Berry Corporation (bry)

You're standing by and welcome to Barry Corporation's second quarter 2024 earnings call. At this time, all participants are in listen-only mode. After the speaker's presentation, there will be a question and answer session. To ask a question during this session, you'll need to press star 1-1 on your telephone. If your question has been answered and you'd like to remove yourself from the queue, simply press star 1-1 again. As a reminder, today's program is being recorded. And now I'd like to introduce your host for today's program, Todd Crabtree, Investor Relations. Please go ahead, sir.

Thank you, Jonathan, and welcome, everyone. Thank you for joining us for BERI's second quarter 2024 earnings teleconference. Earlier today, BERI issued an earnings release highlighting 2024 second quarter results. Speaking this morning will be Fernando Araujo, our chief executive officer, Danielle Hunter, our president, and Mike Helm, our chief financial officer. Before we begin, I would like to call your attention to the Safe Harbor language found in our earnings release that was issued this morning. The release of today's discussion contains certain projections and other forward-looking statements within the meaning of federal securities laws. These statements are subject to risks and uncertainties that may cause actual results to differ materially from those expressed or implied in these statements. These include risks and other factors outlined in our filings with the SEC, including our 10-Q, which will be filed later today. Our investor relations website, ir.bry.com, has a link to the earnings release, an investor deck aligned with this call, SEC filings, and our most recent investor presentation. Any information, including forward-looking statements made on this call or contained in the earnings release and those presentations, reflect our analysis as of the date made. We have no plans or duty to update them except as required by law. Please refer to the tables in our earnings release and on our website for reconciliation between all adjusted measures mentioned in today's calls and the related gap measures. We will also post the replay link of this call and the transcript on our website. I will now turn the call over to Fernando.

Thanks, Todd. Welcome, everyone, and thank you for joining us. In the second quarter, we delivered strong financial and operational results. generating adjusted EBITDA of $74 million and producing 25,300 barrels of oil equivalent a day. Our teams continue to perform reliably and with excellence, and we remain on track to deliver results in line with the guidance provided earlier this year. We are focused on our strategy of creating value by generating sustainable free cash flow with high rates of return in low capital intensity projects optimizing our cost structure and maintaining balance sheet strength while meeting the highest compliance standards. Production quarter over quarter was sustained by a combination of strong results from our development activity and protecting base production. Our thermal dynamite reservoir is an example of protecting the base. Since 2019, exclusive of drilling activity in 2024, we have increased production in this reservoir by 19% through superior reservoir management and workovers. This is a testament to the ingenuity of our technical teams who continue to find capital efficient ways to increase production. In the second quarter, we drilled 19 wells, with 15 in California and four vertical wells in Utah, with production from our drilling activity outperforming expected results. We have the necessary drilling permits in hand that will allow us to complete our planned drilling program for 2024. And in the second quarter, we received new drill permits that will support our development plans in 2025. Turning to Utah, the Uinta Basin has seen increased activity and consolidation, and this is exciting. The four horizontal wells we farmed into earlier this year were put on production in the second quarter and are performing better than our pre-drill estimates. These four wells are adjacent to our existing acreage and operations. We believe the resource on Berry's nearly 100,000 net operated acres, which is almost entirely held by production, has the potential to be significant. Berry has a cost advantage position in this plane. We are in the shallow end of the basin, we have no entry cost, and have significant infrastructure in place which will drive our long-term capital efficiency. An example of this is our gas production and related infrastructure, which will help us reduce fuel costs in our drilling and completion operations. Based on what we know today, these wells are highly economical and would compete for capital with the rest of our portfolio. Our strategy with this play is consistent with our capital discipline and proven financial policy of living within free cash flow while increasing enterprise value. We've kicked off a process to farm out a portion of our 2025 and 2026 program, which we believe will allow us to better manage capital and could potentially bring additional technical insight. We are very excited about the resource potential we have in Utah and look forward to sharing our future development plans later this year. I will now turn the call over to Mike.

