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spk05: and welcome to the Imperial Oil Second Quarter 24 Earnings Call. Today's conference is being recorded. At this time, I would like to turn the conference over to Peter Shaw, Vice President of Investor Relations. Please go ahead.
spk02: Good morning, everyone. Welcome to our Second Quarter Earnings Conference Call. I am joined this morning by Imperial's Senior Management Team, including Brad Corson, Chairman, President, and CEO of Dan Lyons, Senior Vice President, Finance and Administration. Sherry Evers, Senior Vice President of Sustainability, Commercial Development and Product Solutions. And Cheryl Gomez-Smith, Senior Vice President of the Upstream. Today's comments include reference to non-GAAP financial measures. The definitions and reconciliations of these measures can be found in attachment six of our most recent press release and are available on our website with a link to today's conference call. Today's comments may also contain forward-looking information. Any forward-looking information is not a guarantee of future performance and actual performance, and operating results can vary materially depending on a number of factors and assumptions. Forward-looking information and the risk factors and assumptions are described in further detail on our second quarter earnings release that we issued this morning, as well as our most recent Form 10-K. All these documents are available on CDAR+, EDGAR, and our website, so I would ask that you refer to those. Brad is going to start with some opening remarks and then hand it over to Dan, who is going to provide a financial update, and then Brad will provide operations update. Once that is done, we will follow up the Q&A session. So with that, I will turn it over to Brad for his opening remarks.
spk12: Thank you, Peter. Good morning, everybody, and welcome to our second quarter earnings call. I hope everyone is doing well. I wanted to start today's call by taking a moment to talk about the serious wildfire situation that has occurred across Western Canada over the past few weeks. We are deeply thankful for the courageous work of the emergency services as they battle the fires in very difficult conditions to keep our community safe. Our thoughts are with the community of Jasper and others who have been tragically impacted by the destruction of the devastating fires and now as the communities work to rebuild. There have been large fires in the Fort McMurray region near our Curl operations and to a lesser extent around Cold Lake. The teams at our operations have been working closely with local and provincial agencies to ensure we're taking necessary precautions to protect our people and our assets. And fortunately, to date, there have been no impacts to our production and the situation has improved over the past few days. And of course, it's a situation that we will continue to closely monitor and take appropriate actions. Now, turning to our performance over the quarter, our upstream saw record production coupled with stronger price realizations due to the combined benefit of strengthening WTI prices and the tightening of WCS crude differential. We were pleased to see the successful startup of TMX in May, bringing additional egress capacity for Western Canadian Crudes, which has resulted in structural tightening of the differential, reduced price volatility, and a net benefit to Imperial. Our downstream business also performed well over the quarter and contributed very solid earnings despite significant turnaround activity. and some softening of refinery crack spreads. The downstream continues to realize the structural benefits of the Canadian market, including advantaged feedstocks and import parity pricing. So now let's review the second quarter results. I'm very pleased to report a strong second quarter with earnings per share up over 80% year over year. These results were underpinned by strong operations that included the safe and successful execution of several major planned turnaround activities across our integrated portfolio. And while we still have some scheduled turnaround work ahead, we're well positioned for a strong second half of the year. Earnings for the quarter were $1,133,000,000 with cash from operating activities of $1,508,000,000 when excluding the impact of working capital. I'm very pleased by the strong financial results we achieved, especially from a quarter which included significant planned turnarounds both in the upstream and downstream. In the upstream, we achieved total production of 404,000 gross oil equivalent barrels per day in the second quarter. This marks the highest ever second quarter production over the past 30 years when adjusting for the sale of XTO in 2022. The results were underpinned by strong and reliable operations across all of our assets and successful turnaround execution at Curl and Syncrude. Curl had another fantastic quarter and matched the assets record for highest second quarter production. This result contributed to achieving the highest first-half production in the asset's history. And you may recall this follows a record second half in 2023. Coal Lake also saw a strong second quarter, including first production from our Grand Rapids Phase I project, the industry's first solvent-assisted SAG-D operation, which we will discuss in more detail shortly. In the downstream, we continue to see strong operating performance as well. Refinery throughput averaged 387,000 barrels per day, which equates to a refinery utilization in the quarter of 89% and includes the successful month-long turnarounds at both Sarnia and Strathcona. Overall, we feel very positive about the strong first half of the year and are well-positioned to meet our annual guidance. we continue to deliver significant value to our shareholders through our reliable and growing dividend and share repurchase programs. And consistent with our commitment to return surplus cash to shareholders, we announced this morning our plans to accelerate repurchases under the normal course issuer bid with a target to complete the program prior to the end of this year. With that, I'll pass things over to Dan to discuss our financial results in more detail.
