John Abbott

John Abbott inquired about Crescent Energy's long-term maintenance CapEx and oil production targets, specifically if the company would consider plateauing at a higher level than 130,000 barrels per day in 2027-2028 if a more constructive commodity environment emerges, given their one-rig Permian plan.

Answer

CEO David Rockecharlie affirmed that Crescent aims to run the business at a target reinvestment rate, prioritizing returns and free cash flow. He confirmed the company's ability to increase activity across all basins (Eagle Ford, Uinta, Permian) and would allocate capital to the highest-returning opportunities, whether oil or gas, emphasizing their good optionality in the Permian.

John Abbott asked about the optionality of the Uinta asset, given its current role in the portfolio and the program to delineate other zones. He also inquired about Crescent's long-term maintenance CapEx and oil production plateau, specifically asking if the company would consider plateauing at a higher level than 130,000 barrels per day with more than one rig in the Permian if the commodity environment becomes more constructive in 2027-2028.

Answer

CEO David Rockecharlie described the Uinta as an entirely HVP (High Value Project) asset, offering strong returns in a normalized oil market and incredible resource potential, with the ability to methodically expand over time as a one-rig area. Regarding long-term production, CEO David Rockecharlie stated that Crescent aims to run the business at a target reinvestment rate, prioritizing returns and free cash flow. He confirmed the ability to allocate development activity to the best returns across the Eagle Ford, Uinta, and Permian, implying flexibility to adjust production levels based on commodity prices and rates of return.

John Abbott from Wolfe Research, LLC asked about the company's flexibility to pivot capital between oil and natural gas for the remainder of 2025 and into 2026. He also inquired about the company's ability to offset cash taxes beyond 2027.

Answer

CEO David Rockecharlie stated that the company has proven flexibility to shift capital, noting that about 20% of the program can be moved relatively quickly at the margin. CFO Brandi Kendall addressed the tax question, explaining that due to recent legislation, Crescent anticipates roughly $250 million in cash tax savings over the next five years, with federal taxes expected to be near zero for the next couple of years under current assumptions.

John Abbott followed up on the Uinta, asking about the process and potential timeline for delineating the new zones. He also questioned how commodity price outlooks for oil versus gas influence the strategy and timing of asset divestitures.

Answer

EVP & COO Clay Rynd and CEO David Rockecharlie explained the Uinta delineation is a methodical, returns-focused process of data gathering, not a rapid, full-scale delineation, noting they also benefit from the activities of other operators in the basin. Regarding divestitures, David Rockecharlie stated that while commodity prices are a factor, the core focus is on value creation and portfolio optimization, and management believes now is a reasonable time to consider larger-scale non-core asset sales.

John Abbott asked a strategic question about maintaining the company's underlying decline rate while growing through acquisitions and inquired about the specific triggers, such as price or ratios, for shifting activity to dry gas acreage.

Answer

David Rockecharlie, an executive, explained that they maintain a low corporate decline rate by integrating acquired assets, whether high or low decline, into their disciplined, free-cash-flow-focused business model. He stated that the trigger for allocating capital to any area, including dry gas, is purely driven by achieving their target returns on capital, which is a function of price, costs, and well performance.

John Abbott asked about the likelihood of Permian Resources growing production in 2027, when such a decision would be made, and the extent of multi-year growth the company is willing to pursue given its inventory and ground game. He also inquired about the hedging strategy for 2027, particularly in a potentially more positive oil environment.

Answer

Co-CEO James Walter stated that while 2026 production growth is 5% higher than 2025, a return to a more 'growthy scenario' is possible with confidence in the macro environment (supply-demand balance, oil price, service costs). Historically, they've grown closer to 10% per year, with mid-to-high single digits being achievable in an attractive environment. CFO Guy Oliphint clarified that hedging targets (30%, 20%, 10% for years one, two, and three out) remain consistent, serving to provide capital for downturns, and they opportunistically hedge into volatility rather than forcing targets at lower-than-mid-cycle oil prices.