Thank you, Fernando. I will highlight a few financial takeaways for the second quarter. For more in-depth information, please refer to our earnings release issued earlier this morning and our 10Q to be filed later today. In the second quarter, adjusted EBITDA of $74 million was $5 million higher than the first quarter. As Fernando mentioned, second quarter production was consistent with the prior quarter and realized crude prices were $78.18 per VOE and 92% of Brent for the quarter, contributing to total commodity revenue of $169 million. Compared to Q1, Lease operating expenses in Q2 were down 11% to $23.47 for VOE, due primarily to lower energy costs. Adjusted G&A expenses were down 10% due to $7.41 per VOE compared to $8.20 per VOE in Q1. We continue to implement optimization initiatives to manage our expenses. A great example of this is our Utah water disposal project, which will lower our trucking costs and has begun achieving projected annual operating cost savings of approximately $2 million. As we mentioned in Q1, we expected that our capital cadence would peak in the middle of the year, and CapEx for Q2 at $42 million was in line with our expectations and higher than in the first quarter. This is due primarily to development in California and facilities projects, as well as the second quarter Utah farmed-in development program, which has already begun to add production. We expect to remain within our annual CapEx guidance of $95 to $110 million for the year. Adjusted free cash flow year-to-date is tracking higher than in 2023. In the second quarter, our adjusted free cash flow was $19 million, and that included the impact of the higher CapEx. Accordingly, the Board approved a total dividend of 17 cents per share for the quarter. This includes our planned 12 cents per share fixed dividend and based on the adjusted free cash flow generated in Q2, the Board also declared a variable dividend of 5 cents per share, which is higher than the second quarter variable dividend in 2023. On the strength of our free cash flow, we continued to prioritize debt reduction in Q2, driving our revolver balance down to $36 million at the end of the quarter, and we further reduced the revolver to $28 million at the end of July, and this included the final payment of $20 million we made on the 2023 McPherson transaction. Reducing our debt balances speaks to Barry's proactive nature to maintain a strong balance sheet, along with our goal of debt to EBITDA ratio lower than one and a half times. And now I'll turn the call over to Barry's president, Danielle Hunter.

Thanks, Mike. For the third quarter in a row, Barry had zero recordable incidents and zero lost time incidents. I want to acknowledge our employees for another quarter of a truly outstanding safety performance. At Berry, producing oil and gas safely is one of our top priorities and a core component of our ability to deliver sustainable and reliable energy. Another core focus is environmental stewardship. Last quarter, in conjunction with the release of our sustainability report, we announced that we had set a goal to eliminate at least 80% of methane emissions associated with our existing operations from the 2022 baseline by the end of 2025. We estimate that this achievement will reduce Berry's total Scope 1 GHG emissions by approximately 10%. We're pleased to report that we have already completed 60% of this initiative, beginning with the replacement of all regulated natural gas pneumatic devices with zero emission devices. We will continue to strive to operate with the highest safety and compliance standards that our stakeholders expect, and we are always exploring additional ways to make improvements. We look forward to providing future updates on our progress. Back to you, Fernando.

Thanks, Danny. In closing, our second quarter results have delivered on our commitment to create value and generate sustainable free cash flow. We are on track to meet our annual production goals and continue to effectively manage our costs while maintaining an outstanding record of safety and compliance. We have world-class assets, an exceptional team that is always driving operational improvements, and has a proven track record of delivering results. Halfway through 2024, we are well on the way to achieving another solid year of operational and financial performance. We remain very excited about the potential Utah horizontal well development opportunity. The outstanding performance from our four wells to date, the significant running room across our acreage, and the built-in competitive advantages will enhance the economics of our future drilling activities. Our Uinta Basin development has the potential to be complementary to a world-class California portfolio of highly economic locations. I will now turn the call over to the operator for questions.

Certainly. And as a reminder, ladies and gentlemen, if you do have a question at this time, please press star 1-1. And our first question comes from the line of Charles Mead from Johnson Rice. Your question, please.

Yes. Good morning, Fernando, Mike, and Danielle, and the rest of the very team. Fernando, I'm laughing a little bit because I appreciate what you've said on the Uintah Wells, that they're better than expectations. But I think there's probably some reason why you haven't told us the rate or told us what your expectations were. So to whatever extent you can, can you give us some guideposts or some brackets for – That would help us, if not specifically quantify, at least get an understanding of where these wells have come in and maybe what you expect to see over the next 36 or 90 days there.

Very good, Charles. That's a very good question. And let me provide a little more color around the horizontal wells in Utah. As you know, we've farmed into the four wells in acreage. that's adjacent to our acreage to the northeast side of our acreage. And as I mentioned, the well results initially are better than expected, better than pre-drill, and we'll get to those details here in a minute. But just to provide a little more color, we targeted the Eutland Butte Reservoir, which is one of three or four reservoirs being targeted in the basin for horizontal well activity. And I do want to emphasize that we have nearly 100,000 acres operated by Berry. Most of that held by production with really good geology, uniform geology, especially in the U-Lambu Reservoir, that has the potential for horizontal well development. So we're very, very excited about that. In addition to the fact that we do have a cost advantage position, as I mentioned, in the play, we are in the shallow end of the basin, we have no entry cost, and we have significant infrastructure in place to help us put those wells on production. So that's going to drive our capital efficiencies. As far as the production itself, the wells IPed at a rate of about 1,100 barrels of oil equivalent a day, 90% oil, which is very good, 10% gas. But also remember that we are at the shallow end of the basin with lower reservoir pressures. So our IPs are slightly lower compared to some of the IPs in the northern end of the basin, in the deep basin. So we have to be mindful of that. But we do have that cost advantage position that I mentioned before, and that's what's really going to drive some significant improvement in the economics of those wells. So hopefully that helps, Charles.

