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spk00: Good day, and thank you for standing by. Welcome to the High Peak Energy 2024 Second Quarter Earnings Conference Call. At this time, all participants are in a listen-only mode. After the speaker's presentation, there will be a question and answer session. To ask a question during the session, you will need to press star 1 1 on your telephone. You will then hear an automated message advising your hand is raised. To withdraw your question, please press star 1 1 again. Please be advised that today's conference is being recorded. I would now like to hand the conference over to your first speaker today, Stephen Tholen, CFO. Please go ahead.
spk01: Good morning, everyone, and welcome to High Peak Energy's second quarter 2024 earnings call. Representing High Peak today are Chairman and CEO Jack Hightower, President Michael Hollis, and I'm Stephen Tholen, the Chief Financial Officer. During today's call, we will make reference to our August investor presentation and our second quarter earnings release, which can be found on High Peak's website. Today's call participants may make certain forward-looking statements relating to the company's financial condition, results of operations, expectations, plans, goals, assumptions, and future performance. so please refer to the cautionary information regarding forward-looking statements and related risks in the company's SEC filings, including the fact that actual results may differ materially from our expectations due to a variety of reasons, many of which are beyond our control. We will also refer to certain non-GAAP financial measures on today's call, so please see the reconciliations in the earnings release and in our August investor presentation. I will now turn the call over to our Chairman and CEO, Jack Hightower.
spk06: Jack Hightower Thank you, Steve, and good morning, ladies and gentlemen, and thank you for joining us today on this call. My prepared remarks will begin on slide four of our August investor presentation. I'm very proud to report that High Peak had another solid quarter of execution across the board as we continue to stay committed to our 2024 core values, which include maintaining disciplined operations, strengthening our balance sheet, and focusing on maximizing shareholder value. Operationally, our drilling program continued to generate impressive production results, And our operations team remains aggressively focused on optimizing daily operations and reducing our cost structure. Financially, we generated positive free cash flow for the fourth consecutive quarter, even taking into account that the second quarter will be our highest level of CapEx spend this year. And we continue to use our free cash flow to prioritize debt reduction while also executing our opportunistic share buyback program as we implement our primary objective of increasing shareholder value through improved operational results, our return of capital strategy, and ultimately maximizing value through our strategic alternatives process. The second quarter, if you turn to slide five, was another strong operational success for High Peak. Our production remained in the high 40,000 BOE range, which was a nice beat compared to our consensus estimate for the quarter. It's also worth noting that we were delayed bringing online a keypad which pushed out some of our well turn-on dates no later than we initially expected in the quarter. This materially reduced expected second quarter production volumes. Further, the quarter is off to a very strong start in the third quarter, as production volumes have averaged over 52,000 barrels a day. And I want to emphasize that when you think of an average of 48.5 for the last quarter, and then already in the third quarter here, we're over 52,000 barrels a day, and seeing impressive early results from our recent northern extension wells in our flat top operating area. Mike will provide additional insights into our continued strong production results later in the presentation. But after achieving an impressive first quarter reduction in lease operating expenses, our operations team continued to maintain a significant sub $7 per BOE cost level, even considering the lower production volumes due to the PAD delay. Our continued operational success led to High Peak maintaining its peer-leading cash margins, which equated to a net back for the quarter of over 80% of our realized price on a BOE basis. And our cash margins per BOE continue to be over 65% higher than our peer average, which Mike will emphasize is very important to our income stream and our success as a company. As a result of our solid production volumes and sustained lower operating expenses, we generated another strong quarter of cash flow and remain in a very healthy financial position. We also reduced long-term debt by another $30 million at par and continue to opportunistically implement our share buyback program by acquiring over 413,000 shares during the second quarter. Now if you'll turn to slide six, this is really an important slide because we are exceeding our expectations. As a result of our successful first half 24 results, we're updating our 24 guidance ranges in a few key categories. We're raising our production guidance to 45,000 to 49,000 BOE a day, an approximate 4.5% increase compared to our initial 24 range. Our production volumes continue to remain strong, and we are confident in lifting this bar for the remainder of the year. We're also lowering our lease operating expenses per BOE to $6.50 to $7.50, which is a 12.5% reduction from our initial expectations. Our operations team has done an exceptional job optimizing our field-wide program throughout the first half of this year. And I'm hopeful that there are incremental savings that we will continue to see throughout the remainder of the year. We're also narrowing our capital budget from our initial band of $85 million down to a band of only $40 million. This slight increase is due to some additional infrastructure projects that we undertook primarily related to our northern extension area. And Mike will provide some additional color on this in a few minutes. The key takeaway is that we've had a very impressive start to the year, with our results exceeding initial expectations. And we're confident in our ability to continue to achieve higher production volumes and lower costs for the remainder of the year. With that, I'll now turn the call over to our president, Mike Hollis, to provide an operational update as well as some additional details supporting our improved guidance.
