This section should also be read in conjunction with the unaudited consolidated financial statements and accompanying footnotes included under Item 1. Financial Statements and in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2025. DISCLOSURES REGARDING FORWARD-LOOKING STATEMENTS This Quarterly Report on Form 10-Q, particularly Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations and Item 3. Quantitative and Qualitative Disclosures about Market Risk, includes forward-looking statements that are subject to risks, contingencies or uncertainties. You can identify forward-looking statements by words such as “advance,” “anticipate,” “believe,” “commitment,” “continue,” “could,” “design,” “drive,” “endeavor,” “estimate,” “expect,” “focus,” “forecast,” “goal,” “guidance,” “intend,” “may,” “objective,” “opportunity,” “outlook,” “plan,” “policy,” “position,” “potential,” “predict,” “priority,” “progress,” “project,” “prospective,” “pursue,” “seek,” “should,” “strategy,” “strive,” “support,” “target,” “trends,” “will,” “would” or other similar expressions that convey the uncertainty of future events or outcomes. Forward-looking statements include, among other things, statements regarding: •future financial and operating results; •environmental, social and governance (“ESG”) plans and goals, including those related to greenhouse gas emissions and intensity, freshwater withdraw intensity, inclusion and ESG reporting; •future levels of capital, environmental or maintenance expenditures, general and administrative and other expenses; •the success or timing of completion of ongoing or anticipated capital or maintenance projects; •business strategies, growth opportunities and expected investments, including plans to improve commercial performance, lower costs and optimize our asset portfolio; •consumer demand for refined products, natural gas, renewable diesel and other renewable fuels and NGLs; •the timing, amount and form of any future capital return transactions, including dividends and share repurchases by MPC or distributions and unit repurchases by MPLX; and •the anticipated effects of actions of third parties such as competitors, activist investors, federal, foreign, state or local regulatory authorities, or plaintiffs in litigation. Our forward-looking statements are not guarantees of future performance, and you should not rely unduly on them, as they involve risks, uncertainties and assumptions that we cannot predict. Forward-looking and other statements regarding our ESG plans and goals are not an indication that these statements are material to investors or required to be disclosed in our filings with the SEC. In addition, historical, current, and forward-looking ESG-related statements may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve, and assumptions that are subject to change in the future. Material differences between actual results and any future performance suggested in our forward-looking statements could result from a variety of factors, including the following: •general economic, political or regulatory developments, including tariffs, inflation, interest rates, government shutdowns, changes in governmental policies relating to refined petroleum products, crude oil, natural gas, NGLs or renewable diesel and other renewable fuels, or taxation, including changes in tax regulations or guidance promulgated pursuant to the new legislation implemented in the One Big Beautiful Bill Act; •the regional, national and worldwide availability and pricing of refined products, crude oil, natural gas, renewable diesel and other renewable fuels, NGLs and other feedstocks, including increased pricing volatility or supply disruptions due to the U.S.- Iran conflict and market reactions thereto; •disruptions in credit markets or changes to credit ratings; •the adequacy of capital resources and liquidity, including availability, timing and amounts of free cash flow necessary to execute business plans and to effect any share repurchases or to maintain or increase the dividend; •the potential effects of judicial or other proceedings on our business, financial condition, results of operations and cash flows; •the timing and extent of changes in commodity prices and demand for crude oil, refined products, feedstocks or other hydrocarbon-based products or renewable diesel and other renewable fuels; •volatility in or degradation of general economic, market, industry or business conditions, including as a result of pandemics, other infectious disease outbreaks, natural hazards, extreme weather events, regional conflicts such as hostilities in the Middle East and in Ukraine, tariffs, inflation, or rising interest rates; •our ability to comply with federal and state environmental, economic, health and safety, energy and other policies and regulations and enforcement actions initiated thereunder; •adverse market conditions or other risks affecting MPLX; •refining industry overcapacity or under capacity; •foreign imports and exports of crude oil, refined products, natural gas and NGLs; 27 Table of Contents •the establishment or increase of tariffs on goods, including crude oil and other feedstocks imported into the United States, other trade protection measures or restrictions or retaliatory actions from foreign governments; •changes in producer