John Abbott inquired about the likelihood of Permian Resources growing in 2027, the timing of such a decision, and the extent of multi-year growth given their inventory. He also asked about the hedging strategy for 2027, considering a potentially more positive oil environment.

Answer

James Walter, Co-CEO and Director, stated that 2026 production growth is 5% higher than 2025, which he considers a 'yellow light.' Future growth depends on macro confidence, with historical growth closer to 10% per year, but mid-to-high single digits are achievable. Guy Oliphint, EVP and CFO, clarified that 2026 oil hedging is slightly less than 50%, with targets of 30%, 20%, 10% for years one, two, and three out, using hedging to provide capital for downturns.

John Abbott from Wolfe Research, LLC sought to quantify the free cash flow impact of new marketing agreements beyond 2026 and asked for specific details on operational synergies and savings from the recently closed Delaware acquisition.

Answer

Co-CEO James Walter indicated that the free cash flow uplift from marketing should grow beyond 2026 as more capacity comes online and new deals are signed. Co-CEO Will Hickey detailed that the acquisition integration was swift, with immediate synergies in personnel and water handling, and noted the most significant future value will come from the land team's work in trading and coring up the newly acquired acreage.

John Abbott of Wolfe Research inquired if achieving further D&C cost efficiencies below the current $750 per lateral foot would require a major technological change. He also asked about the philosophy of letting efficiencies drive production growth versus managing to a specific production target in a backwardated oil market.

Answer

Co-CEO James Walter explained that further cost cuts could come from both incremental improvements and larger technological step-changes, which historically occur every year or two. Co-CEO William Hickey added that the production level is a balance between the program's excellent returns and the macro backdrop, leading to a 'middle ground' approach focused on delivering strong per-share growth.

John Abbott asked about the strategic importance of maintaining a consistent rig and frac crew count for efficiency and whether the company would consider building DUCs.

Answer

Co-CEO William Hickey expressed confidence in the team's proven ability to flexibly manage rig and frac fleet counts without losing efficiency, noting the current 12-rig program works well but could be adjusted. He clarified that building a DUC inventory is not part of their strategy in a normal oil price environment and would only be considered in a severe downturn, as was done during COVID.

John Abbott inquired about Matador Resources' strategy for the Woodford play, asking if their position is held by production, the significance of drilling their first well in the first half of the year, and potential de-risking in 2027, especially with additional pipeline capacity by year-end.

Answer

Chris Calvert, EVP and Chief Operating Officer, expressed excitement about the Woodford, noting the geoscience team's long-standing interest in deeper basin parts and the potential for it to be additive to their 23 discrete producing horizons. Tom Elsener, EVP of Reservoir Engineering, stated that the primary objective of the first Woodford well is to learn, involving a pilot hole and logs. Andrew Parker, Senior Vice President of Geosciences, added that the Woodford is purely incremental to their current inventory, with no inventory yet awarded, and its success would be a significant win, reinforcing confidence in the Delaware Basin's petroleum system.

John Abbott of Wolfe Research inquired about Matador Resources Company's strategy for the Woodford play. He asked if the position is primarily held by production, the significance of drilling the first well in the first half of 2026 and additional pipeline capacity by year-end, and the potential for further de-risking in 2027.

Answer

Chris Calvert (EVP and Chief Operating Officer) expressed excitement about the Woodford, noting Matador's geoscience team has long explored deeper parts of the basin. Tom Elsener (EVP of Reservoir Engineering) stated that the primary objective of the first Woodford well is to learn as much as possible, including running logs from a pilot hole. He highlighted Matador's position on the eastern side of the basin, where others have had success. Elsener emphasized that the Woodford would be purely incremental to their current inventory, with no inventory yet awarded to it. Andrew Parker (Senior Vice President of Geosciences) added that the team is excited about results in Texas and Matador's New Mexico rock, seeing significant running room.

