Given the high cash balance, what is the optimal cash level, and how aggressive will MPC be with capital returns? Also, how should the Q2 working capital benefit unwind?

MPC's capital allocation priorities remain unchanged, with a target cash framework of roughly $1 billion. The company will continue to prioritize share buybacks. The $3.8 billion working capital benefit in Q2 was driven by higher payables, crude exchanges, and inventory draws, and management expects to rebuild inventory and repay SPR obligations. A $10 crude price move impacts working capital by $550 million. “Our capital allocation priorities are unchanged. The strength of MPLX distribution should allow us to continue to lead in the return of capital. No change when we think about overall the cash balance that we need, roughly $1 billion.”

With 9 million barrels per day of global capacity offline, how long will it take to replenish global product inventories, and could the mid-cycle margin be structurally higher for the next decade due to persistent unplanned downtime?

Management expects a constructive environment into 2027, citing persistent global supply disruptions from the Persian Gulf and Russian-Ukrainian conflicts. They noted that 1/3 of Russian refinery capacity is offline, and U.S. gasoline and distillate inventories are at low levels. The market is in 'max diesel mode,' which puts pressure on other products like gasoline, and volatility is expected to continue. “We remain constructive well into 2027. As you mentioned, the global supply, it's extremely dynamic. As we've seen, it is difficult for us to have a level of prediction as to when it will resolve.”

Can MPC leverage its Washington refinery to supply California, and will the West Coast market tighten further in Q3 due to competitor downtime?

The Jones Act waiver helps move product from the Gulf Coast to the West Coast, but it's not enough to overcome the lack of Asian imports. MPC is well-positioned with its LAR and Pacific Northwest assets to meet consumer demands, especially as competitors face Q3 turnarounds. They are running twice as many California-based crudes due to advantaged economics. “We are extremely well positioned with LAR and our Pacific Northwest assets to meet consumer demands, especially as you rightfully noted several of our competitors there will have turnarounds here in 3Q.”

MPC

Marathon Petroleum (MPC) Q2 FY26 earnings call: guidance and Q&A

Earnings call· Jun 2026 (Q2 FY26)· Energy· Aug 4, 2026

Source: earnings call transcript

Executive summary

Marathon Petroleum Q2 FY26 — Strong Refining Performance and Midstream Growth

Marathon Petroleum delivered a robust second quarter, showcasing strong operational execution and integrated value chain optimization amidst a constructive refining macro environment. The company leveraged its flexible system to capitalize on market dislocations, driving peer-leading profitability per barrel and advancing its midstream growth strategy. MPC remains committed to disciplined capital allocation, prioritizing shareholder returns while strategically investing in high-return projects and digital capabilities to sustain its competitive advantage.

Highlights

Delivered $8.5 billion of adjusted EBITDA, reflecting strong market conditions and operational execution.
Achieved R&M margin capture of 112% in Q2, with year-to-date capture at 108%, driven by crude optimization and strong product margins.
Gulf Coast refineries ran at 100% utilization, delivering $27 of adjusted EBITDA per barrel.
MPLX increased its 2026 capital growth spending outlook by $500 million to $2.9 billion, supporting 12.5% annual distribution growth in '26 and '27.
Returned $2.8 billion of capital to shareholders, including $2.5 billion in share repurchases, demonstrating disciplined capital allocation.

Concerns

Secondary products remain a market-driven headwind, with prices lagging higher clean product prices.
Third quarter R&M turnaround expenses are projected to be approximately $290 million, mainly focused on conversion units, creating a headwind to capture.
The RVO market has seen volatility, though management believes the market remains short on RIN balances.

