Good day and welcome to the Imperial Oil third quarter earnings call. Today's conference is being recorded. At this time, I would like to turn the conference over to Dave Hughes, Vice President, Investor Relations. Please go ahead, sir. Thank you, Marion. Good morning, everybody. Thanks for joining us on our third quarter earnings call. As usual, I'm joined by Imperial's senior management team, including Brad Corson, Chairman, President, and CEO, 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 Jon Wetmore, Vice President of the Downstream. Just let me first go over the cautionary statement. Today's comments include reference to non-GAAP financial measures. The definitions and reconciliations of these measures can be found in our attachment six of our most recent press release and are 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 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 in our third quarter earnings release that we issued this morning, as well as our most recent Form 10-K. All of these documents are available on SEDAR, EDGAR, and on our website, so please refer to those. As usual, Brad and Dan are gonna provide an operating and financial update, after which we'll cut over to the Q&A. With that, I will turn it over to Brad for his opening remarks. Thanks, Dave. Good morning, everybody, and welcome to our third quarter earnings call. I hope you're all doing well. I am really pleased to report another very strong quarter for Imperial. We saw outstanding performance across all of our assets, both upstream and downstream, and we are also seeing this strong operating momentum continue into the fourth quarter. The overall macro environment remains quite positive for our financial performance. We're continuing to experience high commodity prices, driven in large part by supply challenges and ongoing geopolitical events, both of which serve to remind us just how important a stable and reliable energy supply is. Our unrelenting focus on safety and reliability enables our strong operating performance in this environment and underpins the results which we will be talking about this morning. We continue to look for ways to further increase production and ensure reliable energy supplies when Canadians need them most. So far, the fourth quarter seems to be a continuation of this economic environment. With all of our major planned maintenance activities behind us, our plans are to continue running at maximum levels as we have so far this year. This sets us up well for a very strong finish to the year. Over the next few minutes, Dan and I will detail the results of what was a very strong quarter. Now let's review the third quarter results. Earnings for the quarter were just over CAD $2 billion, and our cash from operating activities was almost CAD $3.1 billion. These results reflect the strong operating performance in the quarter, as well as the strong commodity fundamentals we are currently experiencing. I would also remind you that along with strong financial results like this, comes increased royalty and tax contributions to the government that go to support our local communities. We achieved total upstream production of 430,000 barrels per day in the quarter, which reflects a return to normal operations at Kearl, post the second quarter turn-around and ongoing excellent performance at Cold Lake, as well as the impacts of a large planned turnaround at Syncrude. Performance of the downstream continues to excel. Our refinery utilization in the third quarter was 100%, which not only represents the fifth consecutive quarter of utilization above 90%, but also the highest utilization we have seen in over 40 years. This sustained outstanding performance is so important in the current environment, given the current supply challenges we have talked about. The third quarter also saw significant cash generated, including cash received from the proceeds of the sale of our interest in XTO Energy Canada, which closed at the end of August. We opted to use those sales proceeds to reduce our outstanding debt by CAD $1 billion. This also lowers our debt to capital ratio even further from 19% at the end of 2021 to below 16% now. In addition to this debt repayment, we continue to maximize shareholder returns. Not only did we return CAD$ 227 million in dividends. By mid-October, we have fully executed our current normal course issuer bid, well ahead of the program's expiry in June of 2023. These buybacks represented an additional CAD $1.5 billion of cash returned to our shareholders during the quarter and another CAD $434 million in October. Finally, this morning we declared a dividend of CAD 0.44 per share, payable January 1, 2023. That represents an increase of CAD 0.10 per share or over 29%. This is the largest dividend increase in Imperial's history. We also announced our intention to initiate another substantial issuer bid to return an additional CAD 1.5 billion to our shareholders in the fourth quarter. Altogether, as of the end of the third quarter, we have now delivered record shareholder returns of CAD $5.1 billion this year with more to come. With that, I'll pass things over to Dan. Thanks, Brad. Getting into the financial results for the third quarter. Our net income of CAD $2.031 billion was up CAD $1.123 billion from 2021, or about CAD 900 million when we exclude the impact of the XTO sale. This increase was primarily driven by higher margins in the downstream and improved realizations in the upstream. Now, if we look sequentially, our third quarter income of CAD $2.031 billion is down CAD $378 million from the second quarter, or down around CAD 600 million excluding the XTO