Q4 2024 Earnings Call Transcript

Welcome to the fourth 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.

During the question and answer session, if you have a question, please press I will now turn the call over to Phil Gresh, Vice President, Investor Relations. Sir, you may begin.

Thank you, Liz, and welcome everyone to our fourth 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, and Kirk Johnson, Senior Vice President of Global Operations. I also want to formally welcome Guy Baber, the former Vice President of Investor Relations from Marathon Oil, who has joined the investor relations team here at ConocoPhillips.

Ryan and Bill will kick off the call with opening remarks, after which the team will be available for questions. For the Q&A, we'll be taking one question per caller. A few quick reminders. First, along with today's release, we published supplemental financial materials in a slide presentation, which you can find on the investor website.

Second, during this call, we will make forward-looking statements based on current expectations. Actual results may differ due to factors noted in today's press release and in our periodic SEC filings. We'll be making some non-GAAP financial metric references. Reconciliations to the nearest corresponding GAAP measure can be found in the release and on our website.

With that, let me turn it over to Ryan.

Thanks, Phil, and let me extend my welcome to everybody for joining our fourth quarter 2024 earnings conference call. 2024 was certainly another strong year for ConocoPhillips. We executed well operationally, and on a standalone basis delivered 4% production growth year over year, which was above the high end of our full-year guidance range. We showed strong performance across the entire portfolio, delivering 5% growth in the lower 48 and 3% growth in Alaska and international on the same basis. And we delivered a 123% preliminary organic reserve replacement ratio in 2024. Our three-year average is now 131%.

Also enhanced the portfolio. We closed the acquisition of Marathon in late November, which added high-quality, low-cost supply inventory to our portfolio. And we remain confident that we will deliver more than $1 billion of run-rate synergies by the end of 2025, over half of which is included in our capital guidance. In Alaska, we opportunistically exercised our preferential rights to acquire additional working interest at attractive valuations, in Caparack River, and Perito Bay units.

We progressed our global LNG strategy through additional regasification and sales agreements into Europe and Asia. And as we announced this morning, we're making solid progress on our planned $2 billion of asset sales, have agreements in place to sell non-core lower 40 assets for approximately $600 million before customer adjustments in the first half of 2025. We continue to deliver on our returns-focused value proposition. We generated a trailing twelve-month return on capital employed of 14%, or 15% on a cash-adjusted basis. We returned $9.1 billion of capital to our shareholders, representing 45% of our CFO consistent with our long-term track record and well above our 30% commitment.

Now looking ahead to 2025, we remain confident in the plan that we outlined in our third-quarter call. To deliver low single-digit production growth for $12.9 billion of CapEx in the lower 48 on a pro forma basis, we plan to reduce capital spending by over 15% year over year while still delivering low single-digit production growth. This is primarily due to expected material synergy capture associated with the acquisition of Marathon and significant drilling and completion. We also expect to grow production in Alaska and Canada.

And we are doing all of this while continuing to invest in differentiated high-return, longer-cycle projects. Now on these projects, we're making steady progress across the board. We expect 2025 to be the peak year of our long-cycle spending at around $3 billion, followed by a steady stream of project startups from 2026 to 2029. Once these projects are all online, we expect $3.5 billion of incremental CFO from NFV Port Arthur, NFS, and Willow. All combined at $70 WTI, $10 TTF, and $4 Henry Hub.

And that leads to roughly $6 billion of incremental annual sustaining free cash flow relative to 2025. Shifting to shareholder distributions, this morning, we announced a target to return $10 billion back to shareholders this year, assuming current commodity prices. This consists of $4 billion of ordinary dividends and $6 billion in buybacks, positioning us to execute on our objectives to retire the equivalent of the shares issued for the Marathon transaction within two to three years, even with lower WTI prices than at the time of the announcement. So in conclusion, once again, I'm proud of the accomplishments of the entire organization.

Our portfolio is well-positioned to generate competitive returns and cash flow for decades to come. Now let me turn the call over to Bill to cover our fourth-quarter performance and 2025 guidance in more detail.

Thanks, Ryan. In the fourth quarter, we generated $1.98 per share in adjusted earnings. Now we had a number of special items in the quarter. The two largest were related to the Marathon acquisition.

First, we recorded over $400 million of transaction and integration-related expenses. Now this was mostly offset by over $400 million of tax benefits resulting from the utilization of certain foreign tax credits associated with the Marathon acquisition. Both of these items were largely non-cash in the quarter, and the one-time cash benefit will show up as a working capital tailwind in the first quarter of this year. And it is in addition to the NOLs associated with the Marathon acquisition that we expect to recognize over the next few years.

Transaction-related costs will gradually flow through working capital during 2025, as we achieve our premise synergies. Shifting to fourth-quarter operations, we produced 2,183,000 barrels of oil equivalent per day. This included one month of production from the acquired Marathon assets, which added 126,000 barrels per day to the quarter. Excluding Marathon's production, we achieved 8% underlying growth year over year.

