ConocoPhillips Q2 2024 Earnings Call Transcript

Quartr
Provided by Quartr
August 1, 2024

Key Takeaways

  • 34% dividend hike: ConocoPhillips will boost its ordinary dividend by 34% starting in Q4, incorporating DRock into its base payout and targeting top-quartile growth vs. the S&P 500.
  • Record Q2 output and upgraded guidance: Q2 production hit a record 1.945 MMboe/d, driving a raise in full-year guidance to 1.93–1.94 MMboe/d (∼3% organic growth) despite planned turnarounds.
  • Marathon Oil deal on track: The ~$21 billion acquisition of Marathon Oil is expected to close late Q4, pending an August 29 shareholder vote and FTC review, with $500 million of synergy run-rate savings within one year of close.
  • LNG portfolio expansion: The company has secured just under 6 MTPA of LNG placements through 2027, signing new Europe and Asia regas agreements, and aims to grow to 10–15 MTPA of offtake in coming years.
  • Higher operating cost outlook: Although DD&A guidance was lowered to $9.3–9.4 billion and corporate losses pared, adjusted operating expenses are now forecast at $9.2–9.3 billion due to increased transportation, processing and inflationary pressures.
AI Generated. May Contain Errors.
Earnings Conference Call
ConocoPhillips Q2 2024
00:00 / 00:00

There are 15 speakers on the call.

Operator

Welcome to the Second Quarter 2024 ConocoPhillips Earnings Conference Call. My name is Liz, and I will be your operator for today's call. At this time, all participants are in a listen only mode. Later, we will conduct a question and answer session. I will now turn the call over to Phil Gresh, Vice President, Investor Relations.

Operator

Sir, you may begin.

Speaker 1

Thank you, Liz, and welcome everyone to our Q2 2024 earnings conference call. On the call today are several members of the ConocoPhillips leadership team, including Ryan Lance, Chairman and CEO Bill Bullock, Executive Vice President and Chief Financial Officer Andy O'Brien, Senior Vice President of Strategy, Commercial, Sustainability and Technology Nick Olds, Executive Vice President of Lower forty 8 and Kirk Johnson, Senior Vice President of Global Operations. Ryan and Bill will kick it off with opening remarks, after which the team will be available for your questions. A few quick reminders. 1st, along with today's release, we published supplemental financial materials and a slide presentation, which you can find on the Investor Relations website.

Speaker 1

2nd, during this call, we will make forward looking statements based on current expectations. Actual results may differ due to factors noted in today's release and in our periodic SEC filings. We will make reference to some non GAAP financial measures. Reconciliations to the nearest corresponding GAAP measure can be found in today's release and on our website. 3rd,

Speaker 2

when we move to Q and

Speaker 1

A, we will take one question per caller. With that, I will turn the call over to Ryan.

Speaker 3

Thanks, Phil, and thank you to everyone for joining our Q2 2024 earnings conference call. It was another busy quarter for the company. We continued to execute on our returns focused value proposition. We announced a 34% increase in our ordinary dividends starting in the Q4. We announced the planned acquisition of Marathon Oil and we further progressed our global commercial LNG strategy.

Speaker 3

Now starting with results, we delivered record production in the 2nd quarter with strong contributions from the entire portfolio. In the Lower forty eight, we still expect to deliver low single digit production growth in 2024 at a lower level of capital spending relative to 2023. Internationally, production continued to ramp up at Sirmont Pad 267 and the Montney in Canada, Bohai Phase 4B in China and 4 subsea tiebacks in Norway. And we continue to make strong progress at Willow and on our LNG projects at Port Arthur and Qatar. Now shifting to commercial LNG, we recently signed 2 additional long term regasification and sales agreements to deliver volumes into Europe and Asia, both of which will start in 2027.

Speaker 3

With these agreements, we have now secured just under 6,000,000 tons per annum of volume placement for our offtake commitments. And we continue to work new offtake and placement opportunities as we look to expand our commercial LNG portfolio up to 10,000,000 to 15,000,000 tons per annum in the coming years. Now regarding our planned acquisition of Marathon Oil, we remain very excited about this transaction and integration planning activities are underway to ensure a seamless transition upon close. The Marathon Oil shareholder vote has been set for August 29 and we are working through the FTC's second request that we received in mid July. We still expect to close the transaction late in Q4.

Speaker 3

On return of capital, we remain committed to distributing at least $9,000,000,000 to shareholders this year on a standalone basis. As we said back in May, we will be incorporating our DRock into our base dividend starting in the Q4, representing a 34% increase in the ordinary dividend. And consistent with our long term track record, we are confident that we can grow this dividend at a top quartile rate relative to the S and P 500. Finally, as we previously announced with the Marathon acquisition, we will be increasing our annualized buyback run rate by $2,000,000,000 upon closing with a plan to retire the equivalent amount of newly issued equity in 2 to 3 years. So to wrap up, we're pleased with our operational execution and we are looking forward to closing the Marathon transaction later this year.

Speaker 3

Now let me turn the call over to Bill to cover our 2nd quarter performance and 2024 guidance in more detail.

