Granite Ridge Resources - Earnings Call - Q2 2025

Executive Summary

• Q2 2025 delivered robust operational growth: production up 37% YoY to 31,576 Boe/d (51% oil), oil volumes +46%, gas +28%; GAAP net income was $25.1M ($0.19 diluted EPS) and Adjusted EPS was $0.11, with Adjusted EBITDAX of $75.4M.
• Guidance was raised materially: 2025 production to 31,000–33,000 Boe/d (from 28,000–30,000) and total capex to $400–$420M (from $300–$320M), adding ~74 net locations and three years of inventory; dividend maintained at $0.11 per share.
• Versus consensus: revenue modestly beat ($109.2M vs $108.1M*), Adjusted EPS missed ($0.11 vs $0.13*), and Adjusted EBITDAX was slightly above EBITDA consensus ($75.4M vs $74.2M*). The company also booked a $23.9M derivative gain and a $5.8M equity investment loss that influenced GAAP results. Values marked with * retrieved from S&P Global.
• Strategic catalysts: acceleration in Permian operated partnerships (three rigs running), strong Utica non-op outperformance, and explicit intent to explore credit markets (RBL upsizing and potential terming-out via high yield or private credit), positioning for continued scale in 2026.

What Went Well and What Went Wrong

What Went Well

• Production growth and mix: 37% YoY growth to 31,576 Boe/d driven by +46% oil and +28% gas; GAAP net income up sharply to $25.1M ($0.19) and Adjusted EBITDAX reached $75.4M, underscoring operational execution.
• Guidance raised and inventory extended: 2025 production guidance increased ~10% at midpoint and total capex lifted to fund acquisitions, adding ~74 net locations and ~3 years of inventory at ~$1.7M per location.
• Management commitment to value creation: “Our quarterly results continue to validate our business model... We allocate capital to the highest risk-adjusted returns... driving consistent and attractive full-cycle returns,” said CEO Tyler Farquharson.

What Went Wrong

• Cost inflation: LOE rose to $20.1M ($7.00/boe) vs $13.7M ($6.50/boe) in Q2 2024, driven by service cost pressures, notably saltwater disposal, pressuring unit economics.
• Lower realized prices and investment losses: Realized oil price fell to $61.41/bbl (from $69.18 in Q1 and $65.53 in Q4), and the company recorded a $5.8M loss on equity investments in the quarter.
• Outspend and leverage drift: Long-term debt increased to $275.0M with leverage at 0.8x Net Debt/TTM Adjusted EBITDAX (still conservative), and management acknowledged continuing to outspend cash flow while leaning into growth and inventory additions.

Transcript

Speaker 5

Good morning and welcome, everyone, to Granite Ridge Resources' second quarter 2025 earnings conference call. Currently, all participants are in a listen-only mode. A question-and-answer session will follow the formal presentation. If you'd like to ask a question during this time, simply press star followed by the number one on your telephone keypad. If you'd like to withdraw your question, again press the star and one. Please limit comments to one question and one follow-up. I will now turn the call over to James Masters, Investor Relations Representative for Granite Ridge.

Speaker 2

Thank you, operator, and good morning, everyone. We appreciate your interest in Granite Ridge Resources. We will begin our call with comments from Tyler Farquharson, our President and Chief Executive Officer, who will review the quarter's results and company strategy. We will then turn the call over to Kim Weimer, our Interim Chief Financial Officer and Chief Accounting Officer, who will review our financial results in greater detail. Tyler will then return to provide closing comments before we open the call for questions. Today's conference call 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 from those expressed or implied. We ask that you review the cautionary statement in our earnings release.

Granite Ridge Resources disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise. Accordingly, you should not place undue reliance on these statements. These and other risks are described in yesterday's press release and our filings with the Securities and Exchange Commission. This call also includes references to certain non-GAAP financial measures. Information reconciling these measures to the most directly comparable GAAP measures is available in our earnings release on our website. Finally, this call is being recorded, and a replay and transcript will be available on our website following today's call. With that, I'll turn the call over to Tyler.

Speaker 6

Thank you, James, and good morning, everyone. I'm excited to address you today as Granite Ridge Resources' new CEO. Before diving into our second quarter results, I want to acknowledge the leadership transition that occurred during the quarter. Luke Brandenberg stepped down as CEO, and I'm honored to have been appointed to lead the company forward. Luke played a pivotal role in shaping Granite Ridge Resources into the successful business it is today, and on behalf of the team, I want to express our gratitude for his significant contributions. We wish him all the best in his next chapter. Turning to our Q2 performance, our quarterly results continue to validate our business model, with production and cash flow once again exceeding expectations.

