Cameco (NYSE:CCJ) Corporation (CCO), a leading uranium producer, announced robust third-quarter results in 2024, with strong operational performance and strategic advancements despite some market and supply challenges. The company reported an adjusted EBITDA nearing $1 billion for the first nine months and a dividend increase from $0.12 to $0.16 per common share for 2024, with plans to double it by 2026.
Production from the Key Lake Mill is expected to surpass previous estimates, reaching approximately 19 million pounds due to automation and optimization efforts. However, the company revised its 2024 uranium production expectations from the JV Inkai project in Kazakhstan down to 7.7 million pounds from 8.3 million pounds due to sulfuric acid delivery delays. Cameco's fuel services segment saw a 60% production increase year-over-year, supported by new infrastructure at Port Hope.
Key Takeaways
- Cameco's adjusted EBITDA for the first nine months of 2024 is close to $1 billion.
- Dividend per common share increased to $0.16 for 2024, with a future target of $0.24 by 2026.
- Key Lake Mill's uranium production is expected to hit 19 million pounds, up from 18 million pounds.
- JV Inkai's production forecast decreased to 7.7 million pounds due to sulfuric acid supply issues.
- Long-term uranium price has reached the highest level in over a decade.
- The fuel services segment's production has increased by 60% year-over-year.
Company Outlook
- Cameco remains optimistic about its market position and the ongoing demand for nuclear energy.
- The company has a stable long-term outlook, though market dynamics may necessitate adjustments, especially in uranium supply and conversion sectors.
- Cameco is committed to its Tier 1 assets and is exploring potential production increases at the MacArthur River project.
Bearish Highlights
- The decrease in expected production from the JV Inkai project due to sulfuric acid supply issues.
- Long-term contracting activity is slow, influenced by geopolitical factors, including U.S. sanctions on Russian uranium imports.
- Temporary disruptions in acid supply due to complex ownership agreements with Russian partners impacted production.
Bullish Highlights
- The long-term uranium price has risen significantly, with strong market fundamentals supporting future price increases.
- Cameco's investments in automation and digitization have helped mitigate cost inflation.
- Western sources of uranium are becoming increasingly necessary, leading to upward pricing pressure.
Misses
- Cameco adjusted its committed purchases for the year down to 8 million pounds from 9 million pounds.
- There have been delays in shipments from Inkai due to the avoidance of Russian transportation routes following the Ukraine invasion.
Q&A Highlights
- Executives discussed the importance of the Springfields conversion facility and the current tight conversion market.
- The company acknowledged regulatory developments in nuclear energy as co-investment opportunities.
- Cameco criticized a recent uranium price survey, indicating a disconnect between utility expectations and supplier outlooks.
Cameco Corporation (CCO) showcased resilience and strategic foresight during its third-quarter earnings call, balancing operational successes with candid discussions on market and supply challenges. The company's commitment to sustainability and a clean energy future, coupled with its disciplined approach to market engagement, positions it as a forward-thinking player in the nuclear energy sector. Despite some near-term headwinds, Cameco's strong performance and optimistic long-term strategies signal a robust outlook for stakeholders.
InvestingPro Insights
Cameco Corporation's (CCJ) robust performance in the third quarter of 2024 is reflected in its financial metrics and market position. According to InvestingPro data, the company's revenue growth stands at an impressive 27.36% over the last twelve months, with quarterly revenue growth of 24.16% in Q2 2024. This aligns with the company's reported strong operational performance and strategic advancements.
The company's market capitalization of $23.18 billion underscores its significant presence in the uranium industry. Cameco's EBITDA growth of 138.48% over the last twelve months is particularly noteworthy, supporting the company's announcement of adjusted EBITDA nearing $1 billion for the first nine months of the year.
InvestingPro Tips highlight that Cameco has maintained dividend payments for 33 consecutive years, which is consistent with the company's recent dividend increase and plans for future growth. This demonstrates Cameco's commitment to shareholder returns, even as it navigates market challenges.
Another relevant InvestingPro Tip indicates that Cameco is trading at a low P/E ratio relative to near-term earnings growth, with a PEG ratio of 0.77. This suggests that the stock may be undervalued considering its growth prospects, which could be attractive to investors looking at the company's long-term potential in the nuclear energy sector.
For readers interested in a more comprehensive analysis, InvestingPro offers 14 additional tips for Cameco, providing a deeper understanding of the company's financial health and market position.
Full transcript - Cameco Corp (TSX:CCO) (CCJ) Q3 2024:
Operator: Thank you for standing by. This is the conference operator. Welcome to the Cameco Corporation Third Quarter 2024 Results Conference Call. As a reminder, all participants are in listen-only mode and the conference is being recorded. Following the introductory remarks, there will be an opportunity to ask questions. [Operator Instructions]. Webcast participants are asked to wait until the Q&A session before submitting their questions as the information they are looking for may be provided during the presentation. The Q&A session will conclude at 9 a.m. Eastern time. I would now like to turn the conference over to Cory Kos, Vice President, Investor Relations. Please go ahead.
Cory Kos: Thank you, operator. And good morning, everyone. Welcome to Cameco's third quarter conference call. I would like to acknowledge that we are speaking from our corporate office, which is on Treaty 6 Territory, the traditional territory of the Cree (NYSE:WOLF) Peoples, and the homeland of the Métis. With us today are Tim Gitzel, President and CEO; Grant Isaac, Executive VP and CFO; Heidi Shockey, Senior VP and Deputy CFO; and Rachelle Girard, Senior VP and Chief Corporate Officer. I'll hand it over to Tim momentarily to briefly discuss the strength of today's fundamental market dynamics, as well as our progress with the continued execution of our strategy, which has us returning to a Tier 1 cost structure and delivering strong production performance while maintaining a solid financial position. After, we will open it up to your questions. Today's call be approximately one hour concluding at 9 am Eastern Time. As always, our goal is to be open and transparent with our communication. However, we do want to respect everyone's time and conclude the call on time. Therefore, should we not have time to get to your questions during this call, or if you would like to get into detailed financial modeling questions about our quarterly results, we would be happy to follow up with you after the call. There are a few ways to contact us with additional questions. You can reach out to the contacts provided in our news release. You can submit a question through the Contact Tab on our website, or you can use the Ask a Question Form at the bottom of the webcast screen and we'll be happy to follow up with you after this call. If you join the conference call through our website event page, there are slides available, which will be displayed during the call. In addition, for your reference, our quarterly investor handout is available for download in a PDF on our website at cameco.com. Today's conference call is open to all members of the investment community, including the media. During the Q&A session, please limit yourself to two questions and then return to the queue. Please note that this conference call will include forward looking information, which is based on the number of assumptions and actual results could differ materially. You should not place undue reliance on forward looking statements. Actual results may differ materially from these forward looking statements and we do not undertake any obligation to update any forward looking statements we make today, except for as required by law. Please refer to our most recent annual information form and MD&A for more information about the factors that could cause these different results and the assumptions we've made. With that, I'll turn it over to Tim.
