Good morning, ladies and gentlemen, and welcome to the Murphy Oil Corporation second quarter 2022 earnings conference call. If at any time during the 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, Investor Relations and Communications. Please go ahead. Good morning, everyone, and thank you for joining us on our second quarter earnings call today. Joining us is Roger Jenkins, President and Chief Executive Officer, along with Tom Mireles, Executive Vice President and Chief Financial Officer, and Eric Hambly, Executive Vice President of Operations. Please refer to the informational slides that we have 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 interest in the Gulf of Mexico. 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 2021 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 Jenkins. Roger? Thank you, Kelly. Good morning, everyone, and thank you for listening to our call today. On slide two, Murphy continues to deliver a strong value proposition. Our ongoing execution excellence from our three producing areas proves that we are a long-term sustainable company. As we disclosed in our 2022 sustainability report released yesterday, significant improvements in emissions intensity and water recycling. Excuse me. Our offshore competitive advantage is continually reinforced, most recently with the achievement of first oil ahead of schedule from the Khaleesi, Mormont, Samurai, and King's Quay projects in April. We continue to generate strong cash flow with higher oil prices and well performance exceeding expectations as we've been able to increase our shareholder returns through quarterly dividend raises as well as accelerate our debt reduction goals. On to slide three. Murphy remains focused in our three strategic priorities of de-lever, execute, and explore. In June, we continued to advance our delevering plans with the redemption of $200 million of our 2024 senior notes. Subsequent to quarter end, we announced an additional $242 million in long-term debt reduction, which will take out the last of our 2024 notes along with reducing our maturities. These transactions put us well on our way toward accomplishing our $600 million-$650 million debt reduction goal for 2022. The Murphy team continues to have outstanding execution across all projects. We have now brought online four wells in our seven-well Khaleesi, Mormont, Samurai field development with the King's Quay floating production system achieving 97% uptime. The fifth well of this seven-well project is expected to come online imminently. Additionally, we are also acquiring high return bolt-on working interest in two non-operated Gulf of Mexico fields, providing considerable upside to production with several planned development wells. Looking at our onshore assets, recent online wells in the Eagle Ford Shale and Tupper Montney are exceeding production expectations due to enhanced completion designs and longer laterals with average forecast investment recovery or payback of less than six months. Our exploration program continues to advance. We have the drilling permit in hand for our Tulum exploration well in Mexico, and we're finalizing plans to spud in the fourth quarter of 2022. Murphy also recently received offshore operator approval from regulators in Brazil, completing a necessary step in attaining a partner's working interest in the Potiguar Basin. In the Gulf of Mexico, we're progressing plans for our 2023 operated exploration program. Overall, our strong execution across our operations has supported ongoing debt reduction, allowing us to fully restore our dividend to pre-2020 levels of $1 per share on an annualized basis announced yesterday, representing a 100% increase from the fourth quarter of 2021. Further, the three components of our strategy together support our new capital allocation framework that we're disclosing here today. As we target returns to shareholders through repurchases and potential dividend increases tied to debt levels with an ultimate long-term debt goal of $1 billion. On slide four. In the quarter, we produced 164,000 barrels equivalent per day, comprised of 62% liquids. I'm very pleased to see our production volumes at the high end of guidance as a result of outperformance in the Gulf of Mexico and Eagle Ford Shale. Realized prices remained strong this quarter with oil at $109 per barrel, once again above WTI prices. With NGLs at $41 per barrel and natural gas net back to us nearly $4 per thousand cubic feet. On slide 5, we're excited to have published our 2022 sustainability report yesterday. The team has done an incredible job once again as they work within their teams and roles to improve Murphy's environmental footprint year after year. Importantly, we have seen considerable improvement in our various emissions intensities from 2019 to 2021, with a 20% reduction in greenhouse gas emissions, 28% reduction in methane, an