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Ovintiv, formerly known as Encana Corporation, is a North American energy and natural gas production and exploration company.

This year's Fortune 500 marks the 66th running of the list.

After a corporate reorganization completed in January 2020, the energy company formerly known as Encana (and headquartered in Calgary, Alberta) is now Ovintiv, headquartered in Denver. It produces oil and natural gas from a range of land holdings in the U.S. and Canada.

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Formerly known as Encana, Ovintiv was incorporated in 2020. Together with its subsidiaries, Ovintiv explores, develops, produces, and markets natural gas, oil, and natural gas liquids in North America, primarily in West Texas' Permian Basin, Oklahoma's Anadarko Basin, and Canada's Montney Shale, where Ovintiv recently grew in a $2.4 billion deal with Canada's Paramount Resources.

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Q3 2024

Ovintiv (OVV): Company Profile, Stock Price, News, Rankings

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Ovintiv

ovintiv

Good day, ladies and gentlemen, and thank you for standing by. Welcome to Ovintiv's 20 24 Third Quarter Results Conference Call. As a reminder, today's call is being recorded. At this time, all participants are in a listen only mode. Following the presentation, we will conduct a question and answer session.

For members of the media attending in a listen only mode today, you may quote statements made by any of the Ovintiv representatives. However, members of the media who wish to quote others who are speaking on this call today, we advise you to contact those individuals directly to obtain their consent. Please be advised that this conference call may not be recorded or rebroadcast without the expressed consent of Ovintiv. I would now like to turn the conference call over to Jason Verhaist from Investor Relations. Please go ahead, Mr.

Thanks, Joanna, and welcome, everyone, to our Q3 conference call. This call is being webcast and the slides are available on our website at oventive.com. Please take note of the advisory regarding forward looking statements at the beginning of our slides and under disclosure documents filed on EDGAR and SEDAR Plus. Following the prepared remarks, we will be available to take your questions. I'll now turn the call over to our President and CEO, Brendan McCracken.

Thanks, Jason. Good morning, everybody. Thank you for joining us. We announced another strong quarter yesterday. We remain very pleased with our operational and financial execution across the business.

We delivered net earnings of $507,000,000 or $1.92 per share and cash flow of $978,000,000 or $3.70 per share, beating consensus estimates. The cash flow beat was driven by both production and cost outperformance as we exceeded the top end of our production guidance ranges on all products and came in below the bottom end of guidance range on combined TMP and LOE. We generated free cash flow of $440,000,000 which was higher than the Q2 despite lower oil prices. We're excited about what we're doing to make sure that our operational excellence transfers all the way through to financial performance. With the extra production and lower costs we've delivered this year, we're on track to generate an incremental $200,000,000 more free cash flow.

We returned 60% of our 2nd quarter free cash flow to our shareholders via our base dividend and our 3rd quarter share buyback. Importantly, we continued to make progress on debt reduction during the quarter, repaying $210,000,000 for total debt at the end of Q3 at $5,880,000,000 I'll now turn the call over to Corey to discuss our Q3 results in more detail.

Thanks, Brendan. We delivered strong operational performance across the portfolio with 3rd quarter oil and condensate volumes averaging approximately 212,000 barrels per day and total production of about 593,000 barrels of equivalent per day, beating the high end of our guidance. The production beat was driven by the Permian and the Montney, where we continue to see strong well results and outperformance from our base volumes. Our Q3 capital investment was approximately 538,000,000 dollars almost at the bottom end of our guidance range. We met or beat guidance on every item continuing to build on our track record as an industry leading operator.

Our shareholder returns framework continued to balance the allocation of free cash flow to share buybacks with debt repayment during the quarter. We returned $240,000,000 to our shareholders through share repurchases of $162,000,000 and base dividends of $78,000,000 This represents a competitive cash return yield of approximately 9%. Since the inception of our buyback program in the Q3 of 2021 through the Q3 of 2024, we've repurchased more than 40,000,000 shares and distributed approximately $850,000,000 in base dividend payments for total shareholder returns of about $2,700,000,000 We reduced debt by more than $210,000,000 and our 12 month trailing leverage ratio was 1.2 times. In the Q4, we expect to direct $150,000,000 from our previously disclosed legacy disposition settlement to debt reduction. Dollars 50,000,000 of this has already been received and applied to debt reduction in October.

