John Annis

John Annis asked about the specific drivers that could lead LandBridge to the high end versus the low end of its 2026 Adjusted EBITDA guidance. He also questioned the potential for the 2025 vintage acreage, specifically the 1918 Ranch, to achieve a similar surface use economic efficiency (SUEE) growth trajectory as the 2024 vintage acreage.

Answer

CFO Scott McNeely explained that the 2026 guidance was thoughtfully conservative, with potential upside drivers including higher-than-expected produced water volumes from WaterBridge's projects (Speedway, bpx Kraken) and increased oil and gas activity if commodity prices remain strong. He confirmed that a similar SUEE trajectory is absolutely possible for the 2025 vintage acreage, highlighting the 1918 Ranch as a key opportunity for commercialization not substantially baked into the current 2026 guidance.

John Annis from Texas Capital asked about the primary drivers that could lead LandBridge to achieve the high end versus the low end of its 2026 Adjusted EBITDA guidance. He also questioned the potential SUEE trajectory for 2025 vintage acreage, specifically the 1918 Ranch, compared to the impressive growth seen in 2024 vintage acreage.

Answer

Scott McNeely, CFO of LandBridge, explained that the 2026 guidance was thoughtfully conservative. Upside drivers include potential for WaterBridge's projects (beyond Speedway and bpx Kraken) to significantly increase produced water volumes, and higher activity levels if commodity prices remain in the mid-60s or above. He confirmed a similar SUEE trajectory is possible for the 1918 Ranch, highlighting it as a potential upside driver not fully baked into current guidance.

John Annis asked about Range Resources' optionality beyond 2027, specifically the criteria for deciding between continued production growth or maintaining 2.6 Bcfe/day, considering commodity prices and demand-led agreements. He also questioned the 2026 gas differentials and whether current guidance incorporates benefits from mid-2026 takeaway additions.

Answer

CEO Dennis Degner emphasized Range's low capital intensity and inventory depth, allowing for thoughtful growth driven by free cash flow and existing infrastructure like the Rover system. CFO Mark Scucchi explained that 2026 differential guidance is based on market indications and Range's diversified transportation portfolio, with the marketing team optimizing sales and ethane extraction to maximize value.

John Annis asked about Range Resources' optionality beyond 2027, specifically the criteria that would drive decisions to either continue growing production or maintain the 2.6 Bcf per day level, considering commodity views versus demand-led agreements. He also inquired about the 2026 gas differentials, when structural in-basin demand growth might compress Appalachian basis differentials, and if current guidance already incorporates benefits from mid-2026 takeaway additions.

Answer

CEO Dennis Degner explained that the production profile is primarily driven by generating free cash flow through a low-capital-intensity program. He emphasized the flexibility to reduce capital to maintain production above 2.6 Bcfe per day with sub-$600 million CapEx post-2027, or to continue thoughtful growth based on future demand. CFO Mark Scucchi clarified that 2026 differential guidance is based on market-indicated levels and Range's diversified transportation portfolio, with approximately 90% of production priced at the first of the month. He noted the marketing team's continuous optimization efforts and the ability to adjust ethane extraction levels.

John Annis asked for an update on the benefits from recent gathering and compression optimizations and questioned how a slowdown in oil-directed activity might impact service costs for Appalachian operators.

Answer

CEO Dennis Degner noted that past optimizations provided stable production, but the future focus is on system expansion for flexibility and capacity. Regarding service costs, he stated their recently extended e-fleet contract ensures cost consistency. While a broader slowdown could affect conventional fleet pricing, he noted that the market for high-spec rigs and e-fleets remains tight, and Range will gain more clarity on 2026 costs through its annual fall RFP process.

John Annis asked about the requirements for growth beyond 2027 and the drivers behind the decreasing maintenance capital forecast.

Answer

CEO Dennis Degner explained that post-2027 growth could be supported by securing underutilized transport from others or by new in-basin demand from sectors like data centers. He attributed the improved maintenance capital efficiency to continued gains in long-lateral drilling, infrastructure reuse, and the asset's low base decline rate, all enabled by their contiguous acreage position.

John Annis asked about the factors differentiating Expand Energy's top-performing wells in the Haynesville (exceeding 1 Bcf per thousand foot), the potential ceiling for this percentage, and the size and attractiveness of supplying microgrid solutions in Appalachia.