incredible 49% reduction in flaring intensity. Our efforts are supported by receiving third-party assurance for a second consecutive year on our greenhouse gas Scope 1 and 2 data. Their support also focuses on how we positively impact the lives of the people and communities where we work. I'll now turn the call over to our CFO, Tom Mireles, to give a financial update. Tom? Thank you, Roger, and good morning, everyone. Turning to slide six. In the second quarter, we reported net income of $351 million, or $2.23 net income per diluted share, which is our highest quarterly earnings from continuing operations in nearly a decade. After-tax adjustments included the $70 million non-cash mark-to-market gain on derivatives and a $25 million non-cash mark-to-market loss on contingent consideration. As a result, we reported adjusted net income of $305 million, or $1.93 adjusted net income per diluted share. Cash from operations, including non-controlling interest, totaled $621 million for the quarter. After accounting for net property additions, as well as $47 million for the acquisition of high-returning non-operating Kodiak working interests, we achieved positive adjusted cash flow of $267 million. Murphy reported accrued CapEx of $266 million in the second quarter, which excluded non-controlling interest in the Kodiak acquisition. Additionally, $25 million of contingent consideration payments were associated with achieving first oil at the King's Quay floating production system. Slide seven. Our delevering efforts over the past 18 months continue to strengthen the balance sheet. During the second quarter, we redeemed another $200 million of our 2024 senior notes, resulting in $2.3 billion of long-term debt outstanding at the end of the quarter. As of June 30, we had approximately $430 million of cash and equivalents on hand. Following quarter end, we announced an additional $242 million of debt reduction, achieved by the redemption of the remaining $42 million of the 2024 senior notes, as well as the tender offer of up to $200 million of senior notes due 2025, 2027, and 2028. These transactions disclosed through today total nearly $450 million in debt reduction this year, putting us substantially closer to achieving our debt reduction goal for the year of $600 million-$650 million. With that, I'll turn it over to Eric. Thank you, Tom, and good morning, everyone. On slide nine, we saw outstanding well performance from the Eagle Ford Shale this quarter as we produced 36,000 barrels of oil equivalent per day with 86% liquids. As planned, we brought online 17 wells in Karnes and six wells in Catarina for a total of 23 operated wells in the quarter. Last quarter, we disclosed CapEx revisions in our 2022 program related to revised completion designs, and I'm pleased at the great results we have seen from modifying to higher intensity fracs. These wells have exceeded forecasts with Karnes gross IP30 rates averaging 1,900 barrels of oil equivalent per day and Catarina gross IP30s averaging 1,100 barrels of oil equivalent per day, and all wells averaging 93% liquids volumes. Overall, our 2022 drilling and completion program is forecast to average $5.5 million per well. Taking this into account, as well as the strong production rates, we predict achieving full investment recovery or payout of thre to five months for Karnes and 6-11 months in Catarina, assuming a $85 per barrel WTI price. Our 2022 operated program concludes in the third quarter with four Catarina wells, two of which will be in the Austin Chalk formation, and we look forward to reviewing those results. Slide 10. In the Tupper Montney, Murphy produced 275 million cubic feet per day in the second quarter. 15 wells were brought online, five of which were slightly ahead of schedule. The remaining five wells were brought online in July, wrapping up the 2022 program. We recently achieved a record high gross production peak of 415 million cubic feet per day across the entire asset. Our team has done an incredible job this year of managing costs and regulatory challenges, and we were able to bring on these wells for an average of $4.8 million per well. Overall, we are realizing average investment recovery in less than six months, assuming an AECO price of CAD 5.50 per million BTU. Slide 12. Our Gulf of Mexico assets continue to be a home run for us, particularly the fields and assets we purchased in 2018 and 2019. Murphy produced 70,000 barrels of oil equivalent per day in the second quarter, with 79% oil volumes. Approximately 80% of our Gulf of Mexico CapEx budget for the year is dedicated to our major projects at Khaleesi, Mormont, Samurai, and the non-operated St. Malo water flood, and we are pleased that they remain on schedule. The remainder of our capital plan for this asset is dedicated to the development and tieback wells, with the operated Dalmatian number 1 well and 2 non-operated Lucius