This is above the high end of our guidance range. Now inclusive of one month of Marathon, Lower 48 produced 1,308,000 barrels of oil equivalent per day. And by basin, we produced 833,000 in the Permian, 296,000 in Eagle Ford, and 151,000 in the Bobcat. Moving to cash flows, fourth-quarter CFO was over $5.4 billion, and this included over $250 million of AP LNG distributions.

Operating working capital was a $1 billion headwind in the quarter, primarily due to normal changes in accounts receivable and accounts payable. Capital expenditures were $3.3 billion, which included approximately $400 million for spending related to acquisitions that was not premised in guidance. We returned more than $2.8 billion to shareholders, including just under $2 billion in buybacks and $900 million in ordinary dividends in the quarter. We also completed a series of strategic debt transactions following the acquisition of Marathon.

These transactions simplified our capital structure, extended the weighted average maturity of our portfolio, lowered our weighted average coupon rate, and reduced near-term maturities. Ended the year with cash and short-term investments of $6.4 billion and had $1.1 billion in long-term liquid investments. Turning to guidance, we forecast 2025 production to be in the range of 2.34 to 2.38 million barrels of oil equivalent per day. This takes into account 20,000 barrels per day of planned turnarounds.

Turnarounds are expected to be highest in the second quarter with a triennial turnaround at Ecofiska Norway, a turnaround Accutar, and maintenance in Australia. Then in the third quarter, we will have turnarounds in Alaska. For the first quarter, we expect production to also be in a range of 2.34 to 2.38 million barrels of oil equivalent per day. This guidance reflects a 20,000 per day impact on the full quarter from January weather events.

We expect a minimal first-quarter impact from turnarounds, and that's similar to the fourth quarter. For capital spending, our full-year guidance is approximately $12.9 billion. On slide eight of the presentation material, we provide a pro forma bridge from 2024 to 2025 with some of the key year-over-year variables. In the lower 48, we expect to reduce spending by approximately $1.4 billion.

And for long-cycle projects, we expect to see a $400 million increase in spending to roughly $3 billion in 2025, inclusive of capitalized interest of about $400 million. Finally, in Alaska International, we expect to see a $200 million increase in spending driven by our growth opportunities in Canada and Alaska. Shifting to cost guidance, we expect full-year adjusted operating costs to be in the range of $10.9 billion to $11.1 billion. Full-year cash exploration expenses are expected to be $300 million.

Dollars and full-year DD and A expense is expected to be in the range of $11.3 billion. Full-year adjusted corporate segment net loss guidance is approximately $1.1 billion, and we expect our effective corporate tax rate to be in the 36-37% range at strip pricing. Excluding any one-time items, with an effective cash tax rate, the 35-36% range. Finally, on cash flows, we expect full-year APLNG distributions to be about $1 billion, with about $200 million in the first quarter.

So to wrap up, ConocoPhillips had a strong year in 2024. Executed well operationally. We're continuing to deliver on our strategic initiatives, across our deep, durable, and diverse portfolio, and we remain highly competitive on our shareholder distributions. Concludes our prepared remarks. I'll turn it back over to the operator to start the Q&A.

In the interest of time, we ask that you limit yourself to one question. If you have a question, please press star one one on your touch-tone phone. If you're using a speakerphone, you may need to pick up the handset first before pressing the numbers. Once again, if you have a question, our first question comes from the line of Arun Jayaram with JPMorgan.

Yeah. Good morning. Good afternoon. Ryan, you outlined the 10% increase in cash return to $10 billion.

You know, I'm sure the company scrutinized its approach to cash return in 2025 just given how many price volatility and obviously the recent close of Marathon. But I wanted to see if we get some insights on what drove your ultimate decision terms of 2025 to give a quantum of cash return? And how should we think about potential flex and cash return either higher or lower, you know, given potential commodity price changes?

Yeah. Thanks, Arun. You know, I think when we set the new strategy for the company way back in 2016, certainly, delivering a lot of our significant amount of our cash back to the shareholder, and I think that that's something that's important to the company. Important to demonstrate.

We can continue to do that, and I think it's represented in what we kinda set as our target for 2025. I think as we looked at it, we obviously take a look at the forward curve and things are developing in 2025. We take our own view. We have lots of commodity markers that drive our CFOs. We go through the course of the year, but I think despite the recent downdrafts in the WTI, here over the last month, we felt pretty comfortable at $10 billion. And look, you know, I remind people we have a lot of torque to the upside on commodity prices, and look at our past behavior over the number of years, we've been sharing that with our shareholders.

A reminder, if you look at the whole company, a good rule of thumb is about $400 million for every dollar of TI movement. So, obviously, if we get five or ten dollars of uplift, that's pretty significant cash flow to the company, and we typically share that with our shareholders as well. But on the downside, like, we've got a strong balance sheet ended the year with over I think, $7.5 billion of cash and long-term investments. So we've got a lot of flexibility there.

And then as we announced in our prepared remarks, we're on track to dispose of about $2 billion of non-core assets, which, you know, gives us a lot of flex flexibility as we go into 2025. So putting all that together, we felt like $10 billion was a good place to start. And, you know, we'll do, like, everybody watch the volatility of the market and the commodity price, but feel pretty good about where we started the year.