Tim Gitzel: Thank you, Cory. And good morning, everyone. We appreciate you joining us on our call today. I'm sure you all closely followed the US Presidential Election this week. I'd like to offer congratulations to both President-elect Trump and to all of our friends south of the border for shaping the future of your nation by exercising your democratic right to vote. We look forward to ongoing bipartisan support for the nuclear sector across the political spectrum, not only in the US, but here in Canada and throughout the Western world. As we get started here today, I first want to ensure stakeholders look past the noise and understand the headline items in our disclosure this quarter. As I will touch on shortly, we continued to see a trend of improving operational performance in both our uranium and fuel services segments, bringing us back to a Tier 1 cost structure and supporting dividend growth. Our outlook for the year remains strong and consistent with our expectations. And long-term contracting activity is expected to continue gaining momentum with ongoing off-market interest and increased reported volumes added subsequent to the quarter. When it comes to our financials, equity earnings from Westinghouse were and will continue to be impacted by the amortization of the intangible assets that arose as a result of the required accounting for the acquisition. That is why we focus on and provide outlook for adjusted EBITDA as a performance measure for Westinghouse as it adjusts for these elevated amortization costs which do not reflect the underlying business performance. Looking past the quarterly earnings, which as always can vary significantly, there is a clear underlying trend of improving operational performance and cash flow generation across our businesses and investments. This trend is backed by stable and rising market prices driving nearly $1 billion in adjusted EBITDA for the first nine months before those acquisition-related purchase price adjustments. At Cameco, we are exceptionally well positioned and we continue to see growing demand for nuclear power with the agreements to support nuclear that we've all been hearing about becoming signed commitments to build new reactors. In the third quarter, we continued to see the growing positive momentum and support for nuclear energy among governments, energy-intensive industries and within the general public. That support is generating durable, full-cycle demand which we believe is stronger than ever. For the past two years, we've regularly highlighted demand durability across the fuel cycle and the unparalleled opportunities emerging in the near, mid and long-term markets. Those fundamental drivers, things like decarbonization, sustainability, energy security and growing energy demand all remain solid and unchanged. However, on the other side of that equation, future supply continues to be uncertain. With a need for improved long-term market prices to underpin supply economics and support ongoing investment. While the long-term uranium price has now crept up to its highest level in over a decade, we're still not seeing significant investments in the projects needed to satisfy future demand to run the existing reactors, let alone those reactors being saved and restarted, reactor life extensions, and new reactor builds. And as we can clearly see today, following the U.S. ban on Russian uranium imports, uranium supply and services across the fuel cycle take time to respond. Despite the established need for more supply amid the current tight and uncertain market, long-term contracting through the first nine months of the year remained relatively slow. While that's far from unusual in the nuclear fuel cycle, where long-term prices are only quoted monthly due to the low frequency of executed transactions, there are a few key developments that are not only driving utilities to review procurement plans, but prompting producers to re-evaluate sales strategies. Contracting continued to be impacted by things like the U.S. Election, the Russian uranium ban which took effect in early August, uncertainty with respect to the process to obtain waivers under that ban, and new demand emerging from energy intensive industries which could reshape the nuclear fuel cycle landscape in the decades to come. As we expected in our last quarterly call, the cautious approach by fuel buyers has started to give way to an increase in utility interest both publicly in the market and off-market through bilateral negotiations with producers. As contracting picks up, we continue to be selective in committing our uranium inventory and UF6 conversion capacity in order to maintain a contract book that preserves exposure to the rising prices while maintaining downside protection. We're seeing significant interest in the extremely tight conversion segment of the fuel cycle, which remains at historic prices far higher than anyone in our market had anticipated. However, in the uranium market, the first nine months remained lighter, with increased volume subsequent to quarter-end followed a couple of larger uranium contracts signed in October. Those deals boosted long-term contract volumes from just over 50 million pounds at September 30th to about 90 million pounds as of last week. That said, long-term contract volumes still remain well short of replacement rate, so it's important to reiterate that requirements can be delayed and can be deferred, but buying the uranium fuel required to keep the lights on cannot be avoided. Future needs are still future needs, and not only do we need to catch up on over a decade of under-contracting, but the world also has a fleet of retiring fossil fuel generation that needs to be replaced. Nuclear addresses all the key considerations influencing energy policies and international plans for replacing carbon-emitting energy sources. Future energy supply must be secure, carbon-free, reliable, and uninterrupted, and in each of those categories, nuclear is in a class of its own. Amid intensifying geopolitical challenges and various sustainability-related factors, procuring the required nuclear fuel from responsible, reliable, experienced, and sustainable suppliers like Cameco is more important than ever. Therefore, the positive momentum for nuclear energy and the tightness of full cycle supply puts Cameco in a unique position to add significant value with what we believe are the world's premier Tier 1 fuel cycle assets alongside our investments across the reactor life cycle. With a strategy centered on full cycle value, we've continued to optimize those assets as we shift back to a Tier 1 cost structure. With strong production performance through the first nine months of the year and a solid financial footing, our board has approved an increase of our dividend from $0.12 in 2023 to $0.16 per common share for this year. And with fundamental improvement continuing across the market, we have recommended a dividend growth plan under which we expect to at least double the $0.12 dividend in 2023, growing it to $0.24 per common share through 2026. Turning to our results, I want to highlight a few developments this past quarter, starting in the marketing and operational areas of our strategy. In our uranium segment, we continued to evaluate the work and capital required to expand our MacArthur River and Key Lake operations from 18 million pounds per year to the license capacity of up to 25 million pounds per year. However, in the meantime, production at the Key Lake Mill has exceeded our expectations year-to-date, and we now expect production of about 19 million pounds, up from 18 million pounds previously. The improved 2024 outlook is primarily the result of various automation, digitization, and optimization projects we undertook while the operation was in care and maintenance. Although the market conditions were difficult at the time, we intentionally made counter-cyclical investments. Those investments are now paying off. We are not only bending our cost curve, as that improvement work was completed ahead of the incredible inflationary pressure we're seeing today, but as we evaluate the CapEx required to increase production and step with demand in our contract book, we are