Murphy Oil - Q1 2024

Transcript

Operator (participant)

Good morning, ladies and gentlemen, and welcome to the first quarter 2024 earnings conference call and webcast. If at any time during this call you need assistance, please press star zero for the operator. I would now like to turn the conference over to Kelly Whitley, Vice President of Investor Relations and Communications. Please go ahead.

Kelly Whitley (VP of Investor Relations)

Thank you, Jonah. Good morning, everyone, and thank you for joining us on our first quarter earnings call today. Joining us is Roger Jenkins, Chief Executive Officer, along with Eric Hambly, President and Chief Operating Officer, and Tom Mireles, Executive Vice President and Chief Financial Officer. Please refer to the informational slides we've placed on the investor relations section of our website as you follow along with our webcast today. Throughout today's call, production numbers, reserves, and financial amounts are adjusted to exclude non-controlling interests in the Gulf of Mexico. Slide two. Please keep in mind that some of the comments made during this call will be considered forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. As such, no assurances can be given that these events will occur or that the projections will be attained.

A variety of factors exist that may cause actual results to differ. For further discussion of risk factors, see Murphy's 2023 Annual Report on Form 10-K on file with the SEC. Murphy takes no duty to publicly update or revise any forward-looking statements. I will now turn the call over to Roger.

Roger Jenkins (CEO)

Thank you, Kelly. Good morning, everyone, and thanks for listening to our call today. As we turn to slide three, I'd like to reiterate our corporate priorities of de-lever, execute, explore, and return. We remain firmly on track for achieving our $300 million debt reduction goal in 2024, leading to $1 billion of total long-term bond debt outstanding at the year-end 2024. In the first quarter of 2024, we exceeded production guidance in the Eagle Ford Shale and Tupper Montney, with total production of 170,000 barrel equivalents per day at the high end of our guidance range. Murphy's Gulf of Mexico workover program is ongoing. In addition, I'm pleased to report that the Mormont number 2 subsea well is back online in the first quarter after equipment repair.

We're continuing to progress our well delivery programs, and in the second quarter, we will have a new well at Khaleesi and 23 new operated wells all to come online. In exploration, our operating partner is currently drilling Ocotillo exploration well in the Gulf of Mexico, and we will move to the Orange exploration well immediately following. In the first quarter, Murphy was awarded 6 deepwater blocks from the Gulf of Mexico federal lease sale 261. We're also progressing our exploration plans in Vietnam as we've contracted a rig to spud our exploration program in the beginning of the third quarter. We're pleased to continue our hallmark of consistent returns to our shareholders through buybacks and long-standing dividend. We've repurchased $50 million of stock in the first quarter at an average price of $39.25 a share.

Additionally, as announced in January, we increased our quarterly dividend to $0.30 per share, or 120. I'm sorry, $1.20 per share annualized, and our board maintained this level in April, which is back to a 2016 annual level. Our capital allocation focus has been primarily focused on debt reduction since 2020. Between August 2020 and August 2022, excuse me, we reduced total debt by $730 million. Since announcing the framework in August 2022, we've consistently executed a combination of debt reduction, share repurchases, and dividend increases. And since fiscal year 2020, we've reduced debt by $1.7 billion.

We purchased a total of $200 million of stock, or 4.7 million shares at an average price of $42.68 a share, and raised our quarterly dividend 140%. In the first quarter of 2024 specifically, we generate sufficient adjusted cash flow to allow us to purchase $50 million of stock and capitalize on stock price dislocation to oil prices. For 2024, we're solidly on track to achieve our $300 million debt reduction goal and reach Murphy 3.0 of our capital allocation framework, especially with current oil price, prices. Looking forward to reaching this next step and further increasing shareholder returns to 50% of adjusted free cash flow later this year. Slide five.

Murphy produced at the high end of guidance at 170,000 barrels equivalent in the first quarter of 2024, with 89,000 barrels of oil per day. We achieved a slight premium to WTI, as we realized $78 per barrel, and our realized NGL price was $23 a barrel, and net gas was $2.12 per thousand cubic feet. Overall, we generated $746 million of revenue in the quarter, excluding our non-controlling interest. I'll now turn the call over to our Executive Vice President and Chief Financial Officer, Tom Mireles, for an update on our financial results. Tom?

