Marathon Oil Q2 2023 Earnings Call Transcript

AlphaStreet
Provided by AlphaStreet
August 3, 2023
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Operator

Good morning, and welcome to the Marathon Oil Second Quarter 2023 Earnings Conference Call. [Operator Instructions]

I would now like to turn the conference over to Guy Baber, Vice President of Investor Relations. Please go ahead.

Guy Baber
Vice President of Investor Relations at Marathon Oil

Thank you, Danielle, and thank you as well to everyone for joining us on the call this morning. Yesterday, after the close, we issued a press release, a slide presentation and investor packet that address our second quarter 2023 results. Those documents can be found on our website at marathonoil.com. Joining me on today's call are Lee Tillman, our Chairman, President and CEO; Dane Whitehead, Executive VP and CFO; Pat Wagner, Executive VP of Corporate Development and Strategy; and Mike Henderson, Executive VP of Operations. As a reminder, today's call will contain forward-looking statements subject to risks and uncertainties that could cause actual results to differ materially from those expressed or implied by such statements. I'll refer everyone to the cautionary language included in the press release and presentation materials as well as the risk factors described in our SEC filings. We'll also reference certain non-GAAP terms in today's discussion, which have been reconciled and defined in our earnings materials. So with that, I'll turn the call over to Lee and the rest of the team, who will provide prepared remarks today.

After the completion of these remarks, we'll move to a question-and-answer session. Lee?

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Thank you, Guy, and good morning to everyone listening to our call today. First, I want to again kick off our call by expressing my thanks to our employees and contractors for another quarter of comprehensive execution against our framework for success. We don't take such delivery for granted and I'm especially grateful for your commitment to safety and environmental excellence in addition to delivering on all of our operational and financial objectives. Well done on another great quarter, while staying true to our core values. There are a few takeaways I want to leave you all with this morning. First, we delivered another very strong quarter on all fronts, highlighted by sequential increases to our cash flow from operations, free cash flow and our total company oil and oil-equivalent production. We delivered around $530 million of free cash flow during the second quarter, with a significant increase from first quarter driven by strong execution and improving production trend and a catch-up in EG cash distributions. Second key takeaway.

We continue to lead our peer group and the broader S&P 500 in returning capital to our shareholders. During second quarter, we returned $434 million to shareholders including $372 million of share repurchases. Through the first half of 2023, we've returned over $830 million to our shareholders, representing 40% of our top line cash flow from operations consistent with our framework. Our differentiated cash flow-driven return of capital framework continues to prioritize our shareholders as the first call on our cash flow, not the drill bit and non-inflation. First half 2023 return of capital represents a double-digit total shareholder distribution yield on an annualized basis and the highest in our E&P peer space. Our commitment in consistency and returning significant capital is contributing to peer-leading growth in our per share metrics. We've now reduced our outstanding share count by 24% in just the last seven quarters, and we are on track to deliver 30% year-over-year production growth per share. Our third and final key takeaways this morning. Our forward outlook remains compelling and differentiated. We are on track to deliver a 2023 business plan that benchmarks at the top of our high-quality E&P peer group on the metrics that matter most: shareholder distributions, free cash flow generation, reinvestment rate, capital efficiency, free cash flow breakeven and production growth per share.

Our business plan remains on track with operational and financial momentum improving over the second half of the year. More specifically, our first half weighted capital spending and completion activity will drive our third quarter total company oil and oil equivalent production to at or above the high end of our annual guidance range. With both higher production and lower capex over the second half of 2023, we expect continued sequential improvement to our underlying free cash flow generation across the third and fourth quarters. And finally, though our annual production guidance ranges remain unchanged, our full year oil equivalent production is trending above the midpoint of that guidance.

Looking ahead to 2024. While it's too early to share any specific guidance, rest assured that our framework for success and core priorities will remain unchanged. Our case to be -- will be another year of maintenance level oil production that maximizes our sustainable free cash flow and prioritizes shareholder distributions and per share growth. My expectation is that we will once again lead the peer group on the metrics that matter most in 2024, benefiting from any deflation that might present itself in the market, as well as from the added tailwind of a significant financial uplift in EG from our increased exposure to the global LNG market.

With that, I'll turn it over to Dane, who will provide a brief financial update.

Dane Whitehead
Executive Vice President and Chief Financial Officer at Marathon Oil

Thank you, Lee, and good morning, everyone. As we mentioned, second quarter was a tremendous financial quarter for us, as we generated $531 million of adjusted free cash flow and returned $434 million of capital back to shareholders. That's a 10% increase in shareholder distributions relative to the first quarter. Importantly, we expect our financial delivery to improve even further over the second half of the year. On a price normalized basis, we expect our free cash flow generation to improve across the third and fourth quarters relative to the second quarter's already meaningful level, driven by higher expected production and lower capital spending consistent with the phasing of our 2023 program. Returning significant capital back to our shareholders remains foundational to our value proposition in the marketplace. We're focused on building a long-term track record of consistent shareholder returns through the cycle that can be measured in years, not just quarters, and the first half of 2023 represents another successful step in that journey. Through the first two quarters of the year, we returned over $830 million to shareholders, representing 40% of our adjusted CFO. First half return of capital translates to a double-digit shareholder distribution yield on an annualized basis and that's the highest in our peer group.