In the second quarter, we turned 4.9 net wells to sales and increased production by 37% year-over-year to 31,576 BOE/d, driven by a 46% rise in oil production and a 28% rise in natural gas production. This growth reflects the strength of our diversified portfolio of oil and natural gas assets and our disciplined approach to capital allocation, which prioritizes the highest risk-adjusted returns. Our operator partnerships and traditional non-OP investment strategies remain the driver of this success. We partnered with four top-tier operators to unlock substantial value in the Permian Basin and are thrilled with the progress achieved to date. Meanwhile, our traditional non-OP strategy continues to deliver consistent results, with wells coming online ahead of schedule in the Permian and wells outperforming forecasts in the Utica.

On the capital front, we spent approximately $77 million on development and $10 million on acquisitions for a total CapEx spend of $87 million. Year to date, we have invested approximately $149 million of capital on development activities, which is higher than forecast based on the accelerated timing of activities, and $44 million in acquisition capital expenditures. These acquisitions, located in the Permian and Appalachian Basins, added high-quality inventory to our portfolio, enhancing our growth runway. Given our first half performance, driven by stronger-than-modeled production and unexpected acceleration of new production, we are raising our full-year production guidance by 10% at the midpoint to between 31,000 and 33,000 BOE/d, which will result in year-over-year growth of 28%. We are also raising our capital expenditure guidance to an all-in range of $400 to $420 million, driven mainly by new unbudgeted acquisitions expected to close in 2025.

Our deal team's tenacity and strategic approach have led to every transaction we've sourced being off-market. For 2025, we anticipate deploying approximately $120 million in acquisition capital, adding 74 net locations. 80% of this capital targets the Permian Basin through our operator partnership strategy, the remaining allocated to our Appalachian leasing strategy, which has delivered exceptional results to date. Our business development engine is operating at peak performance, securing three additional years of inventory at an attractive entry cost of $1.7 million per location. Our operator partners are doing exactly what we expect them to do: capture attractive development opportunities at below market value. They are doing an excellent job, and we're excited for the opportunity to fund these projects for the long-term benefit of our shareholders. Moving forward, our guidance will identify both development and acquisition capital expenditures separately, which we hope will offer more transparency for our investors.

We occupy a unique niche in the public energy market, looking like an energy company but acting like an investment firm. Our vision is to become the leading public investment platform for energy development, and we will continue to invest alongside proven, high-quality operating teams to capitalize on undervalued opportunity. Since commodity prices declined in early Q2, we have moved aggressively to scale our operator platform and secure long-dated, low-risk inventory at highly attractive entry prices. We have identified nearly $60 million of new inventory acquisitions, $40 million of which are located in the Permian Basin through our operator partners, and $20 million of which are driven by organic acreage leasing in the Utica Shale. Our strategy remains unchanged. We continue to underwrite development projects targeting full cycle returns exceeding 25%, deliver top quartile growth, and return capital to shareholders through our quarterly dividend.

This disciplined approach allows us to remain resilient in any market environment. We may not look like your typical E&P, but we are creating a ton of value. Our investment strategy centers on operator partnerships, with two gaining significant momentum. Our longest-standing partner is Midland-based Admiral Permian Resources. After selling their prior firm, Reliance Energy, to Concho Resources for $1.6 billion, members of the management team founded the first iteration of Admiral Permian backed by Aries Management. Over a three-year period, Admiral scaled its asset base in the Western Delaware Basin to 20,000 BOE/d before divesting to Petrohunt with a trailing EBITDA of nearly $300 million. I gave you their impressive resume to highlight the value of our operator partnership program. We fund proven, highly talented teams to do what they do best: create significant value through finding and developing oil and gas.

We are proud to partner with Admiral Permian Resources in their newest iteration. After just two years of partnership, Admiral produces over 7,000 BOE/d net to Granite Ridge for 22% of our total production, and as of June 30, boasts over 40 net locations of high-quality inventory. PetroLegacy is our second partner, focused on growing an asset position in the Midland Basin. Three years ago, the management team sold PetroLegacy, then backed by NCAP Investments, to Oventiv after growing production in the same area to 35,000 BOE/d. Our third and fourth partners signed in just the last couple of months are still confidential as they are just starting on their asset acquisition phase.