spk04: Thanks, Jack. Now turning to slide seven. As Jack discussed, we're off to a great start this year as shown by our higher than expected production volumes. Our first half production averaged approximately 49,100 BOE per day, which is an increase of roughly 8% compared to our 2023 annual average. Further, our third quarter is off to a great start as well at over 52,000 BOE a day. And our current two-rig development program is expected to continue to support higher volumes throughout the remainder of the year, as evidenced by our raising the production guidance. A few key drivers of this success, our new wells in our northern and northeastern extension areas in Flat Top have exhibited higher initial performance than we originally modeled. Again, as prudent operators, we always start off very conservative as we move to any new area. Our Judith well, located in the northeast corner of Flat Top and is referenced by the number one on the map, exhibited a peak 30-day average IP of over 1,350 barrels of oil a day plus associated gas. It has cumed approximately 85,000 BOEs during the first 70 days of production. Our first 10,000-foot Wolf Camp A well, located in our northern expansion area, that's number two on the map, is currently making over 700 barrels a day of oil and is continuing to increase production as we can pull on the well longer. We also have a two-well pad further to the east on this new acreage, denoted by the number three. The Wolf Camp A and Lower Sprayberry wells on that pad have been drilled, completed, and we expect to turn them online during the third quarter. The petrophysical analysis and cuttings from these two wells confirm that the reservoir is consistent with what we see in our core flat top area. So we continue to be very encouraged and excited about this northern area of the field. And in addition to the successful new wells in our northern extension areas, we're continuing to see strong well performance across our entire acreage. The operations team is firing on all cylinders, and we continue to see better uptime and lower cost across the board. Now turning to slide eight. As Jack previously mentioned, our team has been intensely focused on reducing cost across the board, and they delivered again this quarter. High peaks beaten raise to production and beaten lower to LOE guidance, assuming second quarter pricing, equates to $55 million of additional EBITDAX as well as free cash flow for 2024. Some key drivers to our step change in LOE year over year are optimization of our chemical program throughout the field. Our operations team has been keenly focused on this initiative and continues to make further strides. Chemical cost is a significant component of our OPEX. And as I mentioned last quarter, we continue to fully exploit our world-class, life-filled infrastructure system. Part of this exploitation is being able to dispose of 100% of our produced water that is not being used for recycling through our company-owned system and not having to rely on any third-party disposal. This drives significant OPEX cost reductions as third-party disposal is inherently more expensive. On that note, a key contributor to our higher LOE in the second quarter compared to the first was the central tank battery delay that Jack commented on earlier. The battery commissioning was delayed about a month. We turned those wells on in the second quarter, had all of the usual costs associated with production and no BOEs to divide by, but as you can see in our quarter-to-date production numbers, those wells are now contributing Had the wells come on a month earlier, our LOE would have been more in line with the first quarter. Our overhead electric power distribution system continues to pay huge dividends for Hy-Vee. Not only does it provide more reliability to our operations, i.e. uptime, but we've expanded it to the point to where we've been able to tie in extension area wells into the overhead electrical system at startup. versus having to run new areas of the field on more expensive generator power until the overhead electrical system is ready. And it's no secret that electrical power supply is getting tight in the Permian Basin. And additional power project timelines are being substantially pushed out. Our team has done a fantastic job in recognizing this situation well in advance, taking the initiative to secure an abundant supply and construct a distribution system that efficiently delivers reliable power across our entire field. High Peak is in a great position for life of field development, even at an increased development cadence. In addition, our solar farm is now fully operational and is providing consistent, renewable power to supplement our flat top overhead electrical system. One thing's for sure. There's no shortage of abundant West Texas sunshine during the summer months, and now we're able to exploit this to our material benefit. The solar farm will also help insulate our power cost during electrical spot pricing spikes that the region periodically faces throughout the summer months. Again, our operations team has done a tremendous job over the past few years in building out our world-class infrastructure and optimizing all field operations, all of which are now starting to materially improve our bottom line. Now turning to focus on our capital budget for a moment. As we previously mentioned and messaged, our 2024 capital program was first half weighted, and that's due to a number of reasons. Our first half turn in line cadence is slightly higher at 55% of our annual guide range, This is primarily due to the additional wells that we carried into this calendar year from running a three-rig program during the fourth quarter of last year and partially in Q1 of 24. Furthermore, our second quarter turn in lines were approximately 32% of our entire 2024 program, which speaks to Q2 being our hottest CapEx quarter for the year. And in addition to the