which is expected to add approximately 5,000 to 6,000 barrels oil equivalent per day in 2027. I want to take a minute to talk about the Eagleford decision because it highlights the key role this asset plays in our portfolio. As our offshore opportunity set expands, we can fund part of that growth through near-term high return production and cashflow. Eagleford is one of our best assets to do that. It is flexible, well-weighted and capable of efficiently translating capital into production. Going forward, We expect that Eagleford to become an increasingly important source of cash flow and financial flexibility across the business. This is the strength of our multi-basin portfolio in action, not a change in capital discipline. Our ability to fund growth through our base business while maintaining financial strength was evident this quarter. We generated $110 million of free cash flow, returned $50 million to shareholders through the dividend, maintained leverage below one time, and ended with approximately $2.5 billion of liquidity. Even with the revised capital program at current commodity prices, we expect to generate positive free cash flow for the full year. Operationally, second quarter production averaged 169,000 barrels of oil equivalent per day above the midpoint of our guidance, led by stronger performance at Tupper Motney and continued outperformance in the Eagleford. In the Gulf of America, Chinook No. 8 is now through drilling after reaching a total depth of 26,000 feet and remains on track to come online in the fourth quarter. Lac du Vent is also on schedule for first oil in the fourth quarter, with the pipeline, top sides, and FSO milestones now complete. As we look ahead, years of capital discipline and technical rigor are beginning to translate into a portfolio with multiple exciting pathways to growth. This is the Mercky model in action. Identify the opportunity. tested with discipline, developed it safely and efficiently, and funded through resilient cash flow and financial strength. This full cycle capability and track record across geographies, asset types, and development stages sets Murphy apart and positions us to convert the opportunity ahead into lasting shareholder value. With that, we are ready to take your questions.

We will now begin the question and answer session. At this time, I would like to remind everyone in order to ask a question, press star, then the number one on your telephone keypad. Please stand by while we compile the Q&A roster. The first question is from the line of Aaron Jaram with JP Morgan Securities. Your line is open. Please go ahead.

Eric, good morning. Appreciate the comments and the character letter. Exploration as is investing can be humbling, but did want to maybe get your thoughts on next steps at HSV. What needs to happen in terms of kind of moving to that FID decision? in 2027. And can you give us a little bit of an update on how you are thinking about kind of the development options for HSV?

Arun, thanks for that. Great question. Obviously, we're disappointed that the Forex well was a dry hole, but I will say that we're still very excited about what is a very significant development for us. You know, 200 to 300 million barrel field in shallow water will have very attractive economics. I would have loved for it to be larger. We now have a lot of confidence in the size of the resource and gaining increasing knowledge about how we're going to develop the field in terms of the well count, well spacing, and the type of facility concept is something we'll be evolving over the coming year or so. We're looking at a number of options for the development. One option would be an FPSO. The other option would be a processing platform with a series of well-head platforms tied to an FSO, similar to our LactaVong project. Those are things that we will assess as we plan a development of the field over the coming 12 months or so. We're going to work closely with our partners on a series of approvals required to achieve an approved field development in Vietnam. and after we do that, we will take the project to our board for a final investment decision. As we highlighted in our letter, we're targeting that in the fourth quarter of 2027. And I think we're well on track to do that. Really happy with this significant discovery that'll help us build a really material business in Vietnam. And yeah, I think we're gonna create a lot of value for our shareholders. And I don't think we're getting a lot of recognition of that value creation today. And we're happy to demonstrate our ability to continue to execute developing projects 40% faster than the industry. Great, great.

And maybe my follow-up, you've spud now Bubal West in July. It looks like you'll be appraising the Toronian. Maybe just give us a sense of what your concept is for this appraisal well and what will be the governor of the next in the development or the appraisal program, which could include up to five wells. Yeah, thanks for that.

As we've featured before, we drilled the discovery well in a position where the Tyronian and the Cinnamanian cross. There was one location where we could test both reservoirs. We were fortunate to be able to find oil in both Tyronian and Cinnamanian. And that leaves us with a need to understand the lateral extent of the field, the variability in reservoir quality and thickness across two different reservoir intervals, and also, importantly, learn how much of those structures are oil-filled. So the next well that we're moved to, Bubal West 1X, is moving down dip in the Turonian. The main objective of the well is to test for continuity and variability of reservoir sands and also hopefully determine to prove a deeper oil level than is proven at the base of the Gubal 1X well. We're very intentionally targeting the well to give us high confidence that we have a resource in the Toronian that is in line with or in excess of the volume we need to have a commercial development. As we sit today, we think what we found is a commercial, but we don't have high confidence because we have one penetration and two reservoirs very large reservoirs to test, very large lateral extent. And we're hoping this well gives us high confidence that we'll be able to then move forward with the development as quickly as possible while we continue to assess and appraise the full size and value of the field.