sale, reflecting softer crude prices and refining margins that were partly offset by improved upstream and downstream volumes. Looking at each business line, the upstream, which reported net income of CAD $986 million, is down CAD $360 million from our second quarter net income of CAD $1,346 million. We're down about CAD 570 million when we exclude the impact of the XTO sale. The downstream reported net income of CAD $1,012 million, relatively flat for the second quarter, as strong utilization rates allowed us to continue to take full advantage of the attractive refining margin environment. Finally, our chemicals business continued to demonstrate solid performance, with net income of CAD $54 million in the third quarter, essentially flat with our second quarter net income. Moving on to cash flow. In the third quarter, we generated nearly CAD $3.1 billion in cash flows from operating activities, an improvement of just over CAD $400 million from the second quarter, bringing our year-to-date cash flows from operating activities to almost CAD $7.7 billion, up about CAD $3.8 billion from last year, reflecting strong conditions and favorable working capital impacts. Free cash flow for the quarter was CAD $3.453 billion, bringing our year-to-date free cash flow to about CAD $7.5 billion, around CAD $4.3 billion higher than last year, primarily driven by the increase in cash flows from operations that I just mentioned and by the cash received from the XTO sale. As Brad mentioned earlier, we completed the sale of our interest in XTO during the third quarter. We utilized the proceeds from this structural change in our business to structurally improve our balance sheet by reducing debt by CAD $1 billion, further enhancing our financial resilience and flexibility going forward. On previous earnings calls, we noted that we expected cash payments in 2022 of around CAD $400 million. That remains the case, and that includes about CAD $350 million that has already been paid in the third quarter year-to-date. Looking forward, there are, of course, a number of factors that could impact our final income tax payment for 2022 that will actually be made in the first quarter of 2023. Under current conditions, we continue to anticipate that this first quarter 2023 cash income tax payment would be on the order of CAD $2.5 billion. Finally, we ended the third quarter with just under CAD $3.6 billion of cash on hand. Moving on to CapEx. Capital expenditures in the third quarter totaled CAD $392 million, up from CAD $277 million in the third quarter of 2021, in line with our full year guidance of CAD $1.4 billion. Spending in the third quarter was primarily in the upstream, with increased spend at our Grand Rapids project and volume sustainment at Cold Lake, as well as spending on our in-pit tailings project and new maintenance facilities at Kearl. In the downstream, we continued to progress our renewable diesel project at Strathcona. Shifting to my favorite topic, shareholder distributions. A reliable and growing dividend remains the bedrock of our cash distribution strategy. As Brad noted this morning, we declared a fourth quarter dividend of CAD 0.44 per share payable in January. With this 10 cents per share increase, we have now doubled our dividend over the last two years. Beyond base dividends, we remain committed to returning surplus cash to shareholders through our normal course issuer bid program and other means. We completed our most recent accelerated NCIB program in October, returning CAD $1.9 billion to shareholders over the last four months. Looking back, over the past 18 months, we returned CAD $7.1 billion to shareholders via share buybacks, reducing our share count by 129 million shares, or 18%. As Brad noted, given our robust free cash flow generation, we intend to launch a second substantial issuer bid this year, returning up to an additional CAD 1.5 billion to shareholders in the fourth quarter. The terms and pricing will be determined, and the bid is expected to commence within the next two weeks. Both the dividend increase and our second SIB announcement continue to demonstrate our ongoing commitment to return cash to shareholders. Now I'll turn it back to Brad to discuss our operational performance. Thanks, Dan. Upstream production for the quarter averaged 430,000 oil equivalent barrels per day, which is down 5,000 barrels per day versus the third quarter of 2021, but up 17,000 barrels per day versus the second quarter. This increase reflects our strong operating performance at Kearl and Cold Lake, which more than offset the impacts of a major planned turn-around at Syncrude. While ongoing strength in commodity prices continues to be a key part of the story this year, I would note that the WTI/WCS differential came under some pressure in the quarter, resulting in a widening of around $6 per barrel versus the second quarter. While these pressures have continued so far in the fourth quarter, WCS absolute prices continue to be quite strong. I would also note that at the same time, we saw an increase in downstream crack spreads, notably for diesel, which provides a counter to the wider differentials and highlights the value of integration that we have. Additionally, our downstream directly benefits from the lower prices on the heavy crudes we process, especially when coupled with the higher diesel crack spreads I mentioned. Further, Syncrude synthetic product commanded a strong premium in the third quarter. Now let's move on and talk specifically about Kearl. Production in the third quarter averaged 271,000 barrels per day gross, which was up 47,000 barrels per day versus the second