Good day, ladies and gentlemen, and thank you for standing by. Welcome to Cenovus Energy's Third Quarter Results. As a reminder, today's call is being recorded. Please be advised that this conference call may not be recorded or rebroadcast without the expressed consent of Cenovus Energy. I would now like to turn the conference call over to Mr. Jason Abbate, Senior Vice President, Investor Relations. Please go ahead, Mr. Abbate.

Thank you, operator, and welcome everyone to Cenovus’s 2023 third quarter results conference call. Please refer to the advisories located at the end of today’s news release. These describe the forward-looking information, non-GAAP measures and oil and gas terms referred to today. They also outline the risk factors and assumptions relevant to this discussion. Additional information is available in Cenovus’ annual MD&A and our most recent AIF and Form 40-F. All figures are presented in Canadian dollars and before royalties unless otherwise stated. We have also posted our results on our website at cenovus.com. Jon McKenzie, our President and Chief Executive Officer will provide brief comments and then will take your questions. We ask that you hold off on any detailed modeling questions. You can follow up with those directly with our Investor Relations team after the call. And please also keep to one question with a maximum of one follow-up. You're welcome to rejoin the queue for any other follow-up questions you may have. Jon, please go ahead.

Great, and thank you, Jason, and good morning everybody. I'll start this call with our top priority, which is always health and safety. At our offshore China operations, Liwan 3-1 recently achieved a significant milestone of producing 1 trillion standard cubic feet of natural gas sales with no serious incidents or safety events. This is truly an impressive record of safety, and the comprehensive pre-startup safety reviews conducted at our Toledo and Superior refineries resulted in strong process safety performance throughout the restart of these assets. These achievements underscore the importance of our values and safety commitments in the work that we do every day. And I'm proud of our staff for the hard work and effort that they put into achieving these milestones. Now, we forecasted earlier this year that we would see strength of our operations and the value of our integrated strategy in the back half of the year. Our third quarter results are a demonstration of that with both upstream and downstream businesses delivering strong operational and financial results. Our upstream business saw an increase in production to nearly 800,000 BOE per day in the third quarter, and combined with higher commodity prices, we generated an operating margin of about $3.4 billion. In the conventional business, production volumes were impacted by wildfire activity in Q2, but returned to normal rates in the third quarter. Our production increased over 127,000 barrels per day versus a second quarter number of 105,000 BOE per day. So, I'd again like to thank our staff and contractors that played an integral role in our ability to safely resume our operations following the unprecedented wildfire events. As our oil sands assets continue to perform exceptionally while following the execution of redevelopment programs and the startup of new well pads, both of which support short and long-term production growth. Production increased over 600,000 barrels per day versus the second quarter number of 572,000 barrels per day. At our sunrise oil sands production, third quarter production rose 17% to about 55,000 barrels per day. The asset continues to perform well, as we apply Cenovus operating processes, including the implementation of redevelopment wells, adjusting well designs, and operating parameters. Now, I expect the oil sands assets to continue their positive performance through the remainder of 2023 and beyond. We’ll remain focused on operational reliability in the safe and efficient execution of our growth capital and optimization projects with the Narrows Lake tie-back, Foster Creek Steam Edition, and new well pads at Sunrise being a few key examples that support short to medium-term growth plans. In our offshore segment, our Asia Pacific assets performed extremely well. The company achieved first gas from the MAC Field in Indonesia in September. In the Atlantic, the Terra Nova FPSO has now returned to offshore Newfoundland and is expected to produce first oil in the fourth quarter, while our West White Rose project is also progressing as planned with approximately 75% of the work completed to date. And we'll continue to advance the work for the regulatory dry dock of the CROs FPSO that will commence in January in preparation for the startup of the West White Rose project. So now, turning to the downstream business, the third quarter results generated much healthier operating margins from the refining and upgrading assets in our portfolio. Overall, our downstream business contributed over $900 million in operating margin with favorable crack spreads and tailwinds. Following a challenging first half of the year, the US manufacturing segment, we delivered on our expectations of getting the last of the refining assets online and running reliably. Following the purchase and startup of Toledo and the commissioning and startup of Superior, crude utilization increased significantly from 70% in the prior quarter to 88% in this quarter. This is largely due to Toledo having performed well at 90% utilization through the quarter. You also would've seen a sizable reduction in the unit operating costs in our US manufacturing segment with the majority of our refining assets running at or near full rates in the third quarter and a reduction in the overall operating costs associated with the startup of Toledo and Superior. At the Superior refinery, we achieved a safe startup of the fluid cat cracker in early October, while the startup of this unit was delayed. The business unit completed this complex work without compromising the safety of our staff and assets. And you will know that the Borger refinery is now undergoing planned maintenance, which will impact Q4 throughput. We were really pleased with the Canadian manufacturing segment. Crude utilization was 98% in the quarter with the Lloydminster upgrader and refinery demonstrating strong and stable performance in the ability to capture margins as heavy oil differentials widen. With the seasonally weaker crack spreads in the recent weakness in gasoline cracks, we're focused on optimizing our assets to maximize the economic result. We will continue to build on solid operational execution and reliability. We've demonstrated this quarter going through year-end. And I'd like to highlight our corporate and financial performance. In the third quarter, Cenovus delivered approximately $3.4 billion of adjusted funds flow with both upstream and downstream businesses demonstrating strong performance and contributions to operating margin. Through our base dividend share buybacks and partial payment of common share warrant obligations, we distributed over $1.2 billion directly to shareholders. In addition, the company's net debt was approximately $6 billion at the end of the third quarter. Long-term debt decreased to $7.2 billion after we purchased $1 billion of notes that were due between 2029 and 2047. We did see an increase in our working capital as compared to Q2, although this was driven by largely higher commodity prices. Looking forward, we remain focused on achieving our $4 billion net debt target and delivering 100% of excess free funds flow to shareholders at that time. So, in closing, we believe we've delivered a stronger third quarter in line with our expectations. We're focused on furthering the operational successes that we've achieved in the quarter and continuing to progress both short and long-term goals of the company. And with that, we're happy to take your questions.

