Marathon Petroleum (MPN) Risk Analysis
Risk Overview Q2, 2026
Source: the company's latest filing for the period ended Jun 30, 2026, filed Aug 04, 2026
Risk Change Over Time
Risk Highlights Q2, 2026
Risk Word Cloud
Risk Factors Full Breakdown - Total Risks 44
- Regulation - Risk 1Regulatory and other requirements concerning the transportation of crude oil and other commodities by rail may cause increases in transportation costs or limit the amount of crude oil that we can transport by rail.
We rely on a variety of systems to transport crude oil, including rail. Rail transportation is regulated by federal, state and local authorities. New regulations or changes in existing regulations could result in increased compliance expenditures. Regulations that require the reduction of volatile or flammable constituents in crude oil that is transported by rail, change the design or standards for rail cars used to transport crude oil, change the routing or scheduling of trains carrying crude oil, or require any other changes that detrimentally affect the economics of delivering North American crude oil by rail could increase the time required to move crude oil to our refineries, increase the cost of rail transportation and decrease the efficiency of shipments of crude oil by rail. Any of these outcomes could have a material adverse effect on our business and results of operations.
- Regulation - Risk 2If California or other jurisdictions (i) establish a maximum refining margin and impose a financial penalty for profits above such maximum refining margin, (ii) impose restrictions on turnaround and maintenance activities or (iii) require that petroleum refiners maintain a minimum inventory of transportation fuels, our financial results and profitability could be adversely affected.
In June 2023, the provisions of California's Senate Bill No. 2 (such statute, together with any regulations contemplated or issued thereunder, "SB X1-2") became effective, which, among other things, (i) authorized the establishment of a maximum gross gasoline refining margin and the imposition of a financial penalty for profits above a maximum gross gasoline refining margin, (ii) significantly expanded the reporting obligations to the California Energy Commission ("CEC") for all participants in the petroleum industry supply chain in California, (iii) created the Division of Petroleum Market Oversight within the CEC to monitor and analyze the transportation fuels market, and (iv) authorized the CEC to regulate the timing and other aspects of refinery turnaround and maintenance activities in certain instances. The operational data reporting includes our plans for turnaround and maintenance activities at our Los Angeles refinery and Martinez renewable diesel facility and our plans to address potential impacts on feedstock and product inventories in California resulting from such turnaround and maintenance activities. In late 2023, the CEC adopted (i) an order requiring an informational proceeding on a maximum gross gasoline refining margin and penalty under SB X1-2, and (ii) an order initiating rulemaking activity under SB X1-2 that will be focused on refinery maintenance and turnarounds. In August 2025, the CEC adopted resolutions (i) indicating that the CEC will not take further action on a maximum gross gasoline refining margin and penalty for at least five years and (ii) providing refiners with a potential exemption from a maximum gross gasoline refining margin, if a maximum gross gasoline refining margin is implemented prior to the year 2035. In October 2024, California's governor signed Assembly Bill No.1 (such statute, together with any regulations contemplated or issued thereunder, "AB X2-1") into law, authorizing the CEC to require that petroleum refiners maintain a minimum inventory of transportation fuels including the requirement that petroleum refiners plan for resupply during scheduled maintenance. In August 2025, the CEC adopted an order requiring an informational proceeding on minimum inventory requirements and refinery maintenance resupply planning requirements. To the extent that the CEC establishes a maximum gross gasoline refining margin and imposes a financial penalty for profits above such maximum gross gasoline refining margin or requires that petroleum refiners maintain a minimum inventory of transportation fuels, our financial results and profitability could be adversely affected. Our results of operations, financial performance and safety and maintenance efforts could also be adversely impacted to the extent that restrictions on turnaround and maintenance activities are imposed by the CEC. We cannot reasonably predict the impact that full implementation of SB X1-2 or AB X2-1 will have on our California operations nor can we predict the impact from similarly focused legislation or actions in other jurisdictions in which we operate. The recently adopted legislation in California, and the future enactment of similar legislation in any of the other jurisdictions, could adversely impact our business, financial condition, results of operations and cash flows.
- Regulation - Risk 3Increased regulation of hydraulic fracturing and other oil and gas production activities could result in reductions or delays in U.S. production of crude oil and natural gas, which could adversely affect our results of operations and financial condition.
While we do not conduct hydraulic fracturing operations, we do provide gathering, treating, processing and fractionation services with respect to natural gas and NGLs produced by our customers as a result of such operations. A range of federal, state and local laws and regulations currently govern or, in some cases, prohibit hydraulic fracturing in some jurisdictions. Stricter laws, regulations and permitting processes may be enacted in the future. If federal, state and local legislation and regulatory initiatives relating to hydraulic fracturing or other oil and gas production activities are enacted or expanded, such efforts could impede oil and gas production, increase producers' cost of compliance, and result in reduced volumes available for our midstream assets to gather, treat, process and fractionate.
- Regulation - Risk 4Certain of our facilities are located on Native American tribal lands and are subject to various federal and tribal approvals and regulations, which can increase our costs and delay or prevent our efforts to conduct operations.
Various federal agencies within the U.S. Department of the Interior, particularly the Bureau of Indian Affairs, along with each Native American tribe, regulate natural gas and oil operations on Native American tribal lands. In addition, each Native American tribe is a sovereign nation having the right to enforce laws and regulations and to grant approvals independent from federal, state and local statutes and regulations. These tribal laws and regulations include various taxes, fees, requirements to employ Native American tribal members and other conditions that apply to operators and contractors conducting operations on Native American tribal lands. Persons conducting operations on tribal lands are generally subject to the Native American tribal court system. In addition, if our relationships with any of the relevant Native American tribes were to deteriorate, we could face significant risks to our ability to continue operations on Native American tribal lands. One or more of these factors has in the past and may in the future increase our cost of doing business on Native American tribal lands and impact the viability of, or prevent or delay our ability to conduct operations on such lands. For example, we are subject to ongoing litigation regarding trespass claims relating to a portion of the Tesoro High Plains Pipeline in North Dakota.
See a full breakdown of risk according to category and subcategory. The list starts with the category with the most risk. Click on subcategories to read relevant extracts from the most recent report.