We continue to make progress towards optimizing our capital structure, decreasing our leverage and reducing interest expense. We also remain committed to our mid cycle leverage target of 1 times or about $4,000,000,000 of total debt assuming mid cycle prices. The maturity profile of our bonds will allow us to optimize our debt pay down schedule over the next couple of years as we work towards that target. Our continuous improvement in capital efficiency will allow us to generate additional cash flow and reach our debt target sooner. This bolsters the resilience of our business and enables us to withstand market volatility.

We remain investment grade rated with a stable outlook from all 4 credit rating agencies. I'll now turn the call over to Greg to discuss our operational highlights.

Thanks, Corey. Our teams continue to drive efficiency gains in every part of our business during the quarter. Across the portfolio, we've made significant strides in increasing the speed of our drilling and completions activities and reducing cycle times as a result. This is important for a couple of reasons. First, it shifts revenue earlier in time, which increases returns, but it also results in lower costs because many of the services in our business are billed by the number of hours or days on location.

In the Permian, this was our fastest quarter ever for drilling speed, which averaged more than 2,170 feet per day and was roughly 28% faster than the program average last year. On completions, our Q3 average completed feet per day was about 3,875. This was 21% faster than our 2023 program average. These cycle time improvements mean that we continue to drive our well costs lower. And during the quarter our pace setter well cost in the Permian was less than $600 per foot.

We recently dropped down to 5 rigs from 6 to better align the pace of our drilling and completion activities. We plan to run 5 rigs through the end of the year. We continue to see our 2024 Permian well performance tracking our type curve and we were able to essentially hold volumes flat quarter over quarter at approximately 124,000 barrels per day. We brought 154 wells online since the Q4 of last year and the performance is right in line with our type curve. As a reminder, the 2024 type curve is higher than our 2023 well results incorporating all the improved well productivity we achieved last year.

We remain fully confident in our ability to meet our type curve in the Permian, which is unchanged from the start of the year. In the Montney, we drilled an average of 18 20 feet per day, which was about 6% faster than our 2023 program average. We also drilled the longest well ever in the play in more than 18,000 feet. In fact, Ovendiv has drilled 14 of the 20 longest wells on record in the Montney. On the completion side, our Q3 average of over 5,100 feet completed per day was 24% faster than the program average last year and is on par with our trammel frac averages in the Permian.

Our Montney and well and condensate production averaged 32,000 barrels per day in the quarter and we plan to run 3 rigs in the play through year end. The Montney has the lowest well cost in the portfolio and our pace setter wells cost less than $500 per foot for drilling and completions. Supported by our oil and condensate productivity, the economics on our Montney wells remain outstanding. Even at current strip pricing, we expect to generate a program level IRR of more than 60%. Note that that over 60% IRR result assumes full exposure to strip AECO and our actual realized prices have been much better because of our price diversification strategy.

Moving to the Anadarko, we continue to benefit from the strong free cash flow generation from the asset, in part due to its exceptionally low base decline. Our 2024 program was designed to target the oiliest parts of our acreage. The early production from these wells has displayed 1st year oil cuts of more than 55% with about 85% of 1st year revenue coming from oil. The team has made significant progress on drilling speed, now averaging over 2,600 feet per day less than 8 days from spud to rig release or about 28% faster than the 2023 program average. This improvement contributed to our new pacesetter D and C cost in the Anadarko of about $500 per foot enhanced the economics of our 8 well program, which we completed during the quarter.