Speaker 4

Thanks, Ryan. In the Q2, we generated $1.98 per share in adjusted earnings. We produced 1,945,000 barrels of oil equivalent per day, representing 4% underlying growth year over year. And this includes the impact of 18,000 barrels per day of turnarounds. Lower forty eight production averaged 1,105,000 barrels of oil equivalent per day with 748,000 in the Permian, 238,000 in the Eagle Ford and 105,000 in the Bakken.

Speaker 4

Alaskan International production averaged 839,000 barrels of oil equivalent per day, also representing roughly 4% underlying growth year over year excluding the ceramide acquisition effects. Now this highlights the benefits of our diversified global portfolio. Moving to cash flows, 2nd quarter CFO was $5,100,000,000 which included over 300,000,000 of APLNG distributions. Working capital was $100,000,000 headwind, which was lower than our guidance of 600,000,000 dollars as the expected timing of some of our tax payments shifted into the Q3. Capital expenditures were just under $3,000,000,000 We returned $1,900,000,000 to shareholders in the quarter, including $1,000,000,000 in buybacks and $900,000,000 in ordinary dividends and VEROC payments.

Speaker 4

And we ended the quarter with cash and short term investments of $6,300,000,000 $1,000,000,000 in longer term liquid investments. Now turning to guidance. For the Q3, we expect production to be in a range of 1.87000000 to 1.91 1,000,000 barrels of oil equivalent per day. And this is inclusive of the 90,000 barrels per day of turnaround impacts that we discussed last quarter. The primary driver of that is our once every 5 year turnaround at Surmont, which will impact production by about 50,000 barrels per day during the quarter.

Speaker 4

For the full year, we have raised the midpoint of our production outlook reflecting strong second quarter results. Our new range is 1.93000000 to 1.94000000 barrels of oil equivalent per day, which implies roughly 3% underlying growth year over year. Our full year turnaround forecast continues to be about 30,000 barrels per day. On income statement guidance items, we have lowered our DD and A guidance to a range of $9,300,000,000 to $9,400,000,000 and we have lowered our annual after tax adjusted corporate segment net loss to a range of $800,000,000 to 900,000,000 dollars These decreases are partially offset by higher forecasted adjusted operating costs, which we now anticipate to be in a range of 9 point $2,000,000,000 to $9,300,000,000 primarily due to increased transportation and processing costs and inflationary pressures on the Lower 48. For CapEx, we expect to spend approximately 11,500,000,000 dollars Now this reflects strong progress on our Willow scope for the year as well as some additional capital allocated to Lower 48 partner operate activity that has highly competitive returns.

Speaker 4

On cash flow, we are increasing full year guidance for APLNG distributions by 100,000,000 dollars to $1,400,000,000 and we expect $400,000,000 of these distributions in the 3rd quarter. Additionally, we're going to have a $100,000,000 pension contribution in the 3rd quarter. Finally, regarding working capital, we anticipate a $500,000,000 outflow based on a tax payment shift I mentioned from the Q2 to Q3. And as a reminder, guidance excludes the impact of pending acquisitions. So in conclusion, we continue to deliver on our strategic initiatives.

Speaker 4

We remain focused on executing our plan for 2024. We're committed to staying highly competitive on our shareholder distributions and we're prioritizing towards closing the Marathon transaction. That concludes our prepared remarks. I'll now turn it back over to the operator to start the Q and

Operator

A. Thank you. We will now begin the question and answer session. Our first question will come from the line of Neil Mehta with Goldman Sachs. Your line is now open.

Speaker 5

Good morning, Ryan and team. Thank you for taking the time. My question is just around everything buyback. So if you could just talk about the share repurchase strategy and remind us between now August 29, you're probably going to be out of the market, but your commitment to come back in the back half of the year and get to that over $9,000,000,000 at or above the $9,000,000,000 dollars capital return number. So your perspective on taking advantage of some of the volatility and as you plan for the back half as it relates to share repurchases?

Speaker 4

Yes, Neal. We're very confident in at least $9,000,000,000 of distributions for the year. And if you look at things we've paid out about 40% of CFO in the first half of the year and that's despite having some restrictions on open market repurchases that are related to the Marathon transaction that we've had in place since May. And so as you look at things, as a result of those restrictions, our $4,200,000,000 of distributions in the first half, that's a bit below a $9,000,000,000 annualized run rate.

Speaker 6

But as you

Speaker 4

know, the proxy is now mailed out with regulatory requirements that we have in place, we're restricted from buying back any of our shares until that Marathon shareholder vote, but that is just right around the corner. That's August 29. And so to answer your question, once the Marathon shareholder vote is complete, you should expect us to be leaning into buybacks. And we think that's really important because we've consistently been one of our largest buyers of stock every quarter. And you can run the math on that.

Speaker 4

It's pretty straightforward. That's at least $3,000,000,000 of buybacks that you should expect in the third through the 3rd Q4. And that would put us really right in line with our long term track record of retiring about 5% of our shares on an annualized basis that we've had since the strategy reset. And then as Ryan reiterated in his comments that once we close Marathon, we expect to be increasing our annualized buyback rate by $2,000,000,000 That would put total annualized distributions at a run rate above $11,000,000 inclusive of the base dividend increase slated for the Q4. So yes, leaning into buybacks as we go through the remainder of the year and really quite a little bit of things to be looking forward to, pretty excited about.