Over the trailing seven quarters, we've now returned approximately $4.6 billion back to shareholders. That's almost 30% of our current market capitalization that we've returned in less than two years. We repurchased $4.2 billion of our stock at attractive levels, driving a 24% reduction in our outstanding share count, contributing to pure leading growth in our per share metrics. We remain confident. Our cash flow-driven return of capital framework is uniquely advantaged versus peers, providing investors with first call on cash flow and offering them a differentiated shareholder return profile. Our framework is sector-leading and transparent, providing clear visibility to one of the strongest shareholder distribution yields in the entire S&P 500.

For the full year, we expect to continue to deliver against our framework, returning a minimum of 40% of our top line CFO to shareholders. We're committed to the powerful combination of a competitive and sustainable base dividend and material share repurchases. More or less our base dividend unchanged this quarter. Keep in mind that we've raised it [Indecipherable] last 11 quarters, and we're well positioned for another dividend raise later this year, with the increase expected to be fully funded by the share count reduction from our buyback program. This is consistent with our focus on sustainability and our objective to maintain one of the lowest post-dividend free cash flow breakevens in the peer space.

Additionally, we have ample capacity to continue buying back a significant amount of our stock with $1.8 billion of share repurchase authorization outstanding. Our plan is to maintain our return of capital leadership and improve our already investment-grade balance sheet through gross debt reduction. We can do both and that's exactly what we're demonstrating. We paid down $200 million of high-coupon U.S. ex-debt so far this year and remarketed $200 million of tax in bonds at a favorable interest rate. The strength and durability of our shareholder return and balance sheet enhancement initiatives are underpinned by the quality of our assets, our disciplined capital allocation framework, our peer-leading capital efficiency and our strong free cash flow generation. This is proven out by our leadership position when it comes to the most important metrics for our sector. For full year 2023, we expect to deliver the best free cash flow yield in the high-quality E&P space, the lowest reinvestment rate and among the best capital efficiency, all while maintaining the lowest enterprise free cash flow breakeven on a pre- and post-dividend basis.

With that summary, I'll turn it over to Mike to provide a brief update of our 2023 execution that's delivering the sector-leading outcomes.

Mike Henderson
Executive Vice President, Operations at Marathon Oil

Thanks, Dane. My key message today is that the priorities for our capital program remain unchanged and that we remain fully on track to deliver on our key commitments to the market, including our annual capital spending and production guidance. Starting with our capital program, we spent just over 60% of our full year budget during the first half of the year, fully consistent with our stated business plan. We expect third quarter capital spending to be in the $400 million to $450 million range, with a further moderation expected in the fourth quarter and are well positioned to take advantage of any deflationary tailwind in the second half of the year.

For the full year 2023, the midpoint of our annual capital guidance remains a reasonable assumption for your models. In terms of the service cost environment, first half 2023 pricing was very consistent with our expectations entering the year. We started to see a general plateauing of cost during the second quarter and had improved access to services and equipment. The full micro environment remains dynamic. We've now started to see an improved pricing trend across raw materials and most service lines in equip, consistent with a lower level of industry-wide drilling and completion activity. We'll look to capture better pricing where we can with the balance of the year, while continuing to protect our execution excellence, where we are also seeing a number of positive trends.

To that point, year-to-date, field-level execution has been very strong and efficiency outperformance has us tracking to the higher end of our annual wells sales guidance in the Eagle Ford, Bakken and Permian. While this won't have a material impact on our full year 2023 capital for production, it should enhance our production momentum into 2024, where we also believe there will be more opportunity to capture deflation in the market. Turning to production. The phasing of our capital program is driving strong production momentum into a strengthening commodity price environment. For third quarter specifically, we expect total company oil and oil equivalent production to be at or above the high end of our annual guidance range before a modest sequential decline into the fourth quarter. For full year 2023, we've reiterated our production guidance ranges of forward trending above the midpoint of guidance on an oil equivalent basis. The combination of higher production and lower capital spending over the second half of the year is expected to drive even further improvement to our underlying free cash flow profile. Turning briefly to our integrated gas business in EG after receiving a substantial catch-up cast distribution during second quarter, we expect the relationship between earnings and cash distributions to normalize over the second half of the year.

Third quarter distributions should be somewhat evenly split between dividends and return of capital. Looking a bit further ahead to 2024, we continue to expect to realize significant financial uplift in EG on the back of an increase in our global LNG price exposure. We're right on track with all the necessary contractual milestones. And beginning January 1, 2024, all the sourced LNG will no longer be sold at Henry Hub linkage. It will be sold in the global LNG market. This arbitrage between Henry Hub and global LNG pricing coupled with the highly competitive market for LNG cargoes from reliable suppliers is expected to drive significant financial uplift for our company at current forward cargo pricing. To take further advantage of these new commercial terms, we are actively assessing up to a 2-well infill drilling program at Alba, targeting high confidence, low execution risk, shorter cycle opportunities that could mitigate base decline and maximize equity molecules through the LNG plan under the more attractive global LNG linked pricing. These opportunities are expected to compete with the risk-based returns generated from our U.S. resource plays, although any Alba infill capital spending is unlikely to make a significant impact on our overall 2024 capital program. Yet, it's not just about capturing near-term commercial uplift in EG.