John Abbott asked about Matador's natural gas pricing outlook, particularly concerning negative Waha prices, the impact of additional takeaway capacity in the Permian, and how these factors influence gas pricing in Q4 and longer term, as well as realizations.

Answer

Glenn Stetson, Production Engineer, Joseph Foran, Founder, Chairman and CEO, and Anton Langland, EVP of Marketing, explained that Matador curtailed some wells in Q4 to avoid deep negative Waha pricing, demonstrating operational nimbleness. They anticipate new pipelines (Hue Brinson, Blackcomb, GCX expansion) coming online in 2026 will alleviate capacity issues, improving Waha prices and creating opportunities for drilling gasier benches in 2027-2028. Matador has also put hedges in place for 2026 to protect against downside risk.

John Abbott asked about Antero's willingness to grow beyond the 4.5 Bcf/d target in 2027, given the expanded inventory from the HG transaction and the mix of NGLs and dry gas. He also questioned the potential impact of growing dry gas volumes on basis and how that influences the decision to grow into a tightening basis environment.

Answer

Michael Kennedy, CEO and President, emphasized Antero's position as the most capital-efficient developer, best positioned to meet upcoming demand with its FT to LNG exports and local dry gas for data centers/power generation, thus justifying growth through a steady-state program. He stated that 200 million a day of growth is not material compared to Bcf's of demand, so it would not significantly impact the supply and demand picture or basis.

John Abbott asked about Antero's willingness to grow beyond 4.5 Bcf/d in 2027, considering its expanded inventory from the HG transaction and the balance between NGLs and dry gas. He also questioned the potential impact of Antero's dry gas growth on regional basis differentials, given the tightening basis.

Answer

Michael Kennedy, CFO and SVP of Finance, stated that Antero is well-positioned to grow due to its capital-efficient program, firm transportation to LNG exports, and local dry gas access to data centers and natural gas-fired generation. He emphasized that a steady-state program of three rigs and two completion crews is the most capital-efficient approach, leading to growth. Regarding basis, Mr. Kennedy noted that 200 million a day of growth is not material compared to Bcf's of demand, so it would not significantly impact the supply and demand picture or basis differentials.

John Abbott, on for Doug Leggate, asked about the capital return framework, questioning if there's a share price at which Antero would cease buybacks and how they balance repurchases against cash generation in a higher gas price environment. He also inquired about the breakeven economics of their NGL inventory and at what price point they might reduce activity.

Answer

CFO Michael Kennedy explained their approach is countercyclical and opportunistic, aiming to buy shares when they are undervalued and pay down debt when the share price is higher. He emphasized that buying back shares always adds value. Kennedy also addressed NGLs, noting that the breakeven is dynamic with natural gas prices, citing that even with backwardated oil prices, Antero would generate significant free cash flow at the current gas strip due to its product diversity.

John Abbott followed up on AI, asking about implementation costs and the benefits of internal development versus external vendors. He also asked about the factors shaping 2026 activity and how to gain confidence in future oil growth given the Q4 2025 guide.

Answer

President, CEO & Director Daniel Brown stated AI implementation costs are minimal and that internal development builds crucial organizational momentum. EVP & CSO Michael Lou added they also leverage external vendors. On the 2026 outlook, Mr. Brown emphasized the focus is on free cash flow per share growth, not absolute production. He explained that Q4 production represents a trough due to completion timing, with a strong ramp-up expected in Q1 2026.

John Abbott of Wolfe Research, LLC questioned the implementation cost of Chord's AI initiatives and the benefits of internal development versus external vendors. He also asked about the key factors influencing the 2026 activity plan and how to gain confidence in future oil growth, given the Q4 2025 guidance.

Answer

CEO Daniel Brown explained that AI implementation cost is small, leveraging existing data and internal training, which builds momentum better than third-party solutions. CSO Michael Lou added they also work with vendors. Regarding 2026, Brown emphasized the focus is on free cash flow per share growth, not absolute production. He explained the Q4 production trough is due to completion timing, with a strong ramp-up expected in early 2026.