quarter, which included our annual major turnaround, and just under the 274,000 barrels per day from the third quarter of 2021. This year's third quarter production represents the third-highest quarterly production in Kearl's history. Operations remain strong at Kearl, and I'm pleased to report that October month-to-date production has averaged 305,000 barrels per day. I would also like to highlight that so far in October, Kearl has set a number of single-day production records with the best ever single-day production in the history of the asset, being 357,000 barrels per day on October twelfth. Back on the second quarter call, we provided updated full-year guidance of around 245,000 barrels per day for Kearl, reflecting the challenges we faced in the first quarter. Given the strong performance in the third quarter and so far into the fourth quarter, we are reiterating the current full-year guidance of around 245,000 barrels per day. Finally, turning to operating costs, we saw a reduction in unit operating costs at Kearl in the quarter of around U.S. $6 per barrel versus the second quarter to just over U.S. $25 per barrel. Although we are still facing pressures from high energy prices, this reduction reflects the absence of the second quarter turnaround, as well as the impacts of our ongoing focus on optimization and improving reliability. We continue to work towards a sustainable unit operating cost at or below U.S.$20 per barrel at Kearl. Moving to Cold Lake. 2022 continues to be a great year for our Cold Lake asset. Production for the third quarter averaged 150,000 barrels per day, which was up 6,000 barrels per day from the second quarter and up 15,000 barrels per day from the third quarter of 2021. This is also the fourth consecutive quarter with production at or above 140,000 barrels per day. As I've talked about before, these results reflect our ongoing focus on production optimization and reliability, resulting in year-to-date production of 145,000 barrels per day. If you recall, our original guidance for Cold Lake was 135,000-140,000 barrels per day for the year. With these strong year-to-date performance results, we are now increasing this guidance to a range of 140,000-145,000 barrels per day, and I expect it will likely be at the upper end of that range. Imperial's share of Syncrude production for the quarter averaged 62,000 barrels per day, which was down 19,000 barrels per day from the second quarter and down 16,000 barrels per day from the third quarter of 2021. The lower production reflects the impacts of a major planned turnaround at the asset in the third quarter of the year, which is now largely complete and operations are returning to normal. The interconnecting pipeline between Syncrude and Suncor was heavily leveraged during the turnaround months, averaging about 7,000 gross barrels per day of bitumen and other products during the quarter. This highlights the value of the interconnecting pipelines in support of increasing utilization at the site. To wrap up my comments on the upstream, I would also note that we successfully closed the sale along with ExxonMobil Canada of our XTO assets at the end of August. Imperial's 50% share of these assets represent production of around 5,000 barrels per day of liquids and 65 million cubic feet per day of gas. Cash consideration for Imperial's share of the sale was around CAD $900 million, which Dan already mentioned we used to pay down debt. While debt remains a lower capital allocation priority for us given our strong balance sheet, we felt it made sense to use this non-operating source of cash for that purpose, serving to further enhance our already strong balance sheet and improving our financial flexibility going forward. Now let's move on and talk about the downstream. In the third quarter, we refined an average of 426,000 barrels per day, which was up 14,000 barrels a day versus the second quarter and up 22,000 barrels per day versus the third quarter of 2021. This reflects continued strong operating performance and minimal planned turnaround activity. Refinery utilization was exceptional at 100%, which is the highest quarterly utilization in over 40 years and a result of our continued focus on reliability and optimization. This is up from 96% in the second quarter and 94% in the third quarter of 2021. This is tremendous performance, and I would like to credit our refinery teams who remain focused on reliability and optimization to deliver this phenomenal result. Year-to-date utilization is 96%, which not only reflects strong operating performance, but also the fact that 2022 has been a light year for planned maintenance. We expect to see 2023 go back to more typical maintenance levels, and we will be providing more details on the turnaround schedule when we release our 2023 guidance later this year. Needless to say, having such a light turn-around year has served us very well in the high refining crack spread environment we have been seeing throughout 2022. We are also continuing to progress the Strathcona Renewable Diesel Project and expect a final investment decision in the coming months. To that end, you would have seen our announcement about entering into a long-term contract with Air Products to supply low carbon hydrogen to the project, an important milestone as we continue to progress our plans to build Canada's largest renewable diesel manufacturing facility. Petroleum product sales in the quarter were 484,000 barrels per day, which is up 4,000 barrels per day versus the second quarter and down 1,000 barrels per day versus the third quarter of 2021. Gasoline and diesel demands remain strong at levels similar