Guidance & targets

Category	Target	Timeline	Confidence
MPLX 2026 Capital Growth Spending	$2.9 billion high materiality	FY26	High
MPLX 2026 Adjusted EBITDA Growth	mid-single-digit growth medium materiality	FY26	High
MPLX 2027 Adjusted EBITDA Growth	strong growth medium materiality	FY27	High
MPLX Annual Distribution Growth	12.5% annual growth high materiality	FY26 and FY27 · FY26, FY27	High
Q3 R&M Crude Throughput Volumes	2.8 million barrels per day medium materiality	Q3 · FY26	High
Q3 R&M Turnaround Expenses	$290 million medium materiality	Q3 · FY26	High
Refining Macro Environment	constructive high materiality	through end of year and into 2027 · FY26, FY27	High
Renewable Diesel Environment	constructive medium materiality	remainder of the year · FY26	High
Permian Sour Gas Treating Capacity	over 400 million cubic feet per day medium materiality	by end of year · FY26	High

Segment performance

Segment	Revenue	YoY	QoQ	Margin
Refining & Marketing (R&M) Significant improvement year-over-year, primarily driven by a stronger margin environment. All regions contributed to performance, with Gulf Coast benefiting from crude optimization, higher jet yields, and strong demand. Mid-Con utilization impacted by plant turnaround and maintenance. West Coast supported by strong regional value chain optimization. Adjusted EBITDA per barrel: $24.84Total throughput: nearly 3 million barrels per dayRefinery utilization: 94%Capture: 112%Gulf Coast utilization: 100%Gulf Coast Adjusted EBITDA per barrel: $27Mid-Con utilization: 87%Mid-Con Adjusted EBITDA per barrel: nearly $21West Coast utilization: 93%West Coast Adjusted EBITDA per barrel: over $27	—	—	—	$6.7 billion Adjusted EBITDA
Midstream (MPLX) Increase primarily driven by higher rates and throughputs, including growth from equity affiliates and acquisitions, partially offset by divestiture of noncore assets. MPLX is executing plans to expand value chains and transition projects to cash flow generation. Total processing capacity: 8.1 billion cubic feet per dayDe-ethanization capacity: over 800,000 barrels per dayPermian sour gas treating volumes: exceeded 150 million cubic feet per day	—	+$137 million Adjusted EBITDA	—	—
Renewable Diesel Utilization increased following the Martinez turnaround. Results supported by a more constructive margin environment, feedstock optimization, and improved regulatory credit values. Utilization: 95%	—	+$277 million Adjusted EBITDA	—	—

MPC operating KPIs by quarter

MPC operating KPIs stated on its earnings calls, by fiscal quarter
KPI	Dec 2024 Q4 FY24	Sep 2025 Q3 FY25	Dec 2025 Q4 FY25	Mar 2026 Q1 FY26	This call Jun 2026 Q2 FY26	Change vs prior quarter
Refinery utilization	94% Our refineries ran at 94% utilization, processing nearly 2.8 million barrels of crude per day and refining operating costs were $5.26 per barrel in the fourth quarter. Source: earnings call transcript	95% Utilization in the quarter was 95% as we executed our planned refinery turnarounds safely and on time. Source: earnings call transcript	95% Our refineries ran at 95% utilization with total throughput just over 3 million barrels per day. Source: earnings call transcript	89% Our refineries ran at 89% utilization with nearly 100% capture. Source: earnings call transcript	—	-6 pt
Refinery utilization renewable diesel	—	86% Our renewable diesel facilities operated at 86% utilization, reflecting improved operational reliability. Source: earnings call transcript	94% Results reflect 94% utilization and a onetime benefit from the sale of credits by the Martinez joint venture in the fourth quarter, which were offset by a weaker margin environment compared to the prior year fourth quarter. Source: earnings call transcript	—	—	+8 pt
Refinery utilization Gulf Coast	—	—	98% Regionally, our utilization was 98% in the Gulf Coast, 93% in the Mid-Con, 91% in the West Coast. Source: earnings call transcript	89% Regionally, our utilization was 89% in the Gulf Coast, 88% in the Mid-Con, 92% in the West Coast region. Source: earnings call transcript	100% On the US Gulf Coast, we ran at 100% utilization in the second quarter. Source: earnings call transcript	+11 pt
Refinery utilization Mid-Con	—	—	93% Regionally, our utilization was 98% in the Gulf Coast, 93% in the Mid-Con, 91% in the West Coast. Source: earnings call transcript	88% Regionally, our utilization was 89% in the Gulf Coast, 88% in the Mid-Con, 92% in the West Coast region. Source: earnings call transcript	87% In the Mid-Con, we ran at 87% utilization as we completed plant turnaround and maintenance activity, delivering nearly $21 of adjusted EBITDA per barrel. Source: earnings call transcript	-1 pt
Refinery utilization West Coast	—	—	91% Regionally, our utilization was 98% in the Gulf Coast, 93% in the Mid-Con, 91% in the West Coast. Source: earnings call transcript	92% Regionally, our utilization was 89% in the Gulf Coast, 88% in the Mid-Con, 92% in the West Coast region. Source: earnings call transcript	93% In the West Coast, we ran at 93% utilization and delivered over $27 of adjusted EBITDA per barrel, supported by strong regional value chain optimization. Source: earnings call transcript	+1 pt