We currently have one active rig in the play, which we will continue to run through the end of the year. In the Uinta, our strong well performance combined with our continued progress on cost reductions has made the play competitive

to what we has made the play competitive in our portfolio with margins similar to what we receive in the Permian. Our largely undeveloped land base of approximately 137,000 net acres with about 1,000 feet of collective pay means we have significant scale and running room in the play. Our Q3 oil and condensate production of 29,000 barrels per day is consistent with our expected go forward run rate for production from the asset. As of the end of the Q3, we have brought online 27 net wells, our total expected turn in lines for the year. We recently resumed drilling in the play and we plan to run 1 rig through the end of the year.

Thanks, Greg. Capital efficiency and free cash generation remain the hallmark of our 2024 program as we work to generate superior and durable returns for our shareholders. For the 3rd time this year, we're increasing our production guidance while maintaining our targeted capital spending. We expect to deliver higher volumes across all product streams. This includes 210,000 barrels a day of oil in condensate, up 5,000 barrels a day from our expectations at the start of the year and up 10,000 barrels a day from our original outlook in June of last year.

4th quarter production is set to average 575,000 to 595,000 BOEs per day, with oil and condensate volumes of about 205,000 barrels a day at the midpoint. We expect 4th quarter capital investment to come in around $550,000,000 at the midpoint, and we remain committed to the midpoint of our full year guide at $2,300,000,000 Our 2024 program is repeatable in 2025 beyond allowing us to sustain approximately 205,000 barrels a day of oil and condensate production with capital investment of about $2,300,000,000 per year. In summary, we continue to deliver outstanding results. We're focused on maximizing the profitability of our business, generating significant free cash flow and maintaining our strong balance sheet. We take great pride in producing safe, affordable, reliable and secure energy, while delivering superior returns to our shareholders.

This concludes our prepared remarks. Operator, we're now ready to open the line for questions.

Thank you. First question comes from Gabe Daoud at TD Cowen. Please go ahead.

Thanks. Good morning, Brendan and team. I was hoping, Brendan, we can maybe start with your capital budget. Obviously, you've highlighted your guidance evolution on the volume front and you've increased that quite a bit moving through 2024. But the 2.3 has been pretty static, at least the midpoint of your guidance ranges this year.

So given the efficiency gains you've seen, can you maybe talk a little bit about that 2.3% number and how that trends into 2025?

Yes, for sure, Gabe. Yes, thanks for the question. I think what I'd say is we have definitely stepped the guidance up as we've gone through the year and it's worth reminding ourselves of the production shape that we had planned for this year. And when we closed the ENCAP acquisition, we had a huge number of wells in progress and we were significantly slowing the activity level down in the assets to run them for free cash and returns. Now obviously that integration has gone very well and credit to the team, but we still have that overriding shape in our production profile on where we're landing the oil run rate at a new stable level of 205,000 barrels a day.

And so we originally guided that landing to come in the first half of this year, but outperformance has pushed that landing now into the Q4, which is a fantastic outcome for free cash. And we'll continue to optimize and tune the 2025 program and do our official guidance with our year end results. As you point out, lots of things going in the right direction, but we're still in the midst of pricing for next year on services and equipment and planning the detailed program. So don't want to get out over our skis. And so for now, the $2,300,000 $2,305,000 is the right way to think about next year.

And remember, that's 5,000 barrels a day higher than our original guide.

Got it. Okay. Thanks, Brendan. That's helpful. Obviously, stay tuned for some more formal details.

And then I guess just as a follow-up, maybe can we get your updated comments on M and A and the A and D markets generally? There's been obviously a number of media reports related to you guys. So would love to just get your updated thoughts on all of that. Thanks, Brennan.

Yes, Gabe, for sure. So I mean really a consistent message from us on this topic. What I'd say is acquisitions have an extremely high hurdle for us. We've built up a very high quality portfolio with a deep inventory in each asset and we're extremely disciplined about how we steward our shareholders' capital. And as you can see from our results and our focus, we're really focused on execution and driving free cash flow out of the business.

Thank you. The next question comes from Neal Dingmann at Truist Securities. Please go ahead.

