Good morning ladies and gentlemen, and welcome to the Murphy Oil Corporation Second Quarter 2022 Earnings Conference Call. [Operator Instructions] 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 information on 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 2, Murphy continues to deliver a strong value proposition. Our ongoing execution excellence from our three producing areas, proves that we are long-term sustainable company. As we disclosed in our 2022 sustainability report released yesterday significant improvements and emissions intensity in water recycling. Excuse me. Our offshore competitive advantages continually reinforced most recently with the achievement of first oil ahead of schedule from 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 3. Murphy remains focused on our three strategic priorities of delever, execute and explore. In June we continue to advance our de-levering 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 '24 notes along with reducing our maturities. These transactions put us well on our way toward accomplishing our $600 million to $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, the stem oil 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…

Thank you, Roger and good morning everyone. Turning to Slide 6, 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 a $70 million non-cash mark-to-market gain on derivatives in the $25 million dollar non-cash mark-to-market loss on contingent consideration. As a result we reported adjusted net income at $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-operated Kodiak working interest, 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 7. Our de-levering efforts over the past 18 months continuing 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 a substantially closer to achieving our debt reduction goal for the year of $600 million to $650 million. With that, I'll turn it over to Eric.

Thank you, Tom, and good morning everyone. On Slide 9, we saw outstanding wells 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 in modifying to higher intensity fracks. These wells have exceeded forecast with Karnes gross IP30 rates averaging 1,900 barrels of oil equivalent per day and Catarina gross IP30s averaging 1100 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 three to five months for Karnes and six to 11 months in Catarina, assuming an $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. And 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…

Thank you, Eric. I'll review exploration today on Slide 16. Exploration remains the third pillar of our strategy. Our most near-term opportunities located offshore Mexico, we received a drilling permit on finalizing plans to spud the operated to loom 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 five 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 plan well is the Oso 1 well, which we operate in Op 50% working interest. This time, we're finalizing the second well with partners. We have several great choices among our 20 key prospects in the Gulf. As 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 reduction has exceeded expectation, which continues to elevate our forecast for the year. And for the third quarter of 2022 anticipate production range of 180 to 188,000 barrels equivalent per day with 49% oil and 55% liquids. This accounts for nearly 10,000 barrels of oil equipment per day of onshore and offshore downtime, as well as 6,000 barrels equivalent per day set aside resume Gulf of Mexico storm downtime. Importantly due to outstanding Eagle Ford Shale and Gulf of Mexico execution as well as Bolton acquisitions, we're increasing our full-year 2022 production guidance today to a new range of 168,000 to 176,000 barrels equivalent per day at 52% oil and 58% liquids. This represents a new midpoint…

[Operator Instructions] First question comes from Paul Cheng at Scotia Bank. Please go ahead.

Wanted to just - the first quick one just a mechanic that you don't have a lot of debt mature. So once you get to $1.8 billion in the gross debt should we assume the debt repayment will be followed the maturity schedule or that you 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 going to have CFO, Tom answer that for you, Paul.

Hi Paul, yes, thanks for that question. A lot of this, the timing will depend on the type of price environment that we have and at current prices, it's likely that we would have to tender to get to those longer-dated maturities if things change, then we'll just have to see what the market offers at the time, but the tender offer, what we're thinking.

Okay. And that I think what you, you've mentioned that you guys will be seeking for an investment grade and what need to be done in order for you to get there and what our benefit you'll see once that you have the investment grade?

Okay good question, Paul, thanks for that. So the way we think about it is, we need to execute on our operations. As we have been and continue our debt reduction and 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.

A final question from me what you - with the current commodity price outlook does it in any shape or form change the investment spend in Tupper as well as to keep up that offering? Thank you.

Thank you, for that question Paul right now as we look ahead and 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 feel our Tupper Montney plant to 500 million a day gross, so from last year to this year to next year, there is no, changes in our onshore plan. And that's how we're thinking about it now, as we continue on with this framework. And not focusing on large production increases, but we will have higher production next year as we add on a full year of these Gulf projects and exit [ph] 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. The next question comes from Leo Mariani at MKM Partners. Please go ahead.