potentially now able to achieve a higher baseline level of production before making any additional investments in the Key MacArthur assets. Having more Tier 1 production in our portfolio is always a positive development for us. The additional pounds can be feathered into our long-term contracts, providing further optionality, flexibility, and a de-risking of our supply stack. The first source of supply is our Tier 1 primary production, which always has a home under long-term contracts before it's pulled out of the ground. Based on available production, we then manage our other levers, including inventory, long-term purchases, loan material, and market purchases. We carefully plan these supply sources years in advance, retaining access to multiple levers to manage risks, one risk being that a given source runs short of expectations. That's what we're seeing at JV Inkai in Kazakhstan, which falls into our long-term committed purchase bucket of supply. We now expect production of about 7.7 million pounds of uranium from Inkai, down from last year's production and from our previous 2024 expectation of 8.3 million pounds. The decreased outlook at Inkai is primarily due to the ongoing challenges related to sulfuric acid in that part of the world. There was enough acid procured to achieve the original planned production volume, but the timing of the deliveries of that acid shifted, pushing the development and production schedule into 2025. A portion of our share of this year's production, about 2.3 million pounds, has now arrived at a Canadian port, with shipments to Blind River now underway. However, our remaining allocation for this year is still under discussion with Kazatomprom (LON:KAPq). Of note, we are currently finalizing an updated National Instrument 43-101 technical report for the Inkai mine, in which we will update the expected reserves, production profile, costs, sensitivities, and technical information. So in the third quarter, we had to account for the higher production from Key MacArthur, partially offset by the increased uncertainty on the quantity and timing for our full share of production from JV Inkai. So, we put our supply levers to work, realigning our expected market and long-term committed purchases for the year. We decreased our committed purchases from 9 million to 8 million pounds and shifted our market purchases from up to 2 million pounds to now be up to 3 million pounds for 2024. And although we have either taken delivery of or have commitments for the majority of our expected 2024 market purchases, we may look for additional opportunities to add to our inventory position. In the fuel services segment, production was also strong. In fact, it was 60% higher than our third quarter last year. This was largely thanks to the commissioning of a new closed-loop water system at Port Hope. This additional process infrastructure not only provides positive benefits from a water usage and sustainability perspective, but it allowed us to eliminate the annual summer maintenance outage for the first time, partially offsetting the impact of the temporary operational issues that affected production in the first half of 2024. As expected and as I highlighted, the performance of our Westinghouse investment this year continues to be impacted by purchase price accounting, which is of course not unique to this transaction, but something that is normal course in the case of any acquisition. It's important to look through these impacts as our outlook for Westinghouse's performance this year and over the next five years is positive and unchanged. In fact, when we look at the underlying long-term trends for the industry, we continue to see more opportunities for Westinghouse emerging than we had valued at the time of acquisition, making it a very timely transaction that has fit perfectly into our long-term strategy. Stepping over to the financial aspect of our strategy, we continue to be in great shape. As always, normal quarterly variability and customer deliveries impacted our results. In addition, earnings from our equity-accounted investees impacted our adjusted net earnings this quarter. As I noted earlier, our overall financial results continue to be influenced by the required Westinghouse purchase accounting and other non-operational acquisition-related costs. Equity earnings from JV Inkai were also lower because of the continued delay to the transportation of our share of production from the Inkai mine. We do not take ownership of our share of Inkai's production until it arrives at our Blind River refinery and therefore JV Inkai cannot record revenue on those pounds. Ours is a complex long-term industry that does not lend itself well to quarterly estimates. That's why we provide an annual outlook, which following the third quarter remains largely unchanged for both Cameco and for Westinghouse, with the exception of the realignment of our supply sources and the impact of a stronger U.S. dollar on average realized price, revenue and adjusted EBITDA from Westinghouse compared to the original assumption used. During the quarter, we continued to focus on debt management. We made an additional repayment of $100 million U.S. on the floating rate term loan we used to finance the Westinghouse acquisition, bringing the year-to-date reductions to $400 million. And in the days ahead, we will continue to prioritize repayment of the remaining $200 million outstanding. We've remained diligent in managing liquidity and the capital resources and tools required to deliver on our strategy, maintaining a strong balance sheet guided by our investment-grade rating. To provide flexibility and maintain good financial hygiene, we plan to file a new base shelf prospectus to replace the one that expired in October. Before we wrap up, I want to highlight a few changes to our executive team. At the beginning of October, David Doerksen was appointed Senior Vice President and Chief Marketing Officer. David's been with Cameco since 1998, most recently as Vice President Marketing. He's also held roles in Tax and Treasury, Corporate Strategy and Corporate Development. Lisa Aitken has taken over David's previous role as Vice President Marketing. I have no doubt that the deep uranium market experience that both David and Lisa bring to their new roles will serve Cameco well, as we position the company to leverage opportunities through these very exciting times for the nuclear industry. So, with that, I thank you for your interest today. And I'll stop there and we'd be delighted to take your questions.
Operator: Thank you. [Operator Instructions]. Webcast participants are welcome to submit questions through the box at the bottom of the webcast frame. The Cameco Investor Relations Team will follow-up with you by email after the call. [Operator Instructions]. Our first question is from Ralph Profiti with Eight Capital. Please go ahead.
Ralph Profiti: Thanks operator and good morning. Thanks for taking my questions. Tim, with respect to the long-term contracting that you mentioned in your prepared remarks, I'm just wondering if some of the buying behavior is shifting, specifically with respect to the prioritization of sort of downstream procurement, things like SWU conversion enrichment. And buyers are now starting to thinking about moving upstream as that part of the market gets fulfilled in terms of sort of crowding out some of that Russian material. Just wondering if that's – if this contracting is sort of a signal that that could be happening.
Tim Gitzel: Yeah Ralph, I will answer yes to that. We're two years, two and a half years now into this Russian invasion into Ukraine, and as Grant I think has pointed out many, many times. Once that happened, obviously that caused a bit of a crisis in the whole market. But the utilities often start at the far end in the enrichment space and work their way backwards. I don't think they are finished in enrichment yet. You can see the prices are holding pretty firm, and enrichment conversion are hitting new highs, and we're waiting for it to come down the pipeline really into the uranium space, because we're going to have a problem there going forward as well. So, I think your observation is absolutely right, Ralph.