Tom Mireles (EVP and CFO)

Thank you, Roger, and good morning, everyone. Slide five. In the first quarter, Murphy reported $90 million of net income, or $0.59 per diluted share, and $131 million of adjusted net income or $0.85 per diluted share. We achieved $405 million of adjusted EBITDA due to a combination of strong production and realized prices, with $264 million of accrued CapEx, excluding non-controlling interest. Overall, as Roger mentioned previously, we had an outstanding quarter in returns to shareholders as we repurchased $50 million of stock, paid a higher dividend, and increased our cash balance. In total, we returned over 60% of our free cash flow, all while supporting a front-end loaded CapEx plan with approximately 60% of spending in the first half of 2024. Slide six.

Murphy maintained strong liquidity in the first quarter, with $1.1 billion as of March 31, including more than $300 million in cash and equivalents. I'm pleased that during the quarter, we received positive outlooks from both Moody's and Fitch, revised from stable outlooks previously, with the corporate ratings affirmed at Ba2 and BB+. At quarter end, we had $1.3 billion of senior notes outstanding, with a long-dated weighted average maturity of nearly eight years. We remain on track for further debt reduction this year, and I look forward to reaching Murphy 3.0, with total debt of $1 billion before year end. Slide seven. At Murphy, we seek to continually minimize our impact on the environment, whether that's using natural gas rather than diesel to fuel our onshore operations, or utilizing recycled water for our well completions.

We also support the communities in which we work, like the city of Uvalde in South Texas or here in Houston. Because of this service, we have been presented with awards such as the United States President's Volunteer Service Award from the Houston Food Bank. I look forward to Murphy developing further initiatives to enhance our positive impact. With that, I will turn it over to Eric Hambly, our President and Chief Operating Officer, to discuss our operational updates.

Eric Hambly (President and COO)

Thank you, Tom. Slide 10. Our Eagle Ford Shale wells performed above expectations in the first quarter, achieving total production of 29,000 barrels of oil equivalent per day, with 86% liquids volumes. Our operating partner brought online four Tilden wells during the quarter, while Murphy progressed our 20 well-operated drilling program for the year as planned. We are on track to bring seven operated Catarina wells online in the second quarter, plus an additional four non-operated Tilden wells. Slide 11. In the Tupper Montney, Murphy produced 348 million cubic feet per day and progressed our 2024 well delivery program, with 13 wells that are either now producing or will be online in the near term. This will complete our plans for the year.

We are excited to announce that Murphy has joined the Rockies LNG Partnership, which may create future LNG opportunities for our Tupper Montney acreage as projects in the area near completion. This partnership is comprised of Western Canadian natural gas producers driving LNG export optionality, and we are eager to be a part of it. Murphy maintains a strong price diversification strategy, mitigating against AECO price exposure. For the first quarter, we sold approximately half of our natural gas volumes at the Chicago, Dawn, Malin, Emerson, Henry Hub, and Ventura price points. Slide 12. Our Kaybob Duvernay asset produced 4,000 barrels of oil equivalent per day, with 68% liquids in the first quarter of 2024. We progressed our development program for the year and have three operated wells coming online in the second quarter as planned.

Slide 13. Our Gulf of Mexico assets produced 73,000 barrels of oil equivalent per day with 82% oil volumes. This production was impacted by approximately 13,000 barrels of oil equivalent per day of planned downtime events during the quarter. Murphy is advancing our development program for the year, and we look forward to bringing online the sizable Khaleesi number 4 well in the second quarter, as we found approximately 200 feet of net pay when drilling. We're also progressing the drilling of a new well at our Mormont field, which is scheduled to come online in the third quarter. Additionally, our operating partner has brought online wells at the Saint Malo and Lucius fields during the quarter. In offshore Canada, we produced 6,000 barrels of oil equivalent per day in the first quarter, according to plan.