Good morning Roger, Want to hear a little bit more about the acquisition environment in the Gulf of Mexico obviously a couple of small deals that you guys were able to get together here, it looks nice. I guess there is, certainly kind of a handful of bigger deals 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 Murphy's additional appetite 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 because we really feel we have a competitive advantage in M&A in the Gulf. And we've been in the business so long and so many - we are partners of so many fields that we have a good bit of data. And it gives us a real advantage is analyzing data on occasion, one of the deals today was through a prep right that we were 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, so we look and know about almost all deals very into that business. What we like the number one Leo is high return accretive below 2.0 EBITDA payout deals that payout very quickly, where we understand the assets and further we like M&A on opportunities that have a growth component to it, like when we bought more at Kodiak there is 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 is a two well program there and possibly more. So we're looking for things where we have a competitive advantage information, a lot of knowledge about it with the good operator with work to be done. As to the other deals that come up when large PDP blow down large abandonment obligation deals are not our favorite and will treating that accordingly. So that's kind of how we feel about Leo, if that answers your question.

Yes, that's helpful for sure. And I guess just wanted to kind of talk a little 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 in the call, you indicated there was no real change to your onshore plan. Just wanted to get a sense if these high commodity prices. If you, still intend to kind of step, the capital down a fair bit in 2023 are there other maybe projects and the offshore they're interested you that might get more capital on a relative basis?

Thanks for that Leo question anticipated question today. Thanks for asking it. In the first quarter on our call, we disclosed and we had this capital range of $650 million for 2023 and 2024 which you're greatly familiar. We did increase debt on that call to near $700 with inflation at that time. So, we will still need to recalibrate, these figures are some inflation information for 2023 this is dependent on several things as I stated earlier this morning. It's our plan to maintain our Eagle Ford and Tupper plans at this time. So is no, changes to onshore plan production will be higher due to Gulf wells being online. So I need to work inflation and our teams in the middle of that. And our final plans in the Gulf. And as usual, we just really have no plans to disclose our spending until our customary time in January and but I'm real pleased with our execution. I'm real pleased at our production level. I'm real pleased with the CapEx. We've been spending in onshore and how we're able to do that. And I feel well positioned but - trying to keep CapEx where it was best we can without inflation is the main focus today, Leo.

Okay and then 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 clearly paying off more debt this year and next. But just to be clear on the debt. Is that an absolute debt target you want to hit before you get to the kind of 25% return of capital to shareholders, 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, no scenarios would be very low, but we're talking about bonds, long-term bonds and trying to return capital to shareholders and that's what significant about today Leo. Return capital to shareholders as we paid down debt and I think prior to the [ph] start, they would 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 debt and things can be very positive for our long-term investors.

Thank you. Next question comes from Neal Dingmann at Truist Securities. Please go ahead.

Roger, maybe you have, good morning. Absolutely yes thanks for the details so far. My first question is on shareholder return maybe looking a little bit different. I'm just wondering, could you discuss Roger your view on how you view the value creation as obtains to reward investors with shareholder returns as you suggested going forward versus continued production and reserve growth that you 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 and we believe during that time, we can build. 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 and also will be building cash, which can advance shareholder returns further are used, and other needs at that time. So, we're really into a dividend, which is now we're 60 year dividend paying company. We've paid $1.6 billion in dividends over the last 10 years. So we see a strong dividend return to shareholders through buyback plan as our basis plan to create shareholder value.

Makes a lot of sense. Then, my second is on, let me ask a little bit of a different way in offshore. I'm just wondering you talk about. I know you've got a lot of things going on at King's Quay. Can you talk about potential out of these wells come on further incremental capacity. And then if you also could talk offshore maybe about potential more about - more potential Gulf of Mexico, pref right deals you might be seen.

I'll handle the M&A piece then, Eric will talk about specifics of the operation. These are incredible deals, we're able to be a part of here. It speaks a lot about our company. It's always an advantage to have a press - to have a pref right, this is quite an old deal that came about months and months ago we were able to step in and then another deal with a strategic exits and again by an international player. And in these strategic exits, these companies seek an experienced company with long-term ability in the Gulf, great reputation of the Gulf. Great safety, great regulatory, great balance sheet and 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 30 to 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 because we really want accretive outstanding deals and we've been able to do and I think we'll be able to continue to do it. And then Eric can talk about King's Quay.

Yes, okay. Thanks, Neal. 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 release in our earlier discussion we are 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 will 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 be on NIM plate capacity, and 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 100,000 barrels per day from the facility capacity with minor adjustments to how we operate the facility. So we're pretty excited about our trajectory as we head into the end of the year with the remaining wells to come online there.

