Good day, and thank you for standing by. Welcome to the Imperial Q3 2021 Earnings Call. [Operator Instructions]. I would now like to hand the conference over to your speaker today, Dave Hughes, Vice President of Investor Relations. Sir, please go ahead.

Thank you. Good morning, everybody. Thanks for joining us on our third quarter earnings call. I'm joined today by Brad Corson, Chairman, President and CEO and the rest of the management team, including Dan Lyons, Senior Vice President of Finance and Administration; Simon Younger, Senior Vice President of the Upstream; Sherri Evers, Vice President of Commercial and Corporate Development; and John Wetmore, Vice President of the Downstream. I'm going to start by reading the cautionary statement. Today's comments include reference to non-GAAP financial measures. The definitions and reconciliations of these measures can be found in attachment 6 of our most recent press release and available on our website with the link to this conference call. Today's comments may also contain forward-looking information. Any forward-looking information is not a guarantee of future performance and actual future financial performance and operating results can differ materially depending on a number of factors and assumptions. Forward-looking information and the risk factors and assumptions are described in further detail in our third quarter earnings press release that we issued this morning as well as our most recent Form 10-K, and all of these documents are available on SEDAR, EDGAR and on our website. So I'd ask you to please refer to those. Usual format today, Brad will start with some opening remarks, and then Dan will go over the financial performance. Then back to Brad to talk through our operating performance for the quarter. Then we'll follow it up with a Q&A session. So with that, I'll turn it over to Brad.

Thanks, Dave. Well, good morning, everyone, and welcome to our third quarter 2021 earnings call. I hope each of you are doing well and had the chance to enjoy some time with friends and family over the summer. What a difference a year makes. The third quarter is now in the books, and I'm very much looking forward to taking you through our results today. It was a great quarter by any measure as our strong operational performance continued to allow us to make the most of this very attractive business environment. Our assets performance met or exceeded our expectations. And once again, we have a few records to talk about. And I would note that this was across all of our business lines. Along with very strong operational performance, we continue to benefit from actions we took last year to reduce our overall cost structure and improve reliability. And this combination is so advantageous when commodity prices are continuing to see strength. This is what allows us to capture maximum value today, but also ensures our resiliency in a downturn should that occur in the future. In this quarter, the momentum you have heard me talk about was fully on display. We had very little planned maintenance. And on top of that, high reliability, which allowed us to take maximum advantage of the improving business environment. Over the next few minutes, Dan and I will detail the results of what was, again, a very strong quarter. So now let's turn more specifically to the third quarter results. Earnings for the quarter were $908 million, and our cash from operating activities was over $1.9 billion. both up significantly from the second quarter. Crude prices continued to strengthen through the quarter and downstream and Chemical margins remained robust. Our upstream continues…

Thanks, Brad. Getting into the financial results for the quarter. Our net income in the third quarter was $908 million, up $905 million from the second quarter of 2020. This increase was driven primarily by an increase in upstream realizations and volumes as well as improved margins in our Downstream and Chemical businesses. Now if we look sequentially, our third quarter income of $908 million is up $542 million from the second quarter of this year, driven by higher margins in the downstream and higher volumes in the upstream and downstream driven by substantially lower planned turnaround activity. Looking at each business line. The upstream recorded net income of $524 million, up about $280 million from our second quarter net income of $247 million, driven mainly by higher volumes due to the absence of planned turnaround activity at Kearl and Syncrude. In the downstream, downstream's net income was $293 million in the third quarter, up about $230 million from net income of $60 million in the second quarter, reflecting higher margins and the absence of the planned turnaround at our Strathcona refinery. Our Chemicals business continued to demonstrate strong performance through the third quarter with net income of $120 million -- I'm sorry, $121 million, up from net income of $109 million in the second quarter, driven by strong polyethylene margins. This is the highest quarterly net income in over 30 years for our Chemical business. Moving on to cash flow. In the third quarter, we generated over $1.9 billion in cash flow from operating activities or just over $1.5 billion, excluding working capital effects. Our free cash flow for the quarter was about $1.7 billion, bringing our free cash flow for the year to over $3.2 billion, an improvement of about $3.5 billion from last year. Even with substantial…