Slide 14. During the first quarter, we completed the zone changes on the Marmalard number 1 and number 2 wells as planned, as well as the subsea equipment repair at Mormont number 2. Murphy also initiated work on the Neidermeyer number 1 well workover, with the plan now updated to drilling a sidetrack well, which will delay the online date to the third quarter of 2024. Our workover expenses, which are included in our lease operating expenses, total $50 million for the first quarter, with $65 million forecast for the second quarter. This figure includes the cost of the Neidermeyer sidetrack well. Additional work is planned later this year at the Dalmatian number 2 well for the subsurface safety valve repair, as well as the non-operated Kodiak number 3 well, stimulation, and zone addition.

Slide 15. In Vietnam, we have been progressing our plans for our Lac Da Vang field development project, including advancing award of major contracts this year. We look forward to begin drilling our development wells in 2025 and remain on schedule for achieving first oil in late 2026. Slide 17. In the Gulf of Mexico, we're excited to begin our 2024 exploration program. Our operating partner is currently drilling the Ocotillo exploration well. Immediately following this well, the rig will shift to drill the nearby Orange exploration well. These two Miocene prospects are located near existing infrastructure and could be brought online quickly if either is a discovery. Also, in the first quarter, we expanded our portfolio and were awarded six deepwater blocks from the Gulf of Mexico Federal Lease Sale 261.

Slide 18. We're continuing preparations for our Vietnam exploration program later this year and are excited to have contracted a rig which is currently drilling in country. Murphy will first spud the Hai Su Vang exploration well in Block 15-2/17 in the third quarter and target a mean to upward gross resource potential of 170-430 million barrels of oil equivalent. The rig will then move to drill the Lac Da Hong exploration well in Block 15-1/05, targeting a mean to upward gross resource potential of 65-135 million barrels of oil equivalent. We look forward to seeing the results of these wells as they provide the potential to create a more sizable business in Vietnam.

Slide 19. Our seismic reprocessing work continues to progress for our acreage in Côte d'Ivoire, and we are pleased at the multiple opportunities available across exploration play types. Importantly, Eni recently announced positive results from its Murene-1X exploration well on the Calao discovery nearby. Murphy is excited at this news, and I note that our block, CI-502, in particular, is very near this discovery. In general, our Côte d'Ivoire acreage position is now bookended by two significant Eni discoveries. We will continue to progress our analysis of the data as it comes in, with the final seismic data due by year-end 2024. With that, I will turn it back to Roger.

Roger Jenkins (CEO)

Thank you, Eric. On slide 21, for second quarter 2024, we forecast total production of 176,000-184,000 equivalents per day, with 93,000 barrels of oil during that period. This range is impacted by 2,000 barrels of oil equivalent per day of offshore non-op unplanned maintenance, primarily related to a third-party downstream facility, 1,250 barrels equivalent per day of Eagle Ford Shale downtime as we have offset frack impacts, and a significant downtime of 11,700 barrels equivalent per day at Tupper Montney for plant maintenance that's ongoing. Murphy plans to spend approximately $325 million of accrued CapEx in the second quarter.

For full year 2024, we're maintaining a production guidance of 180-188 thousand equivalents per day, with 52% or 95 thousand barrels a day of oil. Our. This guidance is supported by stronger own-well performance and better results at non-operated offshore fields. We're also maintaining our CapEx range at $920 million-$1.02 billion, excluding NCI. These ranges will support us achieving our 2024 debt reduction goal of $300 million, thereby allowing us to reach Murphy 3.0 and enhance our shareholder returns. On slide 22. Effective at year-end, our long-term strategy remains unchanged since we first disclosed the refreshed projections following last year's opportunities captured in Vietnam and Côte d'Ivoire to support our new opportunities and long-term oil production growth.