wells all being drilled this quarter, while a non-op Kodiak well is being completed. Slide 13. As announced today, we have executed a series of accretive, highly economic bolt-on transactions in our Gulf of Mexico business at the non-operated Kodiak and Lucius fields. Together, the additional working interests and the three new wells online later this year at estimated incremental production of approximately 1,500 barrels of oil equivalent per day for the annualized full year 2022, and 4,100 barrels of oil equivalent per day estimated for the full year 2023. Specifically, in the second quarter, we closed the acquisition of 11% additional working interest in the Kodiak field for $47 million after closing adjustments, with expected investment recovery within one year. We have also signed a purchase and sale agreement to acquire an additional 3.4% working interest in the Lucius field for $77 million after estimated closing adjustments, with closing expected in the third quarter and forecast full investment recovery within two years. Following these transactions, we have a total working interest of 59.3% in Kodiak and 16.1% in Lucius. What we like most about these purchases is that they have active opportunities to further increase their value. Murphy and partners have recently drilled a successful well at Kodiak, which is now being completed, and we are part of a two-well program at Lucius. As we high-grade our portfolio, we also disclose today the divestiture of our 50% working interest in the operated Thunder Hawk field, scheduled to occur in the third quarter. Slide 14. After achieving first oil at the Murphy-operated King's Quay floating production system in early April, we have now brought online a total of four wells in the Khaleesi/Mormont/Samurai field development project. Results from these wells continue to be above expectations, with current combined gross volume of 70,000 barrels of oil equivalent per day, or 18,000 barrels of oil equivalent per day net to Murphy, and approximately 87% oil. The floating production system continues to achieve significant uptime at 97%. The 5th well, and the last in the Khaleesi/Mormont field, is anticipated to flow imminently. The rig will then move to the Samurai field to complete the remaining two wells in the seven-well. Turn it back to Roger. Thank you, Eric. I'll review exploration today on slide 16. Exploration remains the third pillar of our strategy. Our most near-term opportunity is located offshore Mexico, where we received a drilling permit and are finalizing plans to spud the operated Tulum well in the fourth quarter of 2022 at a net cost to us of approximately $23 million. We're looking forward to the results of this well, which is located on the western side of our Block 5 acreage. On slide 17, in the Gulf of Mexico, we're advancing our exploration portfolio there and are targeting a two-well program in 2023. The first planned well is the Oso #1 well, which we operate and hold 50% working interest. At this time, we're finalizing the second well with partners. We have several great choices among our 20 key prospects in the Gulf. Looking at production on slide 19, as announced last quarter, we made several adjustments to enhance our onshore well completion designs, which have been reviewed today. I'm pleased to say we've been seeing immediate positive results from that decision and our top-tier execution. This production has exceeded expectation. This continues to elevate our forecast for the year. For the third quarter of 2022, we anticipate production range of 180,000-188,000 barrels of oil equivalent per day, with 49% oil and 55% liquids. This accounts for nearly 10,000 barrels of oil equivalent per day of onshore and offshore downtime, as well as 6,000 barrels of oil equivalent per day set aside for assumed Gulf of Mexico storm downtime. Importantly, due to outstanding Eagle Ford Shale and Gulf of Mexico execution, as well as bolt-on acquisitions, we're increasing our full year 2022 production guidance today to a new range of 168,000-176,000 barrels equivalent per day at 52% oil and 58% liquids. This represents a new midpoint of 172,000 barrels equivalent per day compared to 168,000 barrels equivalent per day previously. On our capital plan on slide 20, Murphy is maintaining our 2022 CapEx guidance range at $900 million-$950 million, excluding acquisitions. Approximately 60% of our spending occurred in the first half of the year, in part to support our onshore program, as more than 90% of our operated wells are online year to date. Further, approximately 80% of the offshore CapEx is dedicated to major projects in the Gulf. By maintaining this spending level, our increased production volumes and stronger oil prices provide us significant free cash flow to allocate toward our increasing dividend of $1 per share annualized, as well as nearly $450 million in announced debt