Thanks, Dan. I'll now take a few minutes to talk about operational performance in the third quarter, which, as I noted earlier, was very strong across the entire company. That is to say across all business units. Starting with the upstream, production averaged 435,000 oil equivalent barrels a day in the third quarter, which represents an increase of 34,000 barrels per day versus the second quarter of this year and an increase of 70,000 barrels per day versus the third quarter of 2020. It also represents our highest third quarter production in over 30 years. And is the first time we've seen 4 consecutive quarters with upstream production exceeding 400,000 oil equivalent barrels per day since 1990. The increase was a result of continued strong operating performance, driven in large part by our focus on reliability and by the absence of the planned turnaround activity we saw in the third quarter of 2020, notably at Kearl. I'll now talk in more detail about each asset starting with Kearl. And by now, you must be getting used to hearing me talk about Kearl continuing to deliver more and more impressive results. Well, here we go again, and I'm pleased to be able to report that, that trend continued in the third quarter. Kearl production averaged 274,000 barrels per day gross in the third quarter, which is the second best quarter in the asset's history. Recall that in the fourth quarter of 2020, Kearl's production was 284,000 barrels per day. Now this quarter's production of 274,000 barrels per day was up 19,000 barrels per day versus the second quarter due in part to the elimination of the planned turnaround, which has historically started in September. And as we discussed on the second quarter earnings call, we eliminated this second turnaround a full…

Okay. Thanks, Brad. We did have a number of questions pre-submitted. So why don't we open up the Q&A with a couple of those, and then we'll go over to the live Q&A line. The first question comes from Phil Gresh, JPMorgan. How should we think about the production progression over the next few years at Kearl as you aim to ramp to 280,000 plus?

Thanks for the question, Phil. We continue to see record performance out of Kearl based on our supplemental crushing capacity that we have discussed in the past and other enhancements and reliability. And so that gives us great confidence in the assets productive capability. And moreover, as we've announced last quarter, we moved to 1 turnaround starting this year from 2 previously, which a key driver for us increasing our 2021 guidance to 265,000 barrels a day. A target, and as I just mentioned, we remain very confident in achieving given the continued strong performance through the third quarter and now into the fourth quarter. So beyond the 265,000 barrels a day level, we've got other low-cost projects to get to the 280,000 barrel a day level over the next couple of years, including plant debottlenecking, enhanced mine planning, bitumen recovery as well as some digital initiatives. You may recall at our previous Investor Day, we outlined that path to 280,000 barrels a day with Kearl reaching 270,000 barrels a day in the 2023 to 2024 time frame and ultimately to 280,000 barrels a day by 200 -- by 2025. We still see a progressive path. But as evidenced by our recent performance and our track record of continued improvements, I fully expect that we will do better than that 2025 time line. At our upcoming Investor Day in March, we'll give more information on that. But again, I expect that we'll be well ahead of that earlier time line. And I'd also note that as we continue to debottleneck Kearl and really put more barrels over a relatively high fixed cost asset base, we also expect to continue to drive down our overall unit cost. We are only partway through the ramp-up of our autonomous haul truck program, and we talked about realizing a USD 1 per barrel saving from the full rollout, which we expect to achieve over the next 2 years. So in addition, we see a number of opportunities to apply digital solutions more broadly at Kearl, which include drones, other optimization technologies with an overall objective to continue to drive that cost not only the $20 per barrel, but even lower beyond that. Thanks for that question, Phil.

And Phil had a follow-up. Since you pushed back the timing of Investor Day, could you give us some updated thoughts on CapEx in 2022 and beyond? Does the framework from the last Investor Day still hold? Or could there be increases in spending from project activity like renewable diesel and/or inflation?

