 32,364 | $ | 20,538 | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
Expenses related to share-based compensation plans are primarily included as part of administration expense in the statement of earnings.
2025 SECOND QUARTER REPORT 19
| 17. | Financial instruments and related risk management |
| A. | Accounting classifications |
The following tables summarize the carrying amounts and accounting classifications of Cameco’s financial instruments at the reporting date:
At June 30, 2025
| FVTPL | Amortized cost |
Total | ||||||||||
| Financial assets |
||||||||||||
| Cash and cash equivalents(a) |
$ | — | $ | 716,292 | $ | 716,292 | ||||||
| Accounts receivable |
— | 291,100 | 291,100 | |||||||||
| Derivative assets [note 5] |
||||||||||||
| Foreign currency contracts |
45,232 | — | 45,232 | |||||||||
|
|
|
|
|
|
|
|||||||
| 45,232 | 1,007,392 | 1,052,624 | ||||||||||
|
|
|
|
|
|
|
|||||||
| Financial liabilities |
||||||||||||
| Accounts payable and accrued liabilities |
— | 434,871 | 434,871 | |||||||||
| Lease obligation [note 8] |
— | 11,379 | 11,379 | |||||||||
| Derivative liabilities [note 8] |
||||||||||||
| Foreign currency contracts |
10,002 | — | 10,002 | |||||||||
| Interest rate contracts |
2,186 | — | 2,186 | |||||||||
| Long-term debt |
— | 995,965 | 995,965 | |||||||||
|
|
|
|
|
|
|
|||||||
| 12,188 | 1,442,215 | 1,454,403 | ||||||||||
|
|
|
|
|
|
|
|||||||
| Net |
33,044 | (434,823 | ) | (401,779 | ) | |||||||
|
|
|
|
|
|
|
|||||||
At December 31, 2024
| FVTPL | Amortized cost |
Total | ||||||||||
| Financial assets |
||||||||||||
| Cash and cash equivalents |
$ | — | $ | 600,462 | $ | 600,462 | ||||||
| Accounts receivable |
— | 346,800 | 346,800 | |||||||||
| Derivative assets [note 5] |
||||||||||||
| Foreign currency contracts |
103 | — | 103 | |||||||||
|
|
|
|
|
|
|
|||||||
| $ | 103 | $ | 947,262 | $ | 947,365 | |||||||
|
|
|
|
|
|
|
|||||||
| Financial liabilities |
||||||||||||
| Accounts payable and accrued liabilities |
$ | — | $ | 619,035 | $ | 619,035 | ||||||
| Current portion of long-term debt |
— | 285,707 | 285,707 | |||||||||
| Lease obligation [note 8] |
— | 9,839 | 9,839 | |||||||||
| Derivative liabilities [note 8] |
||||||||||||
| Foreign currency contracts |
140,437 | — | 140,437 | |||||||||
| Interest rate contracts |
3,172 | — | 3,172 | |||||||||
| Long-term debt |
— | 995,583 | 995,583 | |||||||||
|
|
|
|
|
|
|
|||||||
| 143,609 | 1,910,164 | 2,053,773 | ||||||||||
|
|
|
|
|
|
|
|||||||
| Net |
$ | (143,506 | ) | $ | (962,902 | ) | $ | (1,106,408 | ) | |||
|
|
|
|
|
|
|
|||||||
20 CAMECO CORPORATION
| (a) | Cameco has pledged $200,055,000 of cash as security against certain of its letter of credit facilities. This cash is being used as collateral for an interest rate reduction on the letter of credit facilities. The collateral account has a term of five years effective November 1, 2023. Cameco retains full access to this cash. |
| B. | Fair value hierarchy |
The fair value of an asset or liability is generally estimated as the amount that would be received on sale of an asset, or paid to transfer a liability in an orderly transaction between market participants at the reporting date. Fair values of assets and liabilities traded in an active market are determined by reference to last quoted prices, in the principal market for the asset or liability. In the absence of an active market for an asset or liability, fair values are determined based on market quotes for assets or liabilities with similar characteristics and risk profiles, or through other valuation techniques. Fair values determined using valuation techniques require the use of inputs, which are obtained from external, readily observable market data when available. In some circumstances, inputs that are not based on observable data must be used. In these cases, the estimated fair values may be adjusted in order to account for valuation uncertainty, or to reflect the assumptions that market participants would use in pricing the asset or liability.