to the second quarter, and jet fuel demand has stabilized at close to pre-pandemic levels. We continue to see a positive downstream margin environment in the third quarter, and although we have seen some softening of motor gasoline margins through the third quarter, diesel margins remain extremely strong. These dynamics are driven by a number of factors, including low product inventories and a global shortfall for diesel fuel. That brings us to chemicals. This business delivered CAD $54 million in earnings in the third quarter, which was essentially flat or up CAD $1 million from the second quarter. Down CAD $67 million from the third quarter of 2021, which, as you know, was a period of all-time high realizations for us in the chemicals business. The performance we have seen so far this year is more indicative of mid-cycle performance and has been very stable throughout 2022. As always, I'd like to wrap up by highlighting a few other items of note, particularly as it pertains to our ongoing commitment to improving sustainability and reducing our overall environmental footprint. First, the Government of Alberta selected the Pathways Alliance to continue exploratory work on the development of a CCS hub, which will allow operators to safely store CO₂ in the Cold Lake area. This is the pore space which we have been talking about recently and an important milestone in the Pathways plan to develop infrastructure in collaboration with governments to help achieve Canada's net zero goals. In addition, the alliance has completed pre-engineering work on the 400-kilometer carbon trunk line and has begun early engagement with more than 20 indigenous communities along the corridor as a reflection of its commitment to meaningful engagement throughout the full cycle of the network's operations. The alliance is also conducting engineering studies for the first phase of the CO₂ capture facilities, as well as executing environmental field programs to support the necessary regulatory application submissions. Really a lot going on here. Second, during the quarter, we released our annual corporate sustainability report, which highlights our plans and progress in key environmental, social, and governance areas. We are very proud of the progress we have made so far and intend to build on that momentum in the coming years. Most recently, in fact, just last week, we announced a unique collaboration with a leading electric vehicle charging solutions company called FLO, to jointly develop charging service options for Imperial's Esso and Mobil branded wholesalers, which includes an agreement to transfer credits to Imperial under Canada's Clean Fuel Regulations. This is expected to support Canada's net zero emissions goals by expanding FLO's charging network for electric vehicles. Our collaboration with FLO will complement other Imperial greenhouse gas emission reduction efforts, including plans to produce and supply lower emission fuels, next generation resource recovery technologies, and carbon capture. In closing, another excellent quarter. We saw high reliability in our operations across the board, including record high utilization in our downstream, allowing us to continue to benefit from a strong business environment and to deliver very strong financial results. We also closed the sale of our interest in XTO Energy Canada, further advancing our strategy to maximize shareholder value by focusing upstream resources on our core long life, low decline oil sands assets. We returned over CAD $1.7 billion to our shareholders in the quarter via our reliable and growing dividend and the accelerated execution of our current normal course issuer bid. Today, we announced our largest dividend increase in history, as well as our plans to initiate our second substantial issuer bid of 2022, both of which continue to underscore our ongoing commitment to drive shareholder value and our continued commitment to shareholder returns. Progress continues in our efforts to lowering our carbon footprint. In addition to signing a hydrogen supply agreement with Air Products, we expect a final investment decision on the Strathcona Renewable Diesel Project in the coming months. We continue to advance our deployment of next generation in situ technology with the Grand Rapids project at Cold Lake. Excuse me. We also released our latest sustainability report, and I would encourage you to have a look to learn more about our plans and progress in this important area. When you couple this with our recent announcements, such as our collaboration with FLO on electric vehicle charging service options, as well as the government of Alberta's awarding of pore space, as just a couple of examples, I hope you can see the active role Imperial is playing in the energy transition and in our journey towards a lower carbon future. As always, I'd like to thank you once again for your continued interest and support of our company. Lastly, a big shout out of thanks to the Imperial team who have worked so hard to deliver these great results. Now we'll move to the Q&A session, so I'll pass it back to Dave. Thanks, Brad. Just like to remind everybody, please, if you could limit yourself to one question plus a follow-up, that just ensures we can get all the questions in. With that, Mary, would you please open up the Q&A line? Thank you. If you wish to ask a question at this time, please signal by pressing star one on your telephone keypad. Please ensure the mute function on your telephone is switched off to allow your signal to reach our equipment. Again, please press star one to ask a question. We can take our first question now from Greg Pardy of RBC