Speaker 3

And Neil, I would add that, look, the share price has been frustrating to watch through the first half of the year and we get it. We've been out of the market due to the Marathon transaction. I would just remind everybody that the shareholders come first in our value proposition and that's been consistent since we reset in 2016. We retired over $400,000,000 of our shares over that period of time. And I think the average price per share that we purchased is somewhere in the $70 per share price.

Speaker 3

So it's been the program has been managed really well. If you look at cumulatively, our return of capital over that period of time from 2017 through what we expect to do the end of this year, that's nearly $57,000,000,000 of capital has gone back to our shareholder over that period of time, representing about 45% of our market cap today. So with the and why we're excited about the Marathon transaction is, this is going to be we're going to be bigger, but we're going to be better and we're going to have more free cash flow We're going to have more funds to distribute back to our shareholders. And we'll retire the shares, as I said in my opening comments, 2 to 3 years just based on our plans as we see it today. So this is an important question.

Speaker 3

It probably got some undercurrent around the share price performance, which we're not pleased with as well, but we're determined to be back in the market as soon as we can and then buy back the shares to hit our return to capital target for

Operator

2024. Our next question will come from the line of Doug Leggate with Wolfe Research. Your line is now open.

Speaker 7

Sorry, guys trying to turn off the mute button. How's everybody doing, Ryan? It was good seeing you a couple of weeks ago. Thanks for taking my questions. So I guess I got done out of a question last time.

Speaker 7

So I'm going to stick to one, but I want to make one comment very quickly and that is that market recognition of value Ryan flows through the dividends for companies of your size. So I commend you on your decision on the dividend decision and I think you only have to look at CNQ to see what I'm talking about. So congratulations on making that decision. My question, however, is on the deal you announced while I was out. And more importantly, the tax benefits that I don't think were really fleshed out on the Q and A.

Speaker 7

Marathon has a lot of legacy NOLs. And what I'm trying to understand is how you use that and whether or not that was incorporated into your risk view of synergies and if not what that could look like ultimately in terms of value?

Speaker 4

Yes, sure. Hi, Doug. This is Bill. Yes, Marathon had about $2,800,000,000 of NOLs as of the end of year last year of December 31, 2023. That's a tax effective value of about 600 $1,000,000 and we certainly expect that Marathon will be using a portion of those losses in 2024 prior to closing.

Speaker 4

But as you point out that this is a stock transaction. As such, we'd be assuming Marathon's tax basis in its assets as well as any of those net operating losses that they have or NOLs. And so just as a reminder, we're in a full tax cash paying position right now. And at today's pricing, we would expect to be able to use any remaining NOLs within the first 3 years or so. And so what I think is important about this is that we don't consider NOLs as synergies.

Speaker 4

We tend to think about synergies as things that we're going to be taking action on. So we didn't bring the NOLs up as part of the deal announcement, but yes, tax benefits are certainly something we consider as part of this transaction. They are real value.

Speaker 2

And Doug, this is Andy. And as Phil mentioned, we didn't include the NOLs as part of our synergies. But in terms of the synergy, things are progressing really well there too. We remain very confident of achieving that $500,000,000 synergy run rate within a year of closing and we see upside to that number. So our activities are now progressing well.

Speaker 2

As we mentioned previously, we expect this to be a pretty seamless integration. We stood up our integration teams. They're focused on reviewing the organizational structures and systems, so that we can be ready to close as soon as we get to go. So there are some obvious G and A synergies, primarily focused on the back office support, the corporate function duplication as well as system integrations. The other synergies that we're looking at are on the operating cost side of things.

Speaker 2

So there's clear adjacency of the operating areas, which is going to lead to efficiencies such as improved productive time of our field staff. We're also going to be able to rationalize the field office. And on the capital side, we've been really digging in here too. We've worked the cost saving opportunities from several angles here. A couple of examples would be our ability to run the consistent program of scale is going to drive savings.

Speaker 2

As we look deeper, we see opportunities to bring the use of our super zippers and remote frac operations to the Mountain Eagles position. So on the synergy side of things, we're progressing really well. We're going to be ready to go day 1 as soon as the transaction closes.

Speaker 3

And I'd say, Doug, I'd add just one last thing. I appreciate your comments on the dividend. Look, I'm probably the holdout on the team given the history and having to make the decision back in 2016. But look, the company has gotten a lot bigger. We've gotten a lot better.

Speaker 3

And we've gotten a lot we've lowered our cost supply, dramatically more resource, more free cash flow, more cash flow at lower prices as we've lowered our sustaining capital as well, balance sheet is in great shape. So it all lent itself to doing the dividend action that we're going to do in the Q4, consistent with the close of the Marathon transaction to your earlier comment. And lastly, on the we do this integration really well. Just look at our Concho experience, the Shell experience. We'll do this one really well and we will over deliver on the synergies.

Operator

Our next question comes from the line of Scott Hanold with RBC Capital Markets. Your line is now open.

Speaker 8

Thanks. My question is around LNG and I'd be interesting to hear about how your strategy is evolving, specifically your recent regas agreement at Zeebrugge and the Asia agreement. How are you thinking about regional targeting and contracting on the future takeaway to get to that 10 to 15 that you've stated out there?