Ralph Profiti: Okay, great. And I want to ask a question on your comments about Westinghouse and your long-term EBITDA growth rate, sort of 6% to 10%. That's a few quarters old and certainly market dynamics have shifted. Just wondering when you'll be in a position to sort of address that growth rate and how you're thinking about the range of that growth given some of the market dynamics are certainly moving forward for us.
Tim Gitzel: Yeah Ralph, we're holding to that 6% to 10%, but Grant, I'm going to ask you to – Grant's on the Board for Cameco of Westinghouse and they are working with him right now on the present and future outlook. So Grant, why don't you take a shot?
Grant Isaac: Yeah, happy to do that. Hi, Ralph. The couple of key points on Westinghouse, obviously we've maintained the guidance for this year from an adjusted EBITDA basis, as you saw in our outlook table. And as you mentioned, we have a 6% to 10% growth rate over the next five years for Westinghouse and I think your comment or your question is a good one. There've been a lot of tailwinds to the nuclear industry and you've seen a lot of news flow around Westinghouse's extraordinarily good position with respect to that tail, those tailwinds. And what we would just say is, we think that remains a very conservative outlook. We tend to wait until some of the bigger projects, for example, the new build of AP1000 hit the final investment decision in order to kind of adjust that upward growth on new builds. So lots of excitement, a lot of prospect for new builds. For those who haven't seen the DOE's latest liftoff report and how prominently the AP1000 feature is in that, I would encourage everybody to have a look at that. But right now, that is really just a conservative view. We take the announcements that have been made for new builds, for example, and all we're factoring in is the growth that's coming from the front end engineering and design work. None of these projects, whether it's Poland, Bulgaria or Ukraine, for example, have hit a final investment decision. When that occurs, yeah, there will be an upward adjustment to that number. So it's conservative, it's consistent with the timeframes that it takes, but let's be very clear, Westinghouse is incredibly well-positioned given all of the tailwinds in the nuclear space.
Ralph Profiti: Yeah, great. Thanks for those important answers.
Tim Gitzel: Thanks for your questions, Ralph.
Operator: The next question is from Adam Wijaya with Goldman Sachs. Please go ahead.
Adam Wijaya: Good morning, Tim, Grant, and team. Thank you for taking my questions. I wanted to just first start on Inkai. So given some of the uncertainty surrounding that deposit, at least in the near and medium term, how are you thinking about the Tier 2 asset base that's currently on care and maintenance? And then a follow-up to that is, how should we be thinking about any potential inorganic growth opportunities, specifically on the mining side?
Tim Gitzel: Thanks Adam for the question. So you mentioned Inkai. We're working our way through Inkai. You saw in our reporting that there's some acid issues. There's acid issues in the country, but ours was a bit of a timing on acid issue. I think we got the allocation we need for the year. We just didn't get it quite at the right time, so we're having to adjust our production numbers there a bit, but we remain committed to the JV Inkai project and the future of that. Tier 2, not yet. You hear us talk about our Tier 1’s. We've got firepower with our Tier 1 assets, especially the MacArthur River Key Lake project, which we continue to evaluate how we can de-risk and de-bottleneck. That project, at some point, increase production from a million pounds. Right now we're moving closer to our license capacity of ‘25, so honestly that's the best project on the planet at the moment, so we'll focus on that. We'll focus on our Tier 1’s, and then when the market calls for us to move to Tier 2, we've been keeping them on care and maintenance now for the last number of years, we'll pull those out. Those aren't Greenfield, those are Brownfield, way shorter to restart than anything Greenfield, and so we've got those in our pocket as well. Then we've got a few projects that we haven't even started yet. We do have our own Greenfields that are well situated, close to existing facilities, in friendly jurisdictions, with competent teams, with great relations with our neighbors, indigenous and otherwise, we would go to those first. So we've got our own package of projects ready to go, whether it's increasing our Tier 1s, bringing on our Tier 2’s, or looking at Greenfield. So as Grant just said a minute ago, we are incredibly well positioned and ready to go when the time calls for it.
Adam Wijaya: Great, that's super helpful. My second question is just on conversion. So clearly remaining the tightest part of the fuel cycle, and understand with the Westinghouse acquisition, the Springfield asset seems really competitively positioned to service that part of the fuel cycle. So what are your latest thoughts on a potential restart here, and then what needs to happen realistically from a contracting perspective from the conversion side of the equation to accelerate any announcement here? Thanks.
Tim Gitzel: Yeah, so we're incredibly excited about that one too, that wasn't in the first part of the answer with Cameco. Grant, you want to talk about Springfields and the…
Grant Isaac: Yeah, a couple of common themes emerging, so the first question that we got this morning was about the pattern of contracting, and it's just important for everybody on this call to remember that when utilities really are thinking about securing that fabricated fuel bundle, they start at the reactor and they work upstream. And as they do that, we've seen pressure on the enrichment space. We've seen a lot of pressure on the conversion space, and I would just echo Tim's earlier comment that the world has yet to see that demand fully hit the uranium space, which is by the way, very, very good news for uranium. To your question about conversion, it remains really tight. Conversion does require the last remaining western conversion facility, Springfields, to come back to the market. That does need to occur. In order to get there, you have to have a very solid plan. Springfields is a multi-purpose facility in the UK, just an incredibly strategic asset. It can do a lot of things, and so part of the thinking around Springfields is making sure that the appropriate investments are well leveraged. Different lines at Springfields may share common infrastructure, so spending that money wisely is priority number one. So you have to have a good, solid industrial plan to restart, and then, like everything else in the nuclear fuel cycle, it has to be coordinated with marketing. Conversion is like uranium. You don't build productive capacity and then start knocking on people's doors and trying to chase in your demand, because it just doesn't exist. So, we need to see a stronger contracting cycle in conversion. Right now, that conversion demand is really chasing production at the three existing western facilities. It hasn't really started to chase the type of pricing required to restart Springfields, but its coming. Just like in uranium, we're very strategically patient and we're very disciplined. This asset has to come back, and the value opportunity for Westinghouse is very significant. We love our position in the conversion space.
Tim Gitzel: Thanks, Adam.