Capital Markets. Please go ahead. Yeah, thanks. Good morning. Brad, I typically don't do this, but my goodness, what an outstanding quarter. I wanted to ask you maybe just about generally around shareholder returns looking into 2023 and then your appetite to do further SIB. It always comes up as a question, right, in terms of the acceleration of the SIB, and then it creates these apparent air pockets in what you might do. Obviously, you've addressed that very elegantly. What's the appetite for an SIB into next year? And then this is the follow-up, of course, but how do you think about that versus specials versus just grinding away on an NCIB and so on? Just wanna kind of dial that in a little bit more than my understanding permits now. Yeah, thanks. Thanks, Greg. I'll make a couple of comments and maybe turn it over to Dan. You know, as you've seen throughout this year, you know, a very strong commitment to shareholder returns, returning cash to our shareholders via a multitude of vehicles. You know, it does start with a long history of a reliable and growing dividend. Of course, we've reinforced those actions with a record-setting dividend increase today. We've continued our philosophy around share buybacks as an important and structural vehicle to return cash to shareholders. As you know, we've got this 5% a year limit with our NCIB. As we've accelerated and exhausted that, you know, for a couple of years running now, that has caused us to now look at SIBs as an additional vehicle to supplement those shareholder returns. We're getting ready to embark on our second one for this year. I think as we look to 2023, you know, it's premature to commit on further SIBs. It's not premature to commit on a long-standing, you know, philosophy and principle on returning cash to shareholders. You know, you will continue to see that as we move into 2023. I think the vehicle that we leverage is kinda yet to be determined. Again, you know, it will be something we'll be continuing to focus on, discuss with the board. I don't know, Dan, anything you wanna add to that? Yeah, just maybe a bit. Well, Greg, by the way, congratulating us at the beginning of your remarks, that's always good. You don't have to apologize for that. We appreciate it. You know. That said, you know, our philosophy of returning surplus cash to shareholders is unchanged, right? We've said, you know, beyond the reliable and growing dividend, our first port of call is the NCIB. I think that's almost a given. Of course, it'll depend on market conditions. If our cash generation is such, you know, current market conditions continue, it will be such that we'll have to go to other means to return surplus cash, and we'll do that. We've done two SIBs, obviously we see that as an attractive way of returning cash. We do continue to think about specials. You know, for us, it's really an investor preference thing, and as we talk to investors, you know, across the spectrum, our investors, there seems to be a pretty strong preference for the SIB over special dividends. I wouldn't rule a special dividend out. You know, philosophy is the same. If cash continues to be strong, you'll continue to see the NCIB and additional returns of cash, you know, through the means available to us. Greg, if I can make one other supplemental comment around that. You know, what we're talking about here is our capital allocation philosophy as it relates to surplus cash. Now, embedded in that decision is also kind of our commitment to reinvesting in the business. You see us doing that, you know, with significant investments at Kearl, at Cold Lake, in our downstream, you know, with our renewable diesel project, and looking further down the road, with our Pathways Alliance and our commitment to net zero by 2050 and all the infrastructure investments that'll be necessary to achieve that. You know, I think we're striking a very good balance between investing in the sustainability of our company and in our future, but at the same time, doing that in a responsible way that also yields you know, significant surplus cash that we can return to our shareholders. Okay. Understood. Very, very thorough rundown. Just the second question comes back to the 100% utilization in the refining. Was that, you know, was that one or two facilities in particular? Have you seen any capacity creep, you know, post your turnaround activity? I'm just trying to get a sense as to how likely this is to get, you know, replicated even conceivably in the fourth quarter. Just has anything really changed structurally in the downstream that 100% utilization might happen again? Yeah, it's a good question. You know, I mean, we are super pleased, super proud of the 100% utilization. There's really nothing that we're seeing in the fourth quarter that suggests, you know, a fundamental change to that. As I did mention, you know, kind of a contributing factor to our overall high utilization throughout the whole year has been our light kind of level of turnaround activity, you know, compared to historical levels. As we move to next year, we'll be returning to more typical levels. That will have an effect on us, you know, as we move to next year. As we sit here today and looking to the rest of the fourth quarter, you know, I expect continued very high utilization. Again, a big credit to our refinery teams to achieve that. All right. Many thanks, guys. Thank you. We can now take our next question from Doug Leggate of Bank of America. Please go ahead. Hey, good morning, guys. This is actually Clay on for Doug. For my first question, I'd also like to touch on cash returns as the market looks like it likes what you've