Good morning, Bren and team. Another excellent quarter. My first question, Bren, is maybe on your notable continued efficiencies that we even saw this last quarter. I'm just wondering specifically, the last few quarters, you all have notably outperformed production forecast using what I certainly what seems to be less expected capital. I'm just wondering, could you give me an idea of maybe some of the bigger drivers around this?

Is it certain areas are outperforming or different things that Greg and the operation teams are doing? I'm just wondering what would have been the drivers of this continued upside?

Yes. Thanks, Neil. And yes, really it's been a very intentional exercise and a lot of the really everything we are doing from an innovation perspective is driven in the service of generating more free cash from the business. And so I'll talk a bit about some of the operational things like you asked, but I would also say it extends all the way through the business to our bottom line financial performance to drive that incremental free cash. And I'd say, look, this is a skill we've built up over time.

And like you pointed to, the results are speaking for themselves. We did investor tours in both the Permian and Montney this year. And really what we're doing there is showcasing the sophistication and cutting edge work that our teams are doing. So a few things I'd point to. What started a foundation really has been our data strategy.

So a lot of what we do is analytical and engineering and geoscience work and you have to have great data to do that with. And over a number of years here, we've built up a unique private data set across North America that I think has given us a real edge to understand true causality. And then second, we've kind of combined that with a real lean in on our culture of innovation where throughout the entire team everybody is engaged on being curious and trying to find those new opportunities. And one of the things we showcased on those Montney and Permian tours this year was the AI machine learning automation that we've deployed not only in our D and C operations, but also in our production operations. And we're excited about how those things are leading to best in class drilling and completion speed and costs, but also lowering our base decline across the portfolio.

And maybe the final thing I'd leave you with is really working hard to break down maybe a bit of an industry bad habit around being insular within the company walls. And one of the things we often say is the only infinite rate of return available to us is learning from another operator's risk capital. And we've been really outward focused at studying and watching the leading edge things that our peers are doing and then backward incorporating those back into our business. And finally, I would just say to your question, it's really spread across all the assets. We've been working hard to create collaboration across each asset in the portfolio and move those ideas rapidly around the company.

So a lot there, Neil, but it's an important part of the story.

No, very detailed. I appreciate that. And then maybe second question for Greg. We'll maybe on the same line a little bit. Simply, just Greg, I like the slide that you talked about and it's notable to optimize Permian program.

And I was just curious, when you look at it today versus maybe a year ago, are things like D and C activity or logistics, I'm just wondering where you're seeing it? You noticed a couple of wells that cost are now coming down, but the returns are at record levels. And I'm just wondering, is that largely driven through more e fleets and completions or what are you doing to sort of set these records?

Thanks for your question, Neil. And it's as Brendan was mentioning, it's really the combination of a lots of things that the teams are working on to improve our execution efficiency and drive down cycle times, which ultimately results in higher returns and more free cash flow. It's a combination of high performance rigs. It's the better frac fleets. When it comes to e fleets, they're a great part of the fleet and part of the improvement, but it really comes down to whatever equipment you're using, how well you can execute with it.

We always point to there's 3 things you can do to improve returns. That's place laterals in the right place, design your jobs to optimize productivity per foot. We also look at increasing lateral whenever we can and then finally just drilling and completing wells as quickly and efficiently as we possibly can. And the teams are working on all of those fronts, which is what's showing up in the strong execution and performance. As Brendan mentioned, that's allowed us to push back that landing zone in the Permian back to the Q4.

And going forward, if we think about the Permian and specifically, we've gotten to a point where we feel like 5 rigs and 1 frac crew will get our whole program drilled. And that same match of rigs and frac fleet will do a lot more feet now than it would have done a year ago. And so that's why we dropped from 6 rigs down to 5, but we feel like that's kind of the go forward status quo for us is running 5 rigs and a frac crew and just being as efficient as we can using all the different technologies that are available to us.

Thank you. The next question comes from Neil Mehta at Goldman Sachs. Please go ahead.

Yes. Thanks so much guys. 2 relatively easy questions for me. One is, one of the big debates of this earning season is how to get the most amount of value out of your natural gas molecule, not only just in the context of Waha, but given basis issues and then the long term demand story that we see for natural gas. So just curious, Brendan, how you guys are shaping your business to maximize the capture on natural gas?