Operator: The next question is from Adam Wong with RBC Capital Markets. Please go ahead.
Tim Gitzel: Good morning, Andrew. [Multiple Speakers]
Andrew Wong: Hey, good morning. How are you doing Tim? So we've seen a lot of momentum on new nuclear and data centers, but we did see the U.S. government push back on that Amazon (NASDAQ:AMZN) and Talon deal. Sounds like maybe more of a speed bump versus changing any major views on using nuclear on – at our data centers, but I'm just kind of curious of your views on that announcement. And then just broadly, we've heard a lot of remarks from U.S. utilities, potentially even considering new builds recently, and potentially within the next maybe 12 months. So maybe just your thoughts on a new build announcement in the U.S. sometime in the future and the AP1000 role within that? Thanks.
Tim Gitzel: Yeah, I'm not sure that's a speed bump. I'm not sure it's not a door opening for more new nuclear behind the meter. But Grant, why don't you answer that?
Grant Isaac: Yeah, my ability to see the silver lining in every dark cloud is pretty astonishing Andrew. I looked at the FERC announcement very different. I think maybe the market misinterpreted that. What it said to me was that the hyperscalers and the industrial onshores that are chasing electrons have to co-invest in new capacity. Rather than show up and start generating a lot of demand into existing grids and increasing the price, they have to co-invest in new capacity. So it actually goes hand-in-glove with some of the announcements that you've seen. The Constellation Microsoft (NASDAQ:MSFT) announcement to bring back Unit 1 at Three Mile Island, new capacity coming to the grid, the hyperscalers co-investing in that new capacity. All the FERC announcement did is confirm that those with in excess of trillion-dollar enterprise values that need electrons are going to have to invest in those electrons themselves. That's a great news story for New Build. I don't look at it as a speed bump at all. I look at it as a very, very clear signal, that very large pockets of demand are coming to buy electrons, and they happen to want the quality of electron that comes out of a nuclear power plant, carbon-free, 24-hour, fully dispatchable base-load power. So I very much view it as good news. And I'm going to go back to something I said earlier. If folks on this call haven't seen the DOE left-off report, they need to go and have a look at it and see the role that the AP1000 could possibly play, and probably draw the same conclusion we do, which is that existing technology, fully operating at the Bogo plants, generation three, reliable technology that doesn't have any technology or fuel risk, is extraordinarily well-positioned to meet this demand. And this demand that's being told needs to be co-invested. I like this outcome, Andrew.
Andrew Wong: That's great. That's really good color, thank you. And then maybe just on MacArthur Key Lake, it's producing really well. What's the potential there for that facility to produce above 20 million pounds, and maybe you don't even need to spend some extra CapEx to really expand production there?
Tim Gitzel: Yeah, Andrew, you're exactly on track. That's what we're evaluating right now. We're continuing to look at – and I was up there earlier this week with our Board, how we can de-risk, de-bottleneck the existing facilities to get to ’25, and I give our teams credit. In those tough times we were in when we had to take the units down at both MacArthur River and Key Lake, we didn't sit on our hands. We actually stepped up and put some thought and some money and some robotics and automation and capital into those assets to really get them ready, because we knew they were coming back. Those are the best assets on the planet. They are not going to sit idle forever. And so the work we did during that period, now we're seeing it bear fruit. And so you see we bumped up production a bit this year. We're going to see how far we can push that without putting a big chunk of new capital into that. Like I say, those are elite assets in the nuclear space. I can tell you, the elite assets in the nuclear space. And we have the elite team running them, and so we'll see what we can do with those assets going forward. But we're going to try and push them as hard as we can without having to put a lot of capital in. Grant?
Grant Isaac: Andrew, I'm just going to jump in on the end of it though, and just remind folks that whenever Cameco talks about increasing production, it does not mean production that's coming to the broader market. It doesn't mean that Cameco is oversupplying. So we increased production after we secured the demand. That production that could possibly come out of McArthur Key has a home in a long-term contract portfolio. I don't want to see anybody taking away from those comments that, ‘oh, Cameco is being irresponsible with production decisions.’ That never happens.
Andrew Wong: Great. Thank you very much.
Tim Gitzel: Thanks Andrew.
Operator: The next question is from Alexander Pearce with BMO Capital Markets. Please go ahead.
Alexander Pearce: Morning, all. So I have a follow-up on one of the earlier questions on Inkai. First off, can you kind of confirm that you think some of the issues at the asset so far this year are transitory? And are you seeing an improvement already? Are you kind of over the hump, as it were? And then you've got a fairly complex ownership agreement of that asset and so I was just wondering if you can help us with how we should think about your share of production going forward from the asset now. Is there any opportunity to catch up on some of the share that you've – the volumes that you've lost so far this year?
Tim Gitzel: So, I think yes and yes. Yes, we're getting over some of the issues. Obviously acid continues to be an issue, sulfuric acid in Kazakhstan. We don't take Russian acid. That's one of the issues with our joint venture that maybe limits it a bit. We have made a commitment to not to deal with the Russians, so that had a bit of an effect on our acid supply. As I say, we've got enough now, but the timing wasn't particularly right for our production this year, so we had to reduce it by a little bit. Complex ownership agreement, yeah we've been there for 25 years. We've got a bunch of complex ownership agreements with them. We'll sort it out. We're in discussions with them now. Our team is talking about what the production allocation is for this year and going forward and we should be able to recoup there. But don't forget, it's 10% I think of our production. So, it's important to us. We're happy to be there, we're happy to be partners with Kazatomprom, but in the bigger ticket Cameco Westinghouse, it's a smaller portion of our business.
Alexander Pearce: Great, thank you.
Tim Gitzel: Thank you, Alex.
Operator: The next question is from Lawson Winder with Bank of America Securities. Please go ahead.
Lawson Winder: Good morning, thank you operator. Hello Tim and Grant! Nice to hear from you. Thank you for the update as always. I just wanted to get your thoughts on, views on uranium pricing, and in particular just referring to the late summer uranium price survey from UXC. And so I mean, as it often does, it indicated a pretty significant disconnect in pricing in terms of where utilities think pricing will go and where suppliers think pricing will go, both in the year end and longer term. And it seems that the utilities in fact believe in that lower pricing, just given the lower contracting volumes this year. They've been softer than in the past several years. So it does seem that the utilities are in fact waiting out for lower pricing beyond potentially just attempting to aid in their own negotiations. Are utilities making a mistake that might cost them more in the future and then, do you think there's a logical explanation for why they might be seeing a different supply-demand situation or at least perceiving it differently? And then historically, what has typically led to the breaking of these type of stalemates?