Speaker 2

Hey Scott, this is Andy. I can take that one. As you mentioned, we have made further progress on marketing our LNG. We did secure 0.75 MTPA of regas capacity at the Zebrugge terminal in Belgium. And then we also entered into a long term sales contract with an Asian buyer approximately 0.5 MTPA.

Speaker 2

So these recent placements, take our total now from the 4.5 we previously communicated to 6 MTPA. I was reminded 2 of that is in support of the FTAs we have with Qatar. Now for competitive reasons, we don't talk too much about in advance where we're developing offtake sources or regas capacity. So as you see from this quarter, we're making really good progress on both fronts. And as we previously communicated, over the long term 10 to 15 MTPA would be a good range of capacity for us.

Speaker 2

At that size, we can achieve the full benefits of scale already across our organization. So I think we're really happy with the progress we've made this quarter and I think everything's on track to what we're trying to achieve here.

Operator

Our next question comes from the line of Betty Jiang with Barclays. Your line is now open.

Speaker 9

Good morning. Thank you for taking my question. So I want to ask about the upward movement in CapEx to the upper end of the guidance range, which was specifically attributed to Willow and then the non operator activity. Can you give us an update on how Willow is tracking versus your plan? And is that responsible for most of the increase in the budget?

Speaker 2

Sure, Betty. This is Andy. Maybe I'll start by just sort of clearing sort of the total guidance, then Kirk can take your Willow question directly. So we initially set a guidance range of $11,000,000,000 to $11,500,000,000 at the beginning of the year and that included a number of uncertainties including Willow. So we now have wrapped up a successful winter construction season and we're halfway through the year and we now have line of sight of achieving the scope of work at Willow around $1,500,000,000 to $1,700,000,000 this year.

Speaker 2

But any large projects such as Willow, achieving scope of milestones on time or early in the 1st few years is really quite critical. It sets the foundation for us for success and de risk our project execution. And I said the other area we specifically called out is the lower 48. Now there are a couple of moving parts here. We see an increase in our partner operated scope.

Speaker 2

And specifically here, when we're balancing our attractive low cost supply opportunities by partners, we're going to participate. And then also on the operating side of things, we are seeing more wells as a result of our efficiencies. So both the partner operating activity and the efficiencies, they're going to provide us some production benefit in 2025. So when we think about it, we're pleased with the scope of work we've achieved so far this year and then the scope we've locked in for the second half. Given we're halfway through the year, we're now comfortable guiding that capital for the total year is going to be about $11,500,000,000

Speaker 4

And Feddy, this is Kirk and I can get a little bit more color here on Willow specifically. Certainly as Andy spoke to, our strong execution and the accomplishments that we've realized here in the 1st part of this year just continues to give us a strong view of what will of capital will be here in 2024. And that's why we're moving into this $1,500,000,000 to 1 point $7,000,000,000 range. Again, it's just a function of really strong execution across our workflows and that is of course factored into our total company guidance. On any large projects such as Willow, achieving our scope and our milestones across the full suite of workflows from engineering through fabrication and construction all the way through supply chain in these 1st few years, especially having just taken FID here late last year.

Speaker 4

It's just critical and this sets the foundation for our success going forward as a project. Certainly, as you heard from me last quarter, our winter construction season here in 2024 wrapped up and we were able to achieve all the critical scope that we had planned here despite some pretty challenging weather that caused some early delays, but ultimately we were able to get all of that critical scope completed. On fabrication, the largest of our operation center modules, we completed ahead of schedule. Those modules shipped and they've now actually arrived in Alaska and we have plans to take offload from barge to shore here this month in August. Engineering is also on track and when we couple up the fact that we're just doing really well on engineering as well as wrapping up these operations center modules a bit early.

Speaker 4

It's allowed us and our contractors to roll directly from fab of the op center modules into the central processing facility modules. And we're able to do that actually a couple of months better than planned, which just puts us in a strong position as this as we set this foundation for the large project. In fact, we cut steel here just last month in July. So I'll wrap it up by again just reinforcing this 1st year post FID is important and it's also important in procurement. All of our major facility contracts have been landed and equipment orders.

Speaker 4

And in fact, we're now at a place where we can say 80% of our total facility spend is wrapped up within contracts and we continue to make progress on that here as we move into the second half of the year. So again, across all the workflows, just hitting these milestones early is really important and it gives us a lot of confidence to reinforce our prior guide on total project capital and we're still on track for a 2029 first oil.

Speaker 3

And Betty, I would step back to sort of very high level, a couple of comments on my side too. You shareholders should want us doing This is de risking the big project as Kirk described. And on the extra OVO work that Andy talked about, look, our choice is to cut back our operated program to hit some capital number for the year and that's not a good decision either. So rather than cut back an operating program just to cover for additional ballots we're getting from other operators, doesn't make a lot of sense to us given the cost of supply those opportunities. So we're wanting to fund both of them at this stage.

Operator

Our next question comes from the line of Steve Richardson with Evercore ISI. Your line is now open.

Speaker 8

Thank you. I wonder if you could just follow-up on that last comment, Ryan, in terms of activity in the Lower 48. So it sounds like a combination of more OBO and also maintaining your program.

Speaker 2

Could you talk a little

Speaker 8

bit about what you're seeing on the leading edge of service cost? And appreciate that that probably doesn't show up in the high level numbers in terms of the second half of this year, but if you could foreshadow kind

Speaker 4

of what you're seeing on

Speaker 8

the leading edge and what that could mean for 2025?