All fair value measurements are categorized into one of three hierarchy levels, described below, for disclosure purposes. Each level is based on the transparency of the inputs used to measure the fair values of assets and liabilities:
Level 1 – Values based on unadjusted quoted prices in active markets that are accessible at the reporting date for identical assets or liabilities.
Level 2 – Values based on quoted prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the asset or liability.
Level 3 – Values based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement.
When the inputs used to measure fair value fall within more than one level of the hierarchy, the level within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement in its entirety.
2025 SECOND QUARTER REPORT 21
The following tables summarize the carrying amounts and level 2 fair values of Cameco’s financial instruments that are measured at fair value:
As at June 30, 2025
| Carrying value | Fair Value | |||||||
| Derivative assets [note 5] |
||||||||
| Foreign currency contracts |
$ | 45,232 | $ | 45,232 | ||||
| Derivative liabilities [note 8] |
||||||||
| Foreign currency contracts |
(10,002 | ) | (10,002 | ) | ||||
| Interest rate contracts |
(2,186 | ) | (2,186 | ) | ||||
| Long-term debt |
(995,965 | ) | (1,055,594 | ) | ||||
|
|
|
|
|
|||||
| Net |
$ | (962,921 | ) | $ | (1,022,550 | ) | ||
|
|
|
|
|
|||||
As at December 31, 2024
| Carrying value | Fair Value | |||||||
| Derivative assets [note 5] |
||||||||
| Foreign currency contracts |
$ | 103 | $ | 103 | ||||
| Current portion of long-term debt |
(285,707 | ) | (285,707 | ) | ||||
| Derivative liabilities [note 8] |
||||||||
| Foreign currency contracts |
(140,437 | ) | (140,437 | ) | ||||
| Interest rate contracts |
(3,172 | ) | (3,172 | ) | ||||
| Long-term debt |
(995,583 | ) | (1,058,055 | ) | ||||
|
|
|
|
|
|||||
| Net |
$ | (1,424,796 | ) | $ | (1,487,268 | ) | ||
|
|
|
|
|
|||||
The preceding tables exclude fair value information for financial instruments whose carrying amounts are a reasonable approximation of fair value. The carrying value of Cameco’s cash and cash equivalents, accounts receivable, and accounts payable and accrued liabilities approximates its fair value as a result of the short-term nature of the instruments.
There were no transfers between level 1 and level 2 during the period. Cameco does not have any financial instruments that are classified as level 1 or level 3 as of the reporting date.
| C. | Financial instruments measured at fair value |
Cameco measures its derivative financial instruments and long-term debt at fair value. Derivative financial instruments and current and long-term debt are classified as recurring level 2 fair value measurements.
The fair value of Cameco’s unsecured debentures is determined using quoted market yields as of the reporting date, which ranged from 2.6% to 3.5% (2024 - 3.1% to 4.9%). The fair value of the floating rate term loan is equal to its carrying value.
Foreign currency derivatives consist of foreign currency forward contracts, options and swaps. The fair value of foreign currency options is measured based on the Black Scholes option-pricing model. The fair value of foreign currency forward contracts and swaps is measured using a market approach, based on the difference between contracted foreign exchange rates and quoted forward exchange rates as of the reporting date.
Interest rate derivatives consist of interest rate swap contracts. The fair value of interest rate swaps is determined by discounting expected future cash flows from the contracts. The future cash flows are determined by measuring the difference between fixed interest payments to be received and floating interest payments to be made to the counterparty based on Canada Dealer Offer Rate forward interest rate curves.
22 CAMECO CORPORATION
Where applicable, the fair value of the derivatives reflects the credit risk of the instrument and includes adjustments to take into account the credit risk of the Company and counterparty. These adjustments are based on credit ratings and yield curves observed in active markets at the reporting date.