Your first question is from Dennis Fong from CIBC.

Hi, good morning, and thank you for taking my question. My first one is just around the pay down of the warrant obligation. So, in the quarter as you highlighted, you did about $600 million. When you think about what's remaining for that, that obligation, as well as your cash returns back going into the fourth quarter, how should we be thinking about share buyback cadence, as well as any other considerations you're taking into going into the end of the year around the buyback? Thanks.

Yes, I'll turn that question over to Kam to answer, but you remember we did those warrant buybacks, I think around $22 and we did take the opportunity in the quarter to pay down about $600 million of that. So, I think there's about $111 million left that we need to pay. I think the deadline is early January, but maybe Kam you could talk a little bit about our thinking around share buybacks.

Thanks, Jon. Hey, Dennis. So, I think, a couple of things I would highlight. First off, Jon alluded to this, but the price at which we had transacted on those warrants is obviously a lot lower than where our share prices today. So, we made a very conscious decision to proactively pay that warrant obligation down in Q3 rather than continue to buy back stock. So, I'd say the principles around that aren't going to change; we'll continue to look at probably paying down that warrant liability in the fourth quarter. I think given where our share price sits today, I think it's not unreasonable to assume that we would pay the rest of that obligation in Q4. When you think about the rest of the buyback program and potential for variables, the approach for us has not changed. We're going to continue to test intrinsic value of the share price at a sort of flat $60 WTI price. If we continue to see opportunities to buy back stock, you should see us active in the market, and the goal is always to fulfill that 50% of excess free funds flow in any particular quarter, either through buybacks or through variable dividends. But we've been continuing to buy back stock through Q3. You'll continue to see us active in Q4, and I think part of that will also include payment of that warrant obligation.

Great. I appreciate that color, Kam and Jon. My second question here or just follow-up is shifting gears a little bit more to the operations side. Appreciate the color that you provided Jon on the flexibility of your downstream operations. I just wanted to ask a quick question about Superior in the FCC unit. As I recall that FCC unit is generally used to help finish gasoline. And through the third quarter, you were building some intermediate product. How should we be thinking about the opportunity set or how you're going to manage that inventory again, just given where gasoline cracks happen to sit and your ability to maintain flexibility within that particular refinery? Thanks.