Great. Thanks, Eric.

Thank you. Your next question is from the line of Neil Mesh with Goldman Sachs. Your line is now open. Please go ahead.

Yeah, Eric, I wanted you to unpack a little bit of the decision to pull forward activity in the Eagleford. You alluded to it a little bit in your comments, but maybe you talk about why you thought this was the right environment and what kind of incremental returns you're going to get on the incremental capex associated with the $70 million acceleration.

Yeah, thanks for that. Before I get just into the Eagleford, I want to back up a bit and talk about how we've been thinking about our overall company business. You know, what we've said over the last few years is we thought we could develop our kind of base business, continue to develop that, and also our emerging and growing Vietnam business with a capital program that's sort of in a 1.2 to 1.3 billion range. And that any additional spending to develop something like BuBall would likely be additive or largely additive. And I would say where we sit today, that is still true. So as we look forward and think we want to maintain our Canadian onshore business effectively flat, maintain the scale of our Gulf of America business relatively flat through the rest of this decade, we look at an additional need for CapEx for appraising and developing Gubal. And the place that we found was most optimal to help provide part of that is through accelerating our Eagleford. If you look at our Eagleford business, we've had increasingly strong well performance over the last few years. generating strong free cash flows even in periods of fairly low oil price in the past couple years and so the reliability of it and the flexibility of it we look at and say this is a great place to invest a little bit more that'll generate more free cash flow next year and likely through the end of the decade that'll help us fund the appraisal of Buval and then as we move into additional volume growth out of Vietnam we'll have even stronger cash flows so it's the best place to find oily production and we can do it scalably and we've had very strong returns and increasing wealth performance from Eagleford so it's kind of the go-to place to do it and I think you'll see us as we as we highlighted in our materials increased spending this year which leads to increased free cash flow next year and while we haven't formulated a plan that we've released for 28 through 29 2030 I think you'll see us increasingly lean into that if it allows us to continue to generate more free cash flow. So we're really about creating shareholder value. I think it's nice to be able to generate incremental oily production growth in the short run, but the primary reason is it's free cash flow generative and can help us fund what we think is an exciting opportunity in Cote d'Ivoire.

Yeah, Eric, that's the follow-up. So the new CapEx plan is 1516 accrued CapEx for this year. Any advice on what we should put in as a placeholder for 27? I know there's a lot of moving pieces, but just any thoughts on the market there so we can calibrate accordingly.

Yeah, that's a fair question. We don't have a number to give you for next year's CapEx, but I'll talk just about how I think about it. I think that you should expect us to increase slightly more in the Eagle firm than in the past with that. alone without any change to investing in Cote d'Ivoire, that would likely put our typical capital program toward the high end of our kind of previous one, two to one, three range, maybe slightly above. That's still something we're going to work on. And then spending on Buval is likely additive to that. So we'll probably see a higher CapEx in 27 than you've seen from us recently. I don't know the number. And importantly, I want to kind of go back to the comment we made about the appraisal program. We're going to drill down We're drilling a well at Bubal West 1X now. Depending on what we find, we may have no appraisal program or a limited appraisal program. We're going to learn from every well, and next year's capital spending will be materially driven by what we continue to find. If we keep finding more oil at Bubal, we'll likely keep spending. If we have less wells required to define the size, scope, and quality of Bubal, then we'll spend less. And so there's a pretty big range around that. We're going to still work on that. The results from the Gual West 1X well will probably materially shape our view of likely spending and spending ranges for 2027. But I think I don't want to try to make you feel like we're likely to come in below $1.25 billion next year. It's going to be higher. I don't know how much higher, but we're going to be disciplined, focused on creating shareholder value and investing in things that are going to be very valuable for our company and our shareholders. Thank you, Eric.

Your next question is from the line of Carlos Escalante with Wolf Research. Your line is now open. Please go ahead.

Hey, good morning, Eric and team. Thank you for the update today. I want to go back to HSV very quickly to clarify a few things and then move on from there. So it looks like it just before was a dry hole, which in my view, it implies that you didn't you didn't find an oil water contact that presumably more of it. So just wondering what what's stopping you from testing an additional well? where you can find that threshold and what gives you the confidence that you don't need to. And perhaps you can speak more broadly about what you found in HSV-3 in terms of a discovery pay or any kind of really property around the well and discovery.