Our next question comes from the line of Pedro Lopez with Evercore ISI.

Hi. Good morning. It's not Pedro, but it's Steve.

Oh, hey, Steven.

No worries. Trying a new look. So I was wondering, Ryan, if we could dig in. It fits you well.

Dig in a little bit in on some of the long-cycle CapEx if we could, and the outlook. Just wondering if you could kinda hit on some of the moving parts around Alaska, Qatar, thoughts on Port Arthur phase two, and are we right in kind of assuming that your equity outlays on major projects are peaking in 2025, or is that a misplaced view?

Hey, Steve. It's Andy. Maybe I can get that one started. There's a few bits to the question.

Maybe I'll start with Port Arthur phase two. And I'll get to the long-cycle capital. So on Port Arthur phase two, this is a great project. You know, it's underpinned by a premier developer.

And a premier EPC company. It's also positive to see a company like Aramco, you know, showing an interest in being part of that project. But as we've said before, we took an equity stake in phase one for unique reasons which included getting the project off the ground. It came with all your options on other phases and other projects.

So we're very keen to see phase two get completed. There's gonna be cost sharing across the common facilities of the two projects. So you're not interested to see, you know, phase two go. I think it's, you know, it's fair to say our primary focus is on building out offtake and regas capacity for ten to fifteen MTPA.

So that's maybe that sort of gives you the background on our thinking on quarter after Phase two. Then moving to the major project capital and the pace of decline of $3 billion as we said in our prepared remarks, our capital guidance for the year is $12.9 billion and that includes $3 billion of long-cycle budget spend which this $400 million of capitalized interest. As we said, 2025 was expected to be the peak spend as we undertake the big con winter biggest winter construction season in Willow. So if you look past 2025, we are gonna see the major projects spend step down each year.

The same time, we'll start to see the projects coming online delivering on our expected cash flow and free cash flow improvements. And the first one of those will be NFV in 2026. That'll be followed by, you know, Port Arthur, then NFS, we'll have Willow in 2029. So be a steady drumbeat of these projects coming on. I think the key point I want you to take away is that yeah, absolutely. We see this year as the peak as the peak spend in these projects.

And I would add to Steven that we try to say that in our opening remarks, you know, look at this this is coming. And gonna be a steady beat of project startups as Andy described. And it kind of a seventy TI, ten dollar TTF, four dollar Henry Hub. Kind of price tag, that results in, you know, three and a half billion or more of CFO but more importantly, you know, over $6 billion of free cash flow coming relative to our 2025 starting point.

So all that's starting to materialize in you know, is out there. And these are great projects, low-cost supply, competitive in the portfolio, and lead to the long-term growth and development company, which we're quite excited about.

Our next question comes from Doug Leggett with Wolfe Research.

Good morning, everybody. Ryan, nothing short of spectacular performance in the lower 48. And my question is that when you laid out the ten-year plan, you talked about low single-digit growth, and I think you're up 10% year over year, 4% sequentially. In the third and fourth quarter. And I have to imagine this product as efficiencies, as all the things that you talked about.

My question is, do you accept that production growth on a go-forward basis or do you trim activity levels and reduce your capital? I'm just trying to understand what the philosophy is. As to how you respond to the extraordinary delivery you've had in your portfolio.

Yeah. Thanks, Dougie. Huge shout out to Nick and his team. They're I think he delivering some, you know, amazing efficiencies with the horizontals, the larger well pads, and just the frac and drilling efficiencies that we experienced are really good.

You know, I know it's a little trite. I guess, you know, production growth is a bit of an outcome from our plans. But I think the way we kind of look at it is we think about planning cycle year over year and we got the great addition of the Marathon assets, which know, gave us another two plus billion barrels of resource sub forty dollar cost of supply. So we get to integrate that into our plans, and we build significant scale and scope, primarily Bakken in the Eagle Ford, but additional scope in the in the Permian as well.

So we step back a minute. What we look at is trying to keep driving the efficiency that Nick's team is delivering for the company. So if you think about it, do you wanna lay down some next frac spreads? Well, all that does is end up building more ducts than we need to build.

And you go the opposite way and say, well, why don't we cut out a couple of rig lines and and that just creates creates a problem on the frac's pride where we gotta take frac holidays and we shut frac crews down for three or four months just to keep all things balanced. So we're just trying to operate within this efficient operating window. And the Marathon transaction just gave us the opportunity to reset optimized plateaus across both the Bakken and the Eagle Ford. So we kind of approach it that way.

We try to set a reasonable scope going into the year, that doesn't allow us to whipsaw the organization both up or down then we try to take a look at what kind of production growth comes out of that. So it truly is an output for the plans trying to keep driving that efficiency. And I write my people back in 2022, AIM, we thought we'd be adding two, three, four rig lines a year to get the kind of growth that we're seeing we haven't done. We haven't added a single rig line over this time frame.