Operating figures the company stated on at least two of the calls shown, checked against each call's transcript. Click a figure to read the sentence. A dash means it was not stated that quarter.

Capital programs

MPLX Secretariat I processing plant completed

Placed into service in April.

MPLX Blackcomb natural gas pipeline underway

Start: July 2026

Began commissioning activities in July, expected to achieve full commercial service in the fourth quarter.

MPLX Harmon Creek III processing plant underway

Start: August 2026

Benefit:increased MPLX total processing capacity to 8.1 billion cubic feet per day and de-ethanization capacity to over 800,000 barrels per day

Beginning operations this week, in line with strategy to add processing capacity on a just-in-time basis.

MPLX Gulf Coast fractionation project underway

Accelerated execution, pulling forward capital MPLX previously expected to deploy in early 2027.

Robinson product flexibility investment completed

Benefit:approximately 10,000 barrels per day of incremental jet fuel production

Completed in Q2, supporting growing regional demand. Aligned with targeted return of 25% or above.

El Paso yield improvement investment completed

Benefit:enhances the refinery's ability to produce specialty gasoline for key markets

Completed in Q2. Aligned with targeted return of 25% or above.

Permian sour gas treating capacity expansion underway

Benefit:expand to over 400 million cubic feet per day

Expected to expand by the end of the year at the Titan treating facility.

Risks & headwinds

Secondary products market-driven headwind

prices of secondary products lag higher clean product prices

Mitigation:Ongoing optimization efforts to maximize value across the barrel.

Q3 R&M turnaround expenses Q3 FY26

$290 million

Mitigation:Activity mainly focused on conversion units in Gulf Coast and Mid-Con regions, limiting ability to upgrade certain products and creating a headwind to capture.

Volatility in RVO market short-term

short-lived volatility

Mitigation:Management believes the market is fundamentally short on RIN balances and will remain so; market is efficient and will respond.

Headwinds to Renewable Diesel imports

tariffs, exclusion from production tax credit, registration and compliance requirements

Mitigation:Advocating for realistic SET 3 rule obligations based on U.S. production and existing import headwinds.

Elevated turnaround season and hurricane season near term (Q3 FY26 and beyond)

more volatility

Mitigation:Operational reliability and integrated system optimization to manage disruptions.

What to watch in Q3 FY26

MPLX Blackcomb pipeline commercial service

Q4 FY26

Current commissioning activities began in July

Target full commercial service

Why it matters

Successful completion of Blackcomb will contribute to MPLX's growth strategy and adjusted EBITDA targets, impacting MPC's capital return capacity.

In July, the Blackcomb natural gas pipeline began commissioning activities, the joint venture partners continue to progress the pipeline as planned with Blackcomb expected to achieve full commercial service in the fourth quarter.

Find out whether MPC delivers this. Inve re-checks your case every morning.

Q&A highlights

What were the key factors behind the strong 112% capture rate in Q2, and how sustainable are these drivers for future modeling?

Management attributed the strong capture to strict inventory discipline, crude sourcing benefits (SPR, Venezuelan, Canadian heavy), derivative unwinds, incremental jet production, and high reliability. They emphasized the role of planning, commercial, and operational competencies, including digital tools, in optimizing results and adapting to market volatility.