Yes, absolutely, Neil. We're very pleased to see even though it's a low number, it's probably better than industry number on gas realization for us the last couple of quarters. And I think that reflects the strategy you're pointing to. And really what we've been doing is based on diversification. So we produce a lot of gas in the Western Canada market and in the Permian.

And both of those markets have been horrific for gas prices through the summer months. And so what we set up over the last several years is basin egress out of both of those places. So really tried to minimize our exposure to those two markets and that has been paying off. And so really we're kind of continuing to lean into that strategy. With the acquisition in the Permian, we picked up a bunch of Waha exposure with that with those assets and we just recently secured some additional capacity starting late next year to egress gas out of the Permian.

So we'll be kind of bringing that pie chart that's in the appendix slides of ours back into kind of more normal place for us where we're getting most of our gas outside of AECO and most of our gas outside of Waha.

Okay. That makes sense, Brennan. And then you talked a little bit about the Uinta in the deck, but just curious on your perspective of monetization of that asset, how we should think about whether that asset could trade and any comments you would have on the process there?

Yes. No, for sure, Neil. And I think pretty consistent message here from us. We're always thinking about how we can create value with our portfolio. That's our job.

But we focus down to the 4 assets that we have today, and they're all great assets. They're competitive for capital, delivering consistent returns across the portfolio. And with the Uinta, what's really helped there is getting our margin competitive. And then the team has been working to drive down drilling costs. So yes, I think that's where I'd leave it.

Thank you. The next question comes from Doug Leggate at Wolfe Research. Please go

ahead. Thanks. Good morning, everyone. Thanks for taking my questions. Brandon, 2 kind of philosophical questions, I guess.

When you look at the extraordinary progress you've made with every other quarter, you're doing a new pacesetter well in one of your basins. It seems that as we look to 2025, there's a choice coming for Ovintiv, which is take the efficiency gains and ultimately, I don't know if it was in your mouth, deliver a higher production number or take the efficiency gains and cut capital. And I'm not again, I'm not trying to get in front of the 25 guide, but it seems that you're going to have some options given to you by the strength of your operations. Which of those 2 would you rather take, higher production or lower capital?

Yes, it's a great dilemma to have. And what I'd say is we'll be driven by value and really free cash generation. So the kind of couple of the parameters that we'll look at as we make those decisions is going to be how do we feel about the macro? So is the world looking for more barrels and BTUs? And then also how do we look from a low level perspective?

Because we really feel like the efficiency gains that the low level program that we're set up for is helpful. So if you look at what we did this year, we chose to kind of let production float up and harvested the free cash flow there. We found that to be the more accretive choice. And so we'll do the same calculus next year. And if the world turns out a little more bearish and it makes sense to pull the capital back and just kind of keep the volumes flat, then that's the choice we would make in that instance.

Okay. And we will watch for the guidance. Thank you for that. I did say I had 2 philosophical questions and you have to forgive me for the second one. Your execution wise, it's been flawless pretty much since you took the helm.

You've done your share of deals. You're a $10,000,000,000 company in a $2,000,000,000,000 sector. It's kind of tough from our discussions, at least with investors, given the commodity backdrop to differentiate. And despite everything you're doing, your share price is ultimately exposed to the whims of the market. Are we going to buy energy?

Are we not going to buy energy or whatever? So my question is, how do you gain relevance? Putting good assets in the hands of good strong management is a way to create value. But I wonder, do you think you have the scale to compete for investor dollars? And if not, what might you do to change that?

Yes. And again, I would say the driver here is going to be shareholder value. We're always engaged in a strategic conversation around how we do that and what's the most effective way to do that. I would say philosophically, I think there is always going to be a space for a strong independent part of the E and P landscape. The innovation and efficiency gains tend to be driven from that group and we're certainly at the forefront of doing that.