Speaker 2

Maybe I'll just start that and then Nick can talk to the details of Lower 48. So in terms of inflation and deflation, as we previously communicated, we're seeing a bit of a bifurcation this year with Lower 48 seeing deflation while ANI is experiencing some inflation. Now I'd say right at the margin, we're seeing slightly more deflation than we expected in the lower 48, while ANI is slightly higher than expected. But that's right at the margin. Overall, our full year expectation is still in the low single digit annual average deflation company wide as we previously guided.

Speaker 2

And I'll let Nick provide a bit more color on the Lower forty eight. But industry wide, what we're seeing, we've seen a 20% drop in rig and frac activity over the last 12 months, driven by efficiency gains and activity reductions. And those efficiency improvements are still resulting in higher production. Specifically to the Lower forty 8, we are seeing high single to low double digit deflation in some of our key spend categories.

Speaker 1

Yes, Steve. This is Nick. Just a little more commentary for the first half, we've seen continued deflation around pumping services. The proppant, there's an oversupply of proppant out in the Permian. So we're seeing some price reduction in there.

Speaker 1

We think that will continue into the second half. And we spoke about OCTG as well. We see that will probably continue in the second half as well. We will probably see a little bit of curtailment or decrease in deflation in the second half going into 2025 because we've seen fairly large gains over the first half of twenty twenty 4. But overall, we're capturing that.

Speaker 1

And when you look at Lower forty eight general, we'll have a full run rate. If you look from July through December, we'll capture that deflation. That's where we see the fact that our 2024 budget is modestly lower than 2023, primarily driven by that market deflation

Operator

capture. Our next question comes from the line of John Royall with JPMorgan. Your line is now open.

Speaker 3

Hi, good morning. Thanks for taking my question. So my question is on production. I'm just looking at your guidance for 3Q and then backing into the guidance for 4Q from your full year guide, it looks like a pretty steadily increasing profile throughout the year if I add back the turnaround impacts in 3Q. And I think that's in line with how you talked about the year generally, but maybe you could just give a little color on the moving pieces in production between the different regions as we progress the back half of the year outside of the turnaround impacts you've already called out?

Speaker 2

Sure. I can take that one. And I think the short answer is, yes, it is pretty steady when you adjust the turnarounds. We're expecting organic production to grow 2% to 4% in 2024 and that should be pretty consistent across the Lower 48 and Alaska and International. And as Bill said in his prepared remarks, organic production was up roughly 4% year over year in the Q2, which is towards the top end of our guidance, again with a balance across lower 48 in ANI.

Speaker 2

Now if you look at our production profile this year, and I think is what you were alluding to is that if you exclude the turnarounds, we're basically growing up 1% each quarter, it's pretty straightforward. The profile that was being a mast of it in the 3rd quarter as that's one of our heaviest turnaround quarters in some time with a 90,000 barrels a day of turnaround impacts that Bill mentioned in the prepared remarks. Maybe just to give a little bit more color on that, that 90,000 barrels is split 50 in Canada, 20 in the lower 48, 6 in Alaska, 5 in Norway and then 4 in Malaysia and Qatar. And in the Lower 48 specifically, now our Q2 actually outperformed our expectations. So we are expecting production to be fairly flat in the 3rd quarter and that's due to the turnaround I just mentioned to the 20,000 miles a day that we have at Eagle Ford.

Speaker 2

Then we'll be up in the 4th quarter versus the 3rd quarter. Bottom line, we're tracking right in line with our guidance just to quarter to quarter somewhat masked a bit with the turnaround activity that you're seeing.

Operator

Our next question comes from the line of Roger Read with Wells Fargo. Your line is now open.

Speaker 10

Yes, thanks. Good morning. Good morning, Rob. Maybe come back on the guidance side on the OpEx front. Obviously, you're talking about costs going up a little bit.

Speaker 10

You've talked about some of the things on the CapEx side. I didn't know if those were tied together like higher activity, higher costs. What part of this is kind of internal versus external? And broadly speaking, what are the inflationary pressures?

Speaker 2

Sure, Roger. This is Andy. I can take that one. As Bill mentioned in the prepared remarks, we have raised the guidance to 9.2 to 9.3 for the full year. Now about half of this is from our Lower 48 non operated position and then the other half is our own lifting costs.

Speaker 2

As primarily a result of the higher transportation and processing costs, some high utilities and some additional work over activity. And we have been experiencing some of these impacts in the Q2 and we're now incorporating those into the full year guidance. Probably another point I would make is that as a reminder, the Q3 is going to be our largest our large turnaround that I just referred to. So with that, we will actually see the Q3 to be the high point of the

Speaker 11

controllable costs

Speaker 2

for this year.

Operator

Our next question comes from the line of Ryan Todd with Piper Sandler. Your line is now open.

Speaker 12

Thanks. Maybe if I could follow-up on the LNG topics from earlier. Congrats on the 2 announced uptick sales that you have in LNG business. Maybe can you speak more broadly in terms of what you're seeing on as you've got out market to gas, what you're seeing more broadly on appetite and market dynamics for LNG sales contracts and maybe how you think about global supply demand dynamics over the next couple of years in those markets?