spk04: Thanks, Brad. Starting with financial results for the second quarter, we recorded net income of $1,133,000,000, an increase of $458 million from the second quarter of 2023, primarily reflecting higher realizations and volumes in the upstream and lower turnaround impacts in the downstream. Looking sequentially, Our second quarter net income is down $62 million from the first quarter of 2024, reflecting lower margins in the downstream and lower volumes in the upstream, partly offset by higher realizations in the upstream. Now, looking at each business line, upstream earnings of $799 million are up $241 million from the first quarter, driven primarily by higher realizations, partly offset by lower volumes associated with a high level of turnaround activity. Downstream earnings of $294 million are down $337 million from the first quarter, mainly reflecting lower refining margins and turnaround impacts. Finally, our chemicals business generated earnings of $65 million, up $8 million from the first quarter, reflecting higher volumes. Moving on to cash flow. In the second quarter, we generated about $1.6 billion in cash flows from operating activities. Excluding working capital effects of $121 million, cash flows from operating activities for the second quarter were about $1.5 billion, up about $400 million from the second quarter of 2023 in line with earnings. We ended the quarter with just over $2 billion of cash on hand. Discussing CapEx, capital expenditures totaled $462 million in the second quarter, down $31 million from the second quarter of 2023. In the upstream, second quarter spending focused on smaller projects to sustain and grow production at Curl, Syncrude, and Cold Lake, as well as progressing the In-Pit Tailings Project at Curl and the SA SAG-D Grand Rapids Project at Cold Lake. In the downstream, second quarter spending mainly included progressing our renewable diesel project at Strathcona. Year-to-date capital expenditures totaled $958 million, which is consistent with 2023 year-to-date spend. Our full-year guidance remains $1.7 billion. Shifting to shareholder distributions, In the second quarter of 2024, we paid $321 million in dividends. On June 24th, we mentioned the renewal of our normal course issuer bid, which allows us to purchase up to 5% of our outstanding common shares over the following 12 months. We started purchasing shares ratably in July, but as Brad mentioned, we plan to accelerate our purchases and complete the program prior to year end in line with our longstanding practice of returning surplus cash to shareholders. Lastly, this morning, we announced the third quarter dividend of 60 cents per share in line with our second quarter dividend. Now I'll turn it back to Brad to discuss our operational performance.
spk12: Thanks, Stan. So now I'll cover our operating results for the quarter. Upstream production for the quarter averaged 404,000 oil equivalent barrels per day, which is down 17,000 barrels per day versus the first quarter and up 41,000 barrels per day versus the second quarter of 2023. While the second quarter typically has higher levels of planned maintenance activity affecting the sequential comparison, I'm very pleased to see a greater than 10% increase in quarterly production year over year and the achievement of the highest second quarter production in over 30 years when adjusting for the sale of XTO. So now I'd like to move on and talk specifically about Curl. Curl's production in the second quarter averaged 255,000 barrels per day gross, which was down 22,000 barrels per day versus the first quarter and up 38,000 barrels per day from the second quarter of 2023. As I mentioned earlier, this matched the best second quarter production ever achieved at Curl and resulted in record first half production of 266,000 barrels per day. And these record first half results follow a record second half of 2023. which further reinforces our confidence in the production guidance we set for Curl. During last quarter's call, I highlighted that the team was hard at work optimizing the schedule and scope of the annual turnaround with the goal of continuing to minimize downtime and cost. I'm very pleased to share that the team delivered on this. The planned turnaround work was completed in under 20 days for the first time in the asset's history. and at a cost below our guidance as well. We've talked extensively about the step change improvement we made in 2021 when we moved from two turnarounds per year to one. Looking more closely at the number of days required for the turnaround activity, at that time we were averaging approximately 70 days per year with two turnarounds. We have now reduced that duration by more than 70% with this year's results. And while we are thrilled with this important achievement, the team is already looking ahead for additional opportunities to reduce turnaround durations and costs even further. And turning to costs, Curl's unit cash operating costs in the quarter were $22.12 U.S. per barrel. While we saw an increase versus the first quarter due primarily to the planned turnaround costs, which we generally expense, we also saw a decrease of about $6 U.S. per barrel compared to the second quarter of 2023, which reflects our focus on cost reductions, including the improvements to our planned turnarounds and reliability. This second quarter performance is also contributing to our year-to-date unit cash costs of $21.45 U.S. per barrel, a $5 U.S. per barrel decrease versus the first half of 2023. With the turnaround behind us now and our expectation for higher volumes in the second half of the year, we expect to make further progress on unit costs towards our $20 U.S. per barrel or below target. Overall, Curl continues to deliver great results, and with a turnaround in the rearview mirror, it is well positioned for a strong second half. And now turning to Cold Lake. Cold Lake production for the second quarter averaged 147,000 barrels per day, which was up 5,000 barrels per day versus the first quarter, and up 15,000 barrels per day versus the second quarter of 2023. You may recall that we went through an extended period of lower production in 2023 due to production and steam cycle timing. So I'm very pleased to see