Yes. Thanks for the second question, Phil. We were really looking forward to getting back together in person at the end of this year for what would have been Investor Day in November. We see a lot of value to that event being in person, as I know you and other analysts and investors do as well. As we reflected on the situation with COVID across Canada and some of the travel restrictions that are still underway. We concluded it was still just a bit too soon for an in-person event like that. And so consequently, we decided to adjust the timing of our Investor Day, moving it one quarter. And so now planning to host that event in March of next year. And soon, I would anticipate you'll get a save-the-date notice from our Investor Relations team. But insofar as 2022 guidance goes, we're planning to share that with you within the next month or so, so that you will have our latest numbers in a timely fashion more along the lines of what you would have received in prior Investor Days. So we'll give you that guidance. But then at our Investor Day early next year, we'll go through our longer-term outlook, which will include an update on the Strathcona renewable diesel project, other capital investment plans. And what you'll see is a story that looks very similar to what we laid out last year with CapEx growing from kind of this year's levels, which we now have updated at $1.1 billion. And we previously projected over the next few years, we'd be averaging around $1.5 billion, $1.6 billion. And really, we see that general magnitude of expenditure continuing, especially with the Strathcona renewable diesel project. We believe we'll mostly be able to include that in those same levels of spending. So that's just kind of a high-level characterization, but more to come with our updated guidance and then the Investor Day in March. I guess also specific to your question on inflationary pressure, we do see some cost pressure in our business, but we don't expect it to materially impact our capital spending levels, given our ability to find offsets and efficiencies.

So I'm going to add another one here that a few folks have asked about this, so I'm going to pull it together into one question. But it sort of follows up from the question about inflation in general, a bit more specifically, and that's what's the impact of the much higher natural gas prices on our refinery profitability. And our fuel cost advantage that we've talked about before, refineries, energy efficiency, is that still an advantage? And then kind of finally, does it have any implications for potential stepping up development of our unconventional assets?

Yes. I mean that's a really good question. Obviously, energy costs are important driver for us. And so we're watching that very carefully and doing everything we can to offset those upward pressures, as I mentioned in my comments on Kearl and generally the downstream. But speaking more broadly about kind of the impact of higher natural gas prices. What we've indicated in our 10-K filing and still is very accurate and representative is really a modest impact overall. We see for every $1 change in gas price -- CAD 1 change in gas price we would estimate about a $90 million net income impact for that CAD 1 change. Now we also produce about $110 million, $115 million cubic feet per day of gas, mostly from our unconventional assets. So that provides some internal offset versus our gas input costs, energy costs across upstream and downstream. And that's why that CAD 1 impact to gas price is pretty modest. I'd also point out that our gas feedstock costs remain advantaged globally and are moving higher in the context of a stronger overall commodity price of environment. So on a net basis, we're really benefiting from higher commodity prices, including for crude and refined products as you can see in the strong cash flow that we generated for the quarter. I'd also note that our refineries are at or near industry best-in-class when it comes to energy efficiency according to our Solomon surveys and that trend has continued for many years now. So we have an advantage over Canadian competitors in the current high price environment for gas and energy. So all that said, we don't take rising costs for granted, and we're always looking for offsets. A good example in our downstream is our recent investment in the 41-megawatt cogeneration unit at our Strathcona refinery, which reduces our electricity price exposure and overall energy costs. And so with the Strathcona cogen project, I would just mention, we now have almost 600 megawatts of cogeneration capacity across all of our portfolio. And as for whether we step up investment on our unconventional acreage to produce more gas, I'd say we're never sitting idle, and we're always considering our investment choices. But at the moment, we're continuing to focus on our core oil sands operations where we haven't yet exhausted all of the highly economic value creation opportunities that we see. That answers your question.

Okay. Operator, I think we'll go over to the live Q&A line now, please.

[Operator Instructions]. Your next question will come from Neil Mehta with Goldman Sachs.