Answer

Josh Viets, EVP and COO of Expand Energy, explained that top-performing wells are driven by a mix of factors, primarily completion design, but also geology and lateral placement (southern NFG acreage). He acknowledged some constraints but sees continued upside across the acreage, with ongoing optimization from cheaper sand. Mike Wichterich, Chairman of the Board and Interim President and CEO, described the microgrid solution in Appalachia as relatively small but exciting, commanding a premium with a reservation fee and higher price, and expects to pursue more such 'singles' that add up over time.

John Annis from Texas Capital asked about the factors differentiating Expand Energy's top-performing wells (20% of 2025 TILs exceeding 1 Bcf per thousand foot, expected to rise above 30% in 2026), inquiring if it's geology, lateral placement, completion intensity, or a combination, and if there's a ceiling on this percentage given the acreage mix. He also asked about the current size and attractiveness of the microgrid solutions opportunity in Appalachia with flexible volume contracts, comparing it to larger supply commitments in the basin.

Answer

Josh Viets, EVP and COO, explained that the top-performing wells are driven by a mix of factors, with completion design being the biggest driver, alongside drilling in the southern part of their NFC acreage. He acknowledged some constraints due to gathering system capacity but sees continued upside across the acreage, citing success with three-mile laterals and ongoing optimization from cheaper sand sources. Mike Wichterich, Chairman of the Board and Interim President and CEO, described the microgrid solution as relatively small but exciting, as these small deals add up and command a premium through reservation fees and higher prices, providing a dual benefit. He stated they plan to do many more such deals.

John Annis from Texas Capital asked for management's rationale for leaning into growth and acquisitions, questioning if it was driven by macro dynamics like the private equity funding environment. He also inquired about how the new CEO views the balance between adding inventory, driving growth, and managing leverage.

Answer

President and CEO Tyler Farquharson explained that the current A&D environment is the most constructive in a long time due to a lack of private equity capital for smaller deals, creating an attractive space for Granite Ridge. He added that with the balance sheet in great shape, the current priority is to lean into growth and scale by adding inventory, even at the expense of near-term free cash flow, to capture value in the current market.

John Annis from Texas Capital asked for management's thoughts on what is driving their confidence to lean into growth and acquisitions, and how the new CEO views the balance between adding inventory, pursuing growth, and managing leverage.

Answer

President and CEO Tyler Farquharson attributed the confidence to a highly constructive A&D environment, created by a lack of private equity capital for smaller transactions, which fits Granite Ridge's model. He explained that the current priority is leaning into growth and scale by adding inventory, which is deemed a valuable long-term investment, even at the expense of near-term free cash flow.

John Annis from Texas Capital asked for the rationale behind the company's confidence in accelerating growth and acquisitions, and how the new CEO prioritizes inventory growth, production growth, and leverage management.

Answer

President and CEO Tyler Farquharson explained that the current A&D environment is highly constructive due to a void in private equity funding for smaller deals. He stated that the company is prioritizing growth and scale by adding inventory, even at the expense of near-term free cash flow, given the strength of the balance sheet and the attractive market opportunities.

John Annis asked for details on which specific basins drove the outperformance of non-op wells and how the shifting oil and gas price environment impacts capital allocation strategy across its portfolio.

Answer

President and CEO Luke Brandenberg attributed the Q1 production beat to both accelerated well timing in the Delaware and Utica basins and outperformance from existing wells, some of which saw increased production as operators opened chokes in response to better gas prices. He emphasized that all opportunities compete for capital based on full-cycle returns, highlighting the value of the company's diversified, 50/50 oil and gas asset base.

John Annis from Texas Capital Bank asked for the reasons behind the resilience of Kimbell's rig activity relative to the broader industry and inquired about the outlook for natural gas growth and its potential impact on the company's production mix into 2026.

Answer

President and CFO R. Davis Ravnaas attributed the rig count resilience to Kimbell's high-quality, diversified asset base, which has been carefully curated through an active acquisition program over 25 years. Regarding the production mix, he noted that while they are optimistic about natural gas, any shift would be slight and lumpy, with no substantial or noteworthy change expected in the near term.

John Annis asked for an outlook on production volume trends for the remainder of 2025, questioning if any factors were causing a conservative stance despite strong activity metrics like line-of-sight wells exceeding maintenance levels.