customers’ drilling plans or in volumes of throughput of crude oil, natural gas, NGLs, refined products, other hydrocarbon-based products or renewable diesel and other renewable fuels; •non-payment or non-performance by our customers; •changes in the cost or availability of third-party vessels, pipelines, railcars and other means of transportation for crude oil, natural gas, NGLs, feedstocks, refined products and renewable diesel and other renewable fuels; •the price, availability and acceptance of alternative fuels and alternative-fuel vehicles and laws mandating such fuels or vehicles; •political and economic conditions in nations that consume refined products, natural gas, renewable diesel and other renewable fuels and NGLs, including the United States and Mexico, and in crude oil producing regions, including the Middle East, Russia, Africa, Canada and South America; •actions taken by our competitors, including pricing adjustments, the expansion and retirement of refining capacity and the expansion and retirement of pipeline capacity, processing, fractionation and treating facilities in response to market conditions; •completion of pipeline projects within the United States; •changes in fuel and utility costs for our facilities; •industrial incidents or other unscheduled shutdowns affecting our refineries, machinery, pipelines, processing, fractionation and treating facilities or equipment, means of transportation, or those of our suppliers or customers; •acts of war, terrorism or civil unrest that could impair our ability to produce refined products, receive feedstocks or to gather, process, fractionate or transport crude oil, natural gas, NGLs, refined products or renewable diesel and other renewable fuels; •political pressure and influence of environmental groups and other stakeholders that are adverse to the production, gathering, refining, processing, fractionation, transportation and marketing of crude oil or other feedstocks, refined products, natural gas, NGLs, other hydrocarbon-based products or renewable diesel and other renewable fuels; •labor and material shortages; •the ability to realize expected returns or other benefits on anticipated or ongoing projects or planned or recently completed acquisitions or other transactions, including the recently completed acquisitions of Northwind Delaware Holdings LLC and BANGL, LLC; •the timing and ability to obtain necessary regulatory approvals and permits and to satisfy other conditions necessary to complete planned projects or to consummate planned transactions within the expected timeframe, if at all; •the inability or failure of our joint venture partners to fund their share of operations and capital investments; •the financing and distribution decisions of joint ventures we do not control; •the availability of desirable strategic alternatives to optimize portfolio assets and the ability to obtain regulatory and other approvals with respect thereto; •our ability to successfully implement our sustainable energy strategy and principles and achieve our ESG plans and goals within the expected timeframe, if at all; •the costs, disruption and diversion of management’s attention associated with campaigns commenced by activist investors; •personnel changes; •the imposition of windfall profit taxes, maximum margin penalties, minimum inventory requirements or refinery maintenance and turnaround supply plans on companies operating in the energy industry in California or other jurisdictions; and •compliance costs and uncertainty associated with cap and invest programs or similar arrangements or programs in California or other jurisdictions. For additional risk factors affecting our business, see the risk factors described in our Annual Report on Form 10-K for the year ended December 31, 2025. We undertake no obligation to update any forward-looking statements except to the extent required by applicable law. EXECUTIVE SUMMARY Business and Economic Environment Update Our Refining & Marketing segment results for the second quarter of 2026 versus the second quarter of 2025 reflect higher realized refining margins supported by stable demand and higher product prices driven by global crude oil supply disruptions as a result of increasing regional conflicts, particularly in the Middle East. Longer term, global demand growth is expected to outpace the net impact of refining capacity additions and rationalizations through the end of the decade. We anticipate these fundamentals, as well as the U.S. refining industry’s current structural advantages over the rest of the world, will support a constructive environment for U.S. refiners. 