Tim Gitzel: I'll just get our marketing guru, Grant, to answer that remark. Grant?
Lawson Winder: Yeah, a lot of questions there jammed into your one question Lawson. So let me just make a couple of observations. First of all, with all due respect to our friends at UXC, I deeply, deeply discount that survey, because no surprise, that survey says those who buy uranium want lower prices and those who sell it want higher prices. I don't think empirically that is useful in any way, shape or form or should really inform anybody's opinion. What we should always do is look at the fundamentals in this market. The fundamentals in this market are very clear and they are very positive. The long-term price is up again. $81.50 now in U.S. dollar terms and we're not even remotely close to replacement rate contracting. This is a market that has never seen these kind of uranium prices with so little demand in the market. That's a pretty positive signal. And the structural gap between uranium supply and uranium demand does not require a Russian ban. On a global basis, there is not enough primary supply capacity and secondary supply availability to meet the demand as it's growing in a very certain and predictable way. That is ultimately what's going to drive prices, and when you see a structural gap, that's a one-way trade. We need higher prices to incent the kind of investment, to generate the primary production that's going to fill that gap. So that's very clear. That's unavoidable. How do we get there? Well, we get there through term demand. And when we think about that term demand, it's always important to remember that utilities decide when they are bringing their term demand to the market, and that term demand is actually set by a number of things. There are some utilities that are contracting. Let's not forget this. Let's not traffic in the assumption that there's no term demand happening. At the end of the third quarter, there was just over 50 million pounds contracted. But within three weeks, another 40 million pounds of uranium was reported as contracted. We've been saying there's a lot of off-market activity going on. And in three weeks, we added another 40 million pounds of long-term contracting in the industry. There's a lot of off-market activity going on. So there are utilities who know they need future supply, and they are working accordingly. But there are some uncertainties that are holding that up. And a big uncertainty there is not whether the Russian ban is going to stay or not. That's a legislative ban. It would require legislative action to overturn. The question is, how easy will waivers be between now and 2028? And that's driving some uncertainty in the market, or let's call it some pause from some of the fuel buyers. But when you step back and look at the overall dynamics, and you see that market-related contracts are being priced at $70, low-$70 escalated floors, $130 escalated ceilings. If you pick the midpoint between those floors and ceilings, that's three-digit uranium. That's $100 uranium. Market-related contracts are signaling that utilities understand the uranium price is going up from the long-term price of $81.50, because structurally it has to in order to get the supply there. So that survey that you referenced at the beginning doesn't capture any of these facts. The facts are pretty clear, and the facts are optimistic – sorry, the facts are very positive, and Cameco's incredibly well-positioned for these facts.
Lawson Winder: Yeah, thank you very much. And just as a follow-up, cost is often cited as a supporter to pricing, and pricing is quite a bit above the cost curve. But I mean, what we've been seeing with some of the other miners that are producing other commodities is that the cost inflation has become a theme again after disappearing for no less than just a couple of quarters. What are you guys seeing in terms of cost inflation? I mean, we obviously know that Inkai has experienced significant cost inflation as a result of the new royalty. But just in Canada, are you seeing any cost inflation that would lead you to believe that the curve is moving up, or are you seeing it in any other countries that would lead you to believe that cost curve is moving higher?
Grant Isaac: Yeah, certainly the cost curve has been moving higher right across the resource space. There's no doubt about that, and Cameco has not been immune to that, whether it's purchasing reagents and energy on North American markets. We've seen some cost increases on the labor side, for example, in our market. But I want to go back to something that Tim highlighted, which is the amped up, the automation and digitization project we did at MacArthur Key, perfectly timed to bend the cost curve ahead of this inflation. So those investments are paying off. They are paying off in lower costs relative to where those assets were running in 2017 before we shut them down, and lower costs relative to where inflation would have otherwise taken them, and then of course, additional production on the same asset base. So this is a really strong story about, we bent the cost curve, and actually got more production out of assets at a time when supply chains had become difficult. The other factor that's influencing the global cost curve loss is that in a bifurcated market, we simply need more Western sources of uranium, conversion and enrichment. And Western sources have historically been more expensive than non-Western sources, primarily because non-Western sources, often from state-owned enterprises that don't have a commercial objective, never really adhere to any sort of production economics in their pricing. You bifurcate the market. You have Western demand chasing smaller Western supply. You need production economic pricing. That's why there's been upward pressure on enrichment, massive upward pressure on conversion. And as I said earlier, that demand has not yet hit uranium in a full way, but it’s coming.
Lawson Winder: Okay, thank you very much.
Tim Gitzel: Thanks Lawson for your questions.
Operator: The next question is from Craig Hutchison with TD Cowen. Please go ahead.
Craig Hutchison: Good morning. Thanks for taking my question. Q4 is setting up to be quite a strong quarter at Westinghouse based on your updated guides this morning. Can you just provide some context on the seasonality? I mean, why Q4 is going to be so strong? And is that a seasonality factor and then something we should expect in future years going forward? Thanks.
Tim Gitzel: Great, thanks for the question. I'm going to ask Heidi Shockey to answer that one. Heidi?
Heidi Shockey: Hi there Craig. It is true there is some seasonality with Westinghouse. Throughout the year we've said that the second half of the year is going to be stronger than the first half. First of all, because through the acquisition we had to mark a lot of our assets and inventory to fair value. So we did sell that inventory in the first half, so that's unique to this year and won't carry on. But there is seasonality to their business. They have two outage seasons typically, one in the spring and one in the fall. And the one in the fall kind of starts end of August and goes until November. So it is primarily in the fourth quarter. We see a lot of more work and higher margin work in that period.
Craig Hutchison: Okay, great. I just have a follow-up question. On the sales forecast, again it seems like Q4 is going to be quite strong. Just can you talk to some of the factors that have pushed sales into the last quarter of the year? Thanks.
