Comstock Resources, Inc. (CRK) Q3 2025 Earnings Call Transcript
Access earnings results, analyst expectations, report, slides, earnings call, and transcript.
Overview
The company's earnings call reveals strong developments in Western and Legacy Haynesville, positive asset divestiture impacts, and robust financial liquidity. Analysts' questions highlight optimism in gas demand and industrial contracts. Despite some unclear responses, the overall sentiment is positive, with strategic expansions and cost efficiencies. Given the market cap, the stock is likely to see a positive reaction in the short term, estimated between 2% to 8%.
Key Financial Performance
Natural Gas and Oil Sales $335 million, a 10% increase year-over-year due to higher natural gas prices.
Operating Cash Flow $190 million or $0.65 per diluted share, reflecting improved financial performance driven by higher natural gas prices.
Adjusted EBITDAX $249 million, showing improved financial results compared to the prior year.
Adjusted Net Income $28 million or $0.09 per diluted share, compared to a loss in the same period in 2024, driven by higher natural gas prices.
Production 1.22 Bcfe per day, reflecting operational efficiency and increased drilling activity.
Drilling and Completion Costs in Legacy Haynesville $1,229 per lateral foot, an industry-leading number in the basin, showcasing cost efficiency.
Divestiture Proceeds $15.2 million from Cotton Valley wells and $430 million from Shelby Trough assets, aimed at improving the balance sheet and reducing long-term debt.
Year-to-Date Oil and Gas Sales $1.1 billion, an 18% increase year-over-year due to improved natural gas prices.
Year-to-Date EBITDAX $802 million, reflecting strong operational performance and higher natural gas prices.
Year-to-Date Net Income $122 million or $0.41 per diluted share, compared to a net loss in the same period last year, driven by improved natural gas prices.
Realized Gas Price $2.99 per Mcfe, reflecting a $0.32 basis differential compared to the NYMEX settlement price and a $0.31 differential compared to the reference price.
Operating Cost per Mcfe $0.77, $0.03 lower than the previous quarter, indicating cost efficiency.
EBITDAX Margin 74%, unchanged from the previous quarter, reflecting stable operational efficiency.
Development Spending $267 million in Q3 and $785 million year-to-date, reflecting ongoing investment in drilling and development activities.
Liquidity $239 million at the end of Q3, expected to improve with proceeds from the Shelby Trough divestiture.
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Operating Highlights
Western Haynesville wells: 3 new wells turned online in Q3 2025, with an average lateral length of 8,566 feet and an average initial production rate of 32 million cubic feet per day.
Legacy Haynesville wells: 28 wells turned to sales in 2025, with an average lateral length of 11,919 feet and a per well initial production rate of 25 million cubic feet per day.
Horseshoe lateral concept: Implemented to combine shorter laterals into longer ones, achieving 35% savings in drilling costs.
Natural gas demand: Driven by LNG exports and AI/data center power needs, with LNG exports reaching a record high of 18.7 Bcf.
Natural gas prices: Higher prices in Q3 2025 led to improved financial results, with oil and gas sales growing to $335 million.
Divestitures: Sold Cotton Valley wells for $15.2 million and Shelby Trough assets for $430 million to improve balance sheet and retire long-term debt.
Drilling and completion costs: Legacy Haynesville costs averaged $1,229 per lateral foot, an industry-leading figure.
Production growth: Activity added in Q3 2025 will drive production growth in 2026.
Shift to Western Haynesville: Focused on expanding Western Haynesville operations, divesting legacy assets to allocate resources more efficiently.
Midstream assets: New Marquez gas treating plant started operations in July, doubling gas treating capacity.
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Risk or Challenges
Market Conditions: The company is exposed to fluctuations in natural gas prices, as evidenced by the differential between realized gas prices and market prices. This could impact revenue and profitability.
Regulatory Hurdles: The company operates in regions that may face regulatory changes, particularly in the energy sector, which could affect operations and compliance costs.
Supply Chain Disruptions: Higher completion costs in the Western Haynesville were attributed to increased frac costs and horsepower usage, indicating potential supply chain or operational challenges.
Strategic Execution Risks: The company is heavily investing in the Western Haynesville, which is still in the delineation phase. Any delays or underperformance in this area could impact future growth and financial performance.
Economic Uncertainties: The company’s financial performance is tied to broader economic conditions, including demand for natural gas and LNG exports, which could be affected by global economic slowdowns.