We'll continue to support and grow our returns to shareholders during this time. In particular, we'll be executing Murphy 3.0, our framework, after reaching our debt reduction goal this year. Longer term, we plan to reinvest approximately 45% of operating cash flow, enabling us to achieve average production of approximately 210,000-220,000 equivalents per day, and as always, over 50% oil weighting. Murphy will continue generating ample free cash flow to allocate towards further shareholder returns, accretive investments, as well as supporting exploration success. Additionally, as part of this plan, we remain committed to achieving metrics that are consistent with investment-grade rating. And I'm pleased with the rating agency outlook improvements achieved this spring that Tom just spoke of.

On slide 23. I'm glad to have a solid first quarter behind us as we continue to execute our plans for the remainder of the year. Our long history of consistently return to shareholders will expand as we reach Murphy 3.0 later this year. We're already ahead of the game with share repurchase in the first quarter. I view our 2024 debt reduction goal as a given. I look forward to buying back more stock to enhance shareholder value. Additionally, we have exploration upside with drilling two wells in the Gulf of Mexico and two wells in Vietnam. Our future is bright, especially consider our long runway of Gulf of Mexico projects, as well as significant future locations across our North American onshore business and our exploration upside. As we approach annual meeting season, we often benchmark our peer group on 2023 10-K data.

When doing so, we find that Murphy is rated one or two in many categories. A few of those: free cash flow per production, the per debt adjusted share growth, production per debt adjusted share growth, lowest reinvestment rates, debt reduction, total debt, debt due 2024-2026, at debt to EBITDA, total cash return per shareholder change year-over-year, and lastly, G&A for EBITDA. Solid company, solid plan, diverse portfolio, exploration upside, locations, sustainable, a long history of shareholder returns. That's Murphy Oil Corporation. As always, I want to thank our outstanding employees for their consistent effort and determination to help us reach all of our goals. With that, that's the end of our prepared remarks today, and we look forward to our questions.

Operator (participant)

Ladies and gentlemen, if you have a question, please press star then followed by the one on your touch-tone phone. You will hear a prompt that your hand has been raised, and if you wish to decline from the polling process, please press star followed by the number two. If you're using a speakerphone, please lift the handset before pressing any keys. Your first question comes from the line of Neal Dingmann from Truist Securities. Your line is open.

Neal Dingmann (Managing Director of Energy Research)

Good morning.

Roger Jenkins (CEO)

Good morning, Neil.

Neal Dingmann (Managing Director of Energy Research)

Thanks for the time. Morning, Roger. My first question, just on shareholder return. You, you just sort of hit on this, Roger, but I just want to go over. Specifically, could you or Tom remind me what bonds, if any, you were able to repay early? And then more, I guess, more importantly, once you get under $1 billion or to Murphy 3.0, besides just stepping up the shareholder return, could we see more exploration work, or what else could we see? Because obviously, your debt at that time will be well under control. So I'm just wondering, besides stepping up the shareholder return, is there something else we would see with that incremental free cash flow?

Roger Jenkins (CEO)

Thank you for that question, Neal. It's a big key part of our strategy. I'm gonna give you a big high-level picture and let Tom talk about the specific bonds. We need to think about this framework as a yearly matter. We easily can forecast, as you and all of your peers are, that we'll easily get rid of this $300 million of debt. There's nuances to calling the debt at different opportunities. We also have an internal target in our plans of how much stock we can buy. Nobody wants to buy back stock more than me, and we see the debt as a given. So we're already ahead of the game on the stock. We have an eyeball as to how much stock we wanna buy, and I would see that going along.

If the debt goes into the third quarter, that's still something we'll be able to do as we go along the way, if you follow me on that. So our strategy is to— As far as long-term, we wanna keep our plans. We keep our low-growth plans. We do not see changes to that plan at any time, but I just reiterated, and we want to continue to buy back this stock while it's undervalued. And as you know, by yourself and many of your peers, we've been ranked number one in cash flow through 2026, available to our market cap, and that's gonna make us have a really big advantage, and we're not really into changing that right now. So I'll let Tom talk about the specific notes.