reduction transactions at this time, with further debt reductions planned for the remainder of the year. What's real important to us today is slide 21, which is our new capital allocation framework. To expand on our previously announced 2022 debt reduction goal of $600 million-$650 million, the board of directors has approved a multi-tier capital allocation framework allowing for additional shareholder returns beyond the quarterly-based dividend of 25 cents per share, while advancing toward a long-term debt target of $1 billion. Additionally, the board has authorized an initial $300 million share repurchase program, allowing Murphy to repurchase shares through a variety of methods with no limit in time. Our framework disclosed today is three straightforward levels, and it's based on an adjusted free cash flow metric calculated as cash flow from activities before changes in working capital, less capital spending, accretive acquisitions, our dividend, NCI distributions, and other projected payments. Murphy 1.0 is where we stand today. With long-term debt exceeding $1.8 billion, we will allocate adjusted free cash flow to reducing debt while maintaining our $0.25 quarterly dividend. Once debt is between $1 billion and $1.8 billion, and we will reach Murphy 2.0. This time we will adjust to allocating approximately 75% of adjusted free cash flow to debt reduction, with the remaining 25% distributed to shareholders, weighted toward repurchases with potential dividend increases. Lastly, we'll achieve Murphy 3.0 when our long-term debt is approximately $1 billion or less. Our framework shifts at this point and to seek to allocate up to 50% of adjusted free cash flow to our balance sheet. Meanwhile, a minimum 50% of adjusted free cash flow will be allocated to shareholders through share repurchases and potential dividend increases. Our plan is primarily to repurchase shares at various stages of Murphy 2.0 and 3.0. At any time, we reserve the right to advance share repurchases should our equity value significantly dislocate from crude oil prices while our company continues to exhibit outstanding execution. On slide 22. In summary today, our assets continue to perform well with enhanced completions of accretive acquisitions, resulting in fast paybacks, higher volumes across all our operations. This leads to additional free cash flow, which allows us to advance our delevering goals and our dividend. We're looking forward to the exploration opportunity in offshore Mexico as we drill there later this year, as well as progressing our 2023 plans in the Gulf. Most importantly, we're able to disclose an exciting capital allocation framework today as we target returns to shareholders through share repurchases and potential dividend increases that are tied to long-term debt levels while we will be seeking an investment-grade credit rating. In closing today, I'd like to thank our employees for their outstanding efforts this past quarter, as this success and operational and financial execution would not have been possible without their contributions. With that, now I'll turn it over to people on the phone here for the call, and I look forward to your questions this morning. Thank you. Ladies and gentlemen, we will now begin the question-and-answer session. Should you have a question, please press star followed by the one on your touch-tone phone. You will hear a three-tone prompt acknowledging your request. If you are using a speakerphone, please lift the handset before pressing any keys. First question comes from Paul Cheng at Scotiabank. Please go ahead. Thank you. Good morning. Good morning, Paul. Roger, just the first quick one you said is the mechanic that you don't have a lot of debt maturing. Once you get to $1.8 billion in the gross debt, should we assume the debt repayment will follow the maturity schedule or that you're just going to continue to use the tender offer or open market purchase to quickly get to that 1.0 or below if you have the excess free cash flow? I'm gonna have our CFO, Tom, answer that for you, Paul. Hey, Paul. Yeah, thanks for that question. You know, a lot of this, the timing will depend on the type of price environment that we have. You know, at current prices, it's likely that we would have to tender to get to those longer-dated maturities. If things change, you know, we'll just have to see what the market offers at the time. The tender offer is what we're thinking. Okay. That, I think Roger mentioned that you guys will be seeking for investment grade. What needs to be done in order for you to get there? What are benefits you will receive once that you're at investment grade? Okay. Good question, Paul. Thanks for that. The way we think about it is we need to execute on our operations as we have been and continue our debt reduction. What we think the benefits are over there is overall lower cost of capital, minimizes our requirements