I think from a scale perspective, look, I think there is an investor relevancy scale, but I think we're there. We continue to have a lot of engagement and don't see that as a barrier as we sit here today. But look, we're always looking for how we create the most shareholder value.

Could I maybe put a part B on that and ask you if you would care to comment about whether you're currently engaged in any particular M and A discussions?

As you know, Doug, we're not able to ever comment on that. So great I can't answer that one.

Thank you. The next question comes from Tallek Amin at Bank of America. Please go ahead.

Hey, good morning guys. Thanks for getting me on. I guess my first question is on Permian oil. It seems to be holding up a little bit better than expected here. It's still above your soft guide of $115,000,000 to $120,000,000 So aesthetically, it looks like you've already mitigated the decline from the Endcap transaction.

When do you think that you'll have a better understanding of where that's going to settle out?

Well, yes, I think, Kalei, great question. What we pointed to here was landing that at around 120,000 barrels a day and really seeing that landing happen in the Q4 here. So we pushed that kind of production up through the middle part of this year, which is great because it let us harvest more free cash and more value and so we're kind of in the midst of that landing right now.

Got it. And I appreciate that. My second is a follow-up on the operational improvements. The stat that jumped out this quarter was the drilling times in the Permian. If you were to extrapolate those cycle times for 2025, how many more wells do you think you'll drill in 2025

over? Yes. I think if you looked at our, TILs for this year, it would put us in the upper end of that Till range, year over year.

That's great color. I appreciate that. Thanks.

Thank you. The next question comes from Arun Jayaram at JPMorgan. Please go ahead.

Good morning. Brendan, I was wondering if you could discuss your thoughts on the implications of LNG Canada, which could start mid next year and implications you think for the Canadian gas market and as well as your position in the mining?

Yes. I think look this is going to be a long term great thing for Canadian gas. I think LNG Canada could start up early 2025. We don't have any special insight there, but that would be kind of the best steering we would have and then ramp up through the year. So you're talking about 2.2 Bcf a day of incremental takeaway, which is a big share of the Canadian gas market.

But what we see when we look at the landscape there is a number of gas leveraged operators have drilled into that upcoming capacity. So perhaps not unlike what we see in the Permian where egress fills relatively quickly, new egress fills relatively quickly. That's probably going to be the dynamic that we see with LNG Canada. So we would say AECO is going to tighten, but it probably might have a bit of a transitory feature to it. So that's kind of been a cautious tone that we've taken.

And anything better than that is upside for us. And then of course, what we're really excited about is some of the projects coming in behind LNG Canada Phase 1 that probably are more towards the end of

decade, but offer even more egress out of the basin and will continue to support AECO pricing.

Brendan, I was wondering if you could characterize what you're seeing in the AND market. Obviously, a large trade potentially in the Midland Basin. But just thoughts on what you're seeing and the ability to maybe leverage what looks to be one of the lower cost structure in the Permian Basin and other basins to your advantage?

Yes, Arun, for sure. I think probably the biggest notable feature has been the increase in valuations that have been paid in the A and D market from when we did our deal. And so for us, acquisitions have a very high hurdle because we've already built up a really high quality portfolio with a deep inventory there. So we're just very disciplined with how we're stewarding the shareholder capital and that's how you should expect us to behave.

Thank you. Next question comes from Jeff Jay at Daniel Energy Partners. Please go ahead.

Hi, guys. I just have one. I noticed you said that 60% of your Permian completions were Triangle Frac. I'm wondering if that's sort of a good go forward rate for your 2025 plan or if there's upside to that 60%?

Yes, I think that's a decent place to start. We're still putting the final details on next year's plan. So it could move around a little bit, but clearly we've marched up over the course of the year and with more and more of the program in triamal frac mode. So it's probably a decent place to start for 2025.

Thank you. Jeff, you donated your extra question to Doug, I guess.

Thank you. At this time, we have completed the question and answer session. And we'll turn the call back to Mr. Voorheist.

Thanks, Joanna. Thanks, everyone, for joining us today. Our call is now complete.

Ovintiv (OVV) Q3 2024 Earnings Call Transcript

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