| D. | Derivatives |
The following table summarizes the fair value of derivatives and classification on the consolidated statements of financial position:
| Jun 30/25 | Dec 31/24 | |||||||
| Non-hedge derivatives: |
||||||||
| Foreign currency contracts |
$ | 35,230 | $ | (140,334 | ) | |||
| Interest rate contracts |
(2,186 | ) | (3,172 | ) | ||||
|
|
|
|
|
|||||
| Net |
$ | 33,044 | $ | (143,506 | ) | |||
|
|
|
|
|
|||||
| Classification: |
||||||||
| Current portion of long-term receivables, investments and other [note 5] |
$ | 16,344 | $ | 68 | ||||
| Long-term receivables, investments and other [note 5] |
28,888 | 35 | ||||||
| Current portion of other liabilities [note 8] |
(10,641 | ) | (83,890 | ) | ||||
| Other liabilities [note 8] |
(1,547 | ) | (59,719 | ) | ||||
|
|
|
|
|
|||||
| Net |
$ | 33,044 | $ | (143,506 | ) | |||
|
|
|
|
|
|||||
The following table summarizes the different components of the gain (loss) on derivatives included in net earnings:
| Three months ended | Six months ended | |||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||
| Non-hedge derivatives: |
||||||||||||||||
| Foreign currency contracts |
$ | 148,067 | $ | (18,667 | ) | $ | 138,581 | $ | (58,542 | ) | ||||||
| Interest rate contracts |
(335 | ) | (95 | ) | 223 | (1,498 | ) | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Net |
$ | 147,732 | $ | (18,762 | ) | $ | 138,804 | $ | (60,040 | ) | ||||||
|
|
|
|
|
|
|
|
|
|||||||||
| 18. | Segmented information |
Cameco has three reportable segments: uranium, fuel services and Westinghouse. Cameco’s reportable segments are strategic business units with different products, processes and marketing strategies. The uranium segment involves the exploration for, mining, milling, purchase and sale of uranium concentrate. The uranium segment also includes our share of earnings from our equity-accounted investee, JV Inkai (see note 6). The fuel services segment involves the refining, conversion and fabrication of uranium concentrate and the purchase and sale of conversion services. The Westinghouse segment reflects our earnings from this equity-accounted investment (see note 6). Westinghouse is a nuclear reactor technology original equipment manufacturer and a global provider of products and services to commercial utilities and government agencies. It provides outage and maintenance services, engineering support, instrumentation and controls equipment, plant modification, and components and parts to nuclear reactors.
Cost of sales in the uranium segment includes care and maintenance costs for our operations that have had production suspensions. Cameco expensed $27,768,000 of care and maintenance costs during the second quarter of 2025 (2024 - $11,855,000). For the six months ended June 30, 2025, Cameco expensed $41,478,000 (2024 - $24,233,000).
Accounting policies used in each segment are consistent with the policies outlined in the summary of material accounting policies.
2025 SECOND QUARTER REPORT 23
Business segments
For the three months ended June 30, 2025
| Uranium | Fuel services |
(i) WEC |
(i) Adjustments |
Other | Total | |||||||||||||||||||
| Revenue |
$ | 705,367 | $ | 162,036 | $ | 1,033,493 | $ | (1,033,493 | ) | $ | 9,613 | $ | 877,016 | |||||||||||
| Expenses |
||||||||||||||||||||||||
| Cost of products and services sold |
417,081 | 106,847 | 580,771 | (580,771 | ) | 9,526 | 533,454 | |||||||||||||||||
| Depreciation and amortization |
71,347 | 13,478 | 95,337 | (95,337 | ) | 1,647 | 86,472 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Cost of sales |
488,428 | 120,325 | 676,108 | (676,108 | ) | 11,173 | 619,926 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Gross profit (loss) |
216,939 | 41,711 | 357,385 | (357,385 | ) | (1,560 | ) | 257,090 | ||||||||||||||||
| Administration |
— | — | 105,863 | (105,863 | ) | 96,436 | 96,436 | |||||||||||||||||
| Exploration |
6,044 | — | — | — | — | 6,044 | ||||||||||||||||||
| Research and development |
— | — | — | — | (708 | ) | (708 | ) | ||||||||||||||||
| Other operating income |
(8,006 | ) | (2,640 | ) | — | — | — | (10,646 | ) | |||||||||||||||
| Loss on disposal of assets |
13 | — | — | — | — | 13 | ||||||||||||||||||
| Finance costs |
— | — | 50,930 | (50,930 | ) | 26,977 | 26,977 | |||||||||||||||||
| Gain on derivatives |
— | — | — | — | (147,732 | ) | (147,732 | ) | ||||||||||||||||
| Finance income |
— | — | (894 | ) | 894 | (5,407 | ) | (5,407 | ) | |||||||||||||||
| Share of earnings from equity-accounted investees |
