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spk07: Ladies and gentlemen, thank you for standing by. Welcome to the Blackstone Minerals Q3 2022 earnings release. At this time, all lines are currently in a listen only mode. There will be a question and answer session at the end of the presentation. You may enter the queue to ask a question by pressing star and the number one on your phone. You may press the star and the number two to exit the queue. As a reminder, this call is being recorded. I would now like to turn the conference over to Evan Kiefer, Vice President of Finance and Investor Relations. Please go ahead.
spk05: Thank you, and good morning to everyone. Thank you for joining us either by phone or online for the Blackstone Minerals third quarter 2022 earnings conference call. Today's call is being recorded and will be available on our website along with the earnings release, which was issued last night. Before we start, I'd like to advise you that we will be making forward-looking statements during this call about our plans, expectations, and assumptions regarding our future performance. These statements involve risks that may cause our actual results to differ materially from the results expressed or implied in our forward-looking statements. For discussion of these risks, you should refer to our cautionary information about forward-looking statements in our press release from yesterday in the risk factor section in our 2021 10-K. We refer to certain non-GAAP financial measures that we believe are useful in evaluating our performance. A reconciliation of those measures to the most directly comparable GAAP measure and other information about these non-GAAP metrics are described in our earnings press release from yesterday, which can be found on our website at blackstoneminerals.com. Joining me on the call from the company are Tom Carter, Chairman and CEO, Jeff Wood, President and Chief Financial Officer, Steve Putman, Senior Vice President, General Counsel, Kerry Clark, Senior Vice President, Land and Commercial, Garrett Grimion, Vice President of Engineering and Geology, and Thad Montgomery, Vice President of Land. I'll now turn the call over to Tom.
spk01: Thanks, Evan, and good morning, and thank you all for joining us. We have a lot of good news to report. We generated total production volumes for the quarter of 40,000 BOE per day, an increase of 19% over our second quarter volumes. All of that increase was from royalty volumes, which were up 23% to 37.3 thousand BOE per day. Our base production is trending up as development activity remains robust across our acreage, and as our target development programs with operators in the Shelby, Trough, Haynesville, and East Texas Austin Chalk continue taking shape while growing and moving forward. Production from the quarter exceeded expectations due to certain operators, particularly in Louisiana Hainesville, bringing new wells online at more aggressive initial flow rates to take advantage of higher natural gas prices. The first payment we receive on newly drilled wells often covers multiple months of early production, so this can have a meaningful impact on our revenues as production and prices hit significant peaks at the same time. We saw that in the third quarter and expect to see similar revenue impacts continue in the future quarters as well. With the higher level of activity, we now expect that our total production for the year will come in at or above the midpoint of our original 22 guidance of 35.5 thousand VOE per day. That implies fourth quarter production levels of around 36,000 VOE per day or better, with potential for further upside from there. Activity levels are ramping up overall, as evidenced by the increasing rig count, both across industry and on our acreage in particular. At the end of the third quarter, we had 92 rigs running on our acreage. That's a 14% increase from 81 at the end of the second quarter, and is well above the 59 rigs on our acreage at the same time last year. The big increase in volumes and the favorable commodity price environment combined to generate record second quarter cash flow for Blackstone Minerals as a public company. We reported adjusted EBITDA of $123 million for the third quarter, which is 9% above the second quarter. Distributable cash flow for the quarter was $116 million, 8% above last quarter. Last week, we announced our third quarter distribution of 45 cents per unit, which also establishes a new high watermark for Blackstone. Last quarter, we went into great detail about the progress we've made on our organic growth projects in the Shelby Trough and Austin Chalk. Both of these programs are gaining pace and garnering interest from potential new basin entrants. Athon has now turned 14 wells to sales, the Shelby Trough and has another 10 wells drilling or waiting on completion. They're working their way up to the full contractual requirement of 27 wells per year and the results have been very good thus far. Our commercial efforts remain heavily focused also on the East Texas Austin Chalk Acreage where development activity and production volumes also continue to grow. Our long history in this area provide us with unparalleled knowledge of the acreage We have been and will continue to be long-term holders of the Austin Chalk, which allows our team to develop and execute commercial strategy from a long-term perspective, focused on responsible, full development across the entire basin. That perspective, combined with high net royalty interest, some remaining working interest, and strong industry relationships, give us more opportunity to influence outcomes than other mineral owners often have. We have brought in four new operators to supplement the development activity of the original three lessees that took part in the test well program in 2020. Over 20 wells have now been drilled in the area and completed with high intensity completions, and another five are currently in development. We've had good success in working with existing operators to step up their development pace and in placing open acreage with new producers, but there's still a lot more to do. We remain focused on the long game and a strategy that employs our unique advantages to expand and accelerate development activity even further across this major acreage position. As these two core areas move further into development mode, we continue to explore other areas within our expansive acreage portfolio to drive new development. As we've said many times over the past few years, we are well positioned to increase volumes by focusing on our commercial strategy of attracting development dollars to maximize the value of our existing acres. This ability to generate production growth without additional equity investments or the occurrence of debt through acquisitions is what sets Blackstone apart from its peers and is largely what has enabled us to generate really strong returns on capital employed over the years. We are excited about the momentum going into 4Q and into next year. Our development success and a strong commodity price environment has allowed us to return more cash to our shareholders, and we're optimistic that that trend will continue into 23 as well. With that, I'll turn it over to Jeff.