to post collateral with counterparties. There's a lot of advantages that we see with getting to it. Final question from me. Roger, with the current commodity price outlook, does it in any shape or form change your investment plan in Tupper as well as the CapEx of the Duvernay? Thank you. Thank you for that question, Paul. Right now, as we look ahead in capital allocation, we have a plan of maintaining near the levels we are in the Eagle Ford. Next year, we have a capital plan to fill our Tupper Montney plant to a 500 million a day gross. From last year to this year to next year, there's no changes in our onshore plan. That's how we're thinking about it now as we continue on with this framework and not focusing on large production increases. We will have higher production next year as we add on a full year of these Gulf projects and exit the year. With this guidance we're providing today, Paul, we're exiting the year at a very high rate and continue that on to the next year, and we're very excited about getting close to 200,000 barrels a day in our business. Thank you. Thank you. The next question comes from Leo Mariani at MKM Partners. Please go ahead. Good morning, Leo. How you doing? I'm doing well. Good morning, Roger. Wanted to hear a little bit more about the acquisition environment in the Gulf of Mexico. Obviously, a couple small deals that you guys were able to get together here. It looks nice. I guess there's certainly kind of a handful of bigger deals, you know, floating around out there as well. Can you maybe just talk about kind of what you're seeing in the market, and then kind of what, you know, Murphy's additional appetite, you know, is for Gulf M&A and how competitive it is out there? Thank you so much for that question, Leo. Good question. Something we do focus on a good bit because we really feel we have a competitive advantage in M&A in the Gulf, and we've been in the business so long we're partners of so many fields that we have a good bit of data, and it gives us a real advantage in analyzing data. On occasion, one of the deals today was through a pref right that we had, which is very valuable, and another is through a purchase of a company strategically wanting to exit the Gulf, an international company. We were able to work with our partnership group and execute that. We look and know about almost all deals, very into that business. What we like, number one, Leo, is high return, accretive below 2.0 EBITDA payout deals that pay out very quickly where we understand the assets. Further, we like M&A on opportunities that have a growth component to it. Like when we bought more at Kodiak, there's a rig program there today, drilled a very successful well there. We're completing that well today with our partner. We are able to purchase more of Lucius. It's operated now by Oxy. After Oxy's reorganization, they're operating that asset extremely well, and there's a two-well program there and possibly more. We're looking for things where we have a competitive advantage, information, a lot of knowledge about it with a good operator, with work to be done. As to the other deals that come up, when large PDP blowdown, large abandonment obligation deals are not our favorite, and we'll, you know, be treating that accordingly. So that's kinda how we feel about Leo, if that answers your question. All right. No, that's helpful for sure. I guess just wanted to kind of talk a little bit about kind of spending for next year. When you guys originally put out the multi-year plan, there was a big step down in capital in 2023. I guess earlier on the call you indicated there was no real change to your onshore plan. Just wanted to get a sense with these, you know, high commodity prices, if you still intend to kind of step the capital down, you know, a fair bit in 2023, or are there other maybe projects in the offshore that are interesting to you that might, you know, get more capital on a relative basis? Thanks for that Leo question, anticipated question today. Thanks for asking it. You know, in the first quarter on our call, we disclosed, you know, we had this capital range of $650 million for 2023 and 2024, which you're greatly familiar. We did increase that on that call to near $700 million with inflation at that time. We'll still need to recalibrate these figures with some inflation information for 2023 that's dependent on several things. As As I stated earlier this morning, it's our plan to maintain our Eagle Ford and Tupper plans at this time. There's no changes to onshore plan. Production will be higher due to Gulf wells being online. I need to work inflation, and our team's in the middle of that, and our final plans in the Gulf. As usual, we just really have no plans to disclose our spending until our customary time in January. I'm real pleased with our execution. I'm real pleased with our production level. I'm real pleased with