As we've stated before and consistent with the recently executed HOA with the EG government and our partner Chevron were equally focused on the longer-term outlook via the gas mega hub concept. By truly leveraging our unique world-class infrastructure in one of the most gas prone areas of West Africa, we expect to extend the life of EG LNG well into the next decade and further enhance our multiyear free cash flow capacity. The next phases of development will include in the same gas cap lowdown as well as potential cross-border opportunities.

With that, I will turn it over to Lee, who will wrap up our prepared remarks.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Thank you, Mike. For years now, I have reiterated that for our company and for our sector to attract increased investor sponsorship. We must deliver financial performance competitive with other investment alternatives in the market as measured by corporate returns, free cash flow generation and return of capital, more S&P, less E&P. We've delivered exactly that type of performance over the last two years and not just competitive, but at the very top. Our one-line investment thesis is this: top-tier sustainable free cash flow generation with an advantaged return of capital profile and sector-leading per share growth, all underpinned by an investment-grade balance sheet. For 2023, we're well positioned to again lead both our peer group and the S&P 500 on the metrics that matter most. If this peer-leading financial and operational delivery is not a one year phenomenon. It's a continuation of a multiyear trend and sustainable. And looking ahead to 2024, I don't expect anything to change. My confidence is underpinned by our high-quality and oil-weighted U.S. unconventional portfolio that's complemented by our unique fully integrated global LNG business in EG. To close, I want to reiterate how proud I am of the way we position our company. We are results driven, but it is also about how we deliver those results. Staying true to our core values and responsibly delivering the oil and gas the world needs. And the world needs more energy, not less. The energy transition is really an energy expansion and oil and gas is uniquely positioned to drive global economic progress, defend U.S. energy security, left millions out of energy poverty and protect the standard of living we have all content to enjoy. With that, we can open the line up for Q&A.

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Operator

[Operator Instructions] The first question comes from Arun Jayaram of JPMorgan. Please go ahead.

Arun Jayaram
Analyst at JPMorgan Chase & Co.

Good morning Lee, Dane and Mike. You mentioned how your free cash flow should inflect in the second half of this year, just given the, call it, $450 million decline in capex, higher output in oil prices. So I wanted to get your thoughts on how you balance in a cash return in the second half between equity holders, debt reduction and perhaps building up the cash balance. You've been operating around $200 million in cash for this year. So just thoughts on balancing those three items.

Dane Whitehead
Executive Vice President and Chief Financial Officer at Marathon Oil

Yes. Sure, Arun. Yes, the cash return conversation is so central to the value proposition for shareholders. I might take a little longer than you anticipated to cover this, but just to be thorough, we've really been steady executing a return of capital framework and it calls for a minimum 40% of operating cash flow in the form of either share repurchases or a base dividend. And obviously, our track record on meeting that minimum return, it's very solid and unwavering and we expect that to continue that going forward. We returned exactly 40% in the first half 2023 CFO to shareholders. That's $700 million in share repurchases plus $125 million base dividend, which equated to 11% annualized distribution yield is really at the top of the class in terms of return. Now on top of that, we also paid off $200 million of 8-plus percent coupon U.S. ex-debt and kind of balancing those share repurchases and returns to investors with debt reduction is something that will be a feature for us going forward. We certainly continue to see share repurchases as the preferred return vehicle for the lion's share of our shareholder returns. Our stock is trading at a free cash flow yield in the mid-teens. So for purchases continue to be very value accretive, a real efficient way to drive per share growth and they're synergistic with growing our base dividend, as I referenced in my prepared comments.

We have $1.8 billion of repurchase authorization outstanding. So plenty of running room there. And the per share growth that we're driving 24% since fourth quarter of 2021 when we restarted this program, it's pretty eye-watering. So for the balance of the year, expect us to continue to return 40% of operating cash flow and look to pay down additional debt. Now make no mistake, the 40% return to shareholders is the top priority. The second priority will be to continue to start to pay down the term loan that we took out when we acquired the Ensign Eagle Ford asset. We have a very significant cash flow inflection that we started to free cash flow inflection that we started to realize in the second quarter, but we expect that to continue in the third and the fourth quarter. And even on a price normalized basis, we're going to have a lot more flexibility than we've had over the past couple of quarters to serve both of those needs, shareholder return and debt reduction. With the tailwind we're seeing in commodity prices, particularly WTI right now, that's going to provide even more flexibility. We can go bigger on share repurchases and we can go faster on debt reduction or some more likely some combination of those.