spk04: All right. Well, thank you, and good morning, everyone. As Tom mentioned, royalty production was up 23% to 37.3 thousand BOE per day for the third quarter. All of that increase was driven by higher gas volumes, and primarily from producers on our acreage in Louisiana, Hainesville. In addition, the price environment remained robust. Our realized prices were down from the second quarter, but remained very healthy at over $95 per barrel for oil and over $8 per MCF for natural gas. Oil differentials improved from last quarter, while our realized gas prices were down as differentials widened and NGL prices fell. The production gains, however, more than offset the downturn in realized prices, and we recorded $218 million in oil and gas revenues, and that's up 6% from last quarter. With the strong production print for the third quarter, we now expect total production for the year to come in at or above our original guidance level, at the midpoint of our original guidance level of 34,000 to 37,000 DOE per day. Prior to this, we are expecting to come in at the low end of that range, so this is a nice recovery in volumes for us. Expenses this quarter were generally in line with last quarter and with our 2022 guidance. We now expect lease operating expenses for the full year to be at the high end of our guidance range of $10 to $12 million, and production costs as a percentage of oil and gas revenues to be below the guidance range of 10 to 12%. We also expect cash G&A to be in line with our original guidance range of $33 to $34 million, and for non-cash G&A to be at the high end of the range of $13 to $15 million. That's due primarily to the increase in our unit price during the year, which impacts the mark-to-market component of our long-term incentive compensation. We added to our 2023 hedge portfolio during the year at attractive prices. Our average hedge prices increased substantially as we move into next year. The strike prices on our natural gas swabs increased from about $3 per MMBTU this year to over $5 per MMBTU in 2023, an increase of over 60%. And it's a similar story for oil. The average strike price on our oil hedges increases by over 20% from approximately $65 per barrel this year to over $80 per barrel for 2023. We'll give our production guidance for 23 in February like we normally do. But even before any benefits of increased production volumes, we were set up very well to deliver higher cash flow in 2023, just from the big step up in our hedge prices. Our strong financial results for the quarter allowed for an increase in our distribution and for further debt reduction. We ended the quarter with $60 million of debt drawn on our credit facility, and as of last Friday, that balance was down to just $19 million. That gives us tremendous financial flexibility, and we added to that flexibility last month by extending the maturity date of the credit facility out five years to October of 2027. In conjunction with that amendment of the facility and as part of the semiannual borrowing base redetermination under the credit facility, our borrowing base was increased from $400 million to $550 million, although we voluntarily elected to limit total commitments under that facility to $375 million. As Tom said, this was a quarter full of positive results driven both by the robust environment and by the early results of some of the major commercial efforts that we've been focused on over the past few years. The really good news is we think these trends should continue to benefit our shareholders into next year and beyond. So, Chastity, with that, we will open the call to questions.
spk00: Thank you. If you'd like to ask a question, please press star 1 on your touch-tone telephone. If you'd like to remove yourself, please press star 2. We'll take our first question from Derek Whitfield with Stifel.
spk06: Good morning, all, and congrats on a strong quarter and update.
spk03: Hey, Derek. Good morning.
spk06: For my first question, I wanted to focus on a subtlety in your production strength commentary for Q3 In your release and prepared comments, you noted strength was due to several high-rate new wells, the majority of which were located in the Louisiana Hainesville. In reviewing Q3 activity updates, we were candidly most encouraged by the non-incremental turn-in lines in the Shelby Trough area, which should arguably drive Q4 volumes, if not Q3, given the profile of these longer lateral modern completions. Is that a fair read in terms of how we're thinking about production impact into Q4?
spk04: Yeah, I think there's two things there, Derek. This is Jeff. One, look, absolutely, as we mentioned in the prepared remarks, we're very encouraged about all of the activity from Athon. They're drilling great wells out there and continuing to ramp up activity. So we've chosen the right partner in the right area. And that's a program that we think is going to benefit production volumes for years. I mean, that's a decade-plus program out there if things work out the right way. So yes, we remain very encouraged by that, but we knew that was coming. So that was fully in the forecast. And while the timing moves around a little bit, you know, I don't think that was a huge move out from our original guidance. What kind of surprised us for the quarter, if you will, were some of these just massive wells that came on in the Louisiana side of the Haynesville. And look, we just, you know, We try to track permits and everything else, but these were frankly some wells that we were not fully expecting. And as we saw a research report come out just yesterday on Southwestern, for example, and these guys are just bringing these wells on at much higher production rates. For example, Southwestern is up 20% on their peak 30-day rates, going well above 30 MMCF a day. So the combination, when we get initial payments for those wells, and that will typically have several months of production. And when those wells are being pulled that hard, it can really create a difference. So I think, you know, there's the underlying growth that we, you know, have fully kind of baked into the forecast from the Shelby trough. And then a little bit of a surprise was just, you know, the size of some of these wells coming on in Louisiana.
spk06: That's great. And maybe shifting over to the Austin Chalk for my follow-up. Based on permits from the seven operators that are engaged in the trend that you noted and the release, what's your current expectation for activity over the next six to 12 months relative to current activity?
spk01: I would say that we will see over the next 12 months, we're hoping for high 20s, low 30s, the next 12 months there's there's some variables in that there's some continuing restructuring of areas with new operators and existing operators and exactly where that comes out it is a little bit unknown but we definitely see the trend up and and more importantly We think that there will be more activity in what we call the core of the play. There's been a fair amount of activity on the extremes of the play, trying to delineate the limits of the play, but we think a lot of that's going to turn into the main fairway of the play where the results have been very good.
spk06: That's terrific. Very helpful. Thanks, guys. Thanks, Eric.
spk07: Once again, if you would like to ask a question, please press star and the number one on your touchtone phone. It appears we have no further questions. I will now turn the call back over to the presenters for any closing remarks. Please go ahead.
spk01: Well, we thank you all for joining us today. We look forward to speaking with you next quarter and hope to continue the trend we're on.
spk03: Thank you.
spk07: This does conclude today's program. Thank you for your participation. You may now disconnect.
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