28 Table of Contents Our Midstream segment results for the second quarter of 2026 versus the second quarter of 2025 reflect previously announced acquisition and divestiture activity as we continue to optimize our assets and execute on progressing our strategic initiatives. We believe our Midstream business is well positioned to meet growing global demand for U.S. energy through the advancement of MPLX’s wellhead-to-water strategy and support the development plans of its producer customers. Strategic Updates Strategic Petroleum Reserve In the first and second quarters of 2026, the U.S. Department of Energy (“DOE”) accepted MPC’s bids to exchange crude oil barrels with the Strategic Petroleum Reserve (“SPR”). Under the arrangements, the SPR agreed to deliver approximately 22 million barrels to MPC throughout 2026 and MPC agreed to return approximately 27 million barrels beginning in April of 2027 through July of 2029. See Note 15 to the unaudited consolidated financial statements for further discussion. Additional $5.0 Billion Share Repurchase Authorization On May 5, 2026, we announced that our board of directors approved an additional $5.0 billion share repurchase authorization. The share repurchase authorization has no expiration date. Future repurchases under the authorization will depend on the macro environment, cash available after opportunities for capital investment and growth of the business, and market conditions. As of June 30, 2026, we had $6.13 billion remaining under the share repurchase authorizations. See Note 8 to the unaudited consolidated financial statements for further discussion of our share repurchase authorizations. Results Our chief operating decision maker (“CODM”) evaluates the performance of our segments using segment adjusted EBITDA. Our CODM is our chief executive officer. The CODM uses adjusted EBITDA by segment results and considers forecast-to-actual variances on a periodic basis when making decisions about allocating capital and personnel as part of the annual business plan process and ongoing monitoring of performance. Amounts included in income before income taxes and excluded from segment adjusted EBITDA include: (i) depreciation and amortization; (ii) net interest and other financial costs; (iii) turnaround expenses; and (iv) other adjustments as deemed necessary. These items are either: (i) believed to be non-recurring in nature; (ii) not believed to be allocable or controlled by the segment; or (iii) are not tied to the operational performance of the segment. 29 Table of Contents Select results are reflected in the following table. Three Months Ended June 30, Six Months Ended June 30, (Millions of dollars) 2026 2025 2026 2025 Segment adjusted EBITDA for reportable segments Refining & Marketing $ 6,655 $ 1,890 $ 8,032 $ 2,379 Midstream 1,778 1,641 3,376 3,361 Renewable Diesel 258 (19) 296 (61) Total reportable segments $ 8,691 $ 3,512 $ 11,704 $ 5,679 Reconciliation of segment adjusted EBITDA for reportable segments to income before income taxes Total reportable segments $ 8,691 $ 3,512 $ 11,704 $ 5,679 Corporate (231) (226) (481) (418) Refining & Renewable Diesel planned turnaround costs (276) (275) (807) (740) Renewable Diesel JV planned turnaround costs(a) (1) (2) (30) (10) Depreciation and amortization (838) (789) (1,647) (1,582) Renewable Diesel JV depreciation and amortization(a) (23) (23) (45) (45) Clean fuel production tax credit(b) — — 32 — Net interest and other financial costs (340) (319) (710) (623) Income before income taxes $ 6,982 $ 1,878 $ 8,016 $ 2,261 Net income attributable to MPC per diluted share $ 17.73 $ 3.96 $ 19.30 $ 3.68 (a) Represents MPC’s pro-rata share of expenses from joint ventures included within the Renewable Diesel segment. (b) Recognition of 2025 clean fuel production tax credits as a result of proposed regulatory guidance issued in February of 2026 which clarified the qualification criteria for 45Z credits. Net income attributable to MPC was $5.14 billion, or $17.73 per diluted share, for the second quarter of 2026 compared to $1.22 billion, or $3.96 per diluted share, for the second quarter of 2025 and $5.65 billion, or $19.30 per diluted share, in the first six months of 2026 compared to $1.14 billion, or $3.68 per diluted share, in the first six months of 2025. Refer to the Results of Operations section for a discussion of consolidated financial results and Segment Results for the second quarter of 2026 as compared to the second quarter of 2025 and the first six months of 2026 compared to the first six months of 2025. MPLX We owned approximately 647 million MPLX common units as of June 30, 2026, with a market value of $36.47 billion based on the June 30, 2026 closing price of $56.33 per common unit. On July 28, 2026, MPLX declared a quarterly cash distribution of $1.0765 per common unit, payable on August 14, 2026 to unitholders of record on August 7, 2026. MPC’s portion of this distribution is approximately $697 million. We received limited partner distributions from MPLX of $1.39 billion in the six months ended June 30, 2026 and $1.24 billion in the six months ended June 30, 2025. During the six months ended June 30, 2026, MPLX repurchased approximately 2 million MPLX common units at an average cost per unit of $56.32 and paid $100 million of cash for the repurchased common units. As of June 30, 2026, MPLX had $1.02 billion remaining under the unit repurchase authorizations. See Note 3 to the unaudited consolidated financial statements for additional information on MPLX. 30 Table of Contents OVERVIEW OF SEGMENTS Refining & Marketing Refining & Marketing segment adjusted EBITDA depends largely on our refinery throughputs, Refining & Marketing margin, refining operating costs and distribution costs. Refining & Marketing margin is the difference between the prices of refined products sold and the costs of crude oil and other charge and blendstocks refined, including the costs to transport these inputs to our refineries and the costs of products