Yeah, thanks, Carlos. I'm happy to provide more context there. Let me go back to where we were at the end of the 2X well. So we drilled 1X, 2X. We had extremely encouraging results, strong DSTs. We had a view at the time that the field was likely toward the high end of our previously guided, which was a pre-drill range of resource. And we told everyone that because we wanted to inform and keep everyone appraised of how we were thinking about it. And we said at the time we thought it was possible that the resource could be even larger. But importantly, we had drilled a fairly large Central area of the field, and we needed to test the northeast and southwest extensions of the field, which is what the purpose of the 3X and 4X wells was. So with the 3X, we were testing for lateral extension to the northeast. How continuous are the sands? Are they the same quality? We weren't really chasing a deeper oil water contact there. We were just chasing for continuity. And then with the 4X well, we were testing what we thought would be an expanded reservoir section with potentially a deeper oil water contact. What we found from the program, from the 3X and the 4X, was that the reservoir thickness was not as extensive as we expected over the entire structure, which tightened up the resource estimate. With the 4X, we found the interval we were looking for, but the reservoir quality was low, so we didn't have any net pay. So the story for 4X was not really about oil-water contact. It was really about the extent of productive reservoir being limited. So now that we have bounded the reservoir with these four wells, we have high confidence in a developable resource that we're going to move forward with the field development plan.

Thank you. I appreciate that. So yeah, presumably a four-way closure. So you don't need to test the other bounds. And then my follow-up and maybe a follow-up to Neil's question. For next year, again, very difficult for you to talk about 27, where we are today. But can you at least frame for us how you're thinking on what is senior to what in terms of the levers you can pull if you needed to have a more lean program, if you will, in 2027? Obviously, it sounds like you're going to prioritize the appraisal at Louisville if you find any kind of success. but wondering what it means for the broader onshore portfolio and maybe the Gulf of America if you need to, again, be leaner on your 27 program.

Yeah, I think what you'll see from us is investing in our Gulf of America business to try to maintain production relatively stable there. And in our Eagleford, likely incrementally more spending than historical. And in Canada onshore, stable investment, stable production. Vietnam. Obviously, we're working through additional development drilling in our Lac de Vang project. We won't have likely additional drilling in Hai Su Vang next year. So we're moving to engineering studies, which is not a lot of spending. And then in Cote d'Ivoire, what we spend will be driven by what we keep finding, as I mentioned before with Neil. And that's really driving a significant uncertainty in our spending. But as I said, We're going to learn from every appraisal well and we'll decide what does that mean about the next well. And so there's a probably broad uncertainty. If we needed to pull back spending for some reason, if oil prices went to be extremely low, we could change our plan for practically any part of our business. We are fortunate in Vietnam and in Cote d'Ivoire that we operate so we can control the pace of any spending. We believe it is valuable for shareholders to quickly appraise Bubal, determine if we have a commercial project definitively, and determine the extent of it so we can move on for field development planning. But if we needed to, we could slow the pace of appraisal. We could go as low as zero appraisal wells in Bubal next year if we chose to. And so we have a lot of flexibility. We're going to continue to spend money where we think it's value-creating for shareholders and maintain flexibility to spend less if it's necessary.

and Derek. Appreciate it as always.

Thanks, Carlos.

Your next question is from the line of Philip Jugworth with BMO. Your line is now open. Please go ahead.

Yeah, thanks. Good morning. Coming back to the Eagleford, which will be a larger part of the program, I know you've always had often chalk in the location count, but it has gotten for attention laid across both the east and west portions of the play. I was just hoping you could talk about how large a contributor the chalk is to your program, go-forward program, or is it largely lower Eagleford focus and still and just how you see the opportunity set here overall?

Sure. Our Eagleford inventory has a fairly limited amount of Austin chalk. Our development programs in Carnes, over part of our Carnes position, will include an occasional one or two Austin Chalk wells in a 10 to 12 well pad that is mostly lower in Upper Eagleford locations. So we have been developing them. They're limited to part of our current position in terms of what we're investing in near term. And so they're not a huge feature for us. We like them where the reservoir quality is good. So we co-develop them where it makes sense. I don't think it's a big driver for our program. So it's not something that is... really worth calling out or highlighting as unique. It's fairly limited, but where we do have them in part of our current position, we really like them.