the CapEx we've been spending in onshore and how we're able to do that. Feel well positioned, but trying to keep CapEx as best we can without inflation is the main focus today, Leo. Okay. Just on the returns of capital, I just wanted to make sure I sort of understood. I know you have these debt targets to hit here, and you're clearly paying off more debt, you know, this year and next. Just to be clear on the debt, is that an absolute kind of debt target you want to hit before you get to the kind of, you know, 25% return of capital to shareholders, or is that more of a net debt target? Thanks for that clarification, Leo. That's a very good question. No, it's straightforward long-term debt. We really don't use the term net debt here. Our net debt in those scenarios would be very low, but we're talking about bonds, long-term bonds, and trying to return capital to shareholders. That's what's significant about today, Leo, return capital to shareholders as we pay down debt. I think prior it was thought there wouldn't be additional returns to shareholders until we reach debt levels, but we have a way of returning more along that path today, and we're real excited about that and think it's gonna be very positive for our long-term investors. Okay. Thanks, guys. Thank you. Next question comes from Neal Dingmann at Truist Securities. Please go ahead. Neal, good morning. Thanks for calling in. Thanks for calling in. Morning. Absolutely. Thanks for all the details so far. My first question's on shareholder return, maybe looking at it a little bit different. I'm just wondering, could you discuss, Roger, your view on how you view the value creation as it pertains to rewarding investors with shareholder returns, as you've suggested going forward, versus continued production reserve growth that y'all are so great at? Thanks for that question, Neal. It's a good question. We believe that we have a company that can be sustainable for a very long time in a 200,000 a day world, slightly growing if we want to. We believe during that time, we can have incredible balance sheet, which gives us incredible flexibility and de-risks our company greatly and return a lot of money to shareholders. We'll be building cash, which can advance shareholder returns further or used in other needs at that time. We're really into a dividend, which, you know, we're a 60-year dividend paying company. We've paid $1.6 billion in dividends over the last 10 years. We see a strong dividend return to shareholders through buyback plan as our basis plan to create shareholder value. No, makes a lot of sense. My second is on, been asked a little bit, but I may ask a different way on offshore. I'm just wondering, you talk about, I know you've got a lot of things going at King's Quay. You talk about potential after these wells come on, further incremental capacity, and then if you also could talk offshore, maybe about more potential, Gulf of Mexico, pref right deals you might be seeing. I'll handle the M&A piece, then Eric could talk about specifics of the operation. These are incredible deals that we were able to be a part of here. It speaks a lot about our company. It's always an advantage to have a prep right. This was quite an old deal that came about months and months ago, and we were able to step in. Then another deal was a strategic exit, again, by an international player. In these strategic exits, these companies seek an experienced company with long-term ability in the Gulf, great reputation in the Gulf, great safety, great regulatory, great balance sheet. We've been there since the '50s, and it gives us a big advantage in buying things from people. There will always be deals that come and go. We obviously have a very senior and experienced BD team here. We hear about things ahead of time. We know what's going on in the business from, you know, 30-40 years experience, really, and puts us well-positioned to know what's going on. We have a lot of information, and we're able to have a unique ability to look at deals. We pass on lots of them, and we take some of them and have a high criteria 'cause we really want accretive, outstanding deals, and we've been able to do it, and I think we'll be able to continue to do it. Eric could talk about King's Quay. Yeah. Okay. Thanks, Neil. First of all, I just wanted to highlight, I think that we're extremely proud of our team's execution on the King's Quay, Khaleesi, Mormont, Samurai production. It's really setting us apart in terms of our execution offshore. As we highlighted in our, on our release in our earlier discussion, we're currently producing about 70,000 BOE per day from the facility. That's on a gross basis. We will soon start flowing the last well in the Khaleesi Mormont project, and that'll add significant production. As we head toward the end of the year, we expect to be approaching the nameplate capacity of King's Quay facility, which