Marathon Petroleum Corporation Q3 FY2025 earnings call

Management Statement and Operational Highlights

• Recognized Mike Hennigan's upcoming departure as Executive Chairman, thanked him for contributions.
• In Q3, strong cash generation of $2.4 billion, 95% utilization, 96% capture (sequentially down from 105% in Q2), year-to-date capture at 102% (vs. 95% prior year). Generated $6 billion operating cash flow, returned $3.2 billion to shareholders, announced 10% dividend increase.
• Completed strategic transactions: sold ethanol joint venture interest, MPLX acquired Delaware Basin sour gas treating business and remaining 55% of BANGL NGL pipeline.
• Fourth quarter outlook: Projected crude throughput 2.7 million bpd (90% utilization), Galveston Bay resid hydrocracker to be at full capacity by end of month, turnaround expense ~$420M (mainly West Coast), operating costs $5.80 per barrel, distribution costs ~$1.6B, corporate costs $240M. LAR refinery multiyear infrastructure project completed in Q4, enhancing competitiveness.

Segment Performance

• Refining and Marketing (R&M): Adjusted EBITDA was $6.37 per barrel. Refineries ran at 95% utilization, processing 2.8 million barrels of crude per day. Mid-Con margins strengthened sequentially but were offset by declining margins in U.S. Gulf Coast and West Coast.
• Midstream: Segment adjusted EBITDA increased 5% year-over-year. MPLX is executing growth strategy, contributing to durable cash flow growth for MPC.
• Renewable Diesel: Facilities operated at 86% utilization. Margins were weaker in Q3 due to higher feedstock costs despite higher diesel prices and RIN values.

Guidance

• Projected crude throughput for Q4: 2.7 million barrels per day (90% utilization).
• Galveston Bay resid hydrocracker expected to be at full operating capacity before end of month.
• Turnaround expense in Q4 projected at approximately $420 million, mainly focused in West Coast.
• Operating costs for Q4 projected at $5.80 per barrel, distribution costs ~$1.6 billion, corporate costs $240 million.

Risks

• Market-driven headwinds affecting capture rates, including West Coast clean product margins falling ~40%, jet to diesel differentials compressing, and secondary product headwinds.
• Downtime of Galveston Bay refinery resid hydrocracker impacted capture by almost 2% across the system.
• Uncertainty in regulatory environment affecting renewable diesel segment, with unknowns regarding feedstock policies and RIN market dynamics.
• Potential delays or uncertainties in pipeline projects impacting West Coast supply/demand balance.

Question and Answer

Q: Neil Mehta from Goldman Sachs asked about capture rates in the quarter.

A: Maryann Mannen and Rick Hessling noted West Coast was the leading driver of lower capture (over 50% of capture change), with clean product margins falling ~40% in West Coast, jet premium to diesel narrowing, and secondary product headwinds. Year-to-date capture at 102% vs. 95% prior year.

Q: Manav Gupta from UBS asked about West Coast refinery closures and MPC's position.

A: Rick Hessling and Maryann Mannen discussed MPC's competitive advantage in West Coast with assets like Anacortes, Kenai, and LAR, feedstock advantage, and LAR project coming online in Q4.

Q: Douglas George Blyth Leggate from Wolfe Research asked about CapEx and share buyback.

A: Maryann Mannen and John Quaid stated commitment to share buyback as return of capital, no intention to take on debt for buybacks, and capital for 2026 expected to be below 2025.

Q: Sam Margolin from Wells Fargo asked about jet to diesel dynamic and macro demand.

A: Rick Hessling attributed jet to diesel volatility to inventory and supply issues, corrected itself, and saw positive demand signals in diesel, jet, and gasoline with global demand growth and U.S. refinery indicators.

Q: Paul Cheng from Scotiabank asked about butane inventory impact on capture and California pipeline proposals.

A: John Quaid said butane inventory build impacted capture by 3%-5%, and Rick Hessling discussed potential pipeline impact on Mid-Con and MPC's focus on integrated value chain in West Coast and Pacific Northwest.

Q: Theresa Chen from Barclays asked about Mid-Con and PADD 4 pipeline impact.

A: Rick Hessling discussed minimal impact of PADD 4 project on Salt Lake facility and light heavy outlook influenced by TMX pipeline and geopolitical factors.

Q: Jason Gabelman from TD Cowen asked about West Coast turnarounds and margin capture.

A: Mike Hennigan and John Quaid discussed West Coast turnarounds driving spend, and John Quaid and Rick Hessling talked about distribution costs and regional margin dynamics.

Q: Matthew Blair from TPH asked about renewable diesel market and crude differentials.

A: Maryann Mannen and John Quaid discussed uncertainty in renewable diesel regulatory environment and crude differentials driven by ANS, Bakken, and Syncrude production.

Q: Phillip Jungwirth from BMO asked about Gulf Coast and Mid-Con crude slate.

A: Rick Hessling talked about planned crude slate for sweet crude in Gulf Coast and Mid-Con, leveraging advantaged barrels.

Q: Ryan Todd from BMO asked about midstream projects and CapEx.

A: Maryann Mannen discussed midstream growth opportunities in Permian, including sour gas treating assets, BANGL acquisition, and future projects like fracs and export dock, supporting MPLX distribution and MPC's capital return.