Good day. Thank you for standing by, and welcome to the SM Energy first quarter 2022 financial and operating results Q&A. At this time, all participants are in a listen-only mode. Please be advised that today's conference is being recorded. If you require any further assistance, please press star zero. I would now like to hand the conference over to Jennifer Samuels, Vice President of Investor Relations. Thank you. Please go ahead. Good morning, and thank you for joining us for our first quarter 2022 Q&A call. To answer your questions today, we have President and CEO, Herb Vogel, and CFO, Wade Pursell. Before we get started, our discussion today may include forward-looking statements and discussion of non-GAAP measures. I direct you to slide 2 of the accompanying slide deck, page 4 of the accompanying earnings release, and the Risk Factors section of our most recently filed 10-K and 10-Q, which describe risks associated with forward-looking statements that could cause actual results to differ. We may also refer to non-GAAP measures. Please see the slide deck appendix and earnings release for definitions and reconciliations of non-GAAP measures to the most directly comparable GAAP measures and discussion of forward-looking non-GAAP measures. Also, look this morning for our first quarter 10-Q, which we have filed. With that, I will turn it back to the operator, Blue, to take your questions. Thank you. At this time, to ask a question, you will need to press star one on your telephone keypad. Again, that is star one to ask a question. To withdraw your question, just press the pound key. Please limit yourselves to one question and one follow-up. Please stand by while we compile the Q&A roster. The first question comes from the line of Leo Mariani from KeyBanc. Your line is now open. Hey, guys. Just wanted to touch base with you here on CapEx. Just wanted to get the sense in terms of the year here in 2022. Is second quarter CapEx really gonna be the peak? Is there a noticeable drop off, you know, in the fourth quarter? Perhaps there's a you know, frac holiday, you know, or something like that. Just additionally, is a frac holiday, if that is the case, in the fourth quarter, something that can still be feasible in this kind of tighter service environment, or might you have to keep crews on? Okay. Thanks, Leo. This is Herb. On CapEx, first, you probably saw in the first quarter that we were underspent by about $20 million. We really just, that's just timing, and we moved that into the second quarter. The peak activities really 2Q and 3Q, and so that leads to, you know, more production in 3Q and 4Q. We really like to keep crews running consistently, if at all possible, because we get much better capital efficiency that way. We'll do what we can to just line things out with steady activity through the year. That's really the way it works. Okay. Then just also wanted to ask about return of capital. Just kind of reading some of the prepared comments in the transcript, it sounded like y'all believe you'll hit your debt metrics in the fourth quarter. It sounds like maybe the board or whatever will be in a position in the fourth quarter to maybe make a decision on a return of capital, and that will be something that investors will receive in 2023. Just wanted to make sure I kind of understood the timing and mechanics there. Yeah. No. You heard the comments right, Leo. I mean, we've been pretty clear about our targets and what we're approaching really quickly. 1x leverage, but also our absolute debt down to $1 billion. You know, if things stay the way they are right now, commodity prices, et cetera, that should occur sometime in the fourth quarter, as you indicated. That would be the time that we would start looking at a potential return of cash to shareholders. Too early to talk about what that might look like, but it would be something that we feel very confident in being sustainable. The method would be, you know, based on, you know, things that we would analyze at that time. Okay. Thank you, guys. Yeah. Your next question comes from the line of Zach Parham from JPMorgan. Your line is now open. Hey, guys. Thanks for taking my question. I guess one, just kind of based on production trajectory for the rest of the year, you know, with your guide, you know, 2Q will be the third straight quarter of declining oil volumes after a big ramp in the back half of 2021. You know, can you talk a little bit about the trajectory of oil production in the back half of the year and into 2023? Yeah, Zach. This is Herb. You know, there's some history there with how much we ramped up in 2021 in 2Q and 3Q following the weather event in Texas. That kind of changed how we ended 2021 and how we started 2022 with relatively few completions at that time. As we step through 2022 and our activity level's pretty flat here and we wind up with more and more completions coming on, that's what leads to great production in 3Q and 4Q. In 4Q, we have those four Permian pads we've talked about before. Those don't come online. That's 20 wells that don't come online until early 2023. It's really difficult to look at the quarterly cadence type of numbers for us when we have those sorts of things going on. We just see it year-over-year. We're really focused on that plan to increase and maximize free cash flow over a 2- to 3-year period. That's how the plan's designed. That's pretty much the way you should look at. What you'd see year-over-year, low single-digit production growth, but generating a lot of free cash flow. Got it. Thanks for that color. Just one on the Eagle Ford. In the prepared remarks, you talked about completing some Eagle Ford wells in 1Q and then 3 more Eagle Ford completions in 2Q. You know, can you talk about what drove the decision to drill some Eagle Ford wells versus spending that capital in the Austin Chalk and kinda how you think about that drilling Eagle Ford wells going forward? A couple things. There were two of them that we talked about, or we talked about the payouts already, delivered, and those were tied together with 7 Austin Chalk wells. They were right