Tom Mireles (EVP and CFO)

All right. Thanks, Roger. Yeah, Neal, you know, we got a little over $300 million to go to reach Murphy 3.0, and we've got more plenty available in our 2027 notes. Those are callable today, and the balance is around $440 million of 2027 notes. And then, our 2028 notes will be callable in July of this year. Now, you asked about, you know, once we get to Murphy 3.0, and we go into this, you know, 50% to shareholders, 50% to the balance sheet. The way we kind of think about that is, you know, Murphy 2.0 was about more of a defensive move, making sure we got our balance sheet in a robust shape.

Murphy 3.0 gives us a chance to be positioned for more of an offensive move. You know, whether it's dry powder or, you know, more opportunities to return to shareholders, either through buybacks or even dividends.

Neal Dingmann (Managing Director of Energy Research)

Thanks, Tom. And then, that completely answers it. And then just secondly, Roger, maybe high level on valuation. Just continuing, it's hard not to notice, you know, that you all trade below some other companies that have materially less production. I'm just wanting your opinion. You know, do you think the market is just still not appreciating the stable offshore production of you all? I mean, I look at your inventory, I look at the production, especially not just the onshore, but the offshore development activity, and continue to be sort of surprised, just the discount. I just would love to hear your opinion on why this discount. I, you know, that I can't piece together.

Roger Jenkins (CEO)

Thanks, thanks for that question, Neal. Really love that question. This is my twelfth year doing this. It used to make me real upset about those matters, but today we're just looking to buy back stock, and we're gonna buy back stock until we do better. We have our balance sheet in order to do so. It just rattled off in a long list of positives about our company, a solid. Can't have those attributes without running a good, solid company. I believe it must be the market cap of our company would be similar to all shale, and all shale doesn't have a workover. All shales are perfectly organized, drilling game plan. If we were all shale, I could tell you exactly the production by quarter. It's almost better to have the same product CapEx every quarter.

But if you look at the free cash flow and the uniqueness of our company and the deals that we've done and the M&A and all the opportunities we have, it's because we're in the oil business, we're in different aspects of the business, and we now have ourself in a situation where growth has slowed, buying back stock is in vogue, but we're gonna have the best balance sheet and buying stock and be patient and get into doing that, especially in 2025, and then we'll go with the valuation from there.

Neal Dingmann (Managing Director of Energy Research)

Makes sense. Well said. Thank you, Roger.

Operator (participant)

Your next question comes from the line of Leo Mariani from ROTH MKM. Your line is open.

Leo Mariani (Managing Director and Senior Research Analyst)

I wanted to touch base on the Gulf of Mexico production here real quick. If I heard some of these numbers right, I think you guys said you had 13,000 barrels a day equivalence of downtime in the first quarter, 2,000 equivalence of downtime in the second quarter. So I guess that's a plus 11,000 barrel a day improvement in 2Q. But just kind of looking at guidance, looks like you're guiding up around 4,000 barrels a day. So just wanted to get a sense of the delta. Is that just kind of natural declines there in the Gulf?

Roger Jenkins (CEO)

I'll let Eric handle that for you, Leo, and thank you for that question.

Eric Hambly (President and COO)

Yeah, Leo, thanks very much. We have quite a bit going on with our Gulf of Mexico program this year. We've noted that we have a number of high-rate wells that are not currently producing, in particular, the Neidermeyer well that we're doing a workover, which has now become a sidetrack. That's a high-rate well, about 4,000 barrels a day. Those should come online early in the third quarter. And then in the middle of the year, we have work going on at our non-op Kodiak and our operated Dalmatian to increase production there. So if you think about those just wells that have historically been producers for us that are coming online toward the middle of the year, you'll see a ramp.

Along with that, we have our Khaleesi Mormont program that'll add volumes that will help offset declines. So as you march through the year, Gulf of Mexico production will increase, and production in Gulf of Mexico in the first quarter was around 73,000 barrels a day, and ought to be up, you know, 9,000-11,000 barrels a day by the end of the year. The end of the last quarter ought to be something like that increase. So offsetting decline with new production and restoring wells to production that have been offline temporarily.