extra wells turned in line during the first half, our infrastructure projects were also first half weighted. As we extended our systems to our new northern acreage areas and flat top, these extension projects provide immediate returns and were constructed in a manner to support full development of these new areas with only incremental future capital requirements. Our facilities spend was also first half weighted as we constructed new tank batteries in these extension areas of the field. As we progress in our development plan and drill more wells in these areas, our facility cost on a dollar per foot basis will drop considerably. DC&E costs are holding steady at prices that we realized during the first quarter. As the industry has seen a reduction in rigs and frac spreads over the last quarter or several quarters, I would expect some additional softening this year, albeit small. And to that fact, we've narrowed our CapEx budget for the remainder of the year and feel very confident that we will remain within our guided range. Now turning to slide nine. High peaks margins per BOE continue a commanding lead amongst our peer group. Our second quarter unhedged EBITDAX margins remain strong at $50.07 per BOE, which continued to be over 65% higher than our peer group average. The chart on the slide highlights that high peaks EBITDAX margin over the past five quarters has averaged over 60% of average NYMEX oil prices. Or said another way, for every BOE that High Peak produces, we realize a net profit of approximately $50, assuming an $80 NYMEX index price. But in comparison with our peer group, who on average only generate profit margins of roughly $30 per BOE at an $80 NYMEX oil price. Another way we like to evaluate our margins is to compare EBITDAX margin per BOE as a percentage of our realized price per BOE. This is less of a comparison versus our peers and more of a view of how efficient we are at converting our produced BOEs into net profit for High Peak. Our second quarter margins show that for every BOE that High Peak produced, We converted over 80% of the realized sales price per BOE into net profit for the company. We have built a very efficient machine here at High Peak, which will allow us to cost-effectively convert our deep inventory of undrilled locations into substantial profit. And as we always say, not all BOEs are created equal. Our high oil cut and our improved cost structure will allow High Peak to continue to generate the differential profits for decades to come. With my comments now complete, I'll turn the call back over to Jack.
spk06: Thanks, Mike. And let's turn to the next page on slide 10. And I want to congratulate our operations team for a very successful quarter. This slide is an important slide to look back and see where you've come from, from a historical growth comparative analysis. And if you look at that we've been in business now four years since we went public, and we want to take the opportunity to highlight a few noteworthy company facts. As you can see, High Peak has demonstrated a track record of significant financially responsible production growth on an annual basis over the past four years. Production has increased by a factor of over 14 times during a short four-year life of the company. Think about that in terms of looking forward into the future. Through 24, we've drilled 289 operated horizontal wells across our acreage position. Collectively, this amounts to drilling over 3.5 million lateral feet. And on a combined basis, our wells have produced over 50 million gross BOEs since going public. This has led to High Peak generating over $2.7 billion of revenue over four years. And we're now on track to generate over $1 billion per year from this year on. So it shows you our history, but also can project into the future as to what our growth can be going forward. I think it's important to look back as well as look forward as you go forward in the future. So high peak, and when you think about on the next slide, slide 11, the takeaways I want to leave you with today is we're continuing to execute on all cylinders. Our asset base continues to deliver strong production results full of oily, high-margin barrels. We expect this trend to continue, which is why we're confident in raising our production guidance. Throughout the past year, we have been intensely focused on optimizing our field-wide operations, expanding our world-class infrastructure system to reach all areas of the field, and as Mike likes to say, life of production going forward. These have led to the realization of significant operating cost reductions as evidenced by our results through the first half of this year. We expect to maintain this lower step change in operating expenses going forward and as such are confident in lowering our LOE guidance range. Second, we've positioned the company for optimal value creation. We've amassed a sizable, highly contiguous acreage position prime for large-scale development. It's truly one of the few remaining opportunities of significant scale in the most sought-after basin in the country, the Permian Basin. We've rapidly increased our oil-weighted high-margin production and reserves to a significant level. We've delineated a long runway of high-value inventory, which spans our entire leasehold position. The scarcity of sub-$50 per barrel break-even inventory amidst the current market trend of extreme consolidation puts High Peak in a very unique and lucrative position. We've built out a world-class infrastructure system which will support life of field development and helps insulate our peer-leading profit margin for decades to come. I can't really provide specific details at this time, but I do want to say that our strategic process is making significant progress, and I'm very excited about what the future holds for High Peak and our shareholders. With our comments now complete, I'll open the call up to questions from analysts.