done here. My follow-up is how the capex and capital will evolve into 2023. Specifically, I'm thinking about capital expenditures and also cash tax. Any color that you can provide there would be helpful. Yeah. Thanks for the question. Maybe I'll first make a comment around CapEx, and then I'll turn it over to Dan, and he can talk more about the other elements. You know, on CapEx, as we shared at our Investor Day earlier this year, you know, our guidance for this year, of course, is CAD $1.4 billion of capital expenditures. We are right on track to achieve that, consistent with the full-year guidance. As we look to the next few years, what we've said is we expect to average about CAD $1.5 billion, you know, which is a combination of maintenance capital and some growth capital. We'll update that outlook when we have our next Investor Day sometime early next year. As we sit here today and we're finalizing our near-term business plans, I think we still feel good about those levels of capital expenditure. I think for now, the CAD $1.5 billion, you know, over the next few years is still a good average for us, and we'll provide a bit more detail, you know, early next year on that. That's kind of the capital story, CapEx story, and I'll turn it over to Dan. Yeah. You know, as I said before, you know, we expect to be cash tax paying, you know, sort of fully cash tax paying in 2023 plus, as you know, especially under the strong market conditions. I talked about, you know, really quite low cash tax payments in 2022 of about CAD 400 million projected for the whole year. I talked about the first quarter, our final payment or catch-up payment for 2022, which we'll make in the first quarter of 2023 about CAD 2.5 billion. I mean, going forward under current conditions, we'd expect to be, you know, cash tax paying at, you know, roughly 24%. Got it. I appreciate that, Dan. My second question is on the downstream result. What stood out to us beyond the really big headline numbers was that the gross margin was nearly identical to the second quarter, and refining benchmarks peaked then. Can you help us understand what the drivers are for third quarter and maybe some idea of how retail contributed to the overall result? Yeah. Thanks for that question. I mean, you know, certainly the margins have stayed quite high in the third quarter, and so that's a large driver for us. That coupled with, you know, us being able to achieve these very high utilization rates, you know, which were higher in the third quarter than the second quarter, that has contributed to us maximizing value through those assets. And then, you know, as is always the case, we're constantly optimizing our crude slates that we run, taking advantage of you know kind of market availability of crudes and discounted crudes. And ensuring, you know, we're placing our products to the highest markets that are available to us. You put all that together and we're able to generate just a hugely profitable third quarter in the downstream. I just kind of paint that picture at the highest level. Jon Wetmore is here with us, and he of course runs our downstream. I'll just kind of offer to him if he wants to add any further detail on that. Yeah. Good morning, everyone. Thanks, Brad. I think one thing I'll say about the third quarter trend on gross margin is that gasoline softened, but diesel strengthened. That's maybe the swap if you're trying to look at it versus the second quarter. Gasoline was very strong in the second quarter, and it did soften globally and softened within North America, but diesel has more than offset that. We do expect the diesel trend to be there in the fourth quarter of this year. You know, very, very positive bullish signals on diesel in the fourth quarter, and I think that's why Brad is signaling that we do expect strong crude rates through the fourth quarter as well, you know, under-pinned by that very good diesel signal. Got it. I appreciate that, guys. Thank you. Thank you. We can now take our next question from Dennis Fong of CIBC World Markets. Please go ahead. Hi, good morning. Appreciate you taking my questions and providing some of that color in your opening comments. Maybe my first one is just to follow on to the discussion around refined products in the downstream side. I was hoping you could highlight some of the investments Imperial has made recently that has either improved the flexibility around either marketing or throughput. As well as a reminder on the kind of the range or limits around the relative amount of diesel production you guys can do. Just a couple of comments on investments. You know, certainly the most recent and material investment we made was in the Sarnia products pipeline that we announced completion and start-up earlier this year. You know, that allows us good access to the high-value Toronto market for our products. We are fully leveraging that asset. We're able to deliver those products reliably, you know, via pipeline at a lower cost than maybe we have been able to do in the past. I think that's a key contributor for us. You know, as we look back a bit longer in history, you know, over the last couple of years, we've been investing in our asphalt manufacturing capability. We've been investing in our ability to run our heavy crudes. That just further strengthens our integration as a downstream. I think, you know, those are all key contributors for us. Of course, as we look ahead, you know, we're progressing our planning and early investments in the Strathcona Renewable Diesel project, which is just another example of how we're positioning ourselves to capture maximum value out of not just