Okay, great. And then on the Buble West appraisal well, I was hoping you could kind of just speak to the confidence in the $90 million well cost, or maybe just break down the incremental costs from the first well. and why you think these won't repeat just to kind of have confidence as the play moves forward and the overall well costs and ultimate F&D.

Sure. Before we drilled the Bubal 1X well, we estimated that a dry hole cost for the well was $65 million. When we drilled the well, we encountered section in the shallow Turonian above the discovered Turonian interval that was slow to drill. fairly slow rate of penetration as we drilled it. It's slower than we had anticipated and we've incorporated that learning into our dry hole cost estimate for the Gubal West 1X well. So instead of assuming it's $65 million, we're moving it to $90 million. If we encounter hydrocarbons in the West 1X well, we're likely to spend additional funds with formation evaluation, logging core, fluid samples, et cetera. And that might push the well cost above $90 million, which is normal how we conduct our business.

Thank you.

Thank you.

Your next question is from the line of Tim Rosvan with KeyBank. Your line is now open. Please go ahead.

Thank you. Good morning, and I appreciate you taking our questions. I want to ask on Vietnam more broadly. You've now wrapped the HSV appraisal program. You've talked about you're really an LDT. I believe it's a 40 to 80 million barrel resource potential area. Given the large size of your position across several blocks, can you talk about longer-term exploration aspirations in Vietnam, maybe 2027 and beyond? And do you ultimately see this asset sort of self-funding future exploration once you get LDV online?

Yeah, that's a really good question. We are drilling the Lakta Trong North 1X well now. And as you mentioned, it has a pre-drill mean to upward resource range of 40 to 80 man barrels, which is a nice prospect to drill. And with success, it likely sets up a development as a tieback of Lakta Trong North and Lakta Trong to the infrastructure at Lakta Vong. As Lakta Vong comes online in the fourth quarter, we'll generate revenue. over the course of a few years. We'll recover the costs of our historical investment in the block, that'd be all of our exploration costs in Block 15-105, and also our development costs of Lac de Vente. And then we'll be able to use the revenue from Lac de Vente to recover costs from the exploration that we're doing going forward, what we're doing now and in future years. We have significant remaining prospectivity on both Block 15-105 and 15-217. and we'll test those likely between now and the end of this decade and stage in a development with standalone developments where the resource size is large enough to be necessary or tiebacks to existing infrastructure in what are likely to be two key hubs, a Lac du Banc and Haise Vong Hub in kind of a north and south position. So we're really excited about the potential there. We have a pretty strong record of having successful exploration here. We keep finding oil and we need to find about 8 to 10 million barrels for an economic tieback. So if we can find 40 to 80, we'll be very happy. It'll be very value trading for us and allow us to maintain a long production plateau of our overall Vietnam business. So we're creating a lot of value here with our shareholders, spending very little money to do it.

Okay, that's good context, thank you. As my follow-up, I just wanted to go back to the Eagleford. You're spending $70 million. Can you just talk, is this like a spot rig that's going to come and drill a couple pads over six months? and then as we think about that, should we be thinking over the medium term that maybe you're going to run this at a 40 to 45,000 barrel a day level? Just trying to kind of contextualize the ramp you're anticipating. Thank you.

Yeah, so where we sit today, we do not have a rig actively drilling in Eagleford. We completed our drilling program that we had originally contemplated and are working through the last of our completions and well on lines. And what we've decided to do is resume drilling instead of resuming drilling in January to pull that forward to begin in October. We'll drill a pad in Carnes and a pad in Caterina this year. We'll probably begin completing the Caterina pad at the end of the year, and we'll bring those new wells online early in 2027. And I think what you'll see is that's just the beginning of an active program next year. I think your range of rates for Eagle for next year is reasonable. I would assume we're a little toward the higher end of what you said than the lower end, but we still have to formulate exactly what our 2027 program is.

Okay. Thanks, Eric. Thank you.

Your next question is from the line of Josh Silverstein with UBS. Your line is now open. Please go ahead.

Yeah, thanks. Good morning, guys. I want to see how we should be thinking about using the balance sheet and the shareholder return profile in this period of higher spending. Are you willing to use the balance sheet to support all these projects getting incremental capital? And then as far as the shareholder return profile, is this really just limited to the base dividend going forward as you examine everything here? Thanks.