is 85,000 barrels of oil per day. So we've been doing some preliminary work on that to figure out what rate we can achieve possibly beyond nameplate capacity. We think if we continue to see outperformance of our wells as we deliver the remaining wells in the seven-well program, we think we could very easily get to 100,000 barrels per day from the facility capacity with minor adjustments to how we operate the facility. We're pretty excited about our trajectory as we head into the end of the year with the remaining wells to come online there. No, it certainly sounds like a lot of upside. Thanks, guys. Thank you, Neal. Thanks, Neal. Thank you. Ladies and gentlemen, as a reminder, should you have any questions, please press star one. Next question comes from Roger Read at Wells Fargo. Please go ahead. Yeah. Hello. Good morning. Hello, Roger. Congrats on the quarter. Glad to see the dividend getting back. I guess two things I'd like to ask you about. One, just because it's topical with the, I don't know if I'll call it aptly named, but let's call it ironically named Inflation Reduction Act. The potential for a royalty increase and how we should think about that potentially impacting your Gulf of Mexico. I'll hold up and then ask my second one. Thanks, Roger, for that. I'll take that question. We see no impact on that. All of our leases have an existing contract with the U.S. government. It's held the test of time. There's no ability in those contracts to raise our royalty rates. The royalty rates described in this, you know, ironically named bill, a good wording from you, is that it's for new leases. It would only pertain to the Gulf new leases from the new plan that's supposed to take place. As you know, at Murphy, we have no federal onshore leases. As far as other things in the bill, such as methane taxes and things to that effect, in our offshore environment, this will be very de minimis, and we see really no impacts of this, very de minimis impacts of this bill on Murphy Oil Corporation. Oh, good. Good to hear. Second question for you. Given the Murphy 3.0 goals on long-term debt, yet, you know, today you announced obviously some acquisitions in the Gulf, and a lot of the questions are focused on more. How would you or how should we think about any future opportunities to do acquisitions within that framework? In other words, if you had to delay the achievability of Murphy 3.0 by six or nine months because of a, you know, very attractive, accretive transaction, just how should we think about that fitting into the overall system? Thanks, Roger, for that question. A good one. Naturally, any company with the framework, it's a targeted framework. An outstanding M&A that comes your way would have to be, you know, judged by you and your board. Do you want to forego a framework of a few months, like you say, to do so? We also see many other name brand peers with frameworks occasionally buying assets as well. We would be no different. Also during that period, we would be building cash, a significant amount at any kind of an oil price there, which will give us loads of flexibility around further shareholder returns or M&A or exploration success. We have a high bar on M&A. We're not looking at M&A to grow or anything like that. It must make unique investment criteria that we focus on. Sure, any company that has an incredible deal, and we've had some incredible deals, and these two today are very good. You would have to delay that a few months as you state. But then during that time, there's a good bit of cash on the balance sheet as well, Roger. Yeah, I recognize that. It does appear to be a pretty fertile environment out there in the Gulf right now for smaller transactions, so I was just curious how you think about it. One last one if I could sneak it in. On the Tulum exploration well, what's the- Yes. What's the expected timeline? Like, when should we anticipate a result to come out of that? The well should spud in October of 2022. The rig is actually working at Kodiak today with our non-op partner. The rig will then come to us. We're drilling a very nice well at Dalmatian, our field we've had for a long time that's very successful. We will then be taking the rig from the eastern Gulf of Mexico and drill the well under our control, and we anticipate that spudding in October. It's probably a two-month well. That's our timing, Roger. That's great. Thank you. Thank you. Thank you. Next question comes from Arun Jayaram at JP Morgan. Please go ahead. Good morning, Arun. Hey, Roger. Good morning, sir. I was wondering if you could provide us some thoughts on how you expect maybe on a gross basis the production profile to play out at the Khaleesi, Mormont, Samurai fields? You know, excluding any. Obviously, you'll have some hurricane risk in 3Q. When do you expect to reach that kind of called plateau peak rate? I assume that you'd expect that