Each partner has their own story, their own unique investment strategy, but taken together, they've hit a very specific investment thesis for Granite Ridge Resources, which is that there now exists a void of private capital in the oil and gas space after a 70% decline in upstream private equity fundraising since 2018. The private capital that remains is focused on mega-deals with concentrated portfolios. This altered supply and demand dynamic has lowered the entry costs and increased the resulting economic returns on smaller development projects. Add to this that the core of the Delaware Basin, for example, is largely held by seven operators overseeing massive asset packages, and it sets up remarkable opportunities for nimble and aggressive teams to piece together smaller deals at attractive prices. That suits the traditional Granite Ridge Resources model to a tee.

For over a decade, our team's daily pursuit has been uncovering value in oil and gas through smart value-add investments, small deal after small deal, utilizing a huge proprietary data set to accurately underwrite, hitting singles and doubles in the premier basins across the United States. We've done this successfully, enjoying the compounding effect of consistently investing to full cycle returns that comfortably exceed our cost of capital. The operator partnership strategy is not all that different. We still evaluate every deal with our partners and underwrite those with the highest risk-adjusted returns. From a macro perspective, volatility persists with oil and natural gas prices softening. Our diversified production mix, roughly balanced between oil and gas, provides a natural balance, and our hedging program, covering approximately 75% of current production, protects our cash flows. Looking ahead, our priorities for the rest of 2025 are clear.

First, we'll advance our operator partnership program, which will account for approximately 65% of our development capital spend this year. With three rigs currently running in the Permian Basin, we have the flexibility to adjust activity based on market conditions. Second, we'll maintain a balance between growth and returns, supporting our 10% production increase while preserving our $0.11 per share quarterly dividend, which offers an attractive yield at current prices. Finally, we'll safeguard our financial flexibility. Our balance sheet remains strong with a leverage ratio of 0.8 times net debt to adjusted EBITDA. We enhanced liquidity following our borrowing base increase to $375 million in the second quarter, and we'll continue to bolster our liquidity by exploring the credit markets in the fall. Before I hand it over to Kim, I want to underscore my confidence in Granite Ridge Resources' future.

We have a proven strategy, a high-quality asset base, and a talented team ready to execute. I'm excited to lead us through this next phase of growth and deliver value for our shareholders.

Speaker 3

Thank you, Tyler, and good morning, everyone. I'll provide a detailed overview of our Q2 2025 financial results, which highlights our operational strengths and disciplined financial management. In Q2, we generated total oil and gas sales revenue of $109.2 million, an increase of 20% compared to Q2 2024. This growth was driven by a 37% increase in production to 31,576 BOE/d. Oil revenues rose by $12 million, reflecting a 46% jump in oil production to 16,009 barrels per day, though partially offset by a 21% decline in realized prices from $77.84 per barrel in the prior year period to $61.41 this quarter. Natural gas revenues increased by $6.6 million, supported by a 28% rise in production to 93,404 MCF per day and a 17% incline in realized prices from $1.98 per MCF to $2.32 per MCF.

Net income for the quarter was $25.1 million or $0.19 per share, reflecting our strong operational performance. Operating cash flow before working capital changes was $69.5 million, providing robust liquidity to fund our capital program and dividend. For the first half of 2025, net cash from operating activities totaled $154.1 million, up from $132.8 million in the prior year. On the cost side, lease operating expenses were $20.1 million or $7 per BOE compared to $13.7 million or $6.50 per BOE in Q2 2024. The increase reflects elevated service costs and higher saltwater disposal costs as the percentage of our production from the Delaware Basin has increased. We continue to optimize efficiency as we scale.

General and administrative expenses rose by $1.9 million year over year to $8.5 million or $2.96 per BOE, driven by certain non-recurring general and administrative expenses, including $1.7 million in severance expense tied to the leadership transition and $1.1 million related to capital markets activities. Including these non-recurring items, G&A remains well controlled. Capital allocation remains opportunistic. Development capital expenditures for the six months ended June 30th totaled $148.6 million, in line with our base case, while acquisition CapEx was $44.4 million, adding 17.5 net locations in the Permian and Appalachian Basin. These deals enhance our inventory and position us for sustained growth. Total capital for the first half, including acquisitions, was $193 million. Our balance sheet continues to be a strength.