Brad, you laid out a little teaser there around capital returns. And as I think about part of the stock reaction today, I think there was maybe some expectation for some incremental updates there. But it sounds like those could be coming. And just talk through how you're thinking about a buyback relative to a tender relative to continued dividend growth and help us to frame out the time line around any such decision?

Yes. Thanks for your question, Neil. Yes, I didn't want to really reinforce our commitment to returning excess cash to our shareholders. We've made that a priority for a long time. We've demonstrated with our actions throughout this year that, that was a high priority for us. I know there is a focus on dividend and share buybacks. And I would just remind you and others that due to the strength of our company and the actions we took through the pandemic, we did not have to cut our dividend. And in fact, we maintained it through last year. And then earlier this year, we announced a very significant increase in the dividend, $0.05 per share on top of the prior $0.22. So almost 25% increase. A little bit later, approaching the summer, we did reinstate our share buybacks with a very accelerated 4% program over 2 months. And then most recently, we've reinstated the kind of a full year 5% share buyback program. So again, we've been very active and committed in returning cash to our shareholders. And so as we look to the rest of this year and into next year, the momentum is building for us as a company. We are generating significant cash. We are seeing our cash balances grow. And so we are committed to returning that excess cash to our shareholders. And that's why I mentioned that we are actively evaluating some very important steps over the coming months. That could include an acceleration of our NCIB program, could also include a substantial issuer bid or perhaps a special dividend. We haven't made any final decisions yet, and it is subject to Board approval, but those discussions are actively underway. And I might also ask Dan to comment a little bit on our views on substantial issuer bid versus special dividend because we have been discussing that with our shareholders, and that's influencing us.

Yes. Thanks, Brad. Yes, regarding NCIB versus a special dividend. I talked to a number of you on the line, we'd like to get folks views, analysts and investors. We're a bit agnostic. But I think the feedback we're getting is pretty significantly in favor of a substantial issuer bid buyback over a special dividend, and there's some research that came out recently that said some of that, too. But mainly, that's really from just talking to investors. So I mean, there's different reasons for that, tax and you have a choice and more structural maybe with NCIB is what folks tell us. So as we weigh those options we'll certainly -- we certainly take investor input into account in a very significant way.

And Dan, is the logical timing to think about an update around this, the fourth quarter call, that's when you made a big decision around dividend bump earlier this year. Is that what we should base case as the clearing point for this decision?

Yes, I wouldn't get into timing. As Brad said, we're actively evaluating all this stuff. And look, I think we -- as Brad said, we're actually committed to returning surplus cash. I think we've demonstrated that. So just -- we're working through that.

Okay. All right. And the follow-up question is just your thoughts on the Canadian oil markets here. WCS has widened out a little bit in terms of the differentials, but Line 3 is now online. Just how do you think about spreads from here? And as oil has stayed firm, do you think that differentials could stay more contained now that you have pipeline takeaway?

Yes. There's no doubt we're very encouraged by the additional takeaway capacity here in Canada. It's been a long time coming to get some more egress capacity. And so now with the Line 3 expansion being up and running, I think that's very positive. And of course, longer term, we're still encouraged by the plans for the TMX completion as well. So all of that provides more access for our barrels to get to the higher-cost markets in the U.S. And I think having more stability and flexibility in that regard should help keep these differentials fairly narrow. We've seen pretty good stability throughout the year in those differentials pretty much in the $13, $14, $15 barrel a range, and that differential, coupled with some very strong WTI pricing puts us in a very strong position. So I think we will continue to see some fairly tight differentials. There's always some volatility that could occur depending on unique situations in the marketplace. And if there are any pipeline disruptions that might occur with unplanned outages, but we're feeling quite encouraged.

And your next question will come from Dennis Fong with CIBC World Markets.