(62,482 | ) | — | — | (125,939 | ) | — | (188,421 | ) | |||||||||||||||
| Foreign exchange losses |
— | — | — | — | 88,946 | 88,946 | ||||||||||||||||||
| Other expense (income) |
— | — | 29,803 | (29,803 | ) | (382 | ) | (382 | ) | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Earnings (loss) before income taxes |
281,370 | 44,351 | 171,683 | (45,744 | ) | (59,690 | ) | 391,970 | ||||||||||||||||
| Income tax expense |
71,085 | |||||||||||||||||||||||
|
|
|
|||||||||||||||||||||||
| Net earnings |
$ | 320,885 | ||||||||||||||||||||||
|
|
|
|||||||||||||||||||||||
| (i) | Consistent with the presentation of financial information for internal management purposes, Cameco’s share of Westinghouse’s financial results has been presented as a separate segment. In accordance with IFRS, this investment is accounted for by the equity method of accounting in these consolidated financial statements and the associated revenue and expenses are eliminated in the “Adjustments” column. |
24 CAMECO CORPORATION
For the three months ended June 30, 2024
| Uranium | Fuel services |
(i) WEC |
(i) Adjustments |
Other | Total | |||||||||||||||||||
| Revenue |
$ | 480,600 | $ | 117,858 | $ | 669,631 | $ | (669,631 | ) | $ | — | $ | 598,458 | |||||||||||
| Expenses |
||||||||||||||||||||||||
| Cost of products and services sold |
284,660 | 76,620 | 475,951 | (475,951 | ) | — | 361,280 | |||||||||||||||||
| Depreciation and amortization |
51,520 | 9,008 | 88,574 | (88,574 | ) | 1,330 | 61,858 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Cost of sales |
336,180 | 85,628 | 564,525 | (564,525 | ) | 1,330 | 423,138 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Gross profit (loss) |
144,420 | 32,230 | 105,106 | (105,106 | ) | (1,330 | ) | 175,320 | ||||||||||||||||
| Administration |
— | — | 88,535 | (88,535 | ) | 65,705 | 65,705 | |||||||||||||||||
| Exploration |
2,703 | — | — | — | — | 2,703 | ||||||||||||||||||
| Research and development |
— | — | — | — | 7,879 | 7,879 | ||||||||||||||||||
| Other operating income |
(2,220 | ) | (788 | ) | — | — | — | (3,008 | ) | |||||||||||||||
| Gain (loss) on disposal of assets |
47 | (5 | ) | — | — | — | 42 | |||||||||||||||||
| Finance costs |
— | — | 54,298 | (54,298 | ) | 43,383 | 43,383 | |||||||||||||||||
| Loss on derivatives |
— | — | — | — | 18,762 | 18,762 | ||||||||||||||||||
| Finance income |
— | — | (793 | ) | 793 | (7,887 | ) | (7,887 | ) | |||||||||||||||
| Share of loss (earnings) from equity-accounted investees |
(47,758 | ) | — | — | 46,721 | — | (1,037 | ) | ||||||||||||||||
| Foreign exchange gains |
— | — | — | — | (5,254 | ) | (5,254 | ) | ||||||||||||||||
| Other expense |
— | — | 20,483 | (20,483 | ) | — | — | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Earnings (loss) before income taxes |
191,648 | 33,023 | (57,417 | ) | 10,696 | (123,918 | ) | 54,032 | ||||||||||||||||
| Income tax expense |
18,024 | |||||||||||||||||||||||
|
|
|
|||||||||||||||||||||||
| Net earnings |
$ | 36,008 | ||||||||||||||||||||||
|
|
|
|||||||||||||||||||||||
| (i) | Consistent with the presentation of financial information for internal management purposes, Cameco’s share of Westinghouse’s financial results has been presented as a separate segment. In accordance with IFRS, this investment is accounted for by the equity method of accounting in these consolidated financial statements and the associated revenue and expenses are eliminated in the “Adjustments” column. |
2025 SECOND QUARTER REPORT 25
For the six months ended June 30, 2025
| Uranium | Fuel services |
(i) WEC |
(i) Adjustments |
Other | Total | |||||||||||||||||||
| Revenue |
$ | 1,324,191 | $ | 296,695 | $ | 1,803,017 | (1,803,017 | ) | $ | 45,562 | $ | 1,666,448 | ||||||||||||
| Expenses |
||||||||||||||||||||||||
| Cost of products and services sold |
781,105 | 166,135 | 1,155,579 | (1,155,579 | ) | 44,907 | 992,147 | |||||||||||||||||
| Depreciation and amortization |
122,794 | 20,436 | 191,676 | (191,676 | ) | 3,843 | 147,073 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Cost of sales |
903,899 | 186,571 | 1,347,255 | (1,347,255 | ) | 48,750 | 1,139,220 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Gross profit (loss) |
420,292 | 110,124 | 455,762 | (455,762 | ) | (3,188 | ) | 527,228 | ||||||||||||||||
| Administration |
— | — | 209,370 | (209,370 | ) | 155,256 | 155,256 | |||||||||||||||||
| Exploration |
13,932 | — | — | — | — | 13,932 | ||||||||||||||||||