Speaker 2

Yes, I can take that one too in terms of what we're seeing. In terms of the offtake side of things, I'll maybe I'll comment from the offtake and the marketing. In terms of the offtake side of it, we're happy with our position and we continue to look for further opportunities that have competitive pricing and high likelihood of FID. The LNG pause is causing some questions from potential buyers on the timing of things. But again, against this backdrop, we've been able to sign 2 deals this quarter.

Speaker 2

And I think that clearly highlights the benefits of our permitted project. And in terms of the marketing of the LNG, we remain happy with the demand we continue to see both in Europe and Asia for new LNG. We're continuing to work opportunities across the globe and there'll be more to come on that as we address them. We don't talk too much about them in advance. But I'd say, big picture, we remain very constructive on LNG and the role it's going to play.

Speaker 2

And we're quite pleased with the progress that we're making to go our position out to the 10 to 15 MTPA that we previously communicated.

Operator

Our next question comes from the line of Neal Dingmann with Truist. Your line is now open.

Speaker 12

Good morning. Thanks for the time. My question is on the Permian gas takeaway and maybe Lower forty eight realization expectations. I'm just wondering, you all suggest you expect the Permian gas price to remain depressed and they can tell the more third party pipeline capacity is added. My question is, are you all thinking the pressure could be for several quarters ahead?

Speaker 12

And would you all consider curtailing anything until gas rebounds? I know you have mostly oil, so just enough there's anything to potentially curtail?

Speaker 2

Yes,

Speaker 4

Neal. So as we indicated on our Q1 earnings call, we expected Lower 48 gas realizations in the Q2 to be particularly low. You'll recall at that time Permian Basin pricings was printing negative. That is in fact how things played out for the quarter. You saw a negative Waha 1st a month and gas daily pricing through the quarter.

Speaker 4

So, yes, 1stmonthlower48 realizations were just under 20% of Henry Hub in the quarter. Now we've got a significant portion of our production is Permian Basin. We've said that we shipped to multiple markets out of the Permian, including the Gulf Coast and West Coast, but a sizable portion of our production does receive in basin pricing. And as we went through the Q2, there was increased maintenance activity in the Permian Basin that put downward pressure on pricing. The basin is pretty constrained right now, takeaways fully utilized, outages are an issue.

Speaker 4

We would expect that to trend to continue into the Q3. Relief is really coming later in the Q3 with Matterhorn pipeline coming on adding some significant takeaway. We think that's going to be really helpful for Permian Basin pricing as we look towards the end of the Q3 and end of the Q4 and should improve overall Lower forty eight capture rates as we go forward. The other thing I just note as you look at Q2, you think about the remainder of the year is that in the Q2, not only was Permian Basin pricing low, but a lot of the premium markets were impacted. California border pricing traded at a discount to Henry Hub, which is a bit unusual.

Speaker 4

Inventory levels were high, milder weather was going on. I would expect as we go out of the shoulder months and into the fall that that will resolve itself too. But the big thing we're looking for is additional takeaway capacity coming out of the Permian Basin with Matterhorn picking up and we've got a little bit of capacity on that. And then to your point about, would you think about curtailing? Well, as we've said repeatedly for ConocoPhillips, this is a pricing issue, not a flow assurance issue.

Speaker 4

And that's really important because we're primarily investing in oil producing opportunities in Permian Basin and we do not routinely flare. So being able to move that production is important. So, we're a long way away from looking at curtailing oil production, but we are looking forward to additional capacity coming out of the Permian Basin.

Operator

Our next question comes from the line of Leo Mariani with Roth. Your line is now open.

Speaker 6

I wanted to just touch base on a couple of your different operating areas from a production perspective. Eagle Ford volumes were up very, very sharply this quarter. And you also saw a pretty nice rise in your Canadian Montney volumes as well. So I was hoping you can give a little color around those. I mean, some of the jump in Eagle Ford production, somewhat temporary, maybe there was a lot of turn in lines and expect production there to moderate later this year.

Speaker 6

And also just on the Montney stuff, is that just going to kind of steadily grow? Just trying to get a sense of trajectory on that asset also. Thanks.

Speaker 1

Yes, Lee, I'll start here. So on the Eagle Ford, you're right. We're really encouraged with the production we hit 238,000 barrels equivalent per day versus the 197,000 from Q1. Take the group back, we had that frac gap that we had in the second half 2023 and then we reinstated that frac crew. And so you're really seeing the benefit in Q2 as we work through that inventory.

Speaker 1

So really encouraged with the wells that we placed online into Q1 and in Q2. So we've seen a strong bump in the production there. Wells are performing very strong throughout. Now as Andy mentioned on the turnarounds, we're currently going through as we speak large turnaround in Eagle Ford that's going as planned as expected. So we'll be slightly down on that.

Speaker 1

That's 20,000 barrels per day impact equivalent per day for Q3 and you'll expect to cap Q4 back up and running. So really strong performance on Eagle Ford overall.

Speaker 4

Yes. And Leo, you asked about Montney as well. We had a really strong start here in 2024, where in Q2 this last quarter, we averaged 43,000 barrels equivalent today. And I too can take you back a bit. That's more than double relative to same quarter last year.