Leo Mariani (Managing Director and Senior Research Analyst)

Okay. That was very helpful in terms of the explanation. And wanted to also have just kind of a similar line of questioning around the Eagle Ford. Looks like that production ticks down a little bit in the second quarter. You guys cited some maintenance that's ongoing, but could you maybe just kind of discuss how the Eagle Ford production trajectory should play out as we roll into 3Q and 4Q?

Tom Mireles (EVP and CFO)

Yep. As you noted, we do have a little bit of downtime in the second quarter. That's primarily offset frack impact because we have an active completion program going in the second quarter. That program continues into the third quarter. The bulk of our operated wells, which generate most of the new production in Eagle Ford, come online in the third quarter. So you ought to see production peak in Eagle Ford in the third quarter and be relatively similar in the fourth quarter.

Leo Mariani (Managing Director and Senior Research Analyst)

Okay, thank you.

Tom Mireles (EVP and CFO)

For the full year, we're predicting 30,000 barrels a day for the Eagle Ford.

Leo Mariani (Managing Director and Senior Research Analyst)

Okay, that's helpful. I appreciate it. Thanks.

Roger Jenkins (CEO)

Thank you, Leo. Appreciate it.

Operator (participant)

Your next question comes from the line of Tim Rezvan from KeyBanc Capital Markets. Your line is open.

Tim Rezvan (Managing Director)

Good morning, Tim. Good morning. Hi, Roger. Thanks for taking my question. I was hoping to dig in a little more on, follow up on the last question, on the Gulf of Mexico. You know, the Neidermeyer, obviously prolific well, 4,000 a day. You said, you know, the workover activity became a sidetrack. I was wondering if you could give a little more context on kind of, you know, what changed and, you know, if you expect that back at, at full capacity in, in early 3Q.

Roger Jenkins (CEO)

Eric, you'll handle that for you. It's just full field there, Tim, this morning.

Eric Hambly (President and COO)

Yeah. So what happened with that well is, the workover that we had planned when we got on the well, we expected that the problem was a packer that was leaking. We confirmed in the early stages of our workover that that was indeed the problem. As we progressed with the work to pull the packer and tubing, we were trying to isolate the lower completion from the upper completion, so basically the productive connection with the reservoir from the tubular goods in the top part of the well.

We were having difficulty isolating the lower completion and decided that the best path forward to have the best success going forward with that well was instead of continue on that path of continuing to fight to get isolation of the lower completion, that we would sidetrack the well, which would give us an opportunity to have a completely new completed well with a very short offset from the existing location. We have sidetracked that well. We like what we've seen so far. We're gonna move forward with a completion that should be a brand-new, fresh completion, which has the best mechanical outcome and should provide the best production rate opportunity. So it should produce in line or better than the well that we're leaving behind.

Tim Rezvan (Managing Director)

Okay.

Roger Jenkins (CEO)

One note on that, Tim. One note on that, Tim, it's 4,000 net. These wells, all these wells we have make 16,000-18,000 barrels a day gross. These are big wells. We happen to own 30-something% of this one, so it makes way more than 4 a day.

Tim Rezvan (Managing Director)

Sure. Yeah. I get that. Okay, that's all I had. Thank you.

Roger Jenkins (CEO)

Thank you, Tim.

Operator (participant)

Again, if you have a question at this time, please press Star, followed by the one on your touch-tone phone. You will hear a prompt that your hand has been raised, and if you wish to decline from the polling process, please press Star, then followed by the number two. Your next question comes from the line of Charles Meade from Johnson Rice. Your line is open.

Roger Jenkins (CEO)

Good morning, Charles.

Charles Meade (Research Analyst)

Good morning. Good morning, Roger, to you and the rest of the Murphy team there. My first question is on 2Q CapEx. The 325 guide is, you call it $60 million higher than what I was looking for, and I think what some other people were looking for. It looks like what you've already laid out, that the big driver of that is really the U.S. onshore completion pace, drilling completion, or I guess I should say North America onshore drilling completion pace. But also that, you know, there's a lot of work going on in the Gulf of Mexico.