| Research and development |
— | — | — | — | 13,274 | 13,274 | ||||||||||||||||||
| Other operating income |
(6,724 | ) | (2,503 | ) | — | — | — | (9,227 | ) | |||||||||||||||
| Loss on disposal of assets |
2,064 | 166 | — | — | — | 2,230 | ||||||||||||||||||
| Finance costs |
— | — | 99,897 | (99,897 | ) | 57,075 | 57,075 | |||||||||||||||||
| Gain on derivatives |
— | — | — | — | (138,804 | ) | (138,804 | ) | ||||||||||||||||
| Finance income |
— | — | (1,323 | ) | 1,323 | (9,096 | ) | (9,096 | ) | |||||||||||||||
| Share of earnings from equity-accounted investees |
(97,683 | ) | — | — | (63,887 | ) | — | (161,570 | ) | |||||||||||||||
| Foreign exchange losses |
— | — | — | — | 89,817 | 89,817 | ||||||||||||||||||
| Other expense (income) |
— | — | 55,235 | (55,235 | ) | (787 | ) | (787 | ) | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Earnings (loss) before income taxes |
508,703 | 112,461 | 92,583 | (28,696 | ) | (169,923 | ) | 515,128 | ||||||||||||||||
| Income tax expense |
124,490 | |||||||||||||||||||||||
|
|
|
|||||||||||||||||||||||
| Net earnings |
$ | 390,638 | ||||||||||||||||||||||
|
|
|
|||||||||||||||||||||||
| (i) | Consistent with the presentation of financial information for internal management purposes, Cameco’s share of Westinghouse’s financial results has been presented as a separate segment. In accordance with IFRS, this investment is accounted for by the equity method of accounting in these consolidated financial statements and the associated revenue and expenses are eliminated in the “Adjustments” column. |
26 CAMECO CORPORATION
For the six months ended June 30, 2024
| Uranium | Fuel services |
(i) WEC |
(i) Adjustments |
Other | Total | |||||||||||||||||||
| Revenue |
$ | 1,041,710 | $ | 190,293 | $ | 1,325,155 | $ | (1,325,155 | ) | $ | — | $ | 1,232,003 | |||||||||||
| Expenses |
||||||||||||||||||||||||
| Cost of products and services sold |
640,520 | 125,023 | 993,278 | (993,278 | ) | (706 | ) | 764,837 | ||||||||||||||||
| Depreciation and amortization |
88,235 | 14,328 | 173,270 | (173,270 | ) | 2,462 | 105,025 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Cost of sales |
728,755 | 139,351 | 1,166,548 | (1,166,548 | ) | 1,756 | 869,862 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Gross profit (loss) |
312,955 | 50,942 | 158,607 | (158,607 | ) | (1,756 | ) | 362,141 | ||||||||||||||||
| Administration |
— | — | 201,242 | (201,242 | ) | 125,513 | 125,513 | |||||||||||||||||
| Exploration |
10,063 | — | — | — | — | 10,063 | ||||||||||||||||||
| Research and development |
— | — | — | — | 17,199 | 17,199 | ||||||||||||||||||
| Other operating income |
(17,112 | ) | (2,675 | ) | — | — | — | (19,787 | ) | |||||||||||||||
| Loss on disposal of assets |
272 | 140 | — | — | — | 412 | ||||||||||||||||||
| Finance costs |
— | — | 118,416 | (118,416 | ) | 81,527 | 81,527 | |||||||||||||||||
| Loss on derivatives |
— | — | — | — | 60,040 | 60,040 | ||||||||||||||||||
| Finance income |
— | — | (2,723 | ) | 2,723 | (14,209 | ) | (14,209 | ) | |||||||||||||||
| Share of loss (earnings) from equity-accounted investees |
(124,888 | ) | — | — | 170,197 | — | 45,309 | |||||||||||||||||
| Foreign exchange gains |
— | — | — | — | (21,859 | ) | (21,859 | ) | ||||||||||||||||
| Other expense |
— | — | 59,969 | (59,969 | ) | 3 | 3 | |||||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||||
| Earnings (loss) before income taxes |
444,620 | 53,477 | (218,297 | ) | 48,100 | (249,970 | ) | 77,930 | ||||||||||||||||
| Income tax expense |
48,984 | |||||||||||||||||||||||
|
|
|
|||||||||||||||||||||||
| Net earnings |
$ | 28,946 | ||||||||||||||||||||||
|
|
|
|||||||||||||||||||||||
| (i) | Consistent with the presentation of financial information for internal management purposes, Cameco’s share of Westinghouse’s financial results has been presented as a separate segment. In accordance with IFRS, this investment is accounted for by the equity method of accounting in these consolidated financial statements and the associated revenue and expenses are eliminated in the “Adjustments” column. |
| 19. | Related parties |
Transactions with key management personnel
Key management personnel are those persons that have the authority and responsibility for planning, directing and controlling the activities of the Company, directly or indirectly. Key management personnel of the Company include executive officers, vice-presidents, other senior managers and members of the board of directors.