Operational Risks: Drilling difficulties in over-pressured zones and higher-than-normal horsepower usage for fracking in deeper wells could lead to increased costs and operational delays.
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Guidance & Outlook
Natural Gas Demand and Production: The company anticipates a bright future for natural gas, driven by growth in LNG exports and increased power demand from AI and data centers. The Haynesville Shale is expected to play a key role in meeting this demand.
Western Haynesville Development: The company plans to focus on the Western Haynesville area, with 4 rigs currently operating. They expect to drill 19 wells and turn 13 wells to sales in 2025. The Western Haynesville is projected to yield significantly more resource potential per section than the legacy Haynesville area.
Legacy Haynesville Development: In 2025, the company plans to drill 33 wells and turn 35 wells to sales in the legacy Haynesville area. They aim to build production back up in 2026.
Drilling and Completion Costs: The company expects continued drilling efficiencies to drive down drilling and completion costs in both the Western and legacy Haynesville areas in 2025.
Midstream Asset Expansion: The company will continue to build out midstream assets in the Western Haynesville to support growing production. The new Marquez gas treating plant, which started operations in July, has more than doubled gas treating capacity.
Financial Liquidity: The company has strong financial liquidity of over $900 million, which will be further enhanced by proceeds from the Shelby Trough divestiture expected to close in December 2025.
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Shareholder Return Plan
The selected topic was not discussed during the call.
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Key Q&A
Q:Could you speak to the broader capital efficiency gains you'd expect as you enter 2026?
A:The company has achieved significant efficiency gains in the legacy Haynesville, particularly with the horseshoe wells and converting shorter wells to longer wells. In the Western Haynesville, there are still improvements to be made, with ongoing efforts to enhance downhole performance and implement new strategies. The addition of the eighth rig this year, with production expected in early 2026, is expected to drive improved capital efficiency.
Q:How do you see gas-on-gas competition unfolding along the Gulf Coast, and what is your perspective on the supply advantage of delivering gas into Sabine Pass?
A:The company believes owning its midstream infrastructure in the Western Haynesville is a significant advantage, allowing direct sales to end users and creating reliable supply relationships. The location near Texas and the LNG corridor positions the company well to support growth in LNG and power generation demand.
Q:How would you characterize the Shelby Trough sale and its proceeds? Are there other similar opportunities in your portfolio?
A:The Shelby Trough sale was described as a win-win, allowing the company to pay down debt and focus on its Western Haynesville investment. The company continues to evaluate opportunities to adjust its balance sheet and strengthen its position in light of AI, data center, and LNG demand.
Q:Can you share the assumptions and dynamics behind the Western Haynesville location count of 2,500-2,600?
A:The company has taken a conservative approach to well spacing and bench assumptions. While the exact working interest in Western Haynesville units is not fully known, the estimates are considered realistic. The company aims to provide a number that is achievable, acknowledging that some units are not yet fully unitized.
Q:What is stopping you from optimizing the Western Haynesville position around 10,000-foot laterals, and how long would that take?
A:The company is constrained by ownership issues with other operators and geologic structures identified on seismic data. While optimization is possible over time, the current configuration reflects a thorough view of the acreage. Additional leasing and adjustments may occur in the future.
Q:Was the second train at the Marquez gas plant part of the original JV deal with Quantum, and what is the expected capacity utilization?
A:The second train was part of the original plan to handle up to 2 Bcf of gross production over the next 5-7 years. While the company did not forecast utilization rates, it is focused on staying ahead of production needs with long lead-time components and equipment.
Q:Do you think the core of the Western Haynesville basin could be larger, and are there plans to explore areas like Olajuwon?
A:The company is optimistic about the potential expansion of the core, with ongoing exploration and data collection. A two-well pad near Olajuwon has been spud, including a Haynesville well and a Bossier test. The company plans to drill 5-6 wells in the area next year.
Q:What are your plans for Western Haynesville activity in 2026, including holding acreage and development?
A:The company plans to focus 90% of its activity on holding acreage, with four rigs operating to ensure no loss of desired acreage. Development will likely push northeast along the trend of the acreage.
Q:Were changes in the legacy Haynesville and Bossier Shale inventory driven by asset sales?
A:Yes, changes were driven by asset sales and recalibration of inventory, including adjustments for longer laterals and optimization.
Q:What methodologies have been applied to choke management in the Western Haynesville, and what are the future plans?