this strong performance so far this year, and we are squarely on track to meet our annual guidance. This strong production, along with lower energy costs, resulted in unit cash costs of $14.30 US per barrel, which is a decrease of over $3 U.S. per barrel compared to last year. And this includes the impacts of Grand Rapids Phase I, which achieved first oil in May and contributed about 3,000 barrels per day to our second quarter results. Grand Rapids continues to ramp up with the pumps installed on the majority of well pairs, and the remaining pumps are on track to be installed over the next several weeks. In June, Grand Rapids achieved production of about 8,000 barrels per day and is currently producing 10,000 to 12,000 barrels per day as we just completed the month of July. On-site reservoir performance continues to be monitored and is aligned with our expectations as we ramp up production and solvent injection. We are well on our way to reaching the expected 15,000 barrels per day of efficient lower unit cash cost barrels as we complete this important step in our strategy to transform Cold Lake. We expect phase one alone will lower Cold Lake's unit costs by around $1 US per barrel. I'm very proud of the work the project team has done to accelerate this project by a year. and deliver industry first ever SA SAGD development. I also wanted to take a moment to provide a brief update on our Lemming redevelopment project, which is another key project for us at Coal Lake. The focus for this year continues to be on facility construction and well completions. During the quarter, fabrication started on various units as civil work continued on site with installation expected in the coming weeks. We are progressing on plan for startup in 2025 with the project expected to average about 9,000 barrels per day of production at peak. I would also like to remind everyone that Cold Lake has just started its planned turnaround at Masqua and will run through to mid-September with an expected volume impact of 3,000 barrels per day in 2024. And now a few comments on Syncrude. Imperial's share of Syncrude production for the quarter averaged 66,000 barrels per day, which was down 7,000 barrels per day versus the first quarter, and flat versus the second quarter of 2023. During the quarter, Syncrude completed its two-month-long coker turnaround ahead of schedule and is expected to start a hydro-treater turnaround at the end of the third quarter. During the quarter, Syncrude leveraged the bidirectional function of the interconnect pipeline to export about 2,000 barrels per day, our share, of bitumen to maximize mine production during the coker turnaround. Once the turnaround was completed, Syncrude reversed the pipeline flow in order to import bitumen and maintain high upgrader utilization rates, helping to produce about 5,000 barrels per day, our share of incremental Syncrude Suite premium. The interconnect pipeline is an important tool that provides optionality, ensuring the team is able to maximize both mine productivity while also maintaining high upgrader utilization rates. So now let's move on and talk about the downstream, which is another positive story. In the second quarter, we refined an average of 387,000 barrels per day, resulting in a utilization of 89%. This was down 20,000 barrels per day versus the first quarter due to month-long turnarounds at both Stracona and Sarnia, and down slightly by 1,000 barrels per day versus the second quarter of 2023. I'm pleased to highlight that Nana Coke achieved record April throughput, which contributed to its highest ever first half throughput record. And from a financial perspective, our structurally advantaged downstream business remained quite profitable in the quarter, despite the significant turnaround activity and narrower crude differentials that affected margin capture. Canadian crack spreads have softened in 2024. However, they do remain above the average of the last five years. So it's important to keep that in context. In the third quarter, there's a planned turnaround at our Nanticoke refinery that is scheduled to start in early September and finish in late October. Strathcona will also be executing its second smaller turnaround which will include work to enable the co-processing of vegetable oils alongside conventional feedstock. We continue to progress the construction of Canada's largest renewable diesel facility at our Strathcona refinery that will add 20,000 barrels a day of throughput capacity when completed. Modules continue to arrive on site and I'm pleased with the progress of the construction, which will continue into next year. The Strathcona Renewable Diesel Project is a highly attractive and strategic opportunity within our portfolio and one that leverages the numerous competitive advantages we have, including our location, scale, expertise and technology. Another exciting milestone in the quarter was the completion of the Calgary Renewable Diesel Blending and offloading distribution terminal, which will further develop our capabilities to continue to meet our customers' demands for lower emission fuel options. Petroleum product sales in the quarter were 470,000 barrels per day, which is up 20,000 barrels per day versus the first quarter and down 5,000 barrels per day versus the second quarter of 2023. We continue to see steady, refined product demand with gasoline, diesel, and jet demand generally consistent with prior year. During the quarter, we completed the proactive replacement of a segment of the Winnipeg products pipeline after a routine inspection found riverbank erosion was causing stress on the pipelines. The maintenance work required several weeks of horizontal drilling under the Red River with the first of two pipelines being returned to service in May and the second pipeline returning to service in late June. We work closely with impacted neighbors and communities as well as the Manitoba government and regulators and also customers throughout this process to ensure they had the latest information on the status of the maintenance work. Our priority was returning the pipeline to service on time and in the safest, most environmentally responsible way. And we appreciate everyone's patience and understanding