Why did MPC swing to a net loss in the first quarter of 2025?

The primary driver was the execution of the second-largest planned maintenance quarter in company history, with refining planned turnaround costs of about $454 million in the quarter (versus $647 million in Q1 2024, so the turnaround burden was actually lower year over year). Beyond turnarounds, the loss reflected weaker market crack spreads, which compressed R&M margin to $13.38 per barrel from $19.35, and higher net interest and other financial costs of $304 million versus $179 million.

How did the Midstream business perform, and what growth is planned?

Midstream adjusted EBITDA increased 8% to $1.72 billion, driven by higher pipeline throughput and growth from equity affiliates. Growth projects include the Traverse natural gas pipeline (FID taken, expected in service in 2027), the BANGL NGL pipeline expansion to 300 thousand bpd (second half of 2026), Blackcomb and Rio Bravo pipelines (second half of 2026), and Harmon Creek III processing expansion (second half of 2026). MPC is also developing two 150 thousand bpd Gulf Coast fractionators (2028–2029) and a 400 thousand bpd LPG export terminal with ONEOK (2028).

Is MPC's balance sheet getting more leveraged, and how is it funding capital returns?

Consolidated debt rose to $30.9 billion from $27.5 billion at year-end 2024, but most of the increase sits at the MPC level ($8.5 billion, up from $6.5 billion), following a $2.0 billion senior notes issuance in February used to refinance maturing notes, including $1.25 billion due May 1, 2025. MPLX debt also rose to $22.4 billion. Liquidity remained solid, with $3.8 billion of cash and $5 billion available under the bank revolver. Q1 capital returns of $1.3 billion exceeded the quarter's adjusted EBITDA contribution to shareholders on a per-period basis, so investors should monitor how buybacks are sustained alongside rising debt.

What is management's outlook for refining margins and second-quarter operations?

Management said seasonal trends are expected to improve refining margins heading into summer demand and that it remains constructive on the long-term refining outlook. For Q2 2025, guidance includes refining operating costs of $5.30 per barrel, planned turnaround costs of $265 million (down from $454 million in Q1), total refinery throughput of 2.945 million bpd, distribution costs of $1.525 billion, and corporate expense of $220 million. Refining capital spending for 2025 includes projects at the Los Angeles, Robinson, and Galveston Bay refineries, including a 90 thousand bpd distillate hydrotreater at Galveston Bay (completion by year-end 2027).

MPC 8-K: Earnings & Results

01—Abstract

Summary

Summary of the 8-K filed May 6, 2025. Cited figures are marked; the original filing is the authoritative source.

Marathon Petroleum (MPC) reported a first-quarter 2025 net loss attributable to MPC of $(74) million, or $(0.24) per diluted share, compared with net income of $937 million^a, or $2.58 per diluted share, in Q1 2024.

The swing was driven mainly by the execution of the company's second-largest planned maintenance quarter in its history, with planned turnaround costs of roughly $465 million^b in the quarter. Adjusted EBITDA fell to $2.0 billion from $3.3 billion a year earlier, as Refining & Marketing segment adjusted EBITDA dropped to $489 million from $1.986 billion on lower market crack spreads. R&M margin per barrel declined to $13.38 from $19.35, and crude capacity utilization rose to 89% from 82%.

The Midstream segment was the bright spot, with adjusted EBITDA up 8% to $1.7 billion^c on higher throughputs and equity affiliate growth. Management is executing a Natural Gas and NGL growth strategy, including MPLX's agreement to acquire the remaining 55% of BANGL, LLC for $715 million, a final investment decision on the Traverse natural gas pipeline, and a Matterhorn Express stake increase to 10% for $151 million. The Renewable Diesel segment improved to $(42) million of adjusted EBITDA from $(90) million, helped by higher utilization at Martinez Renewables.

On the balance sheet, consolidated debt rose to $30.9 billion^d from $27.5 billion at year-end 2024, with MPC-level debt up to $8.5 billion from $6.5 billion, following a $2.0 billion senior notes issuance in February. The company returned about $1.3 billion to shareholders in the quarter, including $1.1 billion of buybacks, and had $6.7 billion remaining under its repurchase authorizations. Investors will likely focus on whether refining margins recover in the seasonal summer period, which management expects, and on the pace of capital returns relative to the higher leverage at the MPC level.