A:The company has varied its approach but is transitioning to a more conservative drawdown strategy based on core data and rate transient analysis.
Q:What is your perspective on industrial contracts for natural gas, and is Comstock willing to participate?
A:The company sees industrial contracts as a great market, especially along the Gulf Coast. It is interested in establishing direct sales to end users to capture more value and better margins.
Q:Will there be any tax leakage on the Shelby Trough sale proceeds?
A:No, the company has sufficient tax attributes to offset the gain, resulting in no cash tax impact.
Q:How many wells are planned for the northern step-out area near Olajuwon in 2026?
A:The company plans to drill 5-6 wells in the area, including a Bossier test.
Q:What are the economics of in-house gas treatment capacity versus third-party opportunities?
A:In-house treatment has lower operating costs once facilities are built, as capital recovery is the main expense. Third-party providers continue to charge based on demand, making in-house treatment more cost-effective long-term.
Q:What is the activity allocation between Western Haynesville and legacy acreage, and how might it change?
A:The company plans to maintain four rigs in Western Haynesville for strategic development and flex activity in the legacy area based on market conditions.
Q:What is the progression of D&C costs in Western Haynesville, and what are the long-term targets?
A:D&C costs vary by area, with a low end of $2,100 per foot and higher costs for deeper areas. The company expects costs to continue decreasing, albeit at a slower rate, with ongoing efforts to improve efficiency.
Q:Review of Unclear Management Responses
A:Management avoided providing specific forecasts for capacity utilization at the Marquez gas plant in 2027, citing the long-term nature of the project. Additionally, they did not provide precise details on the number of wells planned for the northern step-out area near Olajuwon, offering only a general estimate. There was also a lack of clarity on the exact assumptions behind the Western Haynesville location count, as some units are not yet fully unitized.
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Earnings Word Cloud
The most frequently occurring keywords in this quarter's earning call
Cotton Valley
East Texas
Louisiana proceeds
North Louisiana
Shale
Shelby Trough
Slide drilling
Texas North
Trough asset
Valley well
Western acreage
Western inventory
Western location
Western well
acreage Slide
agreement Shelby
area foot
day legacy
day net
divestiture legacy
extent
foot drilling
horseshoe well
inventory Western
inventory legacy
legacy acreage
legacy area
legacy lateral
legacy location
net interest
production rate
property
recap
rig legacy
sale Western
sale legacy
well depth
CRK Transcript
Comstock Resources, Inc. (CRK) Q1 2026 Earnings Call Transcript
Positive5-6
The earnings report shows strong financial performance with significant revenue and net income growth, driven by higher natural gas prices and production volumes. The company has also managed to reduce capital expenditures while increasing operating cash flow, indicating improved operational efficiency. The positive financial results and cost optimization efforts suggest a favorable outlook for the stock price over the next two weeks, despite the absence of additional insights from the Q&A section.
Comstock Resources, Inc. (CRK) Q4 2025 Earnings Call Transcript
Positive2-16
The company demonstrates strong financial health with a significant net income turnaround and high shareholder returns. The strategic focus on Western Haynesville development, cost efficiencies, and midstream expansion are positive. However, the Q&A reveals concerns about production variability and management's lack of specifics on certain metrics. Despite this, the JV with NextEra and financial liquidity are strong positives, outweighing uncertainties, suggesting a positive stock movement.
Comstock Resources, Inc. (CRK) Q3 2025 Earnings Call Transcript
Positive11-4
The company's earnings call reveals strong developments in Western and Legacy Haynesville, positive asset divestiture impacts, and robust financial liquidity. Analysts' questions highlight optimism in gas demand and industrial contracts. Despite some unclear responses, the overall sentiment is positive, with strategic expansions and cost efficiencies. Given the market cap, the stock is likely to see a positive reaction in the short term, estimated between 2% to 8%.
Comstock Resources, Inc. (CRK) Q2 2025 Earnings Call Transcript
Positive7-31
The earnings call summary and Q&A session present a mixed but overall positive outlook. The company shows strong financial liquidity and efficiency improvements, despite some increased costs. The successful drilling and strategic partnerships, like with NextEra, indicate potential growth. Although there are concerns about drilling cost increases and unclear management responses, the strong liquidity, strategic initiatives, and optimistic guidance on future projects suggest a positive market reaction. Given the market cap, a positive sentiment is expected to result in a stock price increase between 2% to 8%.
CRK Slides
CRK Report
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