So it's all driven around around the efficiency. Now I think the point you're getting at is, you know, what is in a in a macro that's growing maybe one, one and a half percent, is the growth too much. I think we do try to take a look at that, at the end of the day, but it's really trying to drive for capital efficiency and returns on the capital that we're getting. We just don't wanna upset that efficient machine one way or the other.

Our next question comes from Lloyd Byrne with Jefferies.

Hey, good afternoon, Ryan, Bill. Team. I really appreciate your comments on cash flow and CapEx. It looks to us as though consensus is embedding almost flat capital and no production growth into the future.

So I think that's important. I know you answered some of it. I just can we go back and go through what you would think is a theoretical maintenance capital number as you look out and I'm also thinking about how efficient you've been in replacing dollars per approved develop in the US.

Hi, Sandy. Yeah. I can take that one. And I think you started it off for me, though.

You know, thinking of sustaining capital, you know, it is a bit philosophical because it does require being in a sustaining world. Maybe I'll try and sort of try and get them in a couple of different ways for you. If you were to take our 2025 capital of $12.9 billion, we've just cleared, that includes $3 billion of preproductive capital and we're still growing the underlying business low single digits. So if you're able to normalize that out sort of you know, in round numbers, you get to about $9 billion in the current commodity price environment we were in a you know, we were trying to just stay flat.

Back at our investor meeting in 2022, so gave a different data point which was to say we could basically mean, tell you, our sustaining capital would be $6 billion that was in a sustaining world at a $40 price. The company's changed a lot since then. We, you know, we've grown with the acquisitions and our organic growth. So if you were to add Marathon or organic growth, the Sirmat acquisition, we'd be closer to about $7.5 billion you know, on an apples to apples you know, forty dollar world right now, but it is like I said, this is kinda hypothetical.

You've gotta be in sort of a sustaining world before you really you can't be doing these kind of things, but if you're trying to if you're trying to model it so hopefully, that's given you a couple of different ways to serve triangulate on the same answer.

Our next question comes from the line of Betty Jiang with Barclays.

Good afternoon. Thank you for taking my question. Maybe just wanna add a bit more color on the lower forty-eight maybe from the CapEx side. The slide, that show the $1.4 billion reduction in the pro forma CapEx Marathon Synergy accounted for $500 million of that reduction.

But could you just give a bit more color on what are the other drivers how much of it is efficiency gains that's lowering while cost and how much of it is development optimization that's perhaps driving a lower overall activity level. And then just if I step back for a bit, if you maintain at this CapEx level, does that mean you would be able to deliver the same low single-digit growth that you outlined before. Because of all the synergies and optimization that you're seeing with Marathon. Thanks.

Well, good morning, Betty. This is Nick. Let me walk you through the few, key components related to that $1.4 billion that you mentioned. And there's it's really around the operational improvements that Ryan was mentioning.

It's that meaningful synergy caps of the $500 million that we talked about there's modest deflation as well. So if I first start with the operational improvement, this is a well-established and demonstrated track record last two and a half years. The team continues to do more with less and just hats off to the team that are calling in today. We demonstrated this 2024 with similar rig and frac activity counts we delivered 15% more scope.

That means more feet drilled, more stages per day, but more in through the bottom line production as we look in Q3 and Q4. Now we're gonna apply the same model, those operating efficiencies, in a level-loaded steady-state development program to the Marathon assets. So we see those efficiency improvements coming forward and that is a key component of the material synergy capture of the $500 million. Now within the synergies itself, in addition to those efficiencies. You've got items like moving on to common contracts, designs around facilities, different well programs, mud programs that are also there.

Now in addition to shifting to our steady-state development program and if you recall know, Heritage Marathon were typically very, front-end, weighted with their activity then ramp down Q3, Q4. We're moving to that over time. But we're also moving our legacy positions in Eagle Ford and Bakken to an Optum plateau, and we'll reassess this as we integrate those assets. So that's another big driver. So you can think about you got the efficiencies, you got material synergy capture, you got activity optimization, and then we expect modest deflation in 2025 as well.

Around $200 million. So all that gets you to the $1.4 billion. Now related to production and continuing on with that, we've looked at we've kinda demonstrated over the last two and a half years that flat activity we can grow the lower forty-eight business. We the teams that continue to drive operating efficiencies, and we do see that for years to come.

At flat activity.

Our next question comes from the line of Devin McDermott with Morgan Stanley.

Hey, good morning. Thanks for taking my question. I wanted to circle back to Alaska. Willow is a big portion of the major capital project spending, and we're in the peak construction season right now.

So I was hoping you can give us a bit of an update on some of the near-term miles and remind us of the cadence we're spending on that project over the next few years and just stepping back, you know, Alaska has gotten a lot of attention from the Trump administration so far and even had its own executive order. So more broadly, could you remind us how you're thinking about the Western North Slope opportunity set and whether or not the policy environment creates more of an opportunity to move forward? Some of this over the next few years. Thanks.

Good morning, Devin. This is Kirk. Yeah. There's a few things certainly in there to unpack.

I'll start with Willow. As you did. I'm certainly happy to report that the progress we made here last year certainly inclusive of the fourth quarter and even just this last month, here in 2025, allows me to say we're really on trend. With the progress that we've been making you've been, you know, hearing from me report out simply that that project team there in Alaska just continues to hit all the key milestones that we've laid out certainly since taking FID back in late twenty-three.