John Abbott inquired about the potential impact of import tariffs on Chord's oil, gas, and NGL realizations. He also asked for the company's latest thinking on its non-operated Marcellus position in light of improving natural gas prices.

Answer

CEO Daniel Brown opined that tariffs would generally benefit domestic producers, likely creating a small incremental pull on domestic barrels and upward price pressure, though the broader economic effects are complex. Regarding the Marcellus asset, Brown described it as a great asset under a capable operator but reiterated that it is "not a core portion of the portfolio" and the company will look to maximize shareholder value from it over time.

John Abbott asked for a comparison of Chord's current 35% base decline rate to its rate in 2022, to better quantify the impact of increased long-lateral development. He also questioned whether Chord's conservative spacing strategy might present an opportunity for future inventory expansion through infill drilling.

Answer

CEO Daniel Brown stated that the 2022 decline rate was likely higher but cautioned that a direct comparison is difficult due to the different asset profile of the newly acquired Enerplus properties. On spacing, Brown and COO Darrin Henke agreed it was a valid point. They confirmed the team is actively re-evaluating spacing and completion intensity, acknowledging they are not yet fully optimized and that even small changes could significantly impact inventory.

John Abbott of Wolfe Research, LLC asked how the company plans to coordinate its operations across three distinct basins to deliver a consistent and level-loaded program. He also had a bookkeeping question about the role of working capital changes in achieving the year-end net debt target.

Answer

President & COO Clay Carrell explained that they are focused on optimizing capital allocation, completion timing, and supply chain management across the basins to improve consistency, noting there is room for further improvement. CFO & Treasurer Marianella Foschi clarified that the Q2 working capital draw was a normal, seasonal event due to tax payments and is expected to partially reverse in the second half of the year, keeping the company on track for its debt target.

John Abbott asked about the expected trajectory of cash taxes over the next three years and when the company might be subject to the Alternative Minimum Tax (AMT). He also inquired about the company's willingness to pursue production growth if commodity prices improve.

Answer

CFO Marianella Foschi stated that cash taxes are guided at $10-$30 million for 2025 and are expected to be similar in 2026. She noted the company does not anticipate hitting the AMT threshold unless oil prices are around $80 per barrel. CEO Chris Doyle responded that while the company would be responsive to a stronger macro environment, any consideration of increasing activity would only come after making significant progress on its balance sheet and deleveraging targets.

John Abbott asked about the minimum activity level required in each basin to maintain operational momentum in a lower price environment. He also questioned if the company might ever return to a variable dividend as a market signal about its stock value.

Answer

CEO M. Doyle stated that a one-rig program in the DJ and a three-rig program in the Permian could serve as a baseload to maintain momentum. Regarding the dividend, he said they are a 'long way away' from that debate, as the current focus is on buybacks to capitalize on what they see as a highly undervalued equity while protecting the balance sheet.

John Abbott of Wolfe Research, LLC inquired about Suncor's capacity for future dividend growth given its improving cost structure and asked about the strategy for potential divestitures, particularly non-operated East Coast assets.

Answer

CFO Kris Smith and President and CEO Rich Kruger reiterated their strategy of delivering consistent, reliable dividend growth, supported by a 'flywheel' effect where share buybacks fund future dividend-per-share increases. Regarding asset sales, Kruger stated the priority is maximizing the performance of all assets first. Decisions on divestitures will be based on whether an asset is worth more to Suncor or another party.

John Abbott sought clarification on the company's breakeven oil price, asking if the cited $53 per barrel figure was a well-head or corporate breakeven. He also inquired about the potential for additional non-core asset sales throughout the year.

Answer

CEO Mikell Pigott clarified that the breakeven figures discussed ($57/bbl today, potentially moving toward $50/bbl) are corporate breakevens. Regarding asset sales, he explained the recent deal was a unique opportunity to monetize acreage they didn't value as inventory. He confirmed the company continuously evaluates its portfolio for similar transactions that can accelerate debt reduction without impacting production guidance.