to stay relatively flat next year outside of any, you know, hurricane-related impacts. Thanks, Arun. I'll have Eric take that operational question. Yeah. Thanks, Arun. So I tried to highlight this in the discussion earlier with Neal. We will soon bring online the Mormont 2 well, which is expected to add quite a bit of production. As we head into the third quarter, we're probably not too far away from facility capacity. We will have very minor decline from the new wells and then bring on the remaining two wells in the overall development in the fourth quarter. Our exit rate for the fourth quarter, if we achieve the well results that we're predicting, should be BOE. Understood. Thanks for that. Roger, sorry, there's three other calls that I cover at the same time, so I apologize if this has been asked. We wanted to get a sense of when do you expect to reach, you know, some of your deleveraging targets and your, you know, your fresh capital returns framework that we're excited to see this morning? Well, you know, Arun, as you know more than anyone, and thanks for that question, it depends on a lot of factors. It depends on inflation going into 2023, and you cover major service on that matter. It depends on pricing. Pricing been quite volatile lately. As we launch our plan on 1.0, we should be near the $1.8 billion at the end of the year because we're already well on that way. We haven't finalized our plans for 2023 that I said earlier, as you would anticipate we wouldn't. At $75-$85 oil, we expect we'll be close to achieving our long-term debt target of $1 billion in 2023, of course. We should be getting there in next year without great difficulty as long as we keep executing. Eric's teams are doing a great job of executing there. Great. Thanks a lot, Roger. Thank you, Arun. Thank you. Next question comes from Paul Cheng at Scotiabank. Please go ahead. Paul, you're back. Yes. Just two quick follow-up. One, you talk about the opportunity in the Gulf of Mexico. How about in Eagle Ford? Any bolt-on acquisition opportunity or you even interest? Secondly, that given the current market condition, what is your going forward hedging strategy? Do you really need to hedge at all going forward? Thank you. Thanks, Paul, for that question on that. You know, Paul, we do look, our business development team, again, I'm blessed with a senior BD team that's been very successful. We do monitor bolt-on in the Eagle Ford. But to be honest with you, Paul, with the plan that we have to keep Eagle Ford flattish, we have ample locations to go for a long time in all of our areas of Eagle Ford, and we're in an oil window. We're heavily oil-weighted with great differentials and net backs in the Eagle Ford. When we look at M&A there, it's quite often heavily drilled or not really as good as the locations we have left in our portfolio. The slowing of the Eagle Ford has made our Eagle Ford very advantaged to us. We incredible work on base production and production engineering. When we go to look at something else, we have to stop what we're doing to do wells that are inferior, quite frankly. That hasn't passed the muster. Offshore, where we're part of a field, we understand the field, it has upside, we like the operator, we like the work that's ongoing, it's just a totally different advantage with very low EBITDA multiples, incredibly high rates of return. You have to be in that game and understand that game to make hay when the sun shines, and we just don't see that in the onshore today. That's why we're well-positioned with a diverse portfolio that allows us to move in and out of things in the Gulf that we make a lot of money on, Paul. Thank you. Tom's gonna handle the hedging strategy for you, Paul. Okay. Yeah, Paul. The way we think about it is the best hedge is to have a strong balance sheet coupled with a strategy that can pretty much work in a multitude of prices and operational environments. This allows us to execute through these different commodity cycles. At current prices, our balance sheet is improving rapidly, so I think that's positioned us well to achieve our long-term debt target. Now, historically, we've considered hedges to ensure that we get a certain return on an acquisition. Potentially under a future scenario, we might consider it to, you know, strategically hedge in that kind of scenario. All right. Thank you. Thank you. There are no further questions from our phone lines. I would now like to turn the call back over to Roger Jenkins for any closing remarks. Thanks, everyone, for calling in today. Real proud of our quarter and our team, and I appreciate everyone for dialing in and answering questions. Contact Kelly and Megan if you have any follow-ups. I appreciate it, and we'll talk to you soon. Goodbye. Ladies and gentlemen, this concludes your conference call for today. We thank you for participating and ask that you please disconnect your-