Are those the two big pieces, or are there other drivers that are contributing to that, high, you know, what looks like high CapEx in 2Q?

Roger Jenkins (CEO)

Thanks for that question, Charles. I'm gonna just frame it a little bit and let Eric get into the details. So we've said all along, over 60% of our CapEx in the first year, and we're still within a percent of that. This is timing of various matters. Timing, actually, we drill faster and completing faster in the onshore business than we have non-up matters, timing on the other. And I'll let Eric get into the detail after that. So we feel that we're still in line. Everything's in line for our debt. Everything's in line to buy back stock. We just moved a few percent of the CapEx to the left. That's really no more than that, and Eric can give you the detail of that.

Eric Hambly (President and COO)

Yeah. Thanks, Roger. As you, as you noted, most of the change is driven by the timing of our onshore North America drilling completion program. That's over $30 million of the change, so that's shifting from later in the year into the second quarter. And then offshore, about $15 million of equipment, subsea equipment related to our Khaleesi Mormont program. We moved some spending that we expected in the fourth quarter up into the second quarter as we pivoted during the time we had our Mormont number two subsea equipment issue. And then some seismic spend moved from the first quarter to the second quarter. You note that we had lower CapEx than our original guide in the first quarter.

So some of the spending we thought would happen for non-DNC related activities, including seismic and our Lac Da Vang development spending, moved from the first quarter of 2024 into the second quarter of 2024, and that's another $11 million or so. So that describes most of the changes in the movement of CapEx. Really, as Roger pointed out, we're just phasing of spending and not overall spending is changing.

Charles Meade (Research Analyst)

Got it. That is helpful detail. And then, Eric, I want to go back to a comment that you made about this. It seemed like you were pretty positive on this Khaleesi number 2 development well, I think it is, and I think you—I believe I heard you mention that there are over 200 feet of pay. And I wonder if you could give us two aspects of context and anything else you want to add. At first, how does that 200 feet or whatever you saw in this most recent well compare to the you know, the initial well there?

And then the second piece is that all in one zone, or is that across a few different zones? And so, you know, we're gonna have a, you know, I guess, what I'm getting at, is this gonna be a monster one-zone completion, or is this the more typical you know, you have, you know, 60 feet in 3 different zones kind of thing?

Eric Hambly (President and COO)

Yeah, thanks for that. I appreciate the opportunity to talk about it. This particular well, the Khaleesi 4 well, was targeting a reservoir that was not in our initial development of the field. As we developed the field, we identified some additional opportunities. This particular one is targeting a shallower reservoir in an uptick position, and so we penetrated this reservoir as we were going to deeper zones, which were the target of our main field development. This is sort of an additional set of volumes that we were able to develop after the initial development program, and we're excited about it. It is in one zone. It's a very nice-looking reservoir with high reservoir quality. Should produce very well for us here, as it comes online, soon.

So if you think about our overall Khaleesi Mormont Samurai development, we had an initial set of wells, which we've talked about how they'll do production-wise. In the development, we have Khaleesi and the two Mormont wells that we're doing this year are similar. They're targeting zones that were not contemplated in initial development. They're additional volumes, which will allow us to extend the plateau of our total Khaleesi Mormont Samurai development. So from that perspective, we're really excited. This development's been tremendous for us, with very fast payout already happened and additional volumes going forward with plateau production out into 2025, 2026.

Charles Meade (Research Analyst)

Got it. That's great detail. Thank you.

Eric Hambly (President and COO)

Thanks.

Roger Jenkins (CEO)

Thanks, Charles. Appreciate it.

Operator (participant)

There are no further questions from our phone lines. I would now like to turn the call over to Roger Jenkins for any closing remarks.

Roger Jenkins (CEO)

Appreciate everyone dialing in today. Had some good dialogue there with our business. We're very, very pleased with our business. Looking forward to the rest of the year and beyond. Appreciate all the attendance today, and we'll be seeing you soon. Check in with our IR team if you have any further questions. Thank y'all.

Operator (participant)

This concludes today's conference call. You may now disconnect.