purchased for resale. The crack spread is a measure of the difference between market prices for refined products and crude oil, commonly used by the industry as a proxy for the refining margin. Crack spreads can fluctuate significantly, particularly when prices of refined products do not move in the same relationship as the cost of crude oil. As a performance benchmark and a comparison with other industry participants, we calculate Gulf Coast, Mid-Continent and West Coast crack spreads that we believe most closely track our operations and slate of products. The following are used for these crack spread calculations: •The Gulf Coast crack spread uses three barrels of MEH crude producing two barrels of USGC CBOB gasoline and one barrel of USGC ULSD; •The Mid-Continent crack spread uses three barrels of WTI crude producing two barrels of Chicago CBOB gasoline and one barrel of Chicago ULSD; and •The West Coast crack spread uses three barrels of ANS crude producing two barrels of LA CARBOB and one barrel of LA CARB Diesel. Our refineries can process a variety of sweet and sour crude oil, which typically can be purchased at a discount to crude oil referenced in our Gulf Coast, Mid-Continent and West Coast crack spreads. The amount of these discounts, which we refer to as the sweet differential and the sour differential, can vary significantly, causing our Refining & Marketing margin to differ from blended crack spreads. In general, larger sweet and sour differentials will enhance our Refining & Marketing margin. Future crude oil differentials will be dependent on a variety of market and economic factors, as well as U.S. energy policy. The following table provides sensitivities showing an estimated change in annual Refining & Marketing segment adjusted EBITDA due to potential changes in market conditions. (Millions of dollars) Blended crack spread sensitivity(a) (per $1.00/barrel change) $ 1,125 Sour differential sensitivity(b) (per $1.00/barrel change) 520 Sweet differential sensitivity(c) (per $1.00/barrel change) 520 Natural gas price sensitivity(d) (per $1.00/MMBtu) 360 (a)Crack spread based on 42 percent MEH, 40 percent WTI and 18 percent ANS with Gulf Coast, Mid-Continent and West Coast product pricing, respectively, and assumes all other differentials and pricing relationships remain unchanged. (b)Sour crude oil basket consists of the following crudes: ANS, Argus Sour Crude Index, Maya and Western Canadian Select. We assume approximately 50 percent of the crude processed at our refineries in 2026 will be sour crude. (c)Sweet crude oil basket consists of the following crudes: Bakken, Brent, MEH, WTI-Cushing and WTI-Midland. We assume approximately 50 percent of the crude processed at our refineries in 2026 will be sweet crude. (d)This is consumption-based exposure for our Refining & Marketing segment and does not include the sales exposure for our Midstream segment. In addition to the market changes indicated by the crack spreads, the sour differential and the sweet differential, our Refining & Marketing margin is impacted by factors such as: •the selling prices realized for refined products; •the types of crude oil and other charge and blendstocks processed; •our refinery yields; •the cost of products purchased for resale; •the impact of commodity derivative instruments used to hedge price risk; •the potential impact of lower of cost or market adjustments to inventories in periods of declining prices; •the potential impact of LIFO adjustments; and •the cost of purchasing RINs in the open market to comply with RFS requirements. Refining & Marketing segment adjusted EBITDA is also affected by changes in refining operating costs in addition to committed distribution costs. Changes in operating costs are primarily driven by the cost of energy used by our refineries, including purchased natural gas, and the level of maintenance costs. Distribution costs primarily include long-term agreements with MPLX, which as discussed below include minimum commitments to MPLX, and will negatively impact segment adjusted EBITDA in periods when throughput or sales are lower or refineries are idled. 31 Table of Contents We have various long-term, fee-based commercial agreements with MPLX. Under these agreements, MPLX, which is reported in our Midstream segment, provides transportation, storage, distribution and marketing services for our Refining & Marketing segment. Certain of these agreements include commitments for minimum quarterly throughput and distribution volumes of crude oil and refined products and minimum storage volumes of crude oil, refined products and other products. Certain other agreements include commitments to pay for 100 percent of available capacity for certain marine transportation and refining logistics assets. Midstream Our Midstream segment gathers, transports, stores and distributes crude oil, refined products, including renewable diesel, and other hydrocarbon-based products, principally for our Refining & Marketing segment. Additionally, the segment markets refined products. The profitability of our pipeline transportation operations primarily depends on tariff rates and the volumes shipped through the pipelines. The profitability of our marine operations primarily depends on the quantity and availability of our vessels and barges. The