today's market, but our view of the future market. Great. Great, thanks. My second question, if you wouldn't mind switching gears, is at the beginning of this year, due to some extreme cold weather that was experienced up in northern operations, performed a little bit less desirably. I was curious as to whether or not you could walk us through some of the learnings or changes you've made to operations to help improve or moderate the risk as we enter this cooler temperature season over the next few months. Thanks. Yeah. Thanks for that question. You're right. You know, we had some disappointing performance late last year and early this year, you know, driven by just the extreme cold weather conditions. Of course, you know, we're accustomed to operating in cold weather. But what we saw was a bit unusual for us. You know, there were several kind of confluence of events that contributed to that downtime. You know, I would first say that based on our third quarter performance, you know, I think there's a strong indication that that is long in our kind of rear-view mirror now. We feel very, very good that with all the work we did to mitigate those situations that we're well prepared for this coming winter. You know, probably the biggest learning we had was around kind of the operating envelopes that we needed to be prepared for with our new crushers. You know, that was the new kind of variable for us. And they experienced some issues in the cold weather, but we've made modifications to that equipment, and you know, we feel quite comfortable. You know, that's the strength of the Kearl organization is they have demonstrated their resilience. They continue to adapt. They continue to interrogate, you know, any bottleneck in the system, any lack of reliability and continue to learn from that and close the gap. You know, that is what's put us clearly on this accelerated pathway to 280,000 barrels per day by 2024, a year earlier than we had previously indicated. You know, the team isn't giving up there. They're gonna continue to work towards further improvements. You know, I'd just kind of leave you with that, we feel quite positive and optimistic about the future at Kearl. Great. I appreciate that incremental color. I'll turn it back. Thanks. Thanks, Dennis. As a reminder, please press star one to ask a question. Take our next question now from Patrick O'Rourke of ATB Capital. Please go ahead. Hey, guys. Good morning. Thanks for taking my questions. Just kind of wondering here in terms of the renewable diesel project. You got the agreement with Air Products there. What sort of technical and regulatory milestones remain between now and FID? In terms of the Air Products deal, does that have any impact on the nature or amount of capital or timing of those capital spend that will be necessary by Imperial? Thanks for the question. Thanks for the interest in the project. We're super excited about it. You know, kind of concluding the contract with Air Products is a key enabler for us to bring that project to FID. As I mentioned, we're anticipating that we will bring it to FID within the coming months. The other key outstanding item that we're working through is some key commercial arrangements around the crop supply that will, you know, be the feedstock for the renewable diesel project. Those discussions are well advanced and going well. You know, obviously, though, that's a key element of the project. You know, from a capital standpoint, you know, we've indicated that our estimated cost is around CAD $500 million investment for that project, and that excludes investments, you know, that Air Products would make or that, you know, crop suppliers would make. When you look at it in total, it's probably closer to CAD $1 billion, including others' investments, third-party investments. The regulatory work is, you know, well advanced. You know, that's not an obstacle for us at this point. Again, we're getting down to kind of the final steps we need to take FID. I'm super excited about advancing this project, and I think it's got great benefit not just for us as a company, but for Canada and our objectives, you know, as society here. Okay. I appreciate that color. Just on the financial side here, you guys have maintained the CAD $1.4 billion capital budget for this year. You're pointing to CAD 1.5 billion next year. This is really in stark contrast to everything that we've seen in the industry from your peers, in terms of being able to mitigate effectively inflation here. I know you don't wanna give away the entire recipe for the secret sauce, but I'm just curious if you can point to any key factors because as I said, this is a pretty significant departure relative to your peers in terms of capital outlays. Yeah. Thanks for recognizing that. It is a big credit to our team. That is the secret sauce. It's the team, and they are working, you know, quite diligently on managing inflationary pressures, both on the operating cost side and on the capital side. You know, we demonstrated our discipline around cost quite dramatically during the depths of COVID when we removed almost CAD $1 billion of operating costs, another CAD $1 billion of capital costs. With that were a lot of structural improvements that we continue to leverage today. Now, when you talk specifically about our CAD $1.4 billion capital budget and our ability to deliver kind of all of the project activities within that original budget, you know, it does speak to the work the team is doing to offset inflationary pressures, continuing to look for further efficiencies in the business. We also benefit from having much of the capital work being contracted