Speaker 4

And then we're up quarter over quarter as well, roughly 3,000 barrels a day. And all that's just being driven by us bringing additional wells online as we seek to fill this new CPF2 capacity obviously that we commissioned here late last year. Also for Montney, our production rates have been in line with our type curves. So really pleased with how we're seeing those wells come online. And we do in fact continue to expect to modestly grow our production throughout 2024, albeit as you know and you've witnessed from us in the Lower 48, unconventional profiles, they can be a bit lumpy quarter to quarter.

Speaker 4

And so I'll guide you here a little bit. We do expect Q3 to be pretty flat to Q2, but then we'll start to see an uptick again here in the last quarter of the year. So of course, naturally, we're seeking to make sure our production remains in sync with this new processing facility and offtake capacity that having just added last year, again, it's 100,000,000 cubic feet a day of gas processing capacity and an additional 30 in both crude and condensate handling capacity with this new phase. And so having brought on the 2nd rig earlier this year, we're slowly ramping into that new capacity and we expect that to continue here modestly into the future. So just again pleased with how we're making some progress on our wells activities, their performance and then obviously everything that we're gaining from the experience we have in the Lower forty eight.

Operator

Our next question comes from the line of Kalei Akhamein with Bank of America. Your line is now open.

Speaker 13

Hey, good morning, guys. I'd like to follow-up on the gas discussion. You talked a little bit about how your Permian is well set up through year end. To the extent you can, I'd like you to expand on that and talk about how the macro is shaping up through the end of 2025. And longer term, maybe that macro gets a little bit more interesting due to power and exports.

Speaker 13

So as you sort of assess that change, wondering if you think your portfolio is appropriately positioned to exploit that kind of macro?

Speaker 2

Hi Clay, I can take that. It's Andy here. Maybe I'll start with the demand side of that and then we can talk about sort of how we might respond to that. So I think you set up the narrative pretty well there in terms of sort of we are expecting to see tailwinds in sort of gas demand for gas on the LNG side, data center size and transportation needs. So just the under construction LNG plants are going to add 10 Bcf to 15 Bcf a day over the next several years.

Speaker 2

And that's alongside the broader electrification trends. So there has been a lot of forecasts, I think we've all seen them on AI driven power demand And they're all constructive for natural gas demand. But I do want to point out it's important, because there are lots of different factors at play here, such as pace of those data center build outs, constraints on the power expansion, the expected improvement in efficiency. So we're still carefully working through that piece of the equation in terms of just seeing how material it's going to be over time. But absolutely, yes, we do see it driving demand.

Speaker 2

Then sort of going to the second half of the question, so do you know what does that mean for us? So in terms of our portfolio, we have a lot of gas opportunities in our portfolio that we're not currently developing today, a lot of dry gas opportunities. Also, we have a lot of associated gas, unconventionals and we could choose to basically target gassier parts of the unconventionals. But for us, the bottom line is, it's got to compete on a cost of supply basis where we are today to make the cut for our annual capital program. And the really nice thing about these gas opportunities is, if the demand is there and the support is there, we can pivot very quickly to the gas in our portfolio, if it makes sense and it's competing on the cost supply basis.

Operator

Our next question comes from the line of Bob Brackett with Bernstein Research. Your line is now open.

Speaker 8

Good morning. And I'll return to Willow project. It's perhaps $7,000,000,000 of CapEx. It's the biggest project I think on the North Slope in the last 20 years. And so I'll ask some questions that are a little nitpicky to get comfort around the durability of the project.

Speaker 8

And I guess on the facility side of spend, you mentioned the arrival of the operation center. The other pieces of the facility, I guess, are the drill pads and then the central processing facility. What's the design philosophy around those? And how do you get comfort that you're in strong control of those?

Speaker 4

Hi, Bob. This is Kirk. Yes, certainly good questions. We've been very proactive in how we plan this project out over the coming years. And certainly what you're hearing from me is how that's playing out for us, which is it's a combination of course naturally we're seeking to build as much of these modules outside of the Alaska North Slope where we have pretty challenging weather conditions.

Speaker 4

It's remote and it takes a lot of effort and a lot of planning to do what we can do each winter within those winter construction seasons. And so we've been very purposeful in how we identify areas in which we can aggregate and build these large modules off-site, whether it be in Alaska or in other regions globally and build those certainly with preferred contractors and partners that can progress those with us. You've heard how I've described we've locked up bulk of our spend upwards of 80% of our total facility spend in the fabrication as well as in the construction of all of this, whether it be off-site through the modules. Obviously, we have to work on the transportation, sea lifting those into Alaska. We're still making a few truckables, and pieces of work that are appropriate that we can do there in Alaska and exploit the talent and the labor markets that we have in Alaska.

Speaker 4

And then of course, we're transporting all of that to the North Slope. And these are across multiple winter construction seasons, which is why you hear me describe the good work that we had this year. We do actually have expectations of even more work next year in 2025 on the North Slope. And again, that's all weather dependent. And this is why it's so important for us when we have good weather to knock that scope out, scope done.

Speaker 4

We expect to have our peak activity both in fabrication and construction in Alaska across 2024 and the 2025 years, expect that to stair step down. But again, that's premised on good weather, strong line of sight to our contractors. And so we just feel like we've got a really strong foundation to how this project is starting just immediately post FID. So we're really happy with how all this is looking for us, Bob.