Yes, I'll let Keith give you a fuller picture on that, but you're exactly right. The FCC is a big gasoline-producing asset, and one of the things we always look at is the forward markets and our ability to move the sales of that gasoline into higher netback periods. And so, we're always watching the winter-summer spreads and looking at that with an eye on containment as well. But maybe Keith, you got some additional thoughts on how we're managing gasoline at Superior in particular.

Yes. Thanks, Dennis. Obviously, Superior being the first stop on the mainline system, and the current rate of differentials, it does provide a significant crude advantage and something different than we had online at the end of 2022. So, we are pretty excited to have this asset up and running and fully operational. We will continue to look at the economics, and obviously, we will make economic decisions on when we run that inventory off. But in today's environment, we're still seeing relatively robust returns to do that. I think the other thing I'd offer up, Dennis, now that we have the integrated network up and running and the other assets up and running, we've been moving some of that intermediate inventory to other assets to run off those products and make finished product. And we've been doing that for a period of time.

Your next question is from Neil Mehta from Goldman Sachs.

Just some early thoughts on 2024 capital would be great. I think you guys do have some interesting growth projects in flight, and so can you help us think about framing this out, recognizing we're going to get a little more clarity on this year over the next couple of months?

You're exactly right. We are going to come up with a more formal budget release in December. But what we've been really trying to communicate to the market is that our capital spending over the next several years is going to be in the $4.5 billion to $5 billion range. So very similar to what you saw in 2023. In 2023, we made a conscious decision to put some capital to work on some growth projects that we have in the portfolio. These are very high-return, very efficient projects that we started funding in ‘23, and we'll continue to fund through next year and really through the planning period that we're looking at. But don't think that the capital budget is going to look much different than what you've seen this year in that $4.5 billion to $5 billion range.

And then to build off that, can you talk about what some of those key growth projects are in 2024 and that maybe that higher spend than perhaps some were expecting a couple of years ago? Some of it's because of differentiated projects, not just because of higher sustaining capital levels. So, providing a little more color on what those are could be helpful.

Again, we've been hopefully clear on differentiating what we consider to be sustaining capital and that's the capital to keep production flat in our fixed assets in a safe and stable condition from the growth capital. But again, these projects we started funding in ‘23 and we'll continue through ‘24, ’25, and ‘26. But maybe Keith, you might want to talk about the big four projects that we've got going on in particular.

Yes, sure Jon. And thanks for the question Neil. I just want to anchor first on the fact that we look at investments in these growth projects at the bottom of the cycle, and they all obviously meet the bar and are relatively low capital to get the growth that we're going to be talking about. As Jon indicated, we've kicked these off through the 2023 period and they'll continue through 2024. But we're pretty excited about the Foster Creek, the Christina Lake, Sunrise, and West White Rose projects all contributing about north of a hundred thousand barrels a day of growth. So, at Foster Creek, we're doing a steam expansion, we'll be able to kind of wrap that up in the 2025 time period and start ramping up steam and production that will add about 30,000 barrels a day of production in the 2026, 2027 timeframe. Christina Lake, we've been talking about this one for a while, but really, it's building a pipeline up into the Narrows resource and bringing that back and processing it at Christina Lake, which is a much different concept than we had probably five or six years ago in a way to access this resource at a much lower capital cost. We'll drop our SORs and we will see an incremental 20,000 to 30,000 barrels a day of production at Christina Lake. Again, this kind of starts ramping up in the 2025 timeframe and full production kind of in 2026. At Sunrise, we've actively worked on applying Cenovus technology since acquiring the asset. We've spent a bit of time with infills and re-drills and redevelopment wells this year, and so you're seeing production kind of north of that 50,000 barrels a day. We're adding pads; the last time a pad was added at sunrise was in 2017. So we have a whole pad development program. The first one we'll be steaming at the back end of 2023 and through 2024. We're also adding additional pads. So, through that 2025 to 2026 timeframe, you can see us fully getting the full utilization of all the steam capacity at the asset, which should drive production up into that mid-60s type range. So, we're going to see a 20,000 to 30,000 barrel-a-day growth at sunrise. And then on our East Coast project, the West White Rose project, this is where a bit more capital will be going in 2024 and 2025. As we finish that project, we're north of 70% complete. We hit some milestones on our gravity-based structure in the quarter. We'll be spending 2024 and 2025 to finish construction, tow it offshore, and commence drilling in 2025. We'll start seeing production growing in 2026 and peaking around 2028 at about an incremental 45,000 barrels a day. We're really excited about the growth projects and the volume it adds at relatively modest or low capital. To Jon's point, we're doing all this in that $4.5 billion to $5 billion capital range over the next couple of years. So, Shane, Neil, just what you should be thinking about is for your model, you should be thinking kind of in the $2.9 to $3 billion range for sustaining capital and then the residual being growth.