prior to these extreme inflationary pressures that we're seeing. The nature of many of our projects involve a lot of earth moving and not so much steel, you know, which has been subject to significant cost pressures. But again, you know, it comes down to this relentless focus on managing costs and a big credit to our team. You know, we expect to maintain that discipline as we look to next year and the years beyond with this average of CAD 1.5 billion. Thanks for that question. Okay, thank you very much. I will now take our next question from Neil Mehta of Goldman Sachs. Please go ahead. Yeah. Good morning, team, and congrats on a great set of results here. Rather the first question is around the widening of the WCS differential. Typically, we think of your upstream business as a little bit more WCS levered and your downstream business more levered to light sweet crude. I'd be curious how you're thinking about that widening of the diff and how it impacts the way we should think about near-term profitability. Yeah. Thanks for the question, Neil. You know, I think you've characterized that right. You know, the upstream business at least Kearl and Cold Lake are tied to WCS differentials. You know, I contrast that to Syncrude, of course, you know, which sells a synthetic product, which is trading at a premium to WTI right now. For you know, for Kearl and Cold Lake, we are directly tied to the WCS differential. That has been under pressure. You know, what's driving that widening of the differential as I think we talked about in the past is a combination of multiple events both on the supply and demand side. You know, broadly speaking, over the last quarter and earlier this year, you know, a significant release of SPR barrels in the U.S., which, you know, have been providing some level of competition and offsetting demand for Canadian heavies. On top of that, with high energy costs, especially natural gas, we're seeing some refiners that are favoring a wider crude slate to produce their products. Then there's been some, you know, kind of near-term disruptions in refinery operations in the U.S. that also, you know, for short periods of time, have depressed the demand of the heavies. You know, lots of factors in play. You know, we think that many of those factors are resolving themselves, you know, as we move into the next year. We expect that differential to start tightening and moving, you know, back towards more normal levels. It’s gonna take a while to rebalance, I think. On the downstream side, I mean, you’re exactly right. We run more light crudes than heavy, but we do run some of our heavy crudes in our own refineries. You know, probably about a quarter of heavy grades. We’re able to take full advantage of that wider differential on the downstream. As I mentioned earlier, and Jon Wetmore mentioned, you know, the diesel crack spreads are extremely high right now. Having an integrated system like we do with both upstream and downstream assets, you know, allows us to, you know, kind of mitigate the effect of those wide heavy differentials on our earnings and cash flow. Yeah. Thanks for that perspective. I just wanted to go back to Kearl. Did I hear you right to say that you got up to 357,000 barrels a day at one point in October? Just how do you think about the sustainability of running above nameplate in fourth quarter? Then tie that into your OpEx per barrel when you're gonna run this hard. I would imagine the $20 a barrel is in sight. Just any thoughts there too. Yeah. Well, you did hear it correct. 357,000 barrels a day, that's our new daily record. There's lots of things that impact, you know, daily performance. It's not necessarily a reflection of a sustainable level for a whole week or a whole month. But obviously, having record production days contribute to an overall, you know, kind of high volume week or high volume month. That's what we're seeing at Kearl. We saw a convergence of, you know, great runtime in our crushers, great runtime in our processing facilities, but coupled with just great efficiency in our mine operation and high quality ore. All those things coming together in one day, you know, give us this sort of record results. Of course, our objective is to string together, you know, multiple record dates. Over the course of, you know, a month or a quarter, we expect there will be some planned downtime, and maybe some unplanned down-time, and those things will dilute the benefit there. Fundamentally, you know, we have continued to raise the bar at Kearl. That gives me great optimism in our ability to achieve this 280,000 barrels a day. You're exactly right. You know, when we look at our target of $20 US per barrel unit cost, having a strong denominator in that calculation is really important. The more volumes we can put through the facility, you know, with high fixed costs that we can dilute across or distribute across a number of barrels, you know, that brings our unit operating costs down and it lowers our break even and makes every barrel more profitable. That's what we're striving to, and we continue to feel good about our ability to get to $20 a barrel. Thanks, Brad. Thanks, Neil. This concludes the question and answer session. I would now like to hand the call back to Dave Hughes for closing remarks. Thank you. On behalf of the management team, I'd like to thank everybody for joining us this morning. also welcome you. If you have any further questions, please don't hesitate to reach out to anybody on the IR team here. We're always happy to follow up. Thank you very much. This concludes today's call. Thank you for your participation. You may now disconnect.