That's a great question, Josh. The way I would frame it is we have not changed our capital allocation plan or framework at all. We still have the exact same priorities. We plan to prioritize investing in our assets to maintain or grow the scale, pay dividend, focus on balance sheet and occasionally share buybacks when it makes sense. And so we really have no change in that. Our plan, as we've been very clear about, is based on adjusted free cash flow, which is after our dividend and a few other things, including M&A. We we will likely going forward have Modest free cash flow. There may be periods between now and first oil at HSV or potentially if we're so fortunate that we have periods of time of negative free cash flow for the whole company. We're going to be measured in our pace and we're going to be very conscious of protecting our balance sheet. We're not afraid of using our liquidity and our balance sheet as necessary. but we're going to keep ourselves in a strong balance sheet position at all times. That's a priority for us. So we will definitely be maintaining our dividend. That's core to us. We paid a dividend since 1961. We're going to continue to pay a dividend, I would imagine, going forward for the entire tenure of me being here. And if we encounter situations where we think our share price is significantly out of whack with intrinsic value, then we'll be active in share buyback. So I think that's the same story you've heard from us in the past. We're fortunate to have even more organic growth opportunities than we had a few years ago. It provides us more challenges in terms of how we choose to allocate capital, but we're in control of the pace as operator everywhere. And we're gonna do what we think is best for shareholder value going forward. Again, not being afraid to use our balance sheet, but always with an eye toward protecting a strong balance sheet at all times.

Got it. And then I just want to see what's potentially on the exploration horizon next year since you've got its new exploration opportunities across West and North Africa and how you would classify them relative to what you've done in Vietnam and Cote d'Ivoire.

Yeah, thanks for that. I think you'll see next year that we'll invest in the Gulf of America in exploring in one or two wells. You'll likely see us invest in Vietnam in our Kulong blocks, most likely in 15105, the inventory that we were just talking about a few minutes ago. And I don't expect other than appraisal drilling in West Africa, we'll have more West Africa drilling activity. We're intentionally phasing in opportunities in West Africa that have They're at different parts of our prospect maturation timeframe. So we signed a block in Morocco recently. We're going to reprocess seismic there. That's very little spending. We're hoping to finalize agreements for Cameroon and Mauritania by the end of this year and next year spend small money with studies, maybe the beginnings of seismic reprocessing, small dollar spending, drilling in Cameroon, Mauritania or Morocco is probably a 2028, 2029, 2030 thing, depending on what we find. We're going to follow our recipe of very detailed regional study leading to detailed prospect maturation and drill or not drill based on the merits of the prospects. that takes some time and as you saw it led to some success here for us in Cote d'Ivoire. So we think we're setting up for a repeatable business model of exploring and emerging on frontier basins and doing it with low entry costs, relatively low well cost targeting large resource and that's very value creating if we can continue to have some success.

Thanks Eric. Thank you.

Your next question is from the line of Leo Mariani with Roth. Your line is now open. Please go ahead.

Yeah, hi. You spoke to this a bit earlier, but clearly you're making a decision to put more capital in the Eagle Ford to ramp it. Presumably that is probably more of a higher oil price type of decision. I would venture a guess that if oil is lower for whatever reason, then perhaps that asset does not see real increase in free cash flow from putting more capital into it, which obviously will generate more production. Can you just provide any kind of thoughts around that? I mean, it just seems like obviously now with higher oil prices, that investment will generate incremental free cash flow in the next several years, but perhaps there's some kind of break even where that starts to go away if oil is low enough.

Yeah, Leo, our decision to invest more in Eagleford is not driven by Thank you for joining us. We feel that Eagleford investment makes sense. We generate strong free cash flow over the last few years doing it. We have increasingly strong well performance. And at even modest oil prices, we'll be investing in it to generate strong free cash flows. So we're not reacting to oil price. We're saying we now have a strong portfolio of organic growth to invest in. And part of the way we can fund that is by generating more free cash flow from Eagleford by investing more in Eagleford.

Okay, appreciate that. And then just on Vietnam, obviously you guys are going to have first oil here in the fourth quarter. You know, just looking at your guidance, you kind of respect the, you know, relatively small amount, but presumably that's going to ramp nicely in 2027. Can you just provide maybe a little color around kind of thoughts on that potential ramp on Vietnam oil mixture?

Sure. As you mentioned, we'll have fairly limited contribution to production this year because of a fourth quarter on line for soil for Lac de Vang. We will continue to drill development wells through this year and into next year. If you look out toward the end of 2027, Lac de Vang net production is probably in the 5,000 to 9,000 barrel a day range. as we continue to drill the remaining development wells in our phase development program through 28 and 29 will ultimately ramp up to 10 to 15,000 barrels a day.

Okay, so just to be clear, is that 5-9 kind of like a 27 exit rate and then obviously it continues to ramp in 28 and 29?