Answer

Davis Ravnaas, President and CFO, responded that Kimbell is reaffirming its existing guidance, consistent with its history of being conservative. He emphasized that despite strong near-term activity indicators—including rig counts, DUCs, permits, and surprisingly robust lease bonus activity—prudence is warranted given broader market uncertainty. He described the growth runway as 'considerable' with no foreseeable end.

John Annis of Texas Capital asked for details on the specific operational factors required to drill top-decile wells and requested more color on the chemical and power optimization projects that helped maintain low lease operating expenses (LOE).

Answer

Co-CEO Will Hickey explained that top wells require near-zero non-productive time and no unplanned trips, noting the best wells are drilled in nearly half the time of an average well. He also described their power optimization projects, such as 'microgrids,' which centralize power generation to improve runtime and have cut power costs by 30% in implemented areas.

John Annis asked how the D&C design and well spacing of the legacy operator on the bolt-on assets compare to Permian Resources' standards. He also inquired about the potential for organic inventory growth from secondary zones.

Answer

Hays Mabry, an executive, noted that the legacy operator's spacing and well productivity were strong and similar to their own. The primary opportunity lies in applying Permian Resources' leading D&C cost structure. Regarding inventory, he stated that while secondary zones like deeper Wolfcamp and Bone Spring shales offer long-term potential, the current development program remains focused on the existing high-return core inventory.

John Annis from Texas Capital inquired about any emerging positive activity on Blackstone's acreage given the recent increase in gas-directed rigs, and how the Revenant agreement and Permian developments are expected to shape the 2026 production trajectory. He also asked for a geological comparison of the newly delineated Shelby Trough areas versus the Western Haynesville.

Answer

Taylor DeWalch, SVP & CFO, responded that while overall activity has been subdued, Blackstone is focused on its specific development agreements, such as the one with Revenant which begins drilling in 2026. He noted the geological similarities between the Western Shelby Trough and Western Haynesville, with formations getting thicker and deeper. Chairman & CEO Thomas Carter added that industry conversations suggest these two areas may ultimately bridge into a single continuous play.

John Annis inquired about current activity levels in the Haynesville shale given the rerate in natural gas prices, including the completion cadence for Aethon's remaining wells. He also asked about the company's acquisition strategy and whether lower oil prices might shift focus from the Shelby Trough to oilier basins.

Answer

Taylor DeWalch, President, CFO, and Treasurer, stated that Black Stone Minerals is encouraged by gas price strength and expects development from Aethon and others to continue on schedule through 2025. On acquisitions, DeWalch confirmed that while the company evaluates all market opportunities, its strategic focus remains on gas-rich areas like the Shelby Trough that align with its long-term strategy and proximity to Gulf Coast demand.

John Annis asked about the focus of Black Stone's Q4 acquisitions, specifically their geographic region and commodity type, and inquired about the current bid-ask spread for mineral opportunities. He also questioned the duration of the accelerated drilling agreements (ADAs) in the Louisiana Haynesville and how the positive natural gas outlook impacts the strategy of executing more ADAs versus waiting for organic activity.

Answer

Tom Carter, Chairman, CEO and President, stated that the acquisition program is focused on expanding their Shelby Trough footprint in the Gulf Coast region to capitalize on long-term natural gas and LNG growth, and they are not actively looking in other basins. Carrie Clark, SVP and Chief Commercial Officer, explained that ADAs are targeted opportunities to ensure predictable production volumes, differing from broader multiyear contracts. Taylor DeWalch, SVP and CFO, added that while current agreements are targeted, there are additional opportunities to continue the program in future years.

John Annis from Texas Capital inquired about the opportunity set for securing power deals in Northeast Pennsylvania, given recent announcements were concentrated in Southwest Appalachia. He also asked a housekeeping question about how recent tax legislation impacts the outlook for cash taxes.

Answer

President and CEO Toby Rice stated that opportunities exist across EQT's entire footprint, though there is currently a strong gravitation of tech companies to Southwest Appalachia. CFO Jeremy Knop explained that the new tax bill is highly beneficial, deferring about $500 million in taxes over the next couple of years. He added that the return of 100% bonus depreciation for gathering CapEx will allow EQT to expense new project spending immediately, further deferring taxes as growth investments ramp up.