John Abbott asked about the portion of the 2025 drilling program aimed at testing new zones, the timeline for derisking the 250 upside locations, and the expected oil production exit rate for the year.

Answer

SVP and COO Katie Hill clarified that very little of the 2025 capital is allocated to appraisal, with the focus being on high-confidence development, particularly on the Point asset. She described the derisking of the 250 upside locations as a deliberate, multi-year effort. President and CEO Mikell Pigott added that the 2025 production profile will be 'V-shaped,' with a dip mid-year followed by a ramp-up toward year-end.

John Abbott, on for Douglas Leggate of Wolfe Research, questioned the company's net debt trajectory, its potential need for additional financing, and whether the recently announced capital expenditure reductions are permanent.

Answer

CFO Karen Davis stated that the company's liquidity is comfortable and she does not anticipate needing to access capital markets again. President and CEO Matthew Lucey and SVP Michael A. Bukowski clarified that the capital reductions are part of the ongoing RBI program aimed at permanent cost savings, with a goal of sustainable reductions in how capital is spent, even though the specific 2025 cuts were discretionary projects.

John Abbott of Wolfe Research, on behalf of Doug Leggate, asked about the company's philosophy on dividend growth and sought clarification on the drivers of the 2025 cash tax rate increase.

Answer

CEO Ezra Yacob affirmed that a sustainably growing dividend, funded by expanding margins and a strong balance sheet, is the foundation of their value proposition. CFO Ann Janssen explained that the 2025 cash tax rate will be higher because $212 million in Alternative Minimum Tax (AMT) credits were fully utilized in 2024 and are no longer available.

John Abbott, on for Doug Leggate, inquired about the long-term dividend growth strategy and the company's cash tax outlook beyond 2027.

Answer

CFO Mark Scucchi characterized the dividend as a 'steady, slowly growing modest' component of capital returns, with opportunistic share repurchases remaining the primary tool. He projected that after fully utilizing NOLs over the next two years, the company's effective cash tax rate would likely be in the 'high teens' starting in 2027.

John Abbott inquired about the impact of recent acquisitions on future cash taxes and at what point the capital intensity of the Permian asset might change as they progress through their inventory.

Answer

EVP and CFO Shannon Young guided to a 20-25% effective tax rate with a 90-100% cash basis, an improvement due to the acquired assets. SVP of Operations Blake Sirgo stated he doesn't see a stark inflection point in capital intensity, as the team is constantly improving inventory quality and finding efficiencies in zones beyond the Wolfcamp A.

John Abbott, on for Doug Leggate, asked about production visibility in the Gulf of America beyond 2025 and the strategy for sustainable production. He also requested an update on the current production level of the EOR business.

Answer

Kenneth Dillon, SVP & President, International Oil and Gas Operations, explained the long-term goal for the Gulf of America is to maintain flat production through a combination of primary drilling, exploration, and 'Gulf of America 2.0' EOR projects. Richard Jackson, President, U.S. Onshore Resources and Carbon Management, stated that EOR production levels are similar to past years with slight declines, but the business has delivered excellent cost efficiencies and is positioned for future growth with lower-cost CO2 from carbon capture.

John Abbott of Bank of America Merrill Lynch inquired about the risk assessment for EQT's 2025 maintenance CapEx and its future evolution, as well as the current understanding and incorporation of benefits from added compression into the company's guidance.

Answer

President and CEO Toby Rice explained that maintenance CapEx is based on asset quality, historical performance, and structural efficiency gains from the Equitrans (E-Train) integration. He noted that reserve development capital intensity will continue to decline. CFO Jeremy Knop added that peak spend for compression investments was pulled forward into 2025 ($130M), accelerating value, and that the current modeling of these projects remains conservative despite recent outperformance in production and CapEx.