When I think about certainly the work that was underway in the fourth quarter and even just this last month in January, the initial mobilization of that of our winter season certainly that you point out is our largest for the project has really gone quite well. So we got a quick and early start. We got some cold weather. Ice road construction activities are I dare I say, modestly ahead of plan, which is really nice for us.

It puts us in a position of taking full advantage of the full winter season knowing that we may certainly have a little bit of weather in front of us. And again, you know, to the note that this is the largest winter construction season, we're in a great position of building on all the activity. That we accomplished here last year. Again, this is a peak year of ice road construction.

It's from those ice roads that we're building gravel roads, gravel pads that allows us to from those ice roads, build our pipeline networks. And then we've got a few unique activities as well here planned this winter season. Think bridge construction as well as some horizontal directional drills for pipeline crossing. So again, lots to do.

And then you even go into the operation module. That you heard me speak about last year. You know, we floated those barged those up to Alaska, landed those and onshore those during the ice-free season. And those are, you know, I've got report outs just this last month that those are moving.

Across into the Willow development area. So we're using crawlers to get those into the into that new pad. So again, some really good progress. We landed our contracts.

Engineering's on track. That puts us in a great position for full fabrication. Across the entirety of this year. So all that culminates again, Devin, into this peak year of spend, which is why we're guiding to an expectation of project capital being roughly $500 million more than we spent in 2024. And then last, I might just help you all a little bit as well.

You know, we're thinking about all of that spend and manifesting and probably close to a third of our total annual spend expectation here in 2025 showing up in the first three to four months of this year. And then so naturally then we expect the capital this year to stair step down into the second, third, and fourth quarter. And then you'd expect the same trend from us when we think about the total project spend the balance of what we've, you know, that we've guided on for the first couple of years post FID. That'll continue to stair step down with very little if any spend in 2029, which is when we're expecting first oil.

So again, great progress here. Look forward to continued hitting milestones for our Willow project here in 2025. And then lastly, yes, there has certainly been quite a bit of press out there around NPRA. And I would probably back up just a little bit to say, first and foremost, I think it's important for me to emphasize that the ruling that came out on MPRA here from the prior administration doesn't affect any of the activities that we're doing up there. Whether it's in Caparra, Western Roselope, or even Willow.

But we did take issue as did the state and certainly other stakeholders with that ruling and so we were pleased to see that President Trump and that administration issued an executive order to, in essence, reverse what came about here late last year. So you know, we recognize that's gonna take a little bit of time here this year. But yes, we're looking forward to partnering with the Department of Interior and especially with the state of Alaska. You know, fundamentally, we believe that continued exploration west of Willow, it's the right thing to do for energy.

It's the right thing to do for the state of Alaska. And its stakeholders. And clearly, we're in a really good position. We're putting ourselves in a position to continue exploring West Willow as that's enabled for us.

So again, some good news out there for us in Alaska.

Our next question comes from the line of Neil Mehta with Goldman Sachs.

Good morning, Ryan and team, or good afternoon. I just love your perspective on slide four specifically around reserve replacement. You know, there's been some discussion about how investors should interpret this number, and it's one where you appear to do pretty well on over the last couple of years. So just your thoughts on where you've been able to drive that reserve replaced in any geographies in particular that want to call out, and how we should interpret the statistic.

Good morning, Neil. This is Andy. We agree that we know we still think that reserves and reserve placements is a really important metric to measure us and to measure oil and gas companies by. So, yeah, we're really pleased to, you know, that we're delivering yet another strong organic reserve replacement ratio this year we said in the prepared remarks, that's 123%.

A little bit of color I can add to that. You know, we're doing that while you know, growing our annual production and also in an environment where prices fell which, you know, that part results in downward revisions due to market factors. So we're particularly pleased that given back, there's still having, you know, above a hundred percent reserve replacement. Specifically to, you know, where it's coming from, again, particularly pleased here in terms of the balance we have know, our lower forty-eight organic reserve replacement ratio excluding market factors was over a hundred percent again.

Were able to make the first initial booking on the NFS project. And then, you know, now that we have, you know, ownership of complete ownership of Sirmont, we're progressing somewhat development plans with new pads. So we were able to do some bookings there. They're kind of, I'd say, the, you know, the three big levers that I'd point to.

You'll see more detail when we publish the k. So that's how it goes for a hundred and twenty-three organic. And then you know, with the additions from the Marathon acquisition, the additional working in Alaska, the total reserve replacement ratio was the two hundred and forty-four percent. So when you put all that together, you know, we're showing know, for 2024, you know, reserves of 7.8 billion boe.

That's up a billion from last year. And our RRP is improving from ten years to ten point seven years. Then one other, real thing I'd add is that, you know, given the Marathon transaction closed so late in the year, you know, the bookings we've got from Marathon primarily represent the approved developed reserves with minimal pad bookings. So the teams right now are working through, you know, integrated pro forma five-year plans.