You asked about cash balance. We're operating around $200 million right now. And in the course of the month, we actually made a negative. It need to borrow on our credit facility a little bit, waiting for the big 20th of the month check for oil receipts, which is -- that's the big time when a big way for cash flow comes into the company. That working capital that we're managing the mechanics of that. We actually just established a commercial paper program, which is very cost effective compared to the credit facility. And so I think we're comfortable with that. Over time, we may build up cash, but I don't -- it's not a priority for us right now. Right now, it's going to be hit to 40%, exceed it where we can and take down that term loan to get that interest expense out of the system.

Arun Jayaram
Analyst at JPMorgan Chase & Co.

That's helpful. My follow-up maybe is for Mike, is kind of maybe a 2-parter. Mike, your updated TIL guidance is about 17 TIL is higher, 230 versus 213. Does that impacting any production from the higher TILs, that was a question from the buy side. And then maybe I'd love to see if you could describe the positive variance in the Eagle Ford this quarter and maybe a little bit light in the Northern Delaware, a couple of those variances in 2Q.

Mike Henderson
Executive Vice President, Operations at Marathon Oil

Yes. Just looking at the wells to sales cadence, I'd probably start the capital program is very much tracking its plan. So kind of we fully expect it to execute on that. Kind of purely typical for us to be more front-end loaded. We are seeing some outperformance from an execution perspective, particularly in the drilling space. Looking back and I think we've got a record quarter in the second quarter from a drilling perspective. Similar story in Permian where I think year-to-date, we've had our best-ever drilling performance, similar story in the completion space. And then in Eagle Ford, again, a similar story there. I think what's encouraging in the Eagle Ford is with the Ensign acreage and since we've got in there, we're probably drilling our wells about 10% faster than what they were drilling them last year. So when you kind of combine all of that together, it's putting a little bit of pressure on the wells to sales in the year, but I think how I think about it, that pressure is going to really translate more so in the fourth quarter.

So if you think about it, we're probably pulling a few wells in from the first quarter into the fourth quarter. So from a capital and production perspective, not going to have a big impact on 2023, but potentially could set us up well or for the run into 2024 in the first quarter there. You asked specifically about Eagle Ford well performance. Yes, I think we highlighted the 74 branch wells in Atascosa County. Those are extended laterals. We're seeing some great performance and great early production performance out of those, and that's an area of the play that we've got some future running room. I expect that's going to be a big part of our execution portfolio in '24 and then into '25. Hopefully, that answered all the questions that you had there.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes. I just think one, Arun, just on Permian to, you'd asked a little bit about why we saw a little bit of a step down sequentially there. Now was generally speaking to a little bit of lag in our workover program and we are on top of a couple of large producers that went down. We had to get a workover rig on them. And then finally, we had some midstream gas takeaway that was a little bit delayed on one of our new pads in the quarter. All that's been resolved now. So really just a question of timing, no well performance issues whatsoever.

Arun Jayaram
Analyst at JPMorgan Chase & Co.

Thanks Lee.

Operator

The next question comes from Josh Silverstein of UBS. Please go ahead.

Josh Silverstein
Analyst at UBS Group

Yes thanks. Good morning guys. You had some comments before on the -- some of the EG infilling opportunities there. Can you also talk about just the product scope of some of the other field developments, the time line for investments? Are these a couple of hundred million dollar projects over three or four years? Just a little bit more about the scope of the opportunity there?

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes. You bet, Josh. Happy to do so. Yes, just maybe stepping back, first of all, on the infill drilling program. The objective here, of course, in EG is to continue to base load, our 3.7 MTPA train. We obviously prefer to do that with equity molecules but to the [Indecipherable] will also drive third-party molecules there to maximize the value proposition out of this really world-class infrastructure. The unique big feature, of course, of the Alba infill program is that we're fully aligned across the value chain, from the Alba PSC, all the way through EG LNG, so those are extremely valuable molecules and would ultimately help us offset and mitigate some of the decline that we're seeing from the Alba field. And again, remember, we have aligned interest that we've got about 64% interest in the Alba unit. We've got about 56% working interest in EG LNG and, of course, are operator of both. So the beauty of the program is this is going to be a very high confidence low execution risk. And in the world of offshore production, we would consider this about a short cycle as you can get.

These are -- this would be jackup drilling over existing facilities, typically reentry, dry trees. And so again, from an offshore perspective, these are relatively straightforward opportunities. The work we're doing now is, of course, assessing the economics, really making sure that we have good solid target locations, working with our partners to ensure there's good alignment there, but ultimately, we believe up to two wells in Alba can compete with those risks at a very strong risk-adjusted returns that we're generating here in the U.S. portfolio. If we can stay on track with an [Indecipherable] in the near term, then they could have us in a position subject to rig availability to may even be able to spud late '24 in that time frame. The way the capital will phase just quite frankly, on a say, a notional couple of billion-dollar budget, it's not going to be material. It will be phased over time. And again, across our total budget, we just don't see this to be a big needle mover for us, but very accretive opportunities for our EG asset.