The first one really relates to capital spending somewhat to this year. So there was a modest decrease in guidance from $1.2 billion to $1.1 billion. I was just hoping to understand, obviously, in light of the stronger production that you're seeing, both from Kearl and Cold Lake. Has that influenced any of your, we'll call it, pace of development for other assets like Grand Rapids and so forth? And how do you think about balancing some degree of, obviously, optimizing the base production levels versus tackling potentially, we'll call it, ESG/expansion-related focused projects? And I've got a separate question for the renewable diesel facility, but really more on the upstream side there.

Yes. Thanks for that question. First, on capital spending, I would just reiterate the comments we made earlier on the call that despite our reduced guidance on capital spending, that in no way reflects a change in focus of our program. It really is just reflecting that as the years progressed and as we continue to lock in efficiencies and achieve capital discipline objectives, we have been able to complete the same amount of work we had planned but at a lower cost. So that's a really good outcome. As we look to the future, and we will talk much more about this at Investor Day in March, we continue to evaluate all of our efficiency projects, our kind of growth opportunities with debottlenecking and other kind of low cost, high efficiency use of capital. And we are positioning all of those in the best time slot that makes sense for us to maximize earnings, maximize value and, of course, capture the market as best we can. So you think about an asset like Cold Lake, one of the reasons we have been so successful with our volumes performance there is because we have cautiously deployed additional rigs to do workovers and other well-optimization activities to increase production there. And that's low cost and high return use of our capital. So we're going to continue to do that. Obviously, this environment encourages that. For bigger investments, we're taking a look at a much longer view of the price environment and certainly need to be cognizant of other risks that we may see long term. When it comes to ESG, and again, you'll hear us talk more about this at Investor Day, but a significant part of our capital strategy is to reduce our overall emissions. You heard us talk at last quarter's call about the startup of one of our boiler flu gas efficiency projects at Kearl, on just 1 boiler, we have plans to expand that to 5 other boilers. We're also deploying new solvent technologies at Cold Lake, which also reduced our emissions. So ESG and lower emission spending is very important to us. It's very prominent in our capital spending plans, but also creates economic value at each of the assets where we're making those investment choices. So more to come on that in March.

Great. Great. And then my follow-up question here is just on the renewable diesel facility there. Just from the language of the initial announcement as well as the potential significance, again, balancing components of a strong economic return as well as ESG-focused projects. It seems like -- I don't -- I'm going to say it's a slam dunk per se, but it seems like a very attractive project to move forward on. So with kind of FID potentially insight, what are some of the last items that you're looking to gain incremental clarity you're on? It sounded like you were continuing to pursue, we'll call it, negotiations and discussions with various government and regulatory bodies. How is that potentially progressing? So I just wanted to get a quick update as to where you're at with the renewable diesel project?

Yes. Thanks for the question, and thanks for the interest. I mean, I think you characterized it well. We do see it as a high priority value-accretive project for us as it does deliver significant environmental benefits. So we are progressing it as quickly, as efficiently as we can. We are still in the middle of several commercial negotiations around sourcing the feedstock around hydrogen production, we're also optimizing our own design to make sure we're leveraging best available technologies. And so all of that is kind of work in progress that will bring us to an FID probably sometime next year. But more work to do there. You also mentioned our discussions with government entities. Yes, those are very important to us. We've had very constructive discussions both at the provincial level and the federal level. I think there is a shared view that this project is very important in the overall kind of Canada's objectives around net 0 and individual provinces like British Columbia, see it also is very strategic for their fuel sources. And so we're just working with all those entities to kind of align on a plan and a strategy their participation and support. But it's all going extremely well. And that's the key message I want to leave with you is we are very encouraged, very optimistic and certainly more to come. And we would expect to have much more detail available in March at Investor Day.

Your next question will come from Greg Pardy with RBC Capital Markets.

The first one is almost like a modeling question, Brad, it's probably for Dan, but it's really just around tax horizon and cash taxability, obviously a high-class problem in the world we're living now in oil price lines. But how should we think about that in '22?

Do you want me to grab that, Brad?