Speaker 3

And Bob, I'd add a couple of other things just from my long term experience on the North Slope. This is, I don't know, 25th or more drill site that we've built on the North Slope. They're all truck and lateral designs. They're the same design that we've done on drill sites for the last 10 or 15 years. So we know how to do them.

Speaker 3

We've done a lot of them and this isn't any incremental scope. And then on the central facilities to your question, we've done both. We've stick built facilities on the North Slope during our winter construction seasons and we've built them off-site and sea lifted them up. And the important part for Willow was the size of the opportunity there for us and the size and scope of the facilities lent themselves to off-site fabrication. And I think the team did a great job hitting the window pretty well on the Gulf Coast.

Speaker 3

When there was ramping down of activity, we could slot our project in pretty quickly, get the good productivity. And then as we've already demonstrated our ability to sealift the facilities up to the North Slope, has gone really well with the first set of facilities showing up. So that's an important distinction because a lot of stick built on the North Slope, but the size of Willow to us demonstrated the need to go off-site and build it on the Gulf Coast, get it take advantage of better productivity and year round building and then ship to the North Slope. So that should give you some comfort. We know what we're doing.

Speaker 3

We've done this before. And these are just repeats of stuff we've done in the past.

Operator

Our next question comes from the line of Kevin McCurdy with Pickering Energy Partners. Your line is now open.

Speaker 1

Hey, good morning. To build on the earlier question about CapEx, your first half CapEx was in line, but now you're pointing to that kind of the high end of the range for the year. We would assume that the Willow spend is more geared towards Q4. But when do you see or when do you expect to see the higher activity and CapEx from the partner operated activity? And how material is the production impact for that activity?

Speaker 1

Yes. Let me jump in here, Kevin, and then if Kirk, you want to add anything on this as well. Maybe I'll just take you back to the total capital for Lower forty 8. As Ryan mentioned, we expect capital to be modestly lower compared to 2023 mainly driven by that market deflation. Now on the operated side, we as we've mentioned before, we are fairly flat on rig and frac crew counts and that's driven by that improved operating capital efficiencies that we continue to realize through 2024 and we'll have deflation capture.

Speaker 1

Now on the non operated side to your point, capital is higher as we've seen higher amount of Permian non operated ballots than anticipated relative to the 2024 guidance given. So that's higher activity. And as Andy mentioned, we'll continue to participate in those. Now these investments are attractive within our cost supply framework and are competitive operator operated program. We've seen that through 2Q especially and that's why we've raised guidance.

Speaker 1

We do detailed analysis on all of these as we go through our cost supply framework. Now if I look in the second half of this year, we'll continue to realize the benefit of the deflation. And like we've seen in previous years that non op activity typically tails off kind of the back end of Q3 and then Q4. So we expect that as well. So again, just kind of circling back, our capital for the year is just modestly lower than 2023.

Operator

Our next question comes from the line of Paul Cheng with Scotiabank. Your line is now open.

Speaker 11

Hi, thank you. Hey guys, good morning. Maybe this is Ryan or maybe just for Bill. If we're looking at for 2025 and 2026, in terms of CapEx, can you share with us some of the moving parts that have been done comparing to 2024? I would imagine total spending will be way down, but that look like Alaska may actually be up the spending compared to.

Speaker 11

So if you can give us some idea that what is the key moving parts that we should take into consideration?

Speaker 2

Paul, you highlighted a few of the moving parts that we'll have in 2025. But at this point, it's a bit early for us to be talking about what the 2025 capital spend is going to be, particularly when we prior to closing the Marathon transaction. So I think that's going to have to wait until we get through later through the year and get the Marathon transaction closed or we're going to be wanting to talk in detail about 25 CapEx.

Operator

Our next question comes from the line of Josh Silverstein with UBS. Your line is now open.

Speaker 2

Yes, thanks guys. Just wanted to

Speaker 14

get an update on some of the LNG product development. I was curious if the permitting slowdown in the U. S. Has actually helped the pace of development at Port Arthur. And then it's I think it's been about a year since the Sogoro LNG announcement.

Speaker 14

I just wanted to get an update on that project too. Thanks.

Speaker 2

Yes. This is Andy. I can take that one. On Port Arthur specifically, as you mentioned, that is our Phase 1 is a fully permitted project. We started construction or the operator started construction there with with the contractor.

Speaker 2

And at this stage, I'd just say things are on track. Really not much else to say in terms of the construction of the project at this point. It's on track and going as planned. And then I think your second question was really on NPL. This one this is impacted projects in U.

Speaker 2

S. And Mexico. These are impacted by the pause. That is impacting the FID there. But I'd probably point you to go and those questions are probably better asked by NPL in terms of sort of the pace of the project and where they're at.

Speaker 2

We see like you see sort of critical milestones being progressed, but they face the same regulatory hurdles that the rest of the industry does. You mentioned, you're correct that we have agreed to take 2.2 MTPA of offtake and NPL. So we're keenly watching the progress there too, but that one is contingent on the LNG pause.

Operator

We have no further questions at this time. Thank you, ladies and gentlemen. This concludes today's conference. Thank you for participating. You may now disconnect.

Powered by Quartr