Josh Silverstein
Analyst at UBS Group

Got it. That's helpful. And then obviously, there's a lot of upside to come as the contract rolls off, but we've also seen a lot of volatility in TTF and international pricing. Is there anything you guys can do to take some of that volatility out? Are there -- is there a hedging liquidity? Are there contracts you can sign. Just anything that you can provide there, given we've seen as much volatility there as we have here.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes, I think we've tried to show the notional uplift that we could obtain from the change in commercial terms that will occur January 1, 2024. And the reality is, Josh, as long as there is arbitrage between Henry Hub and TTF, there's going to be financial uplift in EG. Really, it's just going to be a matter, as you said, of where does that global LNG market price ultimately land. We've shown some sensitivities, $15, $20 and $40 TTF. And in all those cases, there's material uplift relative to what we're seeing in 2023. The work is ongoing from a commercial standpoint from the liquefaction agreement, the lifting agreements all the way through to LNG marketing. More to come on that but as I think we said in our opening comments, the good news for us is we're going out into a very competitive market today where LNG cargoes, particularly Atlantic Margin sourced LNG cargoes that are advanced into Europe are going to be very much sought after. And I would just emphasize that buyers are looking for reliable suppliers. And over the life of EG LNG, we've never missed a cargo. And so I think we're in a very good position to maybe not damp out all the volatility that you referenced, but certainly take full advantage of the market price that's available to us.

Josh Silverstein
Analyst at UBS Group

Great. Thanks guys.

Operator

The next question comes from Scott Hanold from RBC Capital Markets. Please go ahead.

Scott Hanold
Analyst at RBC Capital Markets

Thanks. And good morning. I guess just sticking with EG since we're on that topic. Could you give us some color on how those discussions with counterparties are going and your partners? And just give us a sense, if you could, on what, I guess, counterparties are looking for in terms of duration and flexibility as well, that would be helpful.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes. I would just say, first of all, with this is a competitive process, Scott, that we're in. And from a milestone standpoint, we're right on track in terms of the commercial milestones that we laid out. And so I want to be absolutely clear, there's no question that we'll be receiving global LNG pricing come January 1. Right now, we're in a competitive process with multiple buyers to again drive that competitive tension and deliver what we think will be the most value from whoever that counterparty will ultimately be. But that's an active ongoing competitive process right now, Scott.

Scott Hanold
Analyst at RBC Capital Markets

I mean, are you able to talk about what kind of duration you're looking for? And obviously, you talked about maybe stabilizing the Alba field. Is that part of showing that the assets have duration for those counterparties?

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes. I'll go back to my comment around reliability and security and supply. So certainly, duration is an important element that is in. Of course, the terms that we're currently discussing. But until we kind of complete that competitive discussion, I don't want to get too far into some of the commercial details. Suffice to say though, Scott, that we do believe that we'll be able to provide a very solid runway of LNG cargoes for those counterparties. And so it will be -- certainly, we're looking at a longer-term kind of contractual relationship.

Scott Hanold
Analyst at RBC Capital Markets

Okay. And then my follow-up is a little on 2024. You gave a few tidbits, but clearly, you're sticking to the maintenance program, but with some of the potential tailwinds coming into the year that you spoke of based on your more efficient program. I mean, at a high level, that coupled with maybe some service cost savings, can you give us a sense of how in general, you're thinking about that capex budget relative to the one -- I guess, 195 you're targeting this year?

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes. Well, of course, it's a bit early to start forecasting into 2024. But let me, first of all, just share a few thoughts. The case to be for us remains a maintenance oil production level. That means we're going to be back targeting kind of that notional 190,000 barrels of oil per day. So no real surprises there. And in fact, even at a capital allocation level, I wouldn't expect a see change in terms of the mix amongst even our assets as we look ahead to 2024. I do believe and I think Mike hit upon this in the comments that market trends continue to, I think, give us an opportunity to see some downward pressure in pricing. I think we're well positioned to take advantage of that in the second half of the year. But I don't think from a materiality standpoint, those deflationary impacts are really not going to take root until 2024. Now that's all going to be subject to the market kind of staying where it is. I mean on the service side, it continues to be a supply and demand market for them as well. So do I see an encouraging trend there? Yes. Am I going to give you a quantification of that right now, it's just a bit too early to go there.

Scott Hanold
Analyst at RBC Capital Markets

Thanks.

Operator

The next question comes from Neal Dingmann of Truist Securities. Please go ahead.

Neal Dingmann
Analyst at Truist Securities

My question is on the D&C specifically, like a number of your peers continue to sort of push the limits and see the benefits of going to larger wells, such as the three milers and talking about the upsize that they see on returns from this versus the two milers and 1. I'm just wondering do you all agree with this assessment? And if so, what type of opportunities in your plays do you have for this?

Mike Henderson
Executive Vice President, Operations at Marathon Oil

Yes, Neal, it's Mike. Yes, I definitely, agree with that assessment. It's been a focus area for -- I think it started predominantly with the Permian asset. We've progressed from a lot of single mile laterals there. Team has done an incredible amount of work over the last few years. We've actually traded close to 5,000 acres over the last couple of years. And that's allowed us to develop this inventory of 10 years plus of two milers there. We've now expanded that approach. We're having a look at potential opportunities in the Eagle Ford and the Bakken. What I'd say Permian is probably still the basin that I think presents the most opportunity for us.