in that development, so it made sense to pretty much stagger those in. The newest 2 are DUCs that we've had sitting around for a while. We have some other Eagle Ford DUCs, so it's very capital efficient. Commodity prices are right. It made a lot of sense to do those. Those were in our original plan for the year. I think we talked about 38 completions for the year, and I believe around 30 of those are Austin Chalk, maybe 32, and 6-8 are Eagle Ford. That was the original plan, but very capital efficient when we can get to the DUCs. Got it. Thanks, Herb. Your next question comes from the line of Michael Scialla from Stifel. Your line's now open. Yeah. Good morning. Just looking at slide 6, it shows in your slide deck your capital efficiencies have been among the best in the industry over the last 5 years. Just wanna see if you could provide any update on current well costs. I think it's been a while since you put anything out on what current well costs are. Mike, thanks for that question. You know, we're still running off of contracts in the first quarter that we've had for a while, and that goes for 2Q, largely baked in costs that we had contracted a while ago. That really helps us on the capital efficiency side. The other is we continue to use the same drilling and completion service providers. What happens is we actually wind up drilling faster than expected. When you see things happening with us, it's really just things happen faster, and we don't bake that in our budget process, but every year we think we're at, you know, peak efficiency, and then we do better. That's really just a really experienced team with sustained commitment to those service providers. Sounds good. Is it fair to say you're still in the kinda sub-$700 per foot range with those, given those contracts and the efficiencies that you're seeing? Yes, definitely. Sounds good. One of your largest competitors in the Midland Basin just recently mentioned they're having issues getting sand. Wanted to see if you guys are having any problems with that and any plans to address that if it does become an issue for you. No, Mike, we're really fortunate there. We were quite strategic in getting sand supply committed in 2017, being the anchor customer of a new sand mine in Lamesa. We also use their logistics arm. We have not had any sand availability problems at all, and we're real pleased with that relationship. It continues to deliver. That sand mine is closer to our operations, so it cuts down on the last mile logistics costs. Great. Thanks, sir. You bet, Mike. Again, as a reminder, to ask a question, you will need to press star one on your telephone. We have a follow-up question from Michael Scialla from Stifel. Your line's now open. Yeah, just keep going here. I know it's a continuous process when you're working on your well design. It sounds like you're pretty far along with the Midland now. Can you say where you are in terms of the Chalk, maybe in terms of innings relative to where you are in the Midland and the completion design? Well, yeah. Mike, that's a great question. You know, we are in the you're probably aware we, last quarter, we talked about that additional $18 million in data gathering, which will help us optimize the completion design, and we're in the midst of gathering that data. In some cases, we've got some additional data. We're hard at it. We have not implemented anything really differently so far. There's one minor variation, but that's there's still lots to come. The interesting thing, though, is that we've noticed now that there's 11 operators active in Webb County in the Austin Chalk. Five of them are public and six are private. Our well results have definitely been noticed by industry. Activity's picking up out there. Anything you can say in terms of have you seen any other wells being drilled, and plans do you share data with any of these, or any thoughts around how you approach the competition? Yeah. Mike, we do engage with a few of the other participants on data trade, and then some of them are, other ones are quite new. We're in the oilier part, so we're not doing that much with the dry gas folks down there. It's encouraging to see, and I'm looking forward to seeing what the well results are looking like as they sort out the right landing zone. Some of the early wells were probably not in the optimal landing zone, and now you see people moving towards the better landing zones. Got it. I know you were asked about the Eagle Ford earlier. I just wanted to follow up on that. It looks like those wells are. You'd mentioned they're gonna pay out in less than six months. Is that strictly attributable to higher prices, or did you do anything different with the completion design of the Eagle Ford relative to what you were doing previously? Well, price has definitely helped. The completion design is pretty much the same that we've been running in the Eagle Ford. There were a couple that were drilled in 2019, and those are targeting great landing zone and they're decently long laterals, and that helps also. But we do feel like we have a great Eagle Ford option out there in our inventory that's really not much in our proved reserves, but is out there in our inventory. If there is a sustained high gas price out there, we have quite a bit of inventory to go after. Got it. I guess just one last one in terms of inventory. Anything different on the 400 locations that you talked about in the Chalk? I know you've got 40 wells now that you've delineated the play with. Still looking at that 400 locations as kind of the best number for the inventory there, or any update there? Yeah, Mike, we're sticking with 400 now. You know, we'll see what more we can do, but 400's quite a bit of runway in front of us, and we'll work to optimize that over time. But it's just a great resource base out there. Great. Thanks, Herb. All right. Mike. Your next question comes from the line of Scott Hanold from RBC Capital Markets. Your line's now open. Hey, thanks. Hey, all. I'm just kinda curious, and you know, as you start looking into 2023, there's a lot of obviously concerns about