While long-term debt increased by $25 million this quarter to $275 million, reflecting opportunistic investments in inventory, our leverage ratio remains conservative at 0.8 times net debt to adjusted EBITDA. We recorded a $23.9 million gain on derivatives, primarily unrealized due primarily to the decline in oil prices during the period. We also incurred a net loss on equity investments from the sale of vital shares. Looking forward, we're raising our full-year production guidance to 31,000 to 33,000 BOE/d and our capital expenditure guidance to $400 to $420 million. For Q3, we expect production to modestly grow above Q2 levels, with further growth in Q4 as new wells come online. Capital spending will peak for the year in Q3 with a significant component of acquisition capital before moderating in the fourth quarter in both D&C and acquisitions. Back to you, Tyler.

Speaker 6

Thank you, Kim. In closing, I want to thank our team for their hard work and dedication, which has been critical to delivering these strong results. I also appreciate the continued support of our shareholders. As we move forward, I'm confident that Granite Ridge Resources is well-positioned to navigate market volatility and create long-term value. Our strategy is proven, our assets are exceptional, and our team is best in class. We remain committed to executing our plan, driving growth, and returning capital to shareholders. With that, operator, please open the line for questions.

Speaker 5

At this time, I would like to remind everyone, in order to ask a question, please press star, then the number one on your telephone keypad. Your first question comes from the line of Phillips Johnston with Capital One. Your line is open.

Speaker 4

Hey, thanks for the time. Appreciate the color on the quarterly guidance and productions. It sounds like three up, up a little bit, and then the significant growth really occurs in Q4. If you look at your guidance, it implies the oil mix is going to take up around 53% in the back half of the year versus around 51% in the first half of the year. I just kind of wanted to get a sense of what's driving that oil mix higher.

Speaker 6

Yeah, thanks Phillips. Morning. On oil cut, we actually think we'll be more like 52%. We're slightly lower than what you have. We are seeing some gas acceleration on some new projects from folks that are, you know, Hane Field that are focused. Predominantly, where the growth is coming from is in the Permian, which is obviously an oilier mix than the existing asset.

Speaker 4

Okay, that makes sense. The company's net debt increased to $270 million from around $195 million at the end of 2024. The updated guidance suggests that the outspent of cash flow this year is going to be a little bit wider than it would have been based on prior guidance. You have a strong balance sheet. You mentioned the leverage ratio is solid at 0.8 times. You've got plenty of liquidity. I just wanted to get a sense of the board's appetite to continue adding to the net debt balance as we sort of look out beyond this year into 2026 and beyond.

Speaker 6

Nothing's changed there on that front. We've repeatedly said that we're comfortable in a 1 to 1.25 times span. We ended the quarter Q2 at 0.8 times. We still have some capacity there. With what we're seeing in the acquisition market right now, we're really focused on leaning in on adding inventory, adding duration to the business. We think that's a really attractive investment at this point. I think you'll continue to see us outspend cash flow until we get to where we're comfortable with leverage. I think you could see us outspend again next year, particularly in an acquisition environment such as we're in now.

Speaker 4

Okay, sounds good. Thanks, Tyler.

Speaker 6

Thanks.

Speaker 5

Your next question comes from the line of John Annis with Texas Capital. Your line is open.

Speaker 1

Hey, good morning, all, and thanks for taking my questions. For my first one, I just wanted to get your thoughts on what you're seeing that has given you the confidence to lean into growth and acquisitions at this time, whether it's the macro current dynamics with key funding that you highlighted in the slides or something else. Just some more color on that would be great.

Speaker 6

Sure. Yeah, great question. This is the most constructive environment that we've seen on the A&D front in quite some time. I think a big component of that is just the lack of private equity capital in the space. The private equity capital that is left in the space is focused on much larger format transactions. That has really left a pretty attractive space for us that fits our model well, where we're able to just continue to aggregate smaller transactions at really attractive prices. The other thing that's helping us now is we're adding operator partner teams. We have four teams now that tremendously expand our opportunity set, our deal flow. This year we're seeing A&D activity that we've evaluated up 15% versus where we were last year. I think this setup really fits our model well.

From a macro perspective, with the weakness on oil prices recently, we've seen a lot of the larger operators looking to rationalize their development capital spend. That really leaves us an opportunity to help folks solve those issues that they have on CapEx efficiency.

Speaker 1

Makes sense. For my follow-up, maybe for you, Tyler, I wanted to get your views on how you see balancing, adding inventory, adding growth, and managing leverage. You've clearly been successful balancing the three, but I just wanted to get a sense of how you're viewing these priorities in your new role.