profitability of our light product terminal operations primarily depends on the throughput volumes at these terminals. The profitability of our fuels distribution services primarily depends on the sales volumes of certain refined products. The profitability of our refining logistics operations depends on the quantity and availability of our refining logistics assets. A majority of the crude oil and refined product shipments on our pipelines and marine vessels and the refined product throughput at our terminals serve our Refining & Marketing segment while our refining logistics assets and fuels distribution services are used solely by our Refining & Marketing segment. As discussed above in the Refining & Marketing section, MPLX, which is reported in our Midstream segment, has various long-term, fee-based commercial agreements related to services provided to our Refining & Marketing segment. Under these agreements, MPLX has received various commitments of minimum throughput, storage and distribution volumes as well as commitments to pay for all available capacity of certain assets. The volume of crude oil that we transport is directly affected by the supply of, and refiner demand for, crude oil in the markets served directly by our crude oil pipelines, terminals and marine operations. Key factors in this supply and demand balance are the production levels of crude oil by producers in various regions or fields, the availability and cost of alternative modes of transportation, the volumes of crude oil processed at refineries and refinery and transportation system maintenance levels. The volume of refined products that we transport, store, distribute and market is directly affected by the production levels of, and user demand for, refined products in the markets served by our refined product pipelines and marine operations. In most of our markets, demand for gasoline and distillate peaks during the summer driving season, which extends from May through September of each year, and declines during the fall and winter months. As with crude oil, other transportation alternatives and system maintenance levels influence refined product movements. Our Midstream segment also gathers, treats, processes and transports natural gas and transports, fractionates, stores and markets NGLs. NGL and natural gas prices are volatile and are impacted by changes in fundamental supply and demand, as well as market uncertainty, availability of NGL transportation and fractionation capacity and a variety of additional factors that are beyond our control. Our Midstream segment profitability is affected by prevailing commodity prices primarily as a result of processing or conditioning at our own or third‑party processing plants, purchasing and selling or gathering and transporting volumes of natural gas at index‑related prices and the cost of third‑party transportation and fractionation services. To the extent that commodity prices influence the level of natural gas drilling by our producer customers, such prices also affect profitability. Renewable Diesel Our Renewable Diesel segment processes renewable feedstocks into renewable diesel, markets and distributes renewable diesel and includes joint ventures that produce renewable diesel and renewable feedstocks. Our Renewable Diesel segment adjusted EBITDA is affected by changes in operating costs, distribution costs, throughput and certain regulatory credits. 32 Table of Contents RESULTS OF OPERATIONS The following discussion includes comments and analysis relating to our results of operations. This discussion should be read in conjunction with Item 1. Financial Statements and is intended to provide investors with a reasonable basis for assessing our historical operations, but should not serve as the only criteria for predicting our future performance. Consolidated Results of Operations Three Months Ended June 30, Six Months Ended June 30, (Millions of dollars) 2026 2025 Variance 2026 2025 Variance Revenues and other income: Sales and other operating revenues $ 51,994 $ 33,799 $ 18,195 $ 86,194 $ 65,316 $ 20,878 Income from equity method investments 256 212 44 432 442 (10) Net gain (loss) on disposal of assets (2) 6 (8) (2) 6 (8) Other income 89 84 5 281 187 94 Total revenues and other income 52,337 34,101 18,236 86,905 65,951 20,954 Costs and expenses: Cost of revenues (excludes items below) 43,064 30,025 13,039 74,325 59,385 14,940 Depreciation and amortization 838 789 49 1,647 1,582 65 Selling, general and administrative expenses 894 867 27 1,761 1,650 111 Other taxes 219 223 (4) 446 450 (4) Total costs and expenses 45,015 31,904 13,111 78,179 63,067 15,112 Income from operations 7,322 2,197 5,125 8,726 2,884 5,842 Net interest and other financial costs 340 319 21 710 623 87 Income before income taxes 6,982 1,878 5,104 8,016 2,261 5,755 Provision for income taxes 1,444 268 1,176 1,627 305 1,322 Net income 5,538 1,610 3,928 6,389 1,956 4,433 Less net income attributable to: Noncontrolling interests 400 394 6 740 814 (74) Net income attributable to MPC $ 5,138 $ 1,216 $ 3,922 $ 5,649 $ 1,142 $ 4,507 Second Quarter 2026 Compared to Second Quarter 2025 Net income attributable to MPC increased $3.92 billion in the second quarter of 2026 compared to the second quarter of 2025 primarily due to the following: Revenues and