“Our overall objective with respect to commercial and planning and frankly, our operational execution is to optimize our results, add value in all markets. And there's always variables that we're not able to control. But I think when you look at our results, there's a few things that you should always expect to see that are largely consistent.”

asked by Neil Mehta · answered by Maryann Mannen

3 min read 7 chapters

Detailed narrative

Refining Market Strength and Operational Excellence

Marathon Petroleum reported $8.5 billion in adjusted EBITDA for Q2 FY26, driven by strong market conditions and operational capabilities. The company achieved its lowest level of unplanned downtime this decade, with Gulf Coast refineries running at 100% utilization. R&M margin capture reached 112% in Q2 and 108% year-to-date, reflecting effective crude optimization, feedstock flexibility, and increased clean product yields.

The refining macro environment remains constructive, with over 9 million barrels per day of global capacity downtime and tight U.S. gasoline and distillate inventories.

Strategic Midstream Growth and Capacity Expansion

MPLX, MPC's midstream segment, continued to advance its natural gas and NGL growth strategy. Key projects placed into service include the Secretariat I processing plant in April and the Harmon Creek III processing plant in July, increasing total processing capacity to 8.1 billion cubic feet per day.

The Blackcomb natural gas pipeline began commissioning in July, with full commercial service expected in Q4. MPLX also plans to expand Permian sour gas treating capacity to over 400 million cubic feet per day by year-end, supporting mid-single-digit adjusted EBITDA growth in 2026 and strong growth in 2027.

Disciplined Capital Allocation and Shareholder Returns

MPC returned $2.8 billion of capital to shareholders in Q2, including $2.5 billion in share repurchases, reflecting strong cash generation and adherence to its capital allocation priorities. The company maintains a targeted cash framework of approximately $1 billion, allowing flexibility while supporting capital returns.

Management emphasized that the strength of MPLX's distributions enables MPC to lead in capital returns, with MPLX targeting 12.5% annual distribution growth in 2026 and 2027.

Refining Capture Rate Drivers and Sustainability

The exceptional 112% capture rate in Q2 was attributed to several factors, including strict inventory discipline in a backward-dated market, benefits from crude sourcing and optimization (e.g., SPR exchange barrels, Venezuelan, Canadian heavy, California crudes), favorable impact from derivative unwinds, incremental jet production in a strong margin environment, and high reliability.

Management highlighted the use of advanced planning, commercial, and operational competencies, including digital tools, to rapidly adapt to changing market conditions and optimize across integrated value chains.

Renewable Diesel Performance and Outlook

Following the Martinez turnaround, the Renewable Diesel segment achieved 95% utilization in Q2, contributing to a $277 million year-over-year increase in adjusted EBITDA. This performance was supported by a constructive margin environment, feedstock optimization, and improved regulatory credit values. Management expects a constructive environment through the remainder of the year, noting the market's short RIN balance, but also acknowledged volatility in the RVO market and headwinds to imports.

West Coast Market Dynamics and MPC's Position

The West Coast market remains particularly tight, with the Jones Act waiver allowing Gulf Coast movements but not fully offsetting the lack of Asian imports. MPC is well-positioned with its LAR and Pacific Northwest assets to meet consumer demands, especially with competitors facing turnarounds in Q3.

The company runs twice as many California-based crudes than normal due to advantaged economics from recent refinery closures in the region.

Crude Sourcing and Differential Outlook

MPC maintains high crude optionality, capable of running over 100 different types of crudes across its system, with Garyville being the most flexible. While Canadian heavy crudes often offer better economic advantages than Venezuelan barrels, MPC continues to utilize Venezuelan crudes.

Management anticipates continued pressure on differentials from increasing Venezuelan barrels and potential additional SPR releases (up to 38 million barrels), which would be a tailwind for feedstock costs. The WCS differential is expected to improve from WTI minus $14/barrel to north of $16/barrel by Q4.

Summary of the company's earnings call; see how call summaries are prepared. Not investment advice.