spk00: Our first question comes from the line of John White with Roth MKM Capital. One second, please. John, your line is now open.
spk05: Good morning, gentlemen. Congratulations on a nice production. In terms of lease operating expense, you talked about the past delays related to the tank battery. But weren't there a higher amount of well work over expenses in the quarter?
spk04: I'll take that one, John. Yeah, absolutely. And thank you for the question, and good morning. So if you're referring to quarter over quarter, Q1 we averaged about 39 cents per BOE for work over expenses and we were closer to 69 cents or 68 cents this quarter. What drove a lot of that, again, we did 32% of our completions this quarter for the year. So if you look at kind of a general number and a good go forward kind of modeling number for High Peak on a work over expense basis at our normal cadence. It's somewhere between the 30 to 45 cents of BOE is kind of where I think we would run. So that 25 cent difference between each Q1 and Q2 was associated with a lot of the work that we did bringing these wells on and completing those 26 wells throughout the quarter. And whenever you do that, you do impact some of the wells on either side of what you're completing. And that heavy cadence of completions did drive us to have to do some expense workovers on some of the offset wells around there. So that's what drove the change in Q2.
spk05: Okay. Thanks for that detail. I appreciate it. And I'll turn the call back to the auditor.
spk00: Thank you. Our next question comes from the line of Jeff Robertson at Water Tower Research. Jeff, your line is now open.
spk03: Thank you. Jack and Mike, I apologize. I missed part of your prepared remarks. So if you've answered these questions, I'll read about it in the transcript if you want. But two questions, one on slide 11, your last bullet point, you talk about infrastructure supporting life of field development in Flat Top. And can you just talk about how that infrastructure investment that you have made would impact capital efficiency and returns going forward as you progress through your development program?
spk06: Yeah, Mark, you can answer that.
spk04: You bet, Jeff. And thank you for that question because it's often overlooked the value of the infrastructure that you put in. Obviously, it helps us initially when we build out infrastructure to, for instance, our new northern area. where we built a lot of infrastructure to tie in one battery. So from a capital efficiency standpoint of the initial dollars you put in, it's pretty low day one. However, when we develop that area and have 35, 40 wells coming through that same infrastructure, your kind of dollar per completed lateral foot cost associated with future wells goes down dramatically. So as we've built out and have already spent the money on the vast majority of all the infrastructure that High Peak needs, again, as Jack mentioned, for life of field, and that's for all of the multiple zones that we plan to drill, and at whatever cadence. At one time, we were running as many as six rigs. So again, in the future, depending on commodity price and balance sheet strength, if we ever wanted to increase activity, we could. And we've always kind of talked about the ability to pull back the reins if oil prices were to go lower into the future. We have the leasehold position that's a very differential leasehold position that allows us to hold this whole 137,000 acres with just one rig or less running. So it's a very unique system that we've built. And as you pointed out, Every additional well that we drill in the future gets the benefit from that money that we've spent over the last three and a half years building out that infrastructure.
spk06: And I would add, Jeff, to that. If you think about, we've got an infrastructure now that can go all the way up to 550,000 barrels of product to support our growth. And when you think of 2,600 locations, potentially, even if you go back to 1150 locations just in the Wolfay and the Lower Sprayberry. And with success in the Middle Sprayberry and some other zones, that's expanding rapidly. And so we and others have invested almost a billion dollars now in infrastructure here. And that will allow us to expand all over across our entire acreage position and be able to handle with 100% recycling of the oil and the water as well as completions in the future and be able to handle that and dispose of the excess with our own saltwater disposal system. So that infrastructure now is basically in place. We'll spend a few additional capital dollars going forward, but it'll be very limited expenditures.
spk04: And, you know, Jeff, Also on, obviously, we reduced LOE in the guide down from a midpoint of $8 to a midpoint of $7. And again, being conservative, we want to make sure that we meet and beat that as well. And you kind of see that on kind of slide seven on the production side where we're sitting with production in the guide that we increased the midpoint from 45,000 BOEs to 47,000. And since you may have missed this in the prepared remarks, those two changes in guide over the 2024 calendar year equate to an EBITDA change of about $55 million. And since we're in a free cash flow mode this full year as well as going forward, all of that additional EBITDA goes to free cash flow as well. So again, all of this money and systems and infrastructure we've put in place is paying dividends now and will continue in the future.