Yes, go ahead.

Yes, Greg, obviously, yes, it's a high-class problem. If you asked me a few months ago, I would say we'd have sort of very, very minimal cash tax payments in '22. And I think that's still the case. I don't think it'll have really what I'd call significant cash tax payments in '22. But on current trends, we will become cash task paying in '23. That's probably as good as I can give you at this point. Obviously, it's sensitive to prices, right? We want them higher. So if that drives us to pay tax, that's just fine. But yes, we're getting to the point where losses and depreciation and stuff like that, which have really we've been very, very low taxes for quite a while. We're getting past that point. But I think '22, you'll see minimal -- relatively small amount of cash taxes and much more significant in '23.

Okay. Terrific. And maybe just shifting over to maybe just the pathways initiative. Like I know you're in the middle of negotiations still with governments and so on. But Brad, is there anything you can say in terms of the direction that, that is heading? And obviously, there's been some appointments with the change up in terms of the federal cabinet and so forth. But how should we sort of read maybe the progress on the pathways in terms of what you can see?

Yes. Thanks for the question, Greg. And I'm really excited about the pathways initiative. I think we're making great progress. The consortium of 5 companies are all very engaged. They're working very closely together. Myself and the other CEOs, we're meeting on a very regular basis to kind of review our plans and kind of next steps and progress and again, all very positive. We just issued some new information to the market, I guess, early last week to give some more updates on our plans, talk about the phasing that we see with our emissions reduction initiatives. And all of that is illustrative of kind of our commitment to achieve net 0 by 2050 for the oil sands. And what you would see in those announcements is a significant reduction by 2030. A lot of work underway right now around kind of feasibility studies for the main pipeline from up north and Alberta down to Cold Lake giving design on that. Also looking at all of the potential sources of carbon that we would want to capture and what the time line looks like to complete those capture investments. And then equally important is working with the Alberta government around poor space. And so we've recently submitted our application for access to poor space in the Cold Lake region. And then in parallel, we're in conversations with the federal government around the investment tax credit and the consultation that they've had underway. And I would just say that all of those conversations continue to be very constructive. There is a strong support for this project. There's a strong recognition that it is kind of fundamental to the country achieving their net 0 aspirations by 2050. With respect to some of the new ministerial announcements, obviously, we follow that very closely. Mr. Wilkinson has been a key contact for us on broad environmental issues. He's now staying in the cabinet, moving over to NRCan, which is another very key ministerial position for our engagements. We don't have a lot of experience with the new environmental minister, but we very much look forward to engaging him and talking about our projects and next steps and hopefully, achieving a shared vision of net 0 by 2050. We have a long history of working with many ministers and many governments and our objective is always to make those engagements as constructive as possible and look for ways that we can contribute to Canada's overall goals. So again, things progressing well and more to come, but I'm extremely pleased with the progress we're making.

So we have a few more that were pre-submitted. So we'll start -- the first one comes from Manav Gupta, Crédit Suisse. Neil Mehta had asked a bit about kind of our forward view of the heavy differentials. This one is a bit more specific in that we are seeing some widening of the heavy light spread today? And can you talk about what might be driving that?

Yes. Thanks for that question, Manav. Obviously, there's always a lot of moving parts in the market and especially right now. I think a key factor in that spread. And again, it's generally been pretty tight, although it has widened a little bit in the last month. And I think a contributor to that is we did see some inventory builds here in Western Canada over the last month or so, kind of in parallel to the commissioning of Line 3 and some, if you will, temporary impacts that had on pipeline egress. And I think there was also some very short-term pipeline outages also impacted egress, all very temporary in nature. But it did cause a build in inventory. And so I think that probably had an effect on some of these differentials. So that -- I think that's the key beyond what I've already said.

Manav had a follow-up question related to renewable diesel. Can you talk about feedstock you plan to use for the renewable diesel facility, will it be vegetable oil primarily? Or will you use some tallow?