as we completed this important work. I also want to thank our team for working nonstop since March to complete the work as we committed and minimize the disruption to our customers and communities. And turning now to chemicals, earnings in the quarter were $65 million, which was up $8 million versus the first quarter and down $6 million versus the second quarter in 2023. The higher earnings versus the first quarter were the result of strong polyethylene sales. And before I wrap up, I'd also like to highlight the ongoing work that the Pathways Alliance is progressing. Pathways continues to make progress on the engineering and design of the proposed carbon capture and storage pipeline project, with regulatory filings continuing through the second quarter. And in parallel, we continue to have constructive discussions with the federal and provincial governments in order to finalize the fiscal frameworks necessary for these important projects to proceed timely. And so to wrap up, this was a really strong quarter for us, underpinned by reliable operating performance and successful execution of significant planned maintenance at four of our major facilities. I want to recognize the dedication and hard work by all our teams that delivered these exceptional results. I'm also very excited to see the production growth from further records at Curl and the ramp-up of Grand Rapids and the continued construction progress of our Strattona Renewable Diesel Project. Both Grand Rapids and Strathcona renewable diesel projects are an important part of our growth plans to meet the energy needs of society while generating value for our shareholders' emissions. As I look ahead to the second half of the year, we're very focused on delivering a strong finish, and I'm confident in our ability to achieve our guidance for 2024. We remain committed to returning surplus cash to our shareholders. And as we announced this morning, we are accelerating our recently renewed normal course issuers bid with the intent of completing it prior to year end. As always, I'd like to thank you once again for your continued interest and support. And now we'll move to the Q&A session. So I'll pass it back to Peter. Thank you, Brad.
spk02: As always, we'd appreciate it if you could limit yourself to one question plus one follow-up so that we can get to as many questions as possible. And with that, operator, could you please open up the phone line for questions?
spk05: Thank you. If you are dialed in via the telephone and would like to ask a question, please signal by pressing star 1 on your telephone keypad. If you are using a speakerphone, please make sure your mute function is turned off to allow your signal to reach your equipment. Again, please press star 1 to ask a question. Your first question comes from Greg Party with RBC Capital Markets. Please go ahead.
spk09: Thanks. Yeah, thank you. And, Brad, thanks for the detailed rundown. Wanted to stay with... or just dig in rather into maybe the Grand Rapids and in situ in general. But the technical question, I guess, in the Grand Rapids is what kind of recovery rate are you targeting from the reservoir with respect to just like the percentage of whatever you're bringing back? And then how much, what degree of recycling of the solvent is there? I'm just trying to get a better understanding as to how much of a closed system this is.
spk12: Yeah, thanks for that question, Greg, and good to hear from you. I don't necessarily have those specific details on the reservoir performance from a plan basis. What I will tell you, though, is based on the early data we've gathered, you know, as we just started this production up in May, And as I just commented on, we saw 3,000 barrels per day average for the quarter, and then 8,000 barrels per day in June, and now we're seeing 10,000 to 12,000 barrels per day. All of that is reflective of performance, very consistent with our planning basis. We are quite pleased with how the ramp up has gone so far, recognizing we're at this 10,000 to 12,000 barrel a day range. And we still have multiple pumps still to install, which allow us to get all the wells in a production state, as well as we're just in the process of ramping up diluent injection now as well. We're still in, you know, I would say fairly early stages, but very encouraged by the results we're seeing. And so, you know, I think we'll have more data for you in, you know, in the coming quarter, and that may be a good time to talk more about kind of some of the details of the reservoir.
spk09: Okay, understood. No, thanks for that. related but perhaps just a broader question is you've got you know the um the the not a jb with suncor but i guess uh a data sharing or a collaboration going on with respect to aspen and i'm just i'm wondering how you're thinking about that partnership and then you know what the benefits are to imo yeah um well and i think what you're referring to is
spk12: the joint pursuit of the EBRT pilot that we are in kind of the process of constructing now, and that is a partnership between us and Suncor to build that pilot and operate it. And I just want to clarify The pilot for us, we believe has future applicability to Aspen. The partnership with Suncor is limited to this pilot. That partnership has nothing to do with Aspen per se. But in terms of the pilot itself, we do see it as a potential enabler of a new technology that we can apply to Aspen that will allow us to lower the capital costs, lower the operating costs because it uses significant more affluent and less steam, and also as a result then achieves much lower emissions intensity for the barrels that we would produce. Working together with Suncor allows us to expedite the progress on that pilot, allows us to jointly share in the cost of that pilot, allows us to share technology and insights, you know, that we together will result in a more successful pilot. So we feel quite good about the opportunity. We feel good about where we are progressing this pilot, and we're optimistic that it will have longer-term strategic value to us for Aspen.
spk09: Very good. Thanks very much, Brad. Thanks, Greg.
spk05: Thank you. Your next question comes from the line of Menno Halshoff with TD Cowen. Please go ahead.