But I mean, as we included in the deck, we've got some opportunities that we just brought online in Atascosa County this quarter in Eagle Ford, I expect more of that. I mentioned that earlier in the response to run, I expect more of those types of wells coming into the portfolio next year and potentially even '25, having a look in Bakken is probably a bit more of a limited opportunity set there, but nevertheless, the team are looking at. And even Oklahoma, we're drilling 3-mile springer well at the moment. That's being drilled under the JV that we've got there. But if that proves successful, I could open up a few more parts as well for us and oily pads also in Oklahoma, which is always helpful. So I'd characterize it by yet, we're definitely seeing the uplift and it's something that the teams are actively progressing.

Neal Dingmann
Analyst at Truist Securities

Very good. That's great to hear. And then my second question, just on sort of the regional oil production. I know you guys don't specifically guide on in each of the regions, but there's definitely continues to be a pretty nice notably pick up in the Bakken. And I'm just wondering, I guess, almost simultaneously, it seemed like the Permian fell a little bit more than we were anticipating. I'm just wondering for each of those or anything to read into that? Or is it just more timing of the D&C plan?

Mike Henderson
Executive Vice President, Operations at Marathon Oil

I think in Bakken, you're seeing the benefits, strong execution there in the second quarter. You've seen the benefits and read through into volumes. I think that would translate into the third quarter as well. And Permian, as we mentioned, we've had three or four quarters growing volumes there, but a bit of -- seeing some outperformance there, a little bit of underperformance this quarter. But again, as we mentioned, two contributing factors there. We had a few prolific base wells go down that we had to work over. And that was simply -- that was transitions from ESPs to gas lift. So just it was more of a timing thing there. We do plan for a bit of that in any given quarter, but we just saw a few more wells coming out and normal, and then it was just some tie-ins that we're a little bit late on the gas side for the new 5-well part that we brought on here. So no -- nothing concerning. And again, as we mentioned, we're fine on track early in Q3 from a volume perspective. So we got no concerns there.

Neal Dingmann
Analyst at Truist Securities

That's great details. Thanks Mike. The next question comes from Doug Leggate of Bank of America. Please go ahead.

Doug Leggate
Analyst at Bank of America

Thanks. Good morning everyone. Thanks for having me on. Dan. I wonder if I could just pick up on the cash tax commentary on the slide deck. It's obviously been a moving part -- moving piece for you guys, given the AMT, but can you -- if I look at slide 18, can you give us an idea what that free cash flow delta would look like at different decks on when you expect to transition to cash tax to full cash tax?

Dane Whitehead
Executive Vice President and Chief Financial Officer at Marathon Oil

Yes. I mean maybe not quantify it specifically, but let me just tell you what's happening. So we have in a non-AMT world, sufficient tax attributes not to be taxable U.S. federal income tax taxable until late 2025. When this new rule of the inflation Reduction Act and the AMT that came in with it imposed paying a 15% alternative minimum tax if you're not paying taxes, if you meet certain criteria and the primary criteria is our three year average pretax book income was $1 billion or more. And in 2023, we are not -- we're below that $1 billion threshold. In 2024, we expect to be above that. There was a big loss here, a pandemic loss year in the current three year average number that will roll off and we can get to 2024. So we expect we're going to be AMT-taxable at a 15% rate starting in 2024, and we expect actually to continue at that rate for about a decade. In the background, the conventional NOLs and tax attributes will be converted to AMT credits. And so we'll end up sort of capping our tax rate of 15% in the U.S. for that period of time, a 15% will only apply to U.S. income. We pay a 25% rate in ET and that generates its own foreign tax credit, so it won't get doubled by the AMT tax rate as well. So hopefully, that you can apply that kind of math to any price outcome you're looking at and quantify it.

Doug Leggate
Analyst at Bank of America

That's -- I know it's a complicated issue, Matt -- Dan, thanks for running through that. I guess my follow-up, Lee, is we haven't really heard a lot about REx recently. I wonder if you could just give us your updated thoughts on that thinking on portfolio development and maybe set it alongside how you see the M&A landscape for Marathon after that terrific deal you didn't covered it.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes. Well, let me start and I may ask for some support from Pat as well. On the portfolio development side, we really look at this kind of as a multi-element approach when we talk about resource replenishment, inventory replenishment. On one end of the spectrum, you have large acquisitions like the Ensign acquisition, which, as you stated, was a tremendous win for our shareholder. I think the other avenue that we have are smaller bolt-ons and trades. And I think Mike actually mentioned that some of the trade work in the Permian is giving us access to more extended laterals. And then you have, I would say, our internal kind of self-help, which is -- can be some of the redevelopment activities but also the REx program as well. And so we look across all those dimensions, we talk about resource replenishment and how we continue to build the resource base since we are an extractive industry, we have to stay on top of that. But maybe I'll let Pat talk a little bit about our program, particularly maybe focused on the Texas Delaware program and how that's now kind of progressed from what we would have originally called a REx program now more into developmental program.

