Gulfport Energy Corporation Q3 FY2025 earnings call

John Reinhart highlighted meaningful progress in inventory additions. Since 2023, the company has been focused on adding high-quality, low breakeven locations. In the third quarter, the Ohio Marcellus' resource viability expanded north, doubling the net drillable Marcellus inventory in Ohio. Appraisal drilling of the first 2 U-development wells in the Utica validated U-development feasibility. The company has invested over $100 million in high-quality, low breakeven locations since mid-2023, increasing gross undeveloped inventory by over 40% since year-end 2022, with total net inventory now around 15 years and breakevens below $2.50 per MMBtu. On the capital front, $30 million was allocated to discretionary appraisal development, including drilling and completing the first 2 U-development wells in the Utica, unlocking ~20 gross locations. $35 million was allocated to discretionary development activity to mitigate 2026 production impacts. Land investment of ~$23.4 million was made on maintenance, leasehold, and land, with ~$15.7 million spent on discretionary acreage acquisitions in the first 9 months of 2025. In the Marcellus, the Yankee pad in the core development area showed attractive performance, with the first Marcellus North development planned for early 2026.

Gulfport Energy's average daily production in the third quarter was 1.12 billion cubic feet equivalent per day, a 11% increase from the second quarter of 2025, on track to achieve full-year production of approximately 1.04 billion cubic feet equivalent per day. Financially, the company reported adjusted EBITDA of approximately $213 million for the quarter and generated adjusted free cash flow of around $103 million. Net cash provided by operating activities before working capital changes was approximately $198 million in the third quarter. The all-in realized price for the third quarter was $3.37 per Mcfe, which was $0.30 above the NYMEX Henry Hub index price.

The company plans to allocate an incremental $125 million towards share repurchases during the fourth quarter of 2025. It is expected to allocate approximately $325 million to common stock repurchases in 2025 while maintaining a leverage ratio at or below 1x. The company plans to announce formal capital and production guidance for 2026 in February.

Potential risks include production impacts from simultaneous operations of an offsetting operator and planned third-party midstream maintenance production downtime in the first quarter of 2026. There are also risks related to operational execution and well development, such as ensuring proper well design planning for U-development wells.

Q: Neal Dingmann asked about well results and capital allocation.

A: John Reinhart responded on operational execution, optimization of completions and drilling, and limited upside on pressure managed results.

Q: Brian Velie asked about adding appraisal U-development wells in 2025.

A: John Reinhart and Michael Hodges discussed the right time due to strong cash flow, healthy balance sheet, and focus on expanding high-quality inventory.

Q: Tim Rezvan asked about production shape and impact of 4Q acceleration.

A: Michael Hodges talked about front-loaded capital program and similar production cadence.

Q: Timothy Rezvan asked about Yankee well outperformance.

A: Matthew Rucker discussed applying lessons from first 2 wells and changing completion design techniques.

Q: David Deckelbaum asked about Marcellus delineation.

A: John Reinhart talked about derisked footprint and future development plans.

Q: Jacob Roberts asked about inventory additions and power agreements.

A: Michael Hodges discussed ongoing discussions and importance of inventory.

Q: Peyton Dorne asked about NGL recoveries.

A: Michael Hodges talked about strong NGL recoveries from Marcellus and wet gas Utica wells.

Q: Noah Hungness asked about Ohio energy initiative and lateral lengths.

A: Michael Hodges discussed favorable momentum and Matthew Rucker talked about current development plan.

Q: Carlos Escalante asked about broader consolidation.

A: Michael Hodges discussed compelling opportunities within existing portfolio.

Q: Nicholas Pope asked about U-development risks and production comparison.

A: Matthew Rucker talked about minimal risk due to well design planning and similar production rates.