spk00: Thank you. Our last question comes from Nicholas Pope with Seaport Research. One second, please. Nicholas, your line is now open.
spk02: Good morning, everyone. Can you hear me? Yes, sir. Good morning. I was hoping you guys could talk a little bit about the uses of cash. And obviously it's a good problem to have, but we're kind of looking at three items here with dividends, share repurchases the last two quarters, and options to pay down debt. And I was curious how you're thinking about that going forward. Obviously that debt is very high, high interest payments. I think it's 20% of EBITDA. So I'm curious how you're kind of weighing that relative to these other two shareholder options. return options that you have in place?
spk06: Nick, that is a great question. And we're going to stick with our program to pay down debt. Now, we're going to keep the cash on the balance sheet, because right now we have make-told provisions, and we want to make sure we pay that debt down at par. And of course, our make-told provisions run out in March. We are fully aware that we could refinance, and our cost as a BB rating would go down to six-something, even with a new issuance in the seven-something percent range. But we've got to pretty well make that make-whole payment between now and March, so it'll probably be after that before we would consider changing. But our goal is to pay down debt. Now, we have the optionality of of drilling more if oil prices happen to go way up. But we're going to stick with our program and stick with what we've been doing in the past. And eventually, if we don't successfully have a strategic alternative by then, we would refinance our term debt and pay off our bonds and go forward. And of course, the difference in the cost of that debt compared to what a bond would be today, is almost $220 million a year of additional cash flow. So we have good optionality, but we're very encouraged by our strategic alternative process.
spk02: Got it. That's helpful. Switching to something a little more fun, these new wells. Curious, like going into these northern areas, in the northeastern kind of extensional areas on the newer acreage. I'm curious, kind of as you went into those, were there any big questions that you thought needed to be answered? And, you know, as you get the data from the production on these new wells, is there new zones, new productivity? How does that match up, I guess, with what the expectations were going into the wells? And do you think that affects, you know, inventory and kind of the numbers that we've talked about in the past?
spk06: I'll let Mike answer that, and then I'll follow up if he leaves something out that I think is important.
spk04: There you go. Yeah, so Nick, great questions. Again, any operator, as you move more than a couple miles away from known production, we're all kind of engineers in the background, so we like to be conservative, right? So when we say they beat expectations, Yes, these wells beat the expectations they were using as we were modeling to make sure we had enough risk for that kind of two-mile walkout or as we went north to go yet another two miles north of where we were. But from a petrophysical standpoint, from log analysis, from the cuttings, everything suggested that it should be just as good as what we had down in what we call the core of the flat top area. So were we not expecting to see what we did? No, the answer was we fully expected to get this result. And to answer your question about additional zones, these wells were Wolf Camp A wells and Lower Sprayberry. Now, I mentioned it at the end of last quarter that we were Most likely going to drill a middle sprayberry well sometime in the near future. Well, we have already drilled and completed our first middle sprayberry well, which sits down in kind of the center part of flat top. And we are running the pump in the ground today. So we'll have some information for the third quarter call. Again, there's offset wells touching the west side of our acreage block. And as we drilled that middle sprayberry well, all things were encouraging from cuttings to oil cut that we saw in some of the returns while drilling. So again, we should be able to give an update on that additional zone that we've targeted in flat top. But no, these two new areas are acting as we suspected they would and as they should for modeling. It's just when we do guidance, we always try to put a little left in there for the good guys.
spk06: The only thing I would add, Nick, to what Mike said is from a geological and petrophysical and oil in place analysis, we feel like our whole acreage position, even moving to the east. And as you can well imagine, we still have certain companies that think as we move east that the production is going to decline. And yet, our Judith well, which is our furthest eastern well outside the well in Scurry County, the Virginia well, is our most successful well. And it was a little bit of we anticipated potentially But it's turning out to be one of our very best wells. And so as we move east, we are very excited about the potential of those wells and that production, and definitely adding more locations to the east, and at least being able to prove that up to potential suitors. And so that was an exciting arrangement. And then going forward, we're probably going to drill another wolf bee well. and we'll drill some more middle sprayberry wells, and we'll probably drill another well down to the south at Signal Peak in the huddle zone, the Wolf Camp C zone. So a lot of good things are happening for us, and that definitely adds to the number of locations that we have.
spk02: Got it. It's all very interesting. I appreciate the time. Thanks, guys.
spk00: You bet.
spk02: Thank you, Nick.
spk00: This concludes the question and answer session. Thank you for your participation in today's conference. This does conclude the program. You may now disconnect.
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