other income increased $18.24 billion primarily due to: •increased sales and other operating revenues of $18.2 billion mainly due to an increase in Refining & Marketing segment average refined product sales prices of $1.12 per gallon and increased refined product sales volumes of 7 mbpd; and •increased income from equity method investments of $44 million largely due to increased income from our Martinez Renewables JV of $21 million and Midstream equity method investments of $14 million. Costs and expenses increased $13.11 billion primarily due to increased cost of revenues of $13.04 billion mainly due to increased crude costs and finished product purchases. We recorded a combined federal, state and foreign income tax provision of $1.44 billion for the three months ended June 30, 2026, which was lower than the U.S. statutory rate primarily due to permanent tax benefits related to net income attributable to noncontrolling interests and cross-border tax impacts, partially offset by state taxes. We recorded a combined federal, state and foreign income tax provision of $268 million for the three months ended June 30, 2025, which was lower than the U.S. statutory rate primarily due to permanent tax benefits related to net income attributable to noncontrolling interests, partially offset by state taxes. Six Months Ended June 30, 2026 Compared to Six Months Ended June 30, 2025 Net income attributable to MPC increased $4.51 billion in the first six months of 2026 compared to the first six months of 2025 primarily due to the following: 33 Table of Contents Revenues and other income increased $20.95 billion primarily due to: •increased sales and other operating revenues of $20.88 billion mainly due to an increase in Refining & Marketing segment average refined product sales prices of $0.66 per gallon and increased refined product sales volumes of 55 mbpd; and •increased other income of $94 million primarily due to approximately $75 million of clean fuel production tax credits, of which $32 million related to 2025 activity. Costs and expenses increased $15.11 billion primarily due to: •increased cost of revenues of $14.94 billion mainly due to increased crude costs and finished product purchases; and •increased selling, general and administrative expenses of $111 million primarily due to increased employee related costs of $56 million and fair-value remeasurement of outstanding performance-based stock compensation of $45 million. Net interest and other financial costs increased $87 million largely due to increased interest expense, primarily due to higher MPLX borrowings, partially offset by increased interest income and capitalized interest. We recorded a combined federal, state and foreign income tax provision of $1.63 billion for the six months ended June 30, 2026, which was lower than the U.S. statutory rate primarily due to permanent tax benefits related to net income attributable to noncontrolling interests and cross-border tax impacts, partially offset by state taxes. We recorded a combined federal, state and foreign income tax provision of $305 million for the six months ended June 30, 2025, which was lower than the U.S. statutory rate primarily due to permanent tax benefits related to net income attributable to noncontrolling interests, partially offset by state taxes. Net income attributable to noncontrolling interests decreased $74 million mainly due to a decrease in MPLX’s net income in the first six months of 2026. See further discussion in the Midstream Segment Results section. Segment Results We classify our business in the following reportable segments: Refining & Marketing, Midstream and Renewable Diesel. Segment adjusted EBITDA represents adjusted EBITDA attributable to the reportable segments. Amounts included in income before income taxes and excluded from segment adjusted EBITDA include: (i) depreciation and amortization; (ii) net interest and other financial costs; (iii) turnaround expenses; and (iv) other adjustments as deemed necessary. These items are either: (i) believed to be non-recurring in nature; (ii) not believed to be allocable or controlled by the segment; or (iii) not tied to the operational performance of the segment. Our segment adjusted EBITDA for reportable segments was $11.70 billion and $5.68 billion for the six months ended June 30, 2026 and 2025, respectively. 34 Table of Contents Refining & Marketing The following includes key financial and operating data for the second quarter of 2026 compared to the second quarter of 2025 and the six months ended June 30, 2026 compared to the six months ended June 30, 2025. (a)Includes intersegment sales to the Midstream segment and sales destined for export. 