Grant Isaac: Yeah Craig, great question. So along with Westinghouse having a strong fourth quarter, Cameco as you'll recall from our disclosure in Q4, when we put out our outlook, we were indicating stronger sales volumes in the second half of the year. And if you look at deliveries year-to-date versus our outlook table which hasn't changed, somewhere between 11 million pounds and 13 million pounds of uranium remains to be sold in Q4 and these are committed sales that we have to deliver into. So you got to go back to 2018 or 2019 to see kind of back-end deliveries loaded that way. Just it's a function of when utilities call for deliveries and it just happened to be a strong Q4 for us in the uranium segment, to go along with a strong Q4 in Westinghouse. Which is why it's so important to always remind people, whenever you're looking at our quarterly results, you should also simultaneously look at our outlook table and our guidance, and ask yourself, has anything changed materially there? And if it hasn't, that should help you put the quarter in proper context. So strong uranium segment in Q4, strong Westinghouse in Q4.
Craig Hutchison: Thanks guys.
Tim Gitzel: Thanks Craig.
Operator: The next question is from Mohamed Sidibé with National Bank Financial. Please go ahead.
Mohamed Sidibé: Hi Tim and Grant. Thanks for taking my question. I just had a question on I guess the delayed shipment to be received from Inkai and how we should think about that in relationship with maybe your inventory balance and the implied [inaudible].
Grant Isaac: Yeah, the delays in shipping from Inkai, I'll just go back and remind everybody. We made a decision when the Russians invaded Ukraine, that we would not utilize the normal transportation channels to get material out of Central Asia. Normal transportation channels involved using Russian rails and Russian ports. What we wanted to do, was take advantage of the so-called Trans-Caspian Corridor route, which Kazatomprom had used before and had said was very reliable and very predictable. And I know – all we've discovered in the last couple years is it's neither reliable nor predictable. It just, it takes time to get material assembled in Kazakhstan across the Caspian, the relevant permits through Azerbaijan and Georgia, into the Black Sea and out the Bosphorus to make its way to our Blind River refinery. So the good news is that corridor works, but it doesn't work in the predictable way the old Russian route worked, and that just leads to some timing issues with respect to deliveries. But make no mistake, those deliveries eventually show up and the economic benefit of those deliveries hits our results. It just didn't hit in Q3 as Heidi referred to earlier. So we're just continuing to work that route. We're committed to that route, because we are not going to use the Russian route. So that's how you need to think about those delays. We eventually get the material, and in the meantime we use multiple sources, inventory, long-term purchases, perhaps some market purchases to always meet our sales commitments.
Mohamed Sidibé: Thanks a lot Grant for that. And then just another question for me on the fuel services segment. So great quarter in terms of sales and improvement quarter-to-quarter there. But on the cost fronts, costs are largely flat. Could you maybe give us someone color on what could drive costs, maybe more towards your guided costs for 2024 into Q4?
Heidi Shockey: Yeah, costs in the services segment can vary quite a bit. We have a number of different products in that segment, and they are quite different in terms of cost structure. So from quarter-to-quarter, it will vary based on the volume of sales of the various products. This year we're seeing a little bit higher cost than in the UF6 segment, because of the lower production than we forecast, and of course some inflationary pressures. But it's likely just in the quarter, a difference between the mix of the products that we sold.
Mohamed Sidibé: Thank you.
Tim Gitzel: Thank you, Mohamed.
Operator: The next question is from Bryce Adams with CIBC (TSX:CM). Please go ahead.
Bryce Adams: Thank you. Good morning all. Building on Lawson's question and Grant, you touched on it for a second. But with regard to long-term contracting, can you provide any color on where negotiations for floor and ceiling prices are? What levels are those at generally? How does that compare to negotiations earlier in the year, say in the summer? Just generally, how are those floors and ceilings evolving? Thank you kindly.
A - Grant Isaac: Yeah, happy to do that, Bryce. I'm actually going to expand a little bit and just talk about the connective tissue that can sometimes happen between the spot market and the term market, because it helps explain, I think, in part why there's been a bit of a slowdown in term contracting. So, if you think about the spot market, it's always important to remember, it's small, it's discretionary, it's not fundamental, and it's low quality demand. But it does create a reference point if you will, for fuel buyers. So, when we're negotiating a long-term contract and we want it to be market-related, they almost invariably have a floor and ceiling conversation around them. Floor is today at $70, a little over $70 escalated, ceiling is at $130 escalated. When you see the spot market soften like it's done, and who are the culprits there? Well, it's anybody who produces material and doesn't have a home for it. Those are the culprits for why the spot market is softening. When the spot market softens and comes off like it has, you know $10, utilities are inclined to believe that that should mean a one-for-one reduction in floors and ceilings, right. So, if the spot market has come off $10, then shouldn't floors fall by $10? Shouldn't ceilings fall by $10? And because we're strategic and because we're patient, for us it's always about pricing appropriately for the future. And our message is, the spot market coming off because somebody has sold 50,000 pounds of material in a clumsy way into a thinly traded market, has nothing to do with the appropriate price of uranium two years from now and out and beyond. So it's got nothing to do with where floors and ceilings should be. And when we see that kind of narrative come through the market, we at Cameco will step back and say, okay, well, we'll just – we’ll wait until a better sense returns to the market. So, right now, it's not that the term demand is strictly in the hands of the utilities. There's a counterparty, and that counterparty is a producer who might not be satisfied with a conversation that floors should fall and ceilings should fall, and we would be one of those producers. So we're being very disciplined, very patient in our contracting. That's the connective tissue between long-term market and the spot market, and we're just trying to break that connection in our contracting. What somebody is doing in a clumsy way in the spot market today with a small amount of pounds has nothing to do with the appropriate future price of uranium, and we're just in a position where we can hold out for that, to send that signal accordingly.
Bryce Adams: Okay. So sticking with the $70, $130 escalator ranges, that seems to be the default at the minute, but stay tuned. That could scale up in the next six months, you think?
Grant Isaac: Yeah. If you look at the fundamentals and you look at that long-term price that continues to rise on really small volumes, and then you look at the global cost curve and where it needs to be, to make sure that the supply is there to meet the demand, it is suggestive that higher prices are required. Higher prices are required to incent the primary supply, that's needed not just to replace primary mine depletion, but to replace secondary supply which has dwindled dramatically, and then to grow with a market. That is all very suggestive that this uranium price has yet to see the kind of move that enrichment and conversion has made, simply because the enrichment and conversion demand hasn't fully made its way into uranium yet.
Bryce Adams: Awesome. Thanks Grant.
Tim Gitzel: Thanks Bryce.
Operator: The next question is from Brian MacArthur with Raymond (NS:RYMD) James. Please go ahead.