spk11: Thanks, and good morning, everyone. I'll start with a follow-up on Greg's question on the Grand Rapids, which is obviously ramping up quite nicely. And I'm guessing you may not want to answer this, but what is your current thinking on the next potential growth phase in the In the Grand Rapids, in terms of timing and size, presumably the next one would be in the 15,000 barrel per day range as well, but any thoughts there would be helpful.
spk12: Yeah, thanks for the question, and again, it's exciting to talk about Grand Rapids because we've been working on this project, you know, for several years, and And then more recently, we're able to accelerate it. And now we're seeing some very good reservoir results. So all that's really exciting. And all of that will inform our future development plans. I think it's a little premature for us to talk specifically about the next phase, the next volume that would come with the next phase. But fair to say, you know, we're going to take all the data from this first phase and that will inform a longer term development strategy and you know as we firm that up uh we'll we'll certainly share that uh with the market you know in in future investor days so again premature to give any details but it's an exciting opportunity for us we do see significant running room beyond this first phase. And so now we just need to finish the startup, gather as much data as possible, and then optimize future plans accordingly. So more to come, but it's encouraging.
spk11: Yeah, thanks, Brian. Maybe just a very quick follow-up there. I think in the past you've talked about an incremental 50 to 50, I think 50 to 55,000 of potential growth there? Is that still the right sort of range?
spk12: I don't remember those comments explicitly. We definitely talked about continued growth at Coal Lake that comes both from Grand Rapids, this phase, future phases, lemming, redevelopment, and other, if you will, transformations of that portfolio from existing technologies to new solvent-based technologies. I don't recall the 50,000 number explicitly, but we do see continued growth, and I'll have to take that away and compare that to some of our long-term plans we've shared in the past.
spk11: Okay, and yeah, I was just going to assume that second question was a part of the first, but this second question is quite quick. Just on the renewable Strathcona renewable diesel facility, it sounds like based on your prepared comments, it's all on schedule, but what is your best guess on first volumes from that facility?
spk12: Yeah, thanks for the comments. Again, another exciting growth project for us. The construction at the refinery is going extremely well, and we would anticipate completing that construction by sometime in the spring of next year, and then that will allow us to move into commissioning sometime later in the second quarter, around mid-year. But equally important to keep in mind, you know, this is a complex project, and what we're focused on is the construction of the facilities at our site. We're also sourcing the feedstock. We're also working with the hydrogen supplier the timing for their facilities and availability. So we're working to bring all that together, you know, which again, we're encouraged by the progress we're making and we'll continue to coordinate with them on their timing. And we're excited to bring that product to market as soon as possible.
spk11: Appreciate the thoughts, Brad. I'll turn it back.
spk12: Thank you.
spk05: Thank you. Your next question comes from the line of Patrick O'Rourke with ATB Capital Markets.
spk13: Hey guys, good morning and thank you for taking my question. I guess my first question is with respect to Curl and going back to the 2023 investor day, the plan to sort of get to 300,000 and then alluding to potentially beyond that. With the strong performance you've had year to date here, How does that sort of place you in achieving these targets, and what are the timeframes moving forward around that?
spk12: Yeah, thanks for the question. I'm always excited to talk about Curl because it's such a positive story and a great, you know, testimony to kind of the hard work and commitment and really creativity of our operations organization. You know, the key milestone that we laid out at Investor Day was to achieve 280,000 barrels a day by this year. You know, we've represented that in guidance of 275 to 285. We feel extremely confident in our ability to achieve that based on, you know, the performance I just reported for the first half of the year. you know, including some records. I commented on the record second half of last year. So, you know, what we need to deliver, and I have confidence we will, is a second half of this year that is generally in line with the second half of last year. And if we do that, and I believe we will, that will put us at the upper end of that guidance and and very much achieving that 280,000 barrels a day. So that's the clear milestone we put out there. Then what we talked about at investor day was looking beyond 280 to what's next. And we've identified several opportunities that would allow us to achieve 300,000 barrels a day. The technical and operations teams are currently working to define those individual projects and the individual timing that would go with those. We haven't put a specific timeline out to the market yet for achieving 300 or anything beyond that. But rest assured, it's in our sights and we're working on those details and our plans are to share more of those details with you at our next investor day. So more to come there, but everything we're achieving now not only gives us confidence in 280, but gives us confidence in higher volumes for the future.
spk13: Okay, thank you. And my second question here is just with respect to the downstream unit. There's obviously been a lot of moving parts in the cracks market. You guys have shown some flexibility in the past in order to capture those moving parts or moving cracks across the product slate. If you could maybe speak to what you're seeing in the product demand market right now and what the best opportunities are for you.
spk12: Yeah, thanks for the question. And, you know, as I mentioned, you know, we're feeling quite good about our downstream business, both in terms of, you know, the successful execution of our turnarounds, but also our ability to capture an advantaged market. We're seeing... I would say stable demand across the individual product streams. And whereas in the second quarter we saw some softening of some crack spreads, what we've seen more recently now as we get into the third quarter is some strengthening, you know, driven by continued low inventory levels and products, but also several refinery outages in the U.S., both planned and unplanned. And so that is impacting inventories and supply going forward. So when you put all that together, you know, we feel quite good about you know, our position as we move into the third quarter. And obviously, there are a lot of variables, as you mentioned. But for us, you know, things are lining up in a good place for us.