Your next question is from Menno Hulshof from TD Securities.

Good morning. So, I've got a couple of follow-up questions from some of the prior questions. So maybe I'll start with a high-level one on the operational outlook for downstream. Scale of one to ten, where do you think you are today on a downstream performance from a pure operational perspective relative to where you'd like to get to, and then where else do you see room for improvement within US refining?

Well, I'm going to let Keith answer the specifics on this, but what I would tell you is refining is a core part of our business. We have built a heavy oil value chain that we think has significant value to the shareholders. And we think it's actually quite unique in its construct. Our goal is to be as good at running the downstream as we are our thermal assets. That's not necessarily going to happen overnight, but that's the trajectory that we're on and where we want to take this piece of business; refining and upgrading is an absolutely core part of this business. What you'll see from us over the coming years is a continued focus on sweating these assets, grinding out value, not just on the operating side in terms of reliability, throughput, and the like, but also on the commercial side of this business and making sure that we're making all the right decisions and capturing as much margin as possible. But maybe I'll turn it over to Keith. I don't know that he's going to give you an answer on one to ten, but I think he'll give you some indication of where we think we are.

And I think I just got some direction. So, basically, you've got to think about kind of what the downstream organization has been through; Superior has been down for about five years, and we've now safely restarted that refinery and are pretty excited about it. Toledo kind of came through an event and then a winter freeze event as well. The team there has successfully restarted and has run that refinery reliably since kind of the June timeframe. So, I'm pretty excited about where we are. I think we do continue to have opportunity though, and part of that opportunity is around the integrated nature of that value chain. Now that we're up and running and running reliably, we are actively looking at integration opportunities between Lyman, Toledo and ways to capture additional margin. Obviously, having around 120,000 barrels a day of heavy conversion capacity in today's differential market provides a lot of opportunity and flexibility to capture additional crude advantage at those two refineries. We're going to continue to work on our unit OpEx drop substantially in the US downstream in the quarter. We're going to continue to grind that even lower over the next several quarters and continue to work on our reliability and improve that. So, we're not stopping, but we think we have additional opportunity to drive down unit OpEx, improve reliability, and extract additional margin. The assets are up and running and performing well today.

Maybe I'll just circle back on West White Rose. It's 75% complete. You've got $440 million invested on a net basis since restart. How is that project generally tracking relative to your internal targets? And given that it's offshore, where do you see the most risk between now and 2026? Is it in the timeline or the budget?

Menno, we're pretty happy with where we're at. When we picked up this project, the gravity-based structure had kind of the base of the structure port. Over the past six to eight months, we've finished predominantly that gravity-based structure. We have all the necessary contracts in place for the remainder of the project. The topsides are essentially mechanically complete down in Texas. We're going to start progressing through the commissioning phase. All in all, things are lining up. I will remind folks though, we do have an asset life extension on the FPSO, and that will take about nine months here in 2024. So, we will come off station in early January and come back on production in late August, early September. That extension really is setting us up for the drilling activity that will happen in 2026 and making sure the asset can stay in place to kind of end of life. So, all in all, I would say it's a big project, but it's trending well according to our expectations on both cost and schedule.