Once that's finalized, we'd actually expect to make an additional HUD booking later this year. So again, yeah, another very healthy year. And a good milestone for us in terms of, you know, achieving a hundred percent again.

Our next question comes from Ryan Todd with Piper Sandler.

Good. Thanks. Maybe one on divestitures. You've announced $600 million of asset sales relative to a target of $2 billion. You maybe talk about that program ongoing going forward, the market and appetite for the divestiture efforts and within that, maybe the ongoing discussions around the Port Arthur equity sell down?

Sure. This is Andy. I'm happy to take that one. So as you say, we've had activities, well underway on multiple fronts now with disposition candidates.

As we announced today, we signed PSAs for about $600 million. That's non-core Permian assets. Expect those to close in the first half of the year. Actually reflected this in our guidance.

So that's part of what's in our guidance this year. Also got activity progressing well on other fronts. So we'd actually expect the majority of the $2 billion to be achieved in 2025. So we're really pleased with the progress we're making there. You specifically asked about, you know, quarter after phase one.

We've talked about this one a number of times in the past. You know, as we said before, we took equity in phase one for unique reasons which included getting the project off the ground, and it came with options and other phases on projects for us. So, you know, it was a unique reason why we invested in that project. But the project's now well into execution.

And, you know, we don't necessarily need to be an equity owner, you know, forever in that project. But we also we can be patient. We don't need to rush anything here. Is that so the project is using project financing to fund construction now.

Another way to look at that is that we'll continue to derisk the project every day without additional capital contribution. So, you know, it's an asset we look at. We've had inbounds on that asset and you know, it's one that we'll consider over time. But we feel very confident about the $2 billion target we put out there and we feel good about achieving that.

Our next question comes from the line of Bob Brackett with Bernstein.

Good morning. Some of your peers have talked about opportunities in US that data center power demand, either supplying feedstock gas or, in fact, setting up power demand via CCTTs. What and your strategy clearly has been a more global LNG approach. Can you talk about comparing and contrasting those strategies and maybe highlight anything interesting you might be doing on the domestic power demand side?

Yeah. Thanks, Bob. We like a lot of people, been studying it. We're also getting inbounds on the power side like a lot of people, primarily because we obviously have a lot of natural gas, and we're producing.

We have a commercial power desk, so we buy and sell power all over the US, we have a large land position. Throughout the US. So there's some natural advantages that we have in that space. And we're looking at them and trying to assess some of those inbounds.

It's another way to potentially monetize a lot of gas that maybe we'd get a lower Waha kind of a wellhead price. You talked about our main sort of thrust is in the LNG space. The way I would describe that is we're bullish gas volumes in North America, but were bearish price. So it's a great way to take advantage of those molecules and move them to a higher valued markets through that LNG channel, which we've described to everybody.

But you know, the power requirements are gonna be going up. Certainly, these hyperscalers, data centers, are going to need opportunities for fast and cheap power. So and we sit in an area in the Permian Basin that kinda fits a lot of those kinds of attributes. So we're looking at it.

Can it scale to a really big business in the company? I don't know. But we're looking at those opportunities, but it's first and foremost, kinda fit our framework. We've talked about what our financial framework is, and it's power's no different.

It's gotta be competitive for capital. But, certainly looks like some growth opportunities potentially coming, and we're assessing some of those opportunities right now.

Our next question comes from the line of Scott Hanold with RBC Capital Markets.

Yeah. Hey. Thanks. I was wondering if you could all provide your perspective on you know, there's been a number of initiatives coming out of the White House, and how do you all see that impact the way you all do business and the industry as well. And if you can give your point of view or perspective on you know, the potential for tariffs and how that may impact your outlook.

Yeah. Scott, I can maybe start. Let Andy follow-up with a few more specifics. Like, we were following it closely like everybody else.

It certainly upsets the market. The market will find its own rebalance point if these go on for a long period of time. It does look like they're negotiating opportunity for this administration to do some things that they want. With both our southern neighbor and our northern neighbor.

So it will have some impact in the market. We've done some looking relative to our portfolio, and it's got kind of pluses and minuses. As you might expect. So I can let Andy maybe give you a flare or a feel for specific impacts to the company.

Thanks, Ryan. Good morning, Scott. Yeah. As Ryan said, you know, it's something that we, obviously, we've been looking at closely.

And, you know, no surprise, you know, our primary exposure to the tariffs that, you know, that were announced, you know, last week would have been the sales of our somewhat liquids into the US. We sell around half of our somewhat liquid into the US on a mix of pipeline and rail. But the remainder is actually transported to the Canadian West Coast or sold in the local Alberta market. So, you know, it has, you know, words to be implemented.

It's pretty difficult to say exactly who's gonna carry the burden where. The refiners in the Midwest and the Rockies have fewer options to substitute versus say Gulf Coast or the West Coast refiners. Just thinking about other assets in Canada, the Motney very quickly. We don't actually sell any liquids or gas into the US from the Motney.

And we're actually pretty naturally hedged on gas. Between Martin and Seamont? You come up above Canada. We think about the ConocoPhillips as a total, you know, is where our diversified portfolio really comes into play provide some mitigation.