Permian gas takeaway, and I know your production in the Permian typically is a little bit more oily. You know, can you remind us of how you're positioned there if you've got you know, firm takeaway that's gonna be ample and not seeing any of these issues. You know, also in the Eagle Ford, given the you know, I guess larger kind of gas component there. Can you just remind us of what the gas takeaway capacity for you guys is in the Eagle Ford and you know, how you guys price that. Are you You know, are you seeing some pretty good, you know, differentials to be able to get into the, you know, LNG corridor or other places? Okay. Yeah. Thanks, Scott. Let's go on the Permian gas takeaway. Kind of the perception last quarter was that we'd see quite a bit of tightness in the takeaway in fourth quarter of 2023. Since that time, Kinder has gone out there and said they'd be able to do compression expansions, and those would be online by fourth quarter of 2023. That really pushes things out where you wouldn't be oversupplied until the back half of 2024. We're not really changing our plans at all for any of this because on the volume risk side, most of our purchasers hold firm capacity or they're selling into firm markets, so we don't expect any production curtailments there. That's on the volume risk side. On the price risk side, if things do start getting tight, we've put basis hedges in place. You'll see in our appendix, we've got basis hedges in place through 25. That mitigates the risk on pricing if there is a Waha flow out of some sort. Overall, you know, it's gonna depend on supply and demand out of the Permian if people really crank up production when that shortfall might occur. It's encouraging to see the midstreamers stepping up and making sure that we can deliver the gas, which allows the oil to flow. That's the Permian. On the Eagle Ford, you're probably aware that there was a lot of gas production out of the Eagle Ford, you know, mid-decade, so 2014, 2015, so there's a lot of spare takeaway capacity. What we see and have baked in for July 2023 and beyond is some of our old legacy contracts that were at higher takeaway costs, well, basic costs, they'll drop by about $0.35 per Mcf, and there's plenty of capacity. As to the LNG uplift, you know, we're really just gonna be going with the market. If LNG pulls up Houston Ship Channel or Tennessee Zone 0 or Hub, we would see it brought in that way. We wouldn't see it directly where we could access an international arb on the LNG side. Okay. Back to the Permian, can you know, tell us on the purchasers that take away your gas there? You said they have firm capacity. You know, can you say where that capacity is on there? Is there like, you know, ample room on those lines right now, or is that? You know, do you have? You know, as you look at your projections, I guess, through 2024, I mean, do you have that, you know, pretty much locked in? What we do is we sell to the purchaser at the wellhead. To the purchaser, we only will sell to parties who represent that they have firm capacity on a line or are selling into a firm market, like a local market. That's how we mitigate the volume risk. We won't sell to somebody who doesn't have any capacity at all. Because they have that capacity, let's say they have 20% of one of the pipelines and 15% of another line capacity, that's where our Mcf will flow. Got it. Okay. My follow-up question is, you know, I think this quarter, you guys didn't book a valuation allowance on taxes. Can you remind us of your positioning on, you know, cash taxes, and you know, at this commodity price strip, you know, when that could occur? Hey, Scott, it's Wade. Good question. I would assume that if, you know, if things stayed the way they are currently with the strip and our kind of steady activity profile, that we would probably begin paying some cash taxes later this year in the kind of $10 million to mid-teens million area. Not significant, obviously. You know, on a go-forward basis, and this is very, you know, very round forecasting, but I see something for us that getting up to kind of peaking in an area of $100 million-$150 million a year. That, again, assumes a kind of a strip type price. Obviously that assumes a significant amount of free cash flow offsetting that. That's kind of where things could be headed, assuming there's no big changes. Yeah. Just out of curiosity, what does that like $100 milllion-$150 million in paly on a effective cash tax rate on pre-tax income? Yeah. It's certainly well south of the statutory rate, you know, the 20% area. It's well south of that. Yeah. Are we talking like 10%, 15%, somewhere in there or around 10%? Yeah. Very, very round numbers. You know, probably somewhere in the half of the statutory tax rate area, but that's very round numbers. But that's simply because of the assumption that we, you know, continue with a steady capital program, all of the tax rules stay the way they are, IDCs, et cetera. That, you know, as long as those things are in place, that's what's gonna happen with respect to our rate, effective rate, if you will. Got it. Okay. That makes sense. Appreciate it. Yeah. Again, to ask a question, please press star one on your telephone keypad. That is star one to ask a question. There are no further questions at this time. I would now like to turn the conference back to Herb Vogel for closing remarks. All right. Well, thank you all for your interest in SM Energy. Since I've got the time, I just thought if you're asking why invest in SM Energy now, just consider these key attributes. First, we're producing top-tier low break even assets in two great basins, number 1 and number 4 in the country. We're able to generate significant free cash flow. We're rapidly paying off debt and really moving EV to equity. We're definitely a premier operator pushing technical advancements to add value, and we're enjoying an intrinsic increase in NAV or EV from confirmation of the Austin Chalk. Thanks again for your interest. Ladies and gentlemen, this concludes today's conference call. Thank you for your participation. You may now disconnect.