Pat Wagner
Executive Vice President of Corporate Development and Strategy at Marathon Oil

Doug, this is Pat. As we said, our primary project Delaware access business, Texas delivered oil play that we have now fully integrated that into our Permian asset team. So it's no longer categorized as REx and we talked a little bit about it last quarter. We brought on a four well pad this year doing a downspacing test. That pad has performed exactly as we expected it to. We'll drill another pad in or coming up that will bring online in '24. We're committed to now a development approach that is a four x four Meramec and the Woodford 10,000-foot lateral length is kind of our development plan to be going forward. The good news in this recent path as well as we still are not seeing any communication between the Meramec and the Woodford so we can definitely codevelop those two zones. Our real work now is to try to drive our D&C cost down as low as possible. We've got a lot of experience in Oklahoma in these two formations that we're trying to replicate here in this project. So we'll just continue to mature this project and it's part of the kind of the development portfolio now moving forward.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Sorry, Doug, I was just going to say, I think it's -- we're really now focused for this Woodford-Meramec play really looking at how do we get up the learning curve to get D&C cost down as low as practical. So it really has moved more into a development project that has to compete for capital allocation. And that's exactly what we want to see as an output from the REx program is moving that stuff into development mode. I did want to come back to your question, too, just around M&A, though, real quickly. I think you mentioned, of course, the very successful Ensign acquisition. If anything, Doug, I would say that actually raised the bar for us from an M&A perspective. And we're not going to compromise obviously on our criteria along those lines. I mean we would be making sure that something is absolutely accretive from a financial metric standpoint, it would have to be accretive from a return of capital standpoint. It would have to be accretive to our overall sustainability meaning inventory kind of resource life accretive. There will have to be industrial logic there, meaning it needs to be in one of the basins where we have high execution confidence. And then finally, we wouldn't want to do anything that would damage the financial flexibility and the balance sheet that we worked so hard to establish. That's a very tough filter. And I will tell now you today, as we look into the market, we just don't see anything today that really hits all of that criteria. And that's what we saw in Ensign. It really did tick all of the boxes. And that's why I think that's been such a successful addition to our portfolio.

Doug Leggate
Analyst at Bank of America

Pardon the clarification question, Lee, with the Permian oil play included in your inventory, what would you say the inventory life is now in the Permian and I'll leave it there?

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

We'd probably say today based on your PAT, kind of doing a nominal four x four spacing, recognizing, obviously, that there's some variability across the play, but it's generally a contiguous 55,000 acre position. So we're thinking of several hundred locations right now and we'll get more specific on that as we get up that learning curve on D&C and to really integrate it in with the rest of our enterprise level inventory.

Doug Leggate
Analyst at Bank of America

Thanks guys.

Operator

The next question comes from Matt Portillo of TPH. Please go ahead.

Matt Portillo
Analyst at TPH

Good morning all. Just a follow-up around the shift in the TIL count for the year. We noticed that the Oklahoma assets saw a slight down shift in your expected TILs under the JV. I was curious if that was operationally driven or if just given the low commodity prices, some of those wells are sliding into 2024? And more broadly speaking, how do you think about the return profile in Oklahoma relative to the rest of the portfolio?

Pat Wagner
Executive Vice President of Corporate Development and Strategy at Marathon Oil

Yes. This is Pat. Matt, just a little bit on the JV in Oklahoma. That's a very targeted program and we're getting close to finishing that up. It's just really been focused around lease retention there, using somebody else's capital to try to maintain our lease program. With some other strategic advantages including keeping them active through working there. Mike, you have anything else to add there?

Mike Henderson
Executive Vice President, Operations at Marathon Oil

No. I don't think there's anything. I mean I think we guided 15 to 20 wells there earlier, Matt. I think we just think we're going to be at the low end of the range. I don't think there's anything to read through into that.

Matt Portillo
Analyst at TPH

Perfect. And then maybe just a follow-up on JVs across your asset base. I know you have a couple at this point that are for lease retention purposes, given the strengthening crude market and what could be a better environment for gas and NGLs as we head into 2025, how is the company's aptitude or kind of appetite at the moment for incremental JVs versus retaining those inventory locations and developing those on your own going forward.

Pat Wagner
Executive Vice President of Corporate Development and Strategy at Marathon Oil

This is Pat again. I think what our approach on JVs to date is to keep them very small and targeted to achieve certain strategic objectives. We're not doing large multiyear operated programs. We're just trying to satisfy lease commitments or protect operatorship, things like that. So we'll continue to view them through that lens. And as you see an opportunity to do that, people go ahead and do very small ones. Most of the inventory that we consume in these JVs is not our top-tier inventory to keep that and we will go ahead and drill that. But if there's lesser quality inventory that doesn't compete for capital in the current next few years and we need to execute on it to retain a lease, then we'll bring in a JV partner to help us see that.

Matt Portillo
Analyst at TPH

Thank you.

Operator

The next question comes from Paul Cheng of Scotiabank. Please go ahead.