02—Key points

Key Highlights

Q1 2025 net loss attributable to MPC of $(74) million, or $(0.24) per diluted share, versus net income of $937 million ($2.58 per diluted share) in Q1 2024, driven largely by the second-largest planned maintenance quarter in company history.
Adjusted EBITDA of $1.975 billion, down from $3.281 billion in Q1 2024, with Refining & Marketing adjusted EBITDA falling to $489 million from $1.986 billion on weaker crack spreads.
R&M margin of $13.38 per barrel versus $19.35 a year earlier, partly offset by lower refining operating costs of $5.74 per barrel (from $6.06) and crude utilization of 89% (from 82%).
Midstream adjusted EBITDA rose 8% to $1.72 billion, supported by higher throughputs and equity affiliate growth; the segment is advancing its Natural Gas and NGL strategy.
Newly announced midstream deals include MPLX's $715 million acquisition of the remaining 55% of BANGL (expected to close in July), a $151 million increase in its Matterhorn Express stake to 10%, a $237 million acquisition of Whiptail crude gathering assets, and FID on the Traverse pipeline (1.75 bcf/d, expected in service in 2027).
Total consolidated debt increased to $30.9 billion from $27.5 billion, with MPC-level debt rising to $8.5 billion from $6.5 billion after a $2.0 billion senior notes offering; cash stood at $3.8 billion, including $2.5 billion at MPLX.
Shareholder returns of about $1.3 billion in Q1 ($1.1 billion in buybacks), with $6.7 billion remaining under repurchase authorizations; shares outstanding fell to 309 million from 316 million at year-end 2024.

03—Questions

Frequently Asked Questions

Why did MPC swing to a net loss in the first quarter of 2025?
The primary driver was the execution of the second-largest planned maintenance quarter in company history, with refining planned turnaround costs of about $454 million in the quarter (versus $647 million in Q1 2024, so the turnaround burden was actually lower year over year). Beyond turnarounds, the loss reflected weaker market crack spreads, which compressed R&M margin to $13.38 per barrel from $19.35, and higher net interest and other financial costs of $304 million versus $179 million.
How did the Midstream business perform, and what growth is planned?
Midstream adjusted EBITDA increased 8% to $1.72 billion, driven by higher pipeline throughput and growth from equity affiliates. Growth projects include the Traverse natural gas pipeline (FID taken, expected in service in 2027), the BANGL NGL pipeline expansion to 300 thousand bpd (second half of 2026), Blackcomb and Rio Bravo pipelines (second half of 2026), and Harmon Creek III processing expansion (second half of 2026). MPC is also developing two 150 thousand bpd Gulf Coast fractionators (2028–2029) and a 400 thousand bpd LPG export terminal with ONEOK (2028).
Is MPC's balance sheet getting more leveraged, and how is it funding capital returns?
Consolidated debt rose to $30.9 billion from $27.5 billion at year-end 2024, but most of the increase sits at the MPC level ($8.5 billion, up from $6.5 billion), following a $2.0 billion senior notes issuance in February used to refinance maturing notes, including $1.25 billion due May 1, 2025. MPLX debt also rose to $22.4 billion. Liquidity remained solid, with $3.8 billion of cash and $5 billion available under the bank revolver. Q1 capital returns of $1.3 billion exceeded the quarter's adjusted EBITDA contribution to shareholders on a per-period basis, so investors should monitor how buybacks are sustained alongside rising debt.
What is management's outlook for refining margins and second-quarter operations?
Management said seasonal trends are expected to improve refining margins heading into summer demand and that it remains constructive on the long-term refining outlook. For Q2 2025, guidance includes refining operating costs of $5.30 per barrel, planned turnaround costs of $265 million (down from $454 million in Q1), total refinery throughput of 2.945 million bpd, distribution costs of $1.525 billion, and corporate expense of $220 million. Refining capital spending for 2025 includes projects at the Los Angeles, Robinson, and Galveston Bay refineries, including a 90 thousand bpd distillate hydrotreater at Galveston Bay (completion by year-end 2027).

04—Continue

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