Yes. Kind maybe building on my earlier comments about this project and our optimism about it. With respect to feedstock, we are very much planning to use vegetable oils, not a waste or tallow product. And one of the reasons we chose our Strathcona refinery is because of its location, and it's in close proximity to abundant local agricultural feedstocks. And so as we think about that supply chain we view most of those crop sources being within a day's transit by rail. And so that provides, I think, some natural synergies, co-locating it with Strathcona refinery also provides further strategic advantages, cost efficiencies and also in close proximity to kind of a low carbon fuel market in BC. So all those things were factors for us to choose the location. But Specific to your question on feedstock, being close proximity to that crop base is really important.

From Prashant Rao at Citi, it's related as well to renewable diesel, but a bit more in a strategic nature. Can you talk about where Strathcona renewable diesel fits in the overall goal for longer-term net decarbonization goals, both at Imperial, but also as Imperial fits into ExxonMobil's recent updates on this front? And then is there potential to include the remainder of the downstream asset base in the strategy?

Yes. Thanks for the question. And obviously, a lot of interest in our Strathcona renewable diesel projects. So I very much look forward to talking more about that in the coming months as we progress towards an FID. And I know Jon Wetmore here, who runs our downstream business, he's actively engaged in progressing that project. And I'm sure he'll be sharing more details as well. But specific to your question, we've been examining potential solutions in support of a net 0 future for some time now. And as we approach it, we bucket those solutions into short-term, medium-term, long-term opportunities. And this specific renewable project fits into our short-term bucket, but -- for Strathcona. But its use could certainly be expanded over a longer-term horizon with other refinery applications for us here in Canada. We're already manufacturing advanced fuels, lubricants. And we've been growing our biofuels blending capability as well for some time. So this Strathcona renewable diesel project really builds on that foundation and allows us to participate in the growing renewable fuels market in a very efficient way, very economic way. And you saw ExxonMobil announced the Strathcona renewable diesel project alongside our announcement, which I believe really showcases the importance of this project within their portfolio as well and also just reinforces the alignment between Imperial and ExxonMobil on this key project initiative. And so as I mentioned, we've started with Strathcona given its proximity to the feedstocks and the fuels market. But I very much suspect that there will be other opportunities to progress our lower carbon strategy within our downstream business in other ways over time.

Okay. And we have one final question also from Prashant Rao at Citi. Investors are broadly expecting industry chemicals margins to receive as 2022 unfolds. If you would, could you please talk about Imperial's Chemical business within the global context as this happens? Anything we should keep in mind, which might differentiate your operations from the global trend?

Yes. Thanks for the question, Prashant. You heard me talk quite positively about our chemicals business. And I think the outlook for that business continues to be very strong. We've got a very low-cost chemical business that benefits from a number of structural advantages maybe first and foremost, being the integration with our Sarnia refinery, which really lets us optimize our product mix to extract the most value from shared feedstocks. And also, our facility is in close proximity to our customer base, which is another strength for our chemicals business. And these advantages are certainly what underpins the record profitability we've seen this year, but we've also benefited from some supply shortages and storm-related outages in the Gulf Coast, which admittedly are temporary. But as we look ahead, there will be some additional capacity coming online that will lead to lower industry margins. But most of that capacity is expected to supply export markets and not directly impact the markets we sell into. So we continue to be very optimistic over the long term. And I would just add that we saw our chemical business earn around $50 million per year. Last time we had a bottom of cycle pricing conditions, which just goes to show how resilient and advantaged are our specific Chemical businesses with all those synergies I spoke to. So again, looking ahead, we do see a strong market and potential for us.

Okay. And that's the end of our questions. So I guess I would close by saying thank you very much for joining us and for your continued interest. If you have any further questions or want to have any further discussions, don't hesitate to reach out to the Investor Relations team. And with that, have a great afternoon and a great weekend. Thank you very much.

This concludes today's conference call. Thank you for participating. You may now disconnect.