Your next question is from John Royall from JP Morgan. Please ask your question.

Hi, good morning. Thank you for taking my question. I just wanted to clarify one thing regarding capital allocation. It seems like you're including the warrant pay-down in your calculation for the 50% allocation. Any update you could provide on the potential timing for reaching that floor would be appreciated. Thank you.

Sure. We receive that question almost every quarter, so Kam, I think you’re familiar with this one.

Sure. So just on the warrant, so I think, John, I would just highlight, so when you remember the time when we announced the transaction on the warrant purchase, we did remind everybody that the warrant pay down will be included as part of our shareholder framework. So, to the extent that we pay that liability down, it will be included as part of that 50% of excess free funds flow that we allocate to shareholder returns. So as Jon mentioned, we paid $600 million of that through Q3 on top of the $360 million of buybacks we did. Going to Q4, you should expect us to probably pay that warrant liability completely, the remaining $111 million with the incremental, either going back to share buybacks or variable dividends. On your second question, just around the debt, I think what I would just say is right now the focus for us as the team has talked about is executing the base business, focusing on continuing to progress these growth projects, moving the downstream to continued improvement on reliability and sustained throughput. A function of our debt is really going to be dependent on that and commodity prices. I don’t think I can give you a timeline just given we've seen a lot of volatility in commodity pricing even in the last month or two. So, that timing is going to move around, but I would tell you the focus is absolutely in getting there as quickly as we can.

Yes, and John, I think that's the important piece: we are just operating this business with a focus on getting to $4 billion as quickly and prudently as we can. One of the things that you can count on us is that we will be on that trajectory until we get there.

Great. Thank you. Fair enough. You've mentioned being satisfied with your portfolio as it stands, but you've also expressed a desire to avoid 50/50 joint ventures. You still have one joint venture in the downstream sector that is pending, and your partner has now set a target for asset sales. How are you currently approaching that arrangement with WRB?

Yes, we've been really clear on that set of assets for years now. We have been clear that we want to own and operate those assets that we see as core. We've been also clear that we are more likely sellers of those assets than buyers of those assets. And we've also been clear there's a fairly healthy bid-ask spread that has persisted through time. I don't want to comment on what Phillips is proposing within their portfolio; what we're focused on is running the business, and we're quite happy with holding that JV for the long term if that's required.

Your next question is from Gregory Pardy from RBC Capital Markets. Please ask your question.

You've got lots of capacity on Trans Mountain. Just curious how you're thinking about timing, but perhaps more importantly, how will your marketing strategy work? So, will you sort of look to sell at the dock then to tankers? Or are you looking at something perhaps more integrated with markets in Asia and so on?

Yeah, I know, it's a great question, Greg. It's something we're spending a lot of time on, so I'm going to turn this one over to Drew because Drew's right in the middle of this right now.

Maybe to kind of speak on the premise of TMX. We're really pleased that it's still continuing and progressing and I think even with these latest route change approvals and whatnot, I think it's still pretty positive that that line is going to come into service here in Q2. You can expect from us that we're probably going to get a call online early in the New Year. With that we're going to see a working capital build in order to fulfill our volume commitment there. How we're thinking about that being one of the biggest shippers on that line is that we're also planning for some obvious startup variability. I mean, a line like that, it's pretty substantive in getting that operation up and running, and to a smooth rate is likely to take some time. We expect through 2024 to kind of manage that with probably a little bumpiness in all realities. So, how we're thinking from a marketing strategy is that we are going to initially be looking to secure some agreements and supply FOB at the dock itself. We want to see that get up to a good stable rate; however, we do have some intention to get into new markets. It gives us another great tool and a suite potentially into global markets. We've obviously got some good connections and access into Asian markets with some of our offshore work over in Indonesia and China. So, we are looking at that as a full suite of new market access for us. But we're going to do the right thing as we go into 2024, make sure that once they get up and operating that we can see the reliability of that get there, which I think will take a bit of time, and we'll step ourselves into FOB going onto the water at some point and accessing those new markets that TMX is going to allow us to go after.