Brian MacArthur: Good morning, and thank you for taking my question. I just want to go back to the 11 million pounds to 13 million pounds in the fourth quarter on the uranium site. Can I assume that when you do that the assumption is any utilities that had upward, flexibility in their volumes, in those old contracts that are coming due at that time? That's all reflected in there, i.e., you couldn't end up with 14 million pounds in the fourth quarter or is there still flex in the book that you are not assuming that might come through, given where long-term prices are.
Tim Gitzel: Yeah Brian, it's a great question, getting into a lot of detail. But normally there wouldn't be that kind of upward surprise if you will. Simply because, recall that the typical delivery commitment requires a non-binding notice of delivery say 12 months out from when the utility wants it, may be convert it to a binding notice of delivery six months out. So everything's pretty much baked in the cake now. If they wanted to flex up, they've already sent us that binding notice. There really aren't those kind of surprise opportunities left.
Brian MacArthur: And just as you write new contracts, is that the same way they're still set up? You sort of have a six month notice in a year or that term changing as part of the negotiation strategy as we write new contracts, as well as price and all these for as soon as we talk, but our volume options changing in the market.
Grant Isaac: Oh, many factors are changing. As the market tightens, as you look out into the future in which utilities are looking for material and there's only a couple of producers that are going to have projects and production out into that window, leverage is shifting over to the seller. And as the leverage shifts over to the seller, it's reflected in appropriate pricing mechanisms, higher floors, higher ceilings, better escalators on the floors and ceilings. It translates into lower flex in a contract. We just, we don't have to be offering as much flex as the market tightens. It translates into different requirements for notice period, so that we have more time to plan the production. So we just – we save our contracting for when we're in an up-cycle precisely for these reasons, because it brings more leverage to us, more certainty and predictability to our account, that's why we position when we do. And when the market isn't offering that kind of demand, we leave our production in the ground.
Brian MacArthur: Great. Thanks very much for the detail.
Tim Gitzel: Thank you, Brian
Operator: And our final questions from Gordon Johnson with GLJ Research. Please go ahead.
Gordon Johnson: Hey guys, thanks for taking the question. Just a quick one, typically there's some seasonality with uranium prices and typically from what we've seen, prices have been weak in July, August, September and then in October, November, December they get stronger. Wanted to see if you guys are seeing some of that seasonality, now clearly prices have been weak recently. And also can you juxtapose that against the strength we've seen in enrichment prices and why that may be foretelling or not foretelling with respect to what to expect the uranium price is moving forward. Thanks.
Tim Gitzel: Yeah, a couple of good questions there. If you think about seasonality, I mean there's a few factors going on there. You've heard us say before that actually the uranium calendar or the nuclear fuel cycle calendar starts in September and actually ends the following spring. So it's not based upon a January to December calendar. So typically the World Nuclear Association Conference every September is kind of a kickoff to a contracting year. And then that leads to having all the customers and all the suppliers in the same place at the same time, starts to kick off a lot of contracts. That contracting carries on through the remainder of the year. That is what typically makes the year end a little stronger from pricing. It continues into the spring and then in the past the fuel buyers have kind of gone away for a little bit of a break, and we usually saw some softness from a demand point of view in the summer. So that, the seasonality is just reflected by the fact that the nuclear calendar is really September to the end of August as opposed to January to December. But don't forget the effect of month end games that happens on the uranium price. It comes as a surprise – sorry, sometimes it's a head-scratcher for us, for as long as we've been in our business. That whether it's the price reporters or the equity markets looking at uranium, they are surprised that some people show up with very small volumes and dump them into the market right at the end of every month and yet we don't understand why they're surprised. We know exactly what's going on there. Folks are positioning ahead of an off-take, or they are a trader that's moving material that they can't carry over a reporting period. Month ends tend to be soft, last month end was soft, the month end before that was soft for precisely this reason. So you have the normal seasonality, overlaid by a spot market that has a lot of short-termism in it, but we can always look through that. Fundamentally this market needs more supply, that supply needs to be incented and higher prices are the only thing that's going to cure that structural gap.
Gordon Johnson: Thanks for that. And you kind of answered my next question which was coming out of the, I guess the World Nuclear Symposium in London September 4th through 6th. Have you seen stronger contracts, etc. But I guess can you address that, are you seeing stronger prices in the contracts? Maybe you already answered that, but if you could address that. And then another question, maybe a weak one, but I like to hear from you guys what do you see as the biggest near-term headwinds and tailwinds? Thanks for the questions.
Grant Isaac: Yeah, I'll just finish on the contract. Certainly coming out of the WNA there, and we had said this, we were on a podcast and we said there's a lot of off-market activity going on. No surprise, in the last three weeks, the trade press has posted another 40 million pounds of long-term contracts, kind of reflecting the quality and depth of those off-market conversations. The upward trend in pricing, stalled a little bit with – sorry, with floors and ceilings around market related contracts, stalled a little bit for the reasons I talked about earlier, which is as the spot price softens, because somebody out there is dumping material into a thinly traded market, it tends to create a situation where fuel buyers expect the floor and ceiling prices for future deliveries to fall accordingly, and we just don't play that game. We'll step back from the market and be patient and be disciplined, because a spot market that's softening a little bit today has nothing to do with appropriate prices out into the future. So the symposium was strong, a lot of off-market activity. That proof has now worked its way through the market.
Gordon Johnson: Thanks for the questions guys.
Tim Gitzel: Thanks Gordon.
Operator: That's all the time we have for the question-and-answer session today. I'd like to turn the conference back over to Tim Gitzel for closing remarks.
Tim Gitzel: Well, thank you very much operator and thanks to everyone who joined today. As Cory noted at the start of the intro, if you have any detailed follow-up questions related to the third quarter results or any questions that we didn't get a chance to answer on today's call, please send those in or call us, and we're happy to address those directly. At Cameco, we are a responsible commercial supplier with a strong balance sheet, long-lived Tier 1 assets and a proven operating track record. We're invested across the nuclear fuel and reactor life cycles and believe we have the right strategy to achieve our vision of energizing a clean air world and we will do so in a manner that reflects our values. We're committed to addressing the risks and advancing the opportunities that we believe will make our business sustainable over the long term. So with that, thanks again for joining us today. Stay safe and healthy and have a great day!
Operator: This brings to a close, today's conference call. You may disconnect your lines. Thank you for participating and have a pleasant day!
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