No. If we were to see, you know, tariffs, we'd likely see strengthening differentials for Bakken, for ANS, and possibly even the Permian. So lots of moving parts. And, I mean, probably just scratching on the surface of the implications tabs were implemented.

We'd also see movements in foreign exchange rates that we'd have to factor in. There'd be an awful lot for us to work through. But, ultimately, I'd draw you back to, you know, what we're focused on is what we can control. That's producing the lowest cost supply volumes, and optimizing value with our commercial organizations.

As Ryan said right at the very beginning, you know, we hope to see that, you know, that don't we don't get in a situation of having tariffs, but also doing the work to make sure that we're prepared if they were to come into play.

Our next question comes from the line of Neil Dingmann with Truist Securities.

Good morning. Thanks for the time. Ryan, just a very broad question. Around M and A, specifically cloud realizing early dry on Marathon, I'm just wondering when you look at the Lance landscape out there today, would you characterize every opportunity that fit your requirements as better or worse than, you know, you saw this time last year.

I just don't know kinda how many opportunities you people see out there.

Well, if I don't we've set it in the past, Neil, that consolidation is gonna continue in this business. Know, I don't quite know when companies make strategic decisions to change the direction that they're going and create some opportunity out there. The landscape is certainly changing. There's probably less of the high quality, you know, names out there just on balance as we look over the transactions that have preceded, you know, us and what we've done over the last, you know, three to four years as well.

But you know, that doesn't say consolidation needs to go. But, you know, I go back to sorta our kind of three big tenants in this space is, look, it first and foremost has to Good. Our financial framework, our view of mid-cycle prices going forward. You know, we have to find a way to make the assets better if they were in our portfolio, and it needs to make our company better.

Our ten-year plan better. So those are pretty high hurdles, and we had a unique opportunity when Marathon decided to do something different. Strategically for their company. We weren't out looking, but obviously, we pay attention close attention to everything that's going on in the business, and we take a view of these companies.

Certainly, that landscape is starting to shrink a little bit. Of real real quality sort of opportunities that are that are out there.

Our next question comes from the line of Leo Mariani with B. Riley.

I wanted to just, dive a little bit more, into the divestitures that you disclosed here, the $600 million. Sounds like that's gonna close in the first half of the year. Sounds like it's basically all kind of non-core Permian, but can you provide a volume number associated with that in terms of rough Please how much production, you know, is being sold and just any thoughts on commodity mix? Is that, you know, kind of a standard Permian mix with, you know, a little bit more than half of that being oil?

Yeah. I could take that question. Yeah. It's the production from the assets would have been about 15,000 barrels a day. Last year. The assets are essentially southern north non-core Southern Delaware. So that pretty much gives you sort of a typical mix of what they are.

Our next question comes from the line of Paul Cheng with Scotiabank.

Hey, guys. Good morning. Ryan, now you have a little bit more than two months under the belt with the Marathon asset, can you give us some idea that what's the running room in those assets? Terms of the tier one inventory backlog, if there's anything that you can share, and that can break it down by basin, particularly down in Eagle Ford and Bakken that we need is quite mature over there.

And also, whether that what is your game plan for Ecotology knee? Is there any differences comparing to what ManfroNet has been communicating to the street before they've been acquired. Thank you.

Yeah. Thanks, Paul. Maybe I can take the Equatorial Guinea and Nick can provide some color on the Marathon assets that were acquired. But know, it the at EGR, we're you know, it's certainly pretty pretty pleased with the CFO and the contracts that were established by Marathon that we've walked into at EDG really haven't changed the plans at all that Marathon was walking into.

We look forward to a couple more infill wells that are going on. I think the rig has been sourced, and it's they're about ready to spud. So we'll be bringing it getting getting our feet under the ground with e g I'd say short and medium term, no real changes to what Marathon was doing at e g. Bigger the bigger question is the same thing.

I think Marathon was grappling with, you know, what's the long-term potential in the area that can flow through the LNG plant and be marketed. But you know, we're trying to grow our LNG, and this fits well within the portfolio and what we're trying to do longer term for the company. Maybe I can let Nick address your inventory question for Marathon.

Yeah, Paul. You're right. We've got a couple of months under the belt and look forward to the future months as well. Yeah.

As far as the inventory quality, it's unchanged. You know, we don't see anything that from the acquisition case. We've got, you know, 2,000 competitive well locations as Ryan mentioned around that $40 per barrel cost supply. Roughly about half of that is in Eagle Ford and then you can kinda think the remaining is split between Bakken and Delaware.

So highly competitive out there. We're looking at the current well performance as well. Eagle Ford looks very strong. If you look at both our heritage COP and Heritage Marathon, on a barrel of oil per foot or even on a barrel of oil equivalent per foot, and compare that to prior years from 2022 to 2023 really strong performance in last year's assets.

And we're seeing as we drill these wells they're meeting type curve expectations in Eagle Ford and Bakken as well. Couple other things just along the synergy lines, when we combine these assets, if you look up in the Bakken as we trade experience on our combined acreage for long laterals, we're seeing more opportunities for increased long laterals in the Bakken as an example. The teams are just working to optimize and improve that combined inventories.