Certain key management personnel, or their related parties, hold positions in other entities that result in them having control or significant influence over the financial or operating policies of those entities. As noted below, some of these entities transacted with the Company in the reporting period. The terms and conditions of the transactions were on an arm’s length basis.
Cameco purchases a significant amount of goods and services for its Saskatchewan mining operations from northern Saskatchewan suppliers to support economic development in the region, where the president of several of these suppliers is a member of the board of directors. During the quarter ended June 30, 2025, Cameco paid these suppliers $19,011,000 for construction and contracting services (2024 - $20,420,000). During the six months ended June 30, 2025, Cameco paid these suppliers $42,599,000 (2024 - $46,408,000). The transactions were conducted in the normal course of business and were accounted for at the exchange amount. Accounts payable includes a balance of $1,175,000 at the reporting date (December 31, 2024 - $1,156,000).
2025 SECOND QUARTER REPORT 27
Other related party transactions
| Transaction value | Transaction value | Balance outstanding | ||||||||||||||||||||||
| Three months ended | Six months ended | as at | ||||||||||||||||||||||
| Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | Jun 30/25 | Jun 30/24 | |||||||||||||||||||
| Joint venture |
||||||||||||||||||||||||
| Sales revenue(a) |
$ | 82 | $ | — | $ | 69,656 | $ | 45,182 | $ | — | $ | — | ||||||||||||
| Fuel storage and handling(a) |
1 | 1 | 1 | 25 | — | — | ||||||||||||||||||
| Deferred sales(a) |
68,943 | |||||||||||||||||||||||
| Dividend received(a) |
— | — | 69,747 | — | — | — | ||||||||||||||||||
| Associate |
||||||||||||||||||||||||
| Product purchases(b) |
— | — | — | 145,784 | — | — | ||||||||||||||||||
| Dividends received(b) |
136,970 | 185,447 | 136,970 | 185,447 | — | — | ||||||||||||||||||
| (a) | Cameco has entered into various agreements with Westinghouse and its subsidiaries and has recognized sales revenue related to fuel supply agreements and incurred costs related to fuel storage and handling fees. Contract terms are in the normal course of business and were accounted for at the exchange amount. Cash dividends are also received from Westinghouse. |
| (b) | Cameco purchases uranium concentrate from JV Inkai. Purchases from JV Inkai are based on the prevailing uranium spot price less a 5% discount with extended payment terms. Cash dividends are also received from JV Inkai. |
28 CAMECO CORPORATION
Exhibit 99.4
Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
I, Tim Gitzel, president and chief executive officer of Cameco Corporation, certify that:
| 1. | I have reviewed this quarterly report on Form 6-K of Cameco Corporation; |
| 2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
| 3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
| 4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
| (a) | designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
| (b) | designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
| (c) | evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
| (d) | disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
Page 2
| 5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
| (a) | all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
| (b) | any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: July 31, 2025
| /s/ Tim Gitzel |
| Tim Gitzel |
| President and Chief Executive Officer |
Exhibit 99.5
Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
I, Grant Isaac, executive vice-president and chief financial officer, of Cameco Corporation, certify that:
| 1. | I have reviewed this quarterly report on Form 6-K of Cameco Corporation; |
| 2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
| 3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
| 4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
| (a) | designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
| (b) | designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
| (c) | evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
| (d) | disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
Page 2
| 5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
| (a) | all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
| (b) | any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: July 31, 2025
| /s/ Grant Isaac |
| Grant Isaac |
| Executive Vice-President |
| and Chief Financial Officer |