That's exactly right.

Okay, helpful for sure. And then just last one for me, Eric. You talked about this a little bit, but you guys have really gotten into a number of new exploration plays recently, a lot of which are in Africa, and you kind of rattled off the plans, which seem a little bit limited in terms of capital in the near term, but presumably those plays could require more capital as you get into 28, 29. I imagine there might be you know a shot clock on some of those to get some wells drilled eventually if you think prospects are maturing in the right way. Does this set up for like just you know a lot higher capital later this decade in kind of the success case and then just if that's right just thoughts on how you would kind of handle that fund that?

We haven't characterized that Leo is if we are conducting our typical sort of assessed opportunities and drill and exploration well occasionally and then that would not materially push our capital higher. Obviously Boubal is likely to push our capital higher with success. Exploring and drilling an occasional well is something that fits into our overall exploration program, kind of in line with what we've been spending. If we are fortunate to have a discovery in Morocco, Cameroon, Mauritania, then that would lead to additional appraisal drilling and then development drilling, which would be great. That's obviously a long way away. And as you know, Okay, thank you.

As a reminder, if you would like to ask a question, press star 1 on your telephone keypad. Your next question is from the line of Charles Mead with Johnson Rice. Your line is now open. Please go ahead.

Good morning, Eric, to you and your whole team there. I'd like to go back to the appraisal effort at Bubo, and I apologize if I missed some of the earlier detail, but I think What I heard you say is that the Bubba West is a down-dip Toronian appraisal. But I guess I want to ask two things. I guess the design of the appraisal well and then the plans for the Centermanian. For the design of the appraisal well, there's a lot of competing, I guess, priorities or competing priorities. ways that you design appraisal. Well, is this, is this, you know, for eight miles out, is this just, is the dominant thing to test the extent of the structure or are you really trying to, or are you perhaps instead looking for, you know, for more reservoir development and more, more pay thickness? And then, and then how would you answer that same sort of question for the eventual Centermanian appraisal test?

Okay, thanks, Charles. So the West 1X well is designed to test Turonian down dip. It is testing for variability of reservoirs. That would be reservoir thickness, reservoir quality. We're hoping to get confidence that where we drill it, the Turonian at that location is connected to the Ubal 1X location and also hoping to demonstrate an oil water or an oil level deeper than the oil down to in the Ubal 1 well. So it's doing multiple things. And we think that location is important because with significant oil presence in that well, in the Vival West 1X well, to be clear, that we'll have high confidence that we have a commercial development, but still significant uncertainty about the range of resource. So the location of the 1X well was drilled in a position where there was significant up-dip reservoir in the Santa Mania and the Toronians. and potentially significant down dip potential in both. And the reservoir and the Turonian and the reservoir in the Santa Mania, they cross. If you were looking at them from above, they cross like an X. We drilled the one X well right where they cross. So like I said, potential up dip and down dip from that in both reservoirs. And ultimately, if we have success, we'll continue to identify and drill appraisal wells that will over time reduce uncertainty and give us high confidence in what we need to develop, how we need to develop it. So this next well is really key for us to having high confidence in a commercial discovery.

Got it. So it gets you with confidence over the low end, but with the upper end maybe still more unbounded. Correct. Going to... Going to Vietnam, and I appreciate your comments earlier about the basis that, if I understood right, that with the 4X, HSP 4X, you basically just didn't find reservoir quality rock. I'm curious, does that affect the prospectivity for some of these other blobs you have on your map in Block 15217? I think they're labeled like Bozam and Hai Su Hong. Does this diminish your... your appetite to drill those somewhere down the line?

Those other prospects, we obviously will have learned a little bit from drilling Haizhou Vong through various reservoirs and we will incorporate that into our understanding of those. I would say because of the diversity of different play types there and different reservoirs that those prospects are targeting that we probably still have quite a bit of confidence that they make sense. But again, there's a little more work to do to plan and exploration program there. In 15105, we have, I would say, very well characterized and the learnings from HSV don't significantly impact our prospectivity there. So you'll see us focus on exploring in 15105 in the next couple of years with probably activity in 15217, maybe in 2829, not in 27. Got it. Thank you for that in detail. Thank you.

There are no further questions at this time. I'll turn the call over to Mr. Hambly for closing remarks.

Thank you. I'll close by thanking our employees for their commitment and execution. To our shareholders, we appreciate your continued trust and support. This concludes our call.

This concludes today's call. Thank you for attending. You may now disconnect.