[Operator Instructions] Next question comes from Roger Read at Wells Fargo. Please go ahead.

Good morning, 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'm going to call aptly named but let's got ironically named Inflation Reduction Act. But 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. We have all of our leases have an existing contract with the U.S. government. It's held the test of time. There is no ability in those contracts to raise our royalty rates. The royalty rates described in this ironically, named bill a good worries me is that it's for new leases. So we'd only pertain to the Gulf, new leases from the new plan that supposed to take place. And as you know at Murphy. We have no federal onshore leases. As far as other things in the bills 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 impact of this bill on Murphy Oil Corporation.

Good to hear. Second question for you given the Murphy 3.0 goals on long-term debt yet 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 achieve ability of Murphy 3.0 by six or nine months because of very attractive accretive transaction. Just how should we think about that fitting into the overall system.

Thanks Rogers for that question a good one. Naturally, any company with the framework, it's a targeted framework and outstanding M&A that comes your way would have to be 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 and so we would be no different. Also during that period, we would be building cash during that period, 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. But we have a high bar on M&A, we're not looking at M&A to grow or do anything like that it must make unique investment criteria that we focus on and but sure any company that has a 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.

Yes. I recognize that it was more just trying to, 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 loom exploration well, what's the, 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 is very successful, we will then be taking the rig from the Eastern Gulf to Mexico and drill the well under our control. And we anticipate that spudding in October is probably a two month well, that sort of timing, Roger.

Thank you. Next question comes from Arun Jayaram at JPMorgan. Please go ahead.

I was wondering if you could provide us some thoughts on how you expect, but maybe on a gross basis, the production profile to play out at the Khaleesi Mormont Samurai fields excluding any obviously you have some hurricane risking in 3Q and what type of kind of - when do you expect to reach that kind of caught plateau peak rate. And I assume that you would expect that to stay relatively flat next year outside of any hurricane related impacts.

Thanks, Arun. I'll have Eric take that operational question.

Yes, Thanks, Arun. So I tried to highlight this in the discussion earlier with Neal. We will soon bring online Mormont 2 well which is expected to add quite a bit of production. And 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. And our exit rate for the fourth quarter, if we achieve the well results that we're predicting should be [technical difficulty].

Understood, thanks. Thanks for that. And then Roger, sorry, there's three other calls that I cover at the same times so apologize if this has been asked, but we wanted to get a sense of when do you expect to reach some of your deleveraging targets in 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 have on inflation going into 2023 and you cover major service on that matter, it depends on pricing, pricing been quite volatile lately. So as we launch our plan as to 1.0, we should be near the $1.8 billion at the end of the year because we've already well on that way and we haven't finalized their plans for 2023 that I've said or lose you would anticipate we wouldn't. But it's 75 to 85 oil, we expect be close to achieve in our long-term debt target of one in 2023, of course, so and then we should be getting there next year without great difficulty is to keep executing and Eric teams are doing a great job of executing there.

Thank you. Next question comes from Paul Cheng at Scotiabank. Please go ahead.

Yes. Just two quick follow-up. One, you talk about the opportunity in the Gulf of Mexico how about the Eagle Ford and the bolt-on acquisition opportunity or do you keep an interest. Secondly that given the current market condition what is your going forward hedging strategy. Do you win in need to hedge at all going forward. Thank you.

Thank you, Paul for that question on that, you know, Paul we do look our business development team, again I'm blessed with senior BD team has 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 and all of our areas of Eagle Ford and we are in the oil window, we're heavily oil weighted with great differentials and net backs in the Eagle Ford, and 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 advantage to us incredible work on base production and production engineering and when we go to look at something else we have to stop, what we're doing to do wells that are inferior quite frankly and it hasn't passed the messenger but offshore. We're part of the field. We understand the field, it has upside. We like to operator, or we like to work that's ongoing, It's just a totally different advantage with very low EBITDA multiples incredibly high rates of return, and 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 on shore today and 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. Tom is help hedging strategy for you, Paul.

Okay. Yes, Paul, so that we, the way we think about it is the best hedge is to have a strong balance sheet coupled with the strategy that can pretty much work in multitude of prices and operational environments. So this allows us to execute through these different commodity cycles. At current prices, our balance sheet is improving rapidly. So I think that's, position 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 so potentially under a future scenario we might consider it to strategically head in that kind of scenario hedge.

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. And 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 lines.