No, look, that does help a lot. That may not be as high as some of the other two-mile laterals to the north, but those are really stout rates. So thank you for quantifying that, Fernando. One other piece of it that I'd like to ask is, previously you had said 22,000 acres were prospective, and it was clear way back then that that only reflected a piece of your total position. Now you're at 100, and can you give some context? Does that just reflect your success for these four wells, or is there more that plays into that, like perhaps other industry results to the west?

Another good question, Charles, and we should have been more specific when we talked about the 22,000 acres. The 22,000 acres that we referred to before is the acreage that we're currently applying well permits for. So we're focusing on those 22,000 acres, which is on the northern side of our acreage base, but that's just the area where we're focusing to get permits uh ready and and submitted here in the in the next few weeks but the entire 100 100 000 acres is what's perspective with horse annual activity got it thank you thank you and as a reminder if you have a question at this time please press star 1 1 on your telephone and

This does conclude the question and answer session of today's program. We have a follow-up from Charles Mead from Johnson and Rice. Just one moment. And your follow-up, please.

Yeah. Okay. So two other questions then. One on Utah and then one on California. You mentioned twice that you're at the shallow end of the basin. And so, you know, uh, presumably you've got a Northward dip here and, uh, you know, all other things being equal, usually, uh, shallower means a slightly lower well costs because you've got a little less on the vertical section. Um, but my understanding, a lot of this is, is all, uh, you know, overpressure drilling. And so, so that might not, uh, that might not have as big a, uh, you know, you might not see as big a reduction in well cost to what, when you look at it, what's the significance of being in the, uh, in the shallow end of the basin beyond well costs? And does that perhaps mean that some of the deeper horizons below the Udland Butte, because some of the other operators are talking about a number of horizons that have been historically productive in vertical wells, does that mean maybe some of the deeper horizons are going to be the most prospective for you in the shallower part of the basins?

Another very good question, Charles. And, you know, we are shallower, a couple thousand feet shallower than the deep end of the basin. So our drilling costs are expected to be lower. So that's one of the advantages that we have outside of the infrastructure that we have in place. As you know, we've got 1,200 wells, something like that, in Utah with a lot of infrastructure. Because we are shallower, our reservoir pressures are a little bit lower, and that's just a fact. But with the lower capital costs associated to drilling and completing the wells, and the tap curves we're seeing from these horizontal wells, our economics are going to be very robust. So we're happy about that. Now, do we have opportunities? Deeper than that, yes. You know, we've got the Uinta that we're targeting. Below that, we've got the Douglas Creek as well. And below that, we've got the Wasatch. And there's a few operators targeting with success those reservoirs. The geology is good. It's just an additional upside that we have with those additional reservoirs that happen to be deeper than the Uinta.

Got it.

That helps them provide a little more color.

Yeah, no, it's really interesting. You know, it's been a few years since we've had a kind of, you know, kind of a rapidly unfolding, you know, play like this in the industry. And so it's kind of, you know, fun to turn those cranks again. Yeah, I'm very excited about it.

Yeah. Right, yeah.

Transition to California. Can you give any update there on the outlook for – additional acquisitions, what the marketplace may look like now. I mean, you had that successful McPherson deal not long ago, but if there's more opportunities like that, that might be waiting in the wings.

No, very good. Yeah, we had that successful McPherson acquisition. As you know, great results. We've been able to lower operating expenses by 40% with operational synergy, so that's been a great success. Now, in terms of additional opportunities, you know, as we've mentioned before, we've got a handful of opportunities. We're talking to different parties, mostly small privates. And these would be considered bolt-on opportunities. And this is really part of our base business. Obviously, we're focusing in Kern County. That's when we can realize operational synergies and apply our technical expertise. And we are, like I said, having conversations with a few parties. But it takes time. A lot of these companies, they've been around for many, many years. But at least they're willing to talk. They're willing to have the conversations. And we just have to come up with creative ways to close the deal and come up with a good deal structure that makes sense for everybody. But we are looking at a handful of opportunities in California.

Great. Thank you. Thank you. This does conclude the question and answer session of today's program. I'd like to hand the program back to Fernando Araujo for any further remarks.

Thank you, everyone, for joining the call. Thank you for your interest. And Barry, we look forward to talking to you in Q3. And we are excited about our company, excited about what we have in Utah, excited about the potential activity that we have in California. And we look forward to staying in touch. Thank you so much.

Thank you, ladies and gentlemen, for your participation in today's conference. This does conclude the program. You may now disconnect. Good day.