spk07: Okay, thank you very much.
spk05: Our next question comes from the line of Manav Gupta with UBS.
spk01: Thank you, guys. My first question is, You reiterated your guidance for 2024. Is it safe to assume that the threat of those wildfires has come in even from where it was a week ago? And at this point, you don't expect them to have a direct impact on your operations, which is what is allowing you to reiterate your guidance for the year?
spk12: Yeah, Manav. Thanks for the comment or the question. You know, where we sit today, we feel good about the situation in terms of no impact to our production. And certainly, we hope that will continue through the rest of the summer season. What I can't predict is whether there'll be future wildfires, you know, and where those will occur or when those will occur and what risk, you know, they would present to our operation. But in terms of, you know, what we've seen so far, you know, thanks to the great work by the emergency response services, they have done a really good job in helping manage that risk for our operations. And so we would certainly hope that would continue.
spk01: Perfect. My quick follow-up here is obviously you return a lot of cash to shareholders. Sometimes it gets a little bulked up like last in 2023, a lot of it got in the second half. So if you do complete this NCIB in the next six months, does that leave the door open for a possible SIB somewhere earlier next year? Generally, you put in an SIB in the later half of the year, but if you could spread it out, of course, it will depend on the crude prices and cracks. But does it leave the room open for a possible SIB early next year?
spk12: Yeah, thanks for the question. I'll give you my view on it. Dan may want to add some other comments at the end, but, you know, as you rightly pointed out, you know, our ultimate decision is very much dependent on our surplus cash levels, and those are a function of both our operations you know which are going extremely well but also the external uh price commodity market which is outside our control we all have different views maybe on on what the second half will look like right now it it looks quite supportive um so those are important factors the other consideration is and we've talked about this in the past is the um the regulatory processes restrict us from undertaking an NCIB and an SIB at the same time. And so one of the reasons that we want to accelerate the NCIB is so that gives us flexibility for future decisions around an SIB. And so, you know, by completing this sometime in the second half of the year, you know, then that gives us flexibility for a future SIB. The other reason we do it is it allows us to return more surplus cash, you know, between now and the end of the year versus extending that NCIB into next year. So we will have the flexibility to do an SIB in the first half of the year. We could even have the flexibility to do an SIB before this year is over. But step one is we have to complete the NCIB first, and that's what we're doing. Thank you.
spk04: No, no. Well said, Brad. And look, you know, we try and, you know, the NCIB is simple, efficient. So our practice has been we kind of we do that as our first tool. But our overall our overarching goal is to return surplus cash in a timely manner. So once we exhaust that tool, we've gone to the SIB historically. And that's exactly where we are today. So we'll see what the commodity markets give us. And, you know, rest assured, our philosophy of returning surplus cash in a relatively timely manner is unchanged. And so we'll, you know, accelerate the NCIB. And as Brad pointed out, that just gives us more flexibility to do an SIB if our cash balances warrant that.
spk01: Thank you so much.
spk05: Thank you. Your next question comes from the line of Dennis Fung with CIBC World Markets.
spk08: Hi, good morning, and thanks for taking my questions. The first one, I wouldn't mind digging a little bit more. On the lemming redevelopment program, frankly, it's great to hear you're starting to move forward with the module construction at the facility. I was just hoping to understand how maybe your teams are looking at some of the other projects in the region, Mascua, Machesis, and Mahican. Do similar opportunities to redevelop those regions exist? Obviously, understanding lemming is your first and oldest facility at Cold Lake.
spk12: Yeah, thanks for the question. I mean, there's lots of considerations, you know, as we progress these sort of redevelopments. You know, it's a function of kind of the status of the reservoir, what we see as future potential or remaining potential, what's the best technology to recover that remaining potential. Is it economic to transition to a new technology today, or do we continue with the existing? But the reality is, we've been producing at Cold Lake for over 40 years now, but there is still a significant resource left to develop. And so our teams are looking at the entire resource base at Cold Lake, looking at what's the most efficient way to recover that resource and that's going to precipitate you know future redevelopment opportunities like lemon and as well as you know new opportunities like grand rapids and that's that's what the reservoir team focuses on and and you know we'll we'll be driven by the economics of of those individual um you know, opportunities. So much more to come there, but we do see future opportunities without a doubt.