Our next question comes from the line of Charles Meade with Johnson Rice.

Good morning, Ryan. To you and the Conoco team there. I wanted to go back to Alaska, and you guys highlighted the start of the Nuna project, which I believe was kinda mid-December and I wondered if you could put it put the start-up of that project in the context of your overall called a hundred and eighty thousand barrels full a day. I know you guys said it was twenty-nine wells, but can you tell us, is that gonna be of a magnitude that we're gonna be able to observe the effect of that in your in your one q and two q volumes in twenty-five?

Yeah. Good morning, Charles. This is Kirk. I can take that one.

Yeah. Appreciate the question on the Alaska-based business. We could certainly know, that that business continues to chart a course of really sustaining production here with some really modest growth in the next couple of years. And I think it really highlights the amount of investment opportunities that still exist for us in that business with Nuna being a prime example of that.

So again, maybe just a little bit about Nuna and you pointed some of this out. You know, this is a project in which we have built out a new pad. The first one in roughly a decade, and it shows you know, the great work that the teams are doing in exploring and appraising new targets and taking advantage of the infrastructure that we have up there. First oil was in December.

That came on after drilling and completing and bringing on a couple of wells. We do have plans of eight more wells here this year in 2025. And all of that, as you point out, has actually come on on the heels if you will of having drilled over ten wells from existing gravel. So again, it shows the pragmatism that the team has really deployed of ensuring that we understand what these targets are, we derisk those, before we actually put new gravel out there. We are in fact expecting know, that production to enable us to more than offset decline.

As we look at Alaska's production profile for the next year. And then we have a number of other targets that exist out there for us. And you've heard me speak to some of these before. In Caparic, in addition to Nuna, we have Coyote.

Coyote is a really interesting parallel to Willow. And then in WNS and our Alpine asset, we've gotten our wall in Minky. And so these brookie and topsets put us in a really nice position of using these wells to advance technology to advance, certainly, our capital efficiency knowing that these some of these are a great analog or a parallel to Willow which gives us again that much more of an opportunity as we stand which in 2027. So really pleased with how that's taken shape for us. On our base business in Alaska.

Our next question comes from the line of Josh Silverstein with UBS.

Yeah. Thanks, guys. Just wanted to get an update on the LNG contracting environment. Curious if there's been any shift in thinking around the need for new LNG in Europe. You know, potentially due to Russia, Ukraine ceasefire or anything that the current administration is doing to kind of push you know, more LNG projects here in the Gulf Coast to some potentially over there? Thanks.

Yeah. Good morning. This is Andy. Know, in terms of, you know, what's going on in the LNG space, I just said it's more, you know, continuation.

There's nothing I'd say that's particularly new. Know, what we look at sort of, you know, the situation, you know, with Europe. Heavily dependent on LNG. You know, you've seen the Russian the Russia Ukraine deal for the pipeline gas that came to an end.

That's one and a half Bcf. So capacity that is, you know, is no longer available. You've just seen what's going on with the TTF pricing right now in terms of the cold winter that, you know, that seeing in Europe and just sort of how the inventories are being drawn down. So I would say that you know, in terms of the need for LNG, nothing's really changed.

And in terms of, you know, the way that, you know, we're looking at it, sort of our strategy remains unchanged. We're really looking at how we can build out you know, offtake those with a ten to fifteen MTPA and you've seen in the past where we're building out regas capacity in Europe, and we're also looking for sales into Asia. So I'd kinda just say that really sort of where we're right on track with our strategy and think it's sort of are playing out as we expected them to.

Our last question will come from the line of Alastair Syme with Citi.

Thanks, Ron. Bill and team. Another White House question for you. I mean, the president's made some noises about wanting higher levels of US domestic production than them. I get your points. About running the lower forty-eight business optimal efficiency. But is there anything that would incentivize you to go faster in that business?

You know, not really. I think we're just trying to drive the efficiencies, Alastair. I think the message that I've had for the transition team and for the people that are looking at it is the I'd say we are drilling. Drill baby drilling.

I think we have to build a lot of infrastructure. So I think our focus a lot of our focus and intention right now is on permitting reform. Trying to make sure we can build out the infrastructure both for the power kinds of opportunities that are gonna be out there and then obviously the gas lines that come with it. And then just faster movement within the regular and the permitting environment for wherever you sit on federal lands, whether it's New Mexico, North Dakota, Gulf of Mexico, Alaska, you know, just getting more timely drilling approvals, rights of ways, easements, and all those permits.

They just had slowed down under the prior administration. And there's a real opportunity to get back to kinda normal business, if you will, to what we've had in years past. And that just adds to the overall system. And should lead to you know, more sustained plateau or growth in our production coming out of the lower forty-eight in terms of liquids and certainly the growing amount of gas volumes that are coming as well.

It just creates a better environment for investment and more efficient operations.

Thank you, ladies and gentlemen. This concludes today's conference. Thank you for participating. You may now disconnect.