Paul Cheng
Analyst at Scotiabank

Thank you. Good morning. I have to apologize first that I joined late, so if my question has already been addressed, please let me know, I will look at the transcript. Me just curious that some of your competitors is talking about the refrac and redevelopment opportunity in Eagle Ford. Have you guys do a more detail and notes on that. I assume that currently, your inventory backlog that you mentioned, say, 10 to 12 years, that's not including that. So if we're including those that -- how big is that opportunity for you? And what kind of oil and gas price you need in order for those that to be economic? That's the first question.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes. Paul, let me take a first pass of this and then I'll maybe let Mike sum some details. First of all, in terms of inventory, we do not put refracs into our inventory. So when we talk about inventory life, these are primary development opportunities, new drill wells, if you will. We've had a lot of experience in the Eagle Ford with refrac and redevelopment. It continues to be an area that we pursue. But again, because we have so many primary recovery opportunities there, we usually do them when there's synergy with nearby new development, but maybe I'll let Mike just throw in give you sense as well.

Mike Henderson
Executive Vice President, Operations at Marathon Oil

Yes, Paul. No, you hit the nail in the head there. I mean, our approach with refracs is as we're pulling together a fun development, we're looking at our primary infill. We'll have a look at the section and we'll determined then, is there a potential refrac candidates ended the section. And quite frankly, those opportunities have to compete for capital on a heads-up basis with all of the other opportunities. So rest assured, we're doing refracs. They are profitable and they are competing with infill opportunities. I mean to give you a kind of idea for the scale in any given year, I think we're probably doing less. We're probably in the 10 to 15 new fracs this year and that's kind of how we think about it. It's not a targeted program what we will call and do a bunch of refracs exactly to Lee's point, I think we've got enough primary and sole opportunities that we just don't think to do that. I think probably answered most of your questions there. The pricing, they've got to compete on a heads-up basis with the other capital that we're deploying.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Yes. The other maybe item I would point out, Paul, as well as maybe just reflecting back on the Ensign conversation that we were having. In that acquisition, we placed no value on refrac and redevelopment activities. We based the value really on PDP and the full route 600-plus new primary recovery kind of opportunity that existed there. So as you recall from the acquisition, there were 700 existing wells, many of which -- most of which were completed back in time, right? And so you've got a lot of early generation completion technology out there. We haven't had a chance yet to quantify that because the primary opportunities Ensign are so attractive. They're a little bit further down a priority list, but we absolutely expect in the balance of time to continue not only in the legacy area of Eagle Ford, but also in the inside area of Eagle Ford. So look at refrac and redevelopment opportunities going forward. But again, it's just a question of prioritizing them within the capital allocation.

Paul Cheng
Analyst at Scotiabank

The second question is I want to go back into the EG commercial renegotiation on the post 2023, is it necessary for you that you have 100% of the volume under long-term contract or from a portfolio management standpoint, better off for you to reserve a fairly sizable amount on the spot market so that you can take the opportunity of the trading and maybe other tranche opportunities. And also that I know you already have a large exposure starting next year on the international gas market, but does it make sense for you to further diversify your maybe that when we argue that is financial engineering on your U.S. natural gas exposure to also linked to the international market by signing some supply agreement that with the U.S. Gulf to LNG operator, I know some of your peers have done?

Pat Wagner
Executive Vice President of Corporate Development and Strategy at Marathon Oil

Paul, this is Pat. I'll take that. Maybe I'll start with your second question first on U.S. gas linkage to LNG. I mean we're always exploring ways to maximize our realizations, but we are heavily exposed in EG to the LNG market. So there's nothing even in the U.S. yet. There is a significant amount of gas volume to do that in the U.S. just have not focused on that and don't see us doing that in the near future. In terms of EG, we will commit to a certain level of volumes through a long-term contract. We will have some terms in there that I want to get into too much detail that we'll have how we handle extra volumes, but I expect that we will have capacity above that so on to the spot market as progressed. That's -- a lot of those details are still to come and it depends on the specific negotiations we have with the buyers [Indecipherable].

Paul Cheng
Analyst at Scotiabank

Pat, can I just want to clarify that from a company intention, what will be the ideal mix for the EG contract, do you have a number you might say 70% lock-in on contract and 30% spot or something bigger, something smaller? Any number that you can share?

Pat Wagner
Executive Vice President of Corporate Development and Strategy at Marathon Oil

No, I don't have any specifics to share with you. But I would think the bulk of the contract will be fixed.

Paul Cheng
Analyst at Scotiabank

Got it. Okay. Thank you.

Operator

Seeing that there are no further questions at this time, I would like to turn the call back over to Lee Tillman for closing remarks.

Lee Tillman
Chairman, President and Chief Executive Officer at Marathon Oil

Thank you for your interest in Marathon Oil, and I'd like to close by again thanking all our dedicated employees and contractors for their commitment safely and responsibly deliver the energy the world needs now more than ever. Do not be proud of what they achieve each and every day. Thank you and that concludes our call.

Operator

[Operator Closing Remarks]

Corporate Executives
  • Guy Baber
    Vice President of Investor Relations
  • Lee Tillman
    Chairman, President and Chief Executive Officer
  • Dane Whitehead
    Executive Vice President and Chief Financial Officer
  • Mike Henderson
    Executive Vice President, Operations
  • Pat Wagner
    Executive Vice President of Corporate Development and Strategy
Analysts

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