spk08: Great. I appreciate that color there, Brad. My second question is a bit of a follow-up to Manav's question there, is just around, I guess, cash positions and cash levels. Obviously, understanding last year, at the end of last year, there were specifically we'll call it a lower cash position at the end of 2023. Can you talk towards some of your comfort levels around holding certain levels of cash Now that some of the, we'll call it major projects, whether it be the completion of Grand Rapids Phase 1 or kind of some of the ramp down and spending on a renewable diesel facility, and in conjunction to the stronger operational performance that you're seeing across your assets, how does that maybe speak towards your comfort levels on holding cash in aggregate? And at what levels do you feel most comfortable just looking forward?
spk04: Yeah, you're right. We had a relatively lower cash balance at the end of the year than we've had some prior years, and we felt comfortable with that balance. You know, we don't have an explicit cash target, you know, so it really, so, you know, we have, you know, borrowing capacity if we ever needed it. We have, you know, plenty of operating cash flow. So, you know, we're not looking to carry a whole lot of cash in our balance sheet. We figure investors want that back. And that's really our philosophy. And that's unchanged. So, you know, there's no magic number. You can do the math. We have X on our balance sheet. So we're going to do an SIP. But, you know, our goal is to do SIPs. when we have surplus cash and we've exhausted the NCIB to do those at a reasonable size and a reasonable timeframe. So that'll be a call we make, you know, as our cash balances progress, as the year progresses, as we get into next year. You know, sorry, I can't give you a number, but we don't really have one, but we felt comfortable with last year's balance. So maybe that's a marker for you.
spk07: Great. I appreciate that there, Dan. I'll turn it back.
spk05: Thank you. Your next question comes from the line of Neil Mehta with Goldman Sachs.
spk06: Good morning, team, and thank you for taking my questions. This is Adam Wijaya on for Neil Mehta. Wanted to start on Strathcona. Looks like a pretty good update there with the main reactor installed. Understand that first volumes from the asset are maybe a little bit more longer dated from where we are today, but more broadly, the RD margin environment looks to be a bit tougher. So I wanted to get the team's thoughts on current margins, what it's going to take to see an inflection in margins, and then maybe where you're seeing the greatest signs of demand strength as you kind of look over the next 12 to 18 months.
spk12: Yeah, thanks for the question. I think it is important to distinguish the market that we see and the economic drivers for us relative to maybe what you are seeing today. in other reasons like in the U.S. You know, for us, first of all, we continue to see this as a highly economic project, and it's underpinned by some very unique strategic synergistic kind of elements that we have available to us. We're building this renewable diesel facility integral to our Strathcona refinery, which brings significant economies of scale for us as we can leverage the infrastructure, the operation that already exists today. Secondly, we've designed this facility to process agricultural feedstocks, oils that are available in the general area. We're sourcing from, you know, crops and farms that are relatively close, so there's not significant transportation costs. And we'll be producing a product that has some other technical advantages, that it can be a drop-in fuel that has properties that allow it to be used across a wide range of temperature conditions. And so it can be blended up to a very high rate or even 100% drop-in. All that brings advantages to the product and the value of that product. And then on top of that, you know, what is also unique versus what you see in the U.S. is the regulatory environment that we have here, the clean fuels regulation, the economic support that that provides. Also in British Columbia, there's some additional regulatory incentives. So all of those things together put us in a different but much better place than what you might see in the U.S. So again, we feel quite good about it.
spk06: Got it. That's super helpful. And maybe just shifting gears over to chemicals for a moment and the margin environment, what are you seeing in your own system from a demand standpoint, specifically on margins? And then how do you think about the supply-demand landscape evolving over the next, call it, couple of years with some global supply as expected? Thank you.
spk12: Yeah, you know, we're seeing – obviously some, some strong performance out of our, our chemicals business, you know, generally, uh, flat with what we saw a year ago, um, but still quite material to us. Uh, you know, we, we've seen, uh, continued strength and demand, some strengthening of, um, of polyethylene realizations, which have been at somewhat depressed levels for a while, driven by global supply-demand fundamentals. We are seeing that strengthening as we come out of this cycle. But probably equally importantly are the strategic advantages we have of our chemicals business. recognizing it's integral to our sarnia refinery which may be somewhat analogous to what i just talked about with renewable diesel at strathcona you know the chemical plant is integral we benefit from economies of scale with sarnia access to to off gas from the refinery We have available ethylene supply to us in the region, and we produce a premium product with a unique customer base in close proximity. So we don't have significant transportation logistics to get to our customers. So again, all that leads to a strong chemicals business for us. which has demonstrated its resilience over kind of the full cycle that we see globally.
spk06: Got it. Thanks so much.
spk05: Your next question comes from the line of Doug Leggett with Wolf Research.
spk10: Hey, good morning, guys. Thanks for having me on. How are you doing, Brad? I'm doing well, Doug.
spk12: Welcome back.