Speaker 6

Yeah, that's exactly what we're thinking about every day, those three things. I think right now, you know, we're leaning into growth. We're leaning into scale. We think that, you know, added duration to our inventory is going to pay dividends down the road. We're finding that A&D market very attractive right now to allow us to do that. Since the balance sheet is still in great shape right now, we're choosing to lean in there. That comes at the expense of free cash flow, but we believe over time, you know, we'll get to a point where we will be more free cash flow neutral. This market environment is really conducive to us adding scale and increasing our inventory.

Speaker 1

Thanks, guys. I'll leave it there.

Speaker 5

Your next question comes from the line of Michael Scialla with Stephens. Your line is open.

Speaker 0

Morning. Tyler, you mentioned you could outspend again next year. Sounds like you probably will. If you get all the acreage you anticipate with these acquisitions, then the macro holds together. I guess trying to get your sense of where the 2026 program could go with the operator partnerships. Would the four rigs be possible, or what are you thinking at this point?

Speaker 6

Absolutely. Yeah, four rigs. We're running three now. I could see a scenario definitely where we're with a fourth rig. We just added two new partners. They're aggregating inventory now. That'll take them a little bit of time. At some point in 2026, I do expect that we'd be running at least one rig on one of those two new partners that we added. From a phasing standpoint, from an outlook standpoint, I think that CapEx spend in 2026 would look pretty similar, if not more, compared to what we're doing this year, especially if the A&D environment remains strong.

Speaker 0

Would the mix change if you go to at least four rigs? You are kind of 65% operated, 35% non-operated. Do you see that operated piece going higher next year?

Speaker 6

Yeah, it might tick up, but we're still seeing a ton of opportunity on the non-OP front, particularly in the Appalachian Basin. Most of the non-OP deals that we've done this year have been in the Utica windows. You know, we still expect to see a pretty good clip of non-OP opportunities even as we move into 2027 and 2028. Yes, I think that the % of capital going to operator partnerships might tick up, but we'll still have a pretty healthy component from non-OP.

Speaker 0

Great. Thanks, Tyler.

Speaker 5

Your next question comes from the line of Noah Hungness with Bank of America. Your line is open.

Speaker 1

Morning, Tim. For my first question here, you guys are growing, you know, over 24% this year. I mean, how can we think about the growth trajectory of the company moving forward? Is that a level that you like, a level of growth that you like to see, or would you maybe want to moderate that kind of back to the original plan of what was mid-teens growth?

Speaker 6

Yeah, production growth isn't a target. We don't set a target and then try to achieve the target. Again, it's driven by where we are on leverage, where we are on scale, what's free cash flow look like. I think right now, given this environment and where the balance sheet is, I would expect quite a bit of growth into 2026. It's a bit early for us to talk about what that looks like. I think it might not be as strong as this year, but would be mid-teens type growth given what we're buying now, a lot of that inventory at 2026, 2027. Right now we're prioritizing growth. I would expect that to continue with where we are with our balance sheet.

Speaker 1

That's helpful. For my second question here, you guys mentioned exploring the credit markets or looking to explore the credit markets in the fall of 2025. How can we, like, could you just add some color around what you're thinking there? Are you thinking about increasing your RBL size, potentially going to the high yield market to term out some debt? Just thoughts there.

Speaker 6

Yeah, you know, kind of all the above, right? We increased the RBL by $50 million in the spring. Given this level of activity here in 2025, I'd expect us to be able to get a pretty healthy increase again in the fall. That's certainly on the table and something that we're pursuing now. I think we're also looking at options that would help us term out some of that RBL balance. That could either be, you know, traditional high yield market or some sort of private credit option as well. Those are all on the table, and those are things that we'll evaluate here as we head into the fall.

Speaker 1

Makes sense. Thanks for the time.

Speaker 5

I would like to remind everyone, in order to ask a question, press star, then the number one on your telephone keypad. Your next question comes from the line of Phillips Johnston with Capital One. Your line is open.

Speaker 4

Sorry for the follow-up. Just wanted to ask if any of these partnerships are structured like earnouts to where your working interest is reduced after, you know, certain payout targets are met? Or are they generally more of like a heads-up type of arrangement?

Speaker 6

There is, after a return hurdle is achieved, a reversion of some of our interest to the operator partnership teams. There is no upfront promote in any way. There's nothing on the front end, but there is, after the return thresholds are met, a back-end part of our interest.

Speaker 4

Okay, makes sense. Thanks, Tyler.

Speaker 6

No problem. Thank you.

Speaker 5

There are no further questions at this time. Thank you all for attending. This does conclude today's conference call. You may now disconnect.