35 Table of Contents Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 Refining & Marketing Operating Statistics Net refinery throughput (mbpd) 2,944 3,060 2,898 2,955 Refining & Marketing margin per barrel(a)(b) $ 36.33 $ 17.58 $ 27.24 $ 15.57 Less: Refining operating costs per barrel(c) 5.72 5.34 5.97 5.53 Distribution costs per barrel(d) 5.88 5.52 6.02 5.64 Other income per barrel(e) (0.11) (0.07) (0.06) (0.05) Refining & Marketing segment adjusted EBITDA per barrel $ 24.84 $ 6.79 $ 15.31 $ 4.45 Refining planned turnaround costs per barrel $ 1.03 $ 0.90 $ 1.53 $ 1.32 Depreciation and amortization per barrel 1.53 1.45 1.52 1.52 Per barrel fees paid to MPLX included in distribution costs above 3.90 3.59 3.93 $ 3.72 (a)Sales revenue less cost of refinery inputs and purchased products, divided by net refinery throughput. (b)See “Non-GAAP Financial Measures” section for reconciliation and further information regarding this non-GAAP financial measure. (c)Refining operating costs exclude planned turnaround and depreciation and amortization expense. (d)Distribution costs exclude depreciation and amortization expense. (e)Includes income or loss from equity method investments, net gain or loss on disposal of assets and other income or loss. The following information presents certain benchmark prices in our marketing areas and market indicators that we believe are helpful in understanding the results of our Refining & Marketing segment. The benchmark crack spreads below do not reflect the market cost of RINs necessary to meet EPA renewable volume obligations for attributable products under the Renewable Fuel Standard program. Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 Benchmark Spot Prices (dollars per gallon) Chicago CBOB unleaded regular gasoline $ 3.16 $ 2.01 $ 2.58 $ 2.00 Chicago ULSD 3.69 2.07 3.10 2.10 USGC CBOB unleaded regular gasoline 3.07 1.95 2.58 1.96 USGC ULSD 3.68 2.08 3.21 2.19 LA CARBOB 3.63 2.37 3.11 2.37 LA CARB diesel 3.98 2.21 3.42 2.30 Market Indicators (dollars per barrel) WTI $ 92.70 $ 63.68 $ 82.77 $ 67.52 MEH 95.28 64.65 85.14 68.70 ANS 103.53 68.88 90.99 72.39 Crack Spreads: Mid-Continent WTI 3-2-1 $ 36.38 $ 15.54 $ 23.72 $ 12.50 USGC MEH 3-2-1 28.12 12.83 21.35 11.44 West Coast ANS 3-2-1 39.85 22.38 33.35 20.49 Blended 3-2-1(a) 33.54 15.63 24.46 13.49 Crude Oil Differentials: Sweet $ 0.39 $ (0.76) $ (0.35) $ (0.78) Sour (3.00) (2.24) (3.96) (2.74) (a) Blended 3-2-1 Mid-Continent/USGC/West Coast crack spread is 40/42/18 percent in 2026 and 2025. 36 Table of Contents Second Quarter 2026 Compared to Second Quarter 2025 Refining & Marketing segment revenues increased $17.47 billion primarily due to an increase in average refined product sales prices of $1.12 per gallon and increased refined product sales volumes of 7 mbpd. Net refinery throughput decreased 116 mbpd due to increased planned turnaround activity, primarily in the Mid-Continent region, occurring in the second quarter of 2026 compared to the second quarter of 2025. Refining & Marketing segment adjusted EBITDA increased $4.77 billion mainly due to increased per barrel margins. Refining & Marketing segment adjusted EBITDA was $24.84 per barrel for the second quarter of 2026, versus $6.79 per barrel for the second quarter of 2025. Refining & Marketing margin was $36.33 per barrel for the second quarter of 2026 compared to $17.58 per barrel for the second quarter of 2025, primarily due to higher crack spreads. Refining & Marketing margin is affected by our performance against the market indicators shown earlier, which use spot market values and an estimated mix of crude purchases and product sales. Based on the market indicators and our crude oil throughput, we estimate a net positive impact of approximately $4 billion on Refining & Marketing margin for the second quarter of 2026 compared to the second quarter of 2025. Our reported Refining & Marketing margin differs from market indicators due to the mix of crudes purchased and their costs, the effect of market structure on our crude oil acquisition prices, the effect of RIN prices on the crack spread, and other items like refinery yields, other feedstock variances and fuel margin from sales to direct dealers. These factors had an estimated net positive effect of approximately $800 million on Refining & Marketing segment adjusted EBITDA in the second quarter of 2026 compared to the second quarter of 2025. We purchase RINs to satisfy a portion of our RFS compliance. Our expenses associated with purchased RINs and included in Refining & Marketing margin were $683 million and $314 million in the second quarter of 2026 and 2025, respectively. The increase in the second quarter of 2026 was mainly due to higher RIN costs and blending requirements, partially offset by lower RIN sales and obligated volume in addition to increased RINs generated. For the three months ended June 30, 2026, refining operating costs, excluding depreciation and amortization, increased $45 million, or $0.38 per barrel, largely due to increased major maintenance and engineered projects conducted during turnaround activity, partially offset by lower energy costs. Distribution costs, excluding depreciation and amortization, increased $38 million, or $0.36 per barrel, and include fees paid to MPLX. The change in the second quarter of 2026 primarily reflects rate increases, partially offset by a decrease in third party marine costs. Refining planned turnaround costs increased $0.13 per barrel, or $25 million, due to the scope and timing of turnaround activity. Six Months Ended June 30, 2026 Compared to Six Months Ended June 30, 2025 Refining & Marketing segment revenues increased $20.31 billion primarily due to an increase in average refined product sales prices of $0.66 per gallon and increased refined product sales volumes of 55 mbpd. Net refinery throughput decreased 57 mbpd due to increased planned turnaround activity, primarily in the Mid-Continent