spk10: Thank you. I'd love to say that garden leave is a thing. It turns out it's a nightmare, but we'll talk about that some other time. Anyway, two quick questions, if I may. I wanted to ask you, Bec, I know Carol has been kind of beaten to death for a while, but you guys have been knocking it out of the park for several years now. I want to understand what the maintenance scheduling, what role that plays in the potential, I don't want to call it debottlenecking, but the ability to enhance the long-term production capacity. We've seen, obviously, one of your competitors obviously changed their maintenance scheduling to instead of once every year, once every couple of years. What have you guys been doing there, and what role is that playing in changing the production capacity? My follow-up is a quick one for Dan. I just wonder, with everything that's going on today coming out of maintenance, Dan, where would you say your dividend break-even is today? And those are my two questions. Please go ahead.
spk12: All right. Thanks. Thanks, Doug. And I'm inferring that your question around kind of turnarounds is mainly applicable to curl. Um, and, but if not, let me know. Okay. So for curl, um, this has been a significant focus of, of ours. And I think an area that, you know, we are a leader in this space. If, if you go back, um, to 2021 at Curl. And prior to that, we were typically having two turnarounds per year, which would be one on each train. And they were roughly an average of 35 days each. So about 70 days of turnaround activities. Subsequent to that, in the 21-22 timeframe, we we're able to demonstrate to ourselves that we could shift from two turnarounds a year to one turnaround a year. And that obviously allowed us to reduce our volume impacts of turnarounds in half and also significantly reduce our cost structure at Curl. Now that we have a few years of run time on that, has proven very successful for us. And every time we do one of those turnarounds on extended interval, it further validates the decision we took and our ability to maintain the full integrity, reliability of the system, but with less downtime. And we further now have employed more technology, more opportunities to take that one turnaround per year and now shorten it to less than 20 days. And that's what I was referring to in my earlier comments about we've now achieved essentially a 19-day turnaround, which is our only turnaround for the year. And you compare that to a few years ago when we had 70 days per year. So 70 to 19, huge improvement in our overall production capability, huge improvement in our cost structure. And I would just say we're not done yet. You know, the team is actively working on further opportunities to reduce the duration of our turnarounds. And so I'm quite encouraged by that. And all that, of course, then translates to more production from Curl. It's part of our roadmap. That's got us to 280 for this year, and we expect to 300 in future years. It's allowing us to reduce our cost structure from the high 20s U.S. dollar per barrel down to a target of $20 this year, and we believe there's an opportunity to go even lower than $20. So huge value at Curl. And I think that's a great lead-in to Dan to talk about, you know, what does that mean about break-evens and dividends and all that sort of thing.
spk03: Yeah, so Doug, I heard you say dividend. What was your specific question about the dividend?
spk10: Yeah, so basically, you know, I don't know if you've got a chance to look at our reinstatement materials, but there's extraordinary correlation or market recognition of value with long-term sustainable dividend growth. on a per share basis. And you guys have, you've led, I don't want to make the pitch here, but you've led the whole industry, not just your Canadian peers, but the global majors. However, the big difference is you've still got a relatively low yield and we think a lot of firepower to sustain that dividend growth relative to peers that maybe don't have, right? So what I'm trying to figure out is where do you see your dividend break even today so that we can kind of put a hand, get a handle on what the sustainable growth capacity continues to be for Imperial. Because ultimately, that's what we think drives your share price. So I hope that's a clear enough, you know, articulation of the question.
spk04: You know, as we've said before, our break-even with sustaining capital and dividends, you know, for our last investor day, it's about $35 US WTI. And as you well stated, our philosophy is to have reliable and growing dividend. And both of those are important. We want to continue to grow it strongly as we have in the past. You know, when I got here, I think the dividend was 16 cents a share. Now it's 60 cents. So we've had some strong growth. But it's important that that growth be sustainable. And, you know, we look at the breakeven closely. We look at various scenarios. But I think, you know, and certainly we believe we have room for continued strong growth. And it goes to really what Brad was saying. How do we do that? Well, it's supported by stronger structural free cash flow. And that comes from volume growth. And that comes from lower unit op-eds, right? And we're working both of those hard. And as our plans come to fruition, that just supports further dividend growth in the future. So, you know, we had a significant increase, you know, earlier this year. And as we go through time, we'll continue to look at that in the context of our business and hope to show continued growth and, very importantly, you know, sustainable growth.
spk10: So right around $35 is the answer, Dan, for the current level?
spk04: Yeah, well, that's the most recently disclosed level in our investor day. When we do our next investor day, we'll put out the most current number. But that's a good ballpark number to work with, certainly.
spk10: Tremendous. Thanks very much indeed, guys. I appreciate you taking my questions. Thanks, Doug.
spk05: This does conclude today's question and answer session. I would now like to turn the call back to Peter Shaw for any additional or closing remarks.
spk02: Thank you. On behalf of the management team, I would like to thank everyone for joining us this morning. As always, if anyone has further questions, please don't hesitate to reach out to the investor relations team, and we'd be happy to answer those questions. And with that, we thank you very much, and we hope you enjoy the rest of your day and the weekend. Thank you.
spk05: this does conclude today's call thank you for your participation you may now disconnect
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