We look forward to learning more about this as time progresses. This smoothly transitions into the topic of networking capital. I have a question for Kam regarding cash flow generation; clearly, there are challenges, especially with rising prices as Jon mentioned. What do you anticipate for the remainder of the year? I'm asking because the key question for you is when the company will reach $4 billion. I'm interested in your thoughts on this.

So just on the working capital, a couple of things I would highlight. When you look at Q2 relative to where we ended Q3, first off, we did book the liability associated with the warrant purchase, which was that full $711 million. So, we drew that down at the end of Q3 for $600 million. So that was partly what drove working capital up in Q3 relative to Q2. The second piece I would just say is when you look at our inventory, we didn't see a lot of change from a volume perspective relative to where we're in Q2, but obviously prices moved up significantly quarter-over-quarter, which is the lion's share of the increase that you've seen in the working capital. But as we move into the fourth quarter, it's obviously things continue to move around as we look at our marketing strategy on selling our barrels, but I don't expect a big change. And Drew kind of highlighted the one sort of more structural change that you'll see in Q1 when we add more barrels into the system for the line fill associated with TMX.

Your next question is from Manav Gupta from UBS. Please ask your question.

Could you provide some insight into the recent widening of WCS? What factors are contributing to this situation, and what do you anticipate for the spread once TMX is operational in Q2?

Sure. Good morning, Manav, it’s Drew. Great question. As you've alluded to, the crack or the differential has widened here, and that was not unexpected. We've had some incremental growth come out of the basin here over the course of this year. With condensate pricing being quite attractive, people are really moving a lot of sales volumes. So, we expected this to widen out. As I alluded to, with TMX coming on, I think in the near term people also probably saw some of those potential delays in construction issues that have kind of come out as of late. I think people probably shifted some of their positions on timing, but we fully expect as the line fill even starts here early in the new year, you'll start to see things already head down the path of tightening back up. As it comes into full operation in Q2 sometime, we do expect in the second half of next year for it to tighten back up to what we saw when we had some egress space here earlier this year and late last year. We would expect it to come down substantially from where it is, probably in the order of half of what we're seeing today. But that probably will not show itself until it's actually up and operational and probably gets through some of its bumpiness as it starts up.

Manav, I'd say one of the big differences this year from last year, and we certainly saw differentials widen last year when we had the keystone outage and the like, but with the upstream, sorry, with the downstream up and running and performing the way it is, does insulate us from a lot of those wider spreads that we were exposed to last year. While at a corporate level, we'd still like to see narrower spreads, we're much less exposed to that kind of widening through the fourth and first quarter this year than we were last year. Again, we're really pleased to have those refining assets up and running and performing well.

Perfect. I'm going to ask a follow-up question based on the response you provided to John. I got a whole bunch of questions on my Bloomberg, so I'm going to follow up on this, as it relates to those two assets. Is it more of a case of a price or is it more of a case that you always thought of Toledo as a core asset you want to operate, and these two don't actually fit that picture? Which one is it more? Is it price or is it more of they don't fit?

What I want to tell you is Toledo's an absolutely core asset for us. It consumes 90,000 barrels a day of heavy and it takes the molecules that we produce inside our upstream. It consumes Christina Lake and it consumes sunrise heavy oil, providing us insulation against heavy oil differentials and location differentials. So, it's an absolutely core asset for us and a key piece of infrastructure. What I don't want to do is give anybody the impression that we're doing anything other than focusing on our base business right now. Our core set of assets that we have, our intention is to continue to build on the operating momentum we have, drive our debt down to $4 billion, and move to a hundred percent shareholder payout. That is our focus right now. I understand there's rumor swirling, but they shouldn't be.

Thank you. Congrats on a great quarter and good to see downstream make a material contribution.

There are no further questions, which concludes our question and answer session. I will now hand the call back to Mr. McKenzie for the closing remarks.

Okay. Well, thank you very much, everybody. We certainly appreciate your interest in the company and wish you the best, and we'll talk to you again in the New Year. Thank you.

Thank you. Ladies and gentlemen, the conference has now ended. Thank you all for joining. You may all disconnect.