region, occurring in the first six months of 2026 compared to the first six months of 2025. Refining & Marketing segment adjusted EBITDA increased $5.65 billion mainly due to increased per barrel margins. Refining & Marketing segment adjusted EBITDA was $15.31 per barrel for the first six months of 2026, versus $4.45 per barrel for the first six months of 2025. Refining & Marketing margin was $27.24 per barrel for the first six months of 2026 compared to $15.57 per barrel for the first six months of 2025, primarily due to higher crack spreads. Refining & Marketing margin is affected by our performance against the market indicators shown earlier, which use spot market values and an estimated mix of crude purchases and product sales. Based on the market indicators and our crude oil throughput, we estimate a net positive impact of approximately $5.5 billion on Refining & Marketing margin for the first six months of 2026 compared to the first six months of 2025. Our reported Refining & Marketing margin differs from market indicators due to the mix of crudes purchased and their costs, the effect of market structure on our crude oil acquisition prices, the effect of RIN prices on the crack spread, and other items like refinery yields, other feedstock variances and fuel margin from sales to direct dealers. These factors had an estimated net positive effect of approximately $400 million on Refining & Marketing segment income in the first six months of 2026 compared to the first six months of 2025. We purchase RINs to satisfy a portion of our RFS compliance. Our expenses associated with purchased RINs included in Refining & Marketing margin were $1.28 billion and $668 million in the first six months of 2026 and 2025, respectively. The increase in the first six months of 2026 was mainly due to higher RIN costs and blending requirements, partially offset by lower obligated volume and RIN sales. 37 Table of Contents For the six months ended June 30, 2026, refining operating costs, excluding depreciation and amortization, increased $172 million, or $0.44 per barrel, largely due to increased major maintenance and engineered projects conducted during turnaround activity, partially offset by lower energy costs. Distribution costs, excluding depreciation and amortization, increased $141 million for the first six months of 2026, or $0.38 per barrel, and include fees paid to MPLX. The increase primarily reflects rate increases and increased third party marine costs. Refining planned turnaround costs increased $0.21 per barrel, or $101 million, due to the scope and timing of turnaround activity. Supplemental Refining & Marketing Statistics Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 Refining & Marketing Operating Statistics Crude oil capacity utilization percent(a) 94 97 91 93 Refinery throughput (mbpd): Crude oil refined 2,798 2,883 2,732 2,754 Other charge and blendstocks 146 177 166 201 Net refinery throughput 2,944 3,060 2,898 2,955 Sour crude oil throughput percent 48 45 48 45 Sweet crude oil throughput percent 52 55 52 55 Refined product yields (mbpd): Gasoline 1,439 1,526 1,426 1,506 Distillates 1,131 1,117 1,077 1,073 Propane 71 70 67 69 NGLs and petrochemicals 237 242 210 202 Heavy fuel oil 29 61 77 67 Asphalt 81 81 78 77 Total 2,988 3,097 2,935 2,994 Refined product export sales volumes (mbpd)(b) 436 399 399 393 (a)Based on calendar-day capacity, which is an annual average that includes down time for planned maintenance and other normal operating activities. (b)Represents fully loaded refined product export cargoes for each time period. These sales volumes are included in the total sales volume amounts. 38 Table of Contents Midstream The following includes key financial and operating data for the second quarter of 2026 compared to the second quarter of 2025 and the six months ended June 30, 2026 compared to the six months ended June 30, 2025. (a)On owned common-carrier pipelines, excluding equity method investments. (b)Includes operating data for entities that have been consolidated into the MPLX financial statements as well as operating data for partnership-operated equity method investments. 39 Table of Contents Three Months Ended June 30, Six Months Ended June 30, Benchmark Prices 2026 2025 2026 2025 Natural Gas NYMEX HH (per MMBtu) $ 2.94 $ 3.51 $ 3.21 $ 3.69 C2 + NGL Pricing (per gallon)(a) $ 0.90 $ 0.80 $ 0.83 $ 0.87 (a)C2 + NGL pricing based on Mont Belvieu prices assuming an NGL barrel of approximately 10 percent ethane, 60 percent propane, five percent Iso-Butane, 15 percent normal butane and 10 percent natural gasoline. Second Quarter 2026 Compared to Second Quarter 2025 In the second quarter of 2026, Midstream segment adjusted EBITDA increased $137 million mainly due to increased sales and operating revenues of $295 million. These increases were primarily driven by increased rates and throughputs, including growth from equity affiliates and acquisitions, partially offset by the divestiture of non-core gathering and processing assets. Six Months Ended June 30, 2026 Compared to Six Months Ended June 30, 2025 Midstream segment adjusted EBITDA increased $15 million in the first six months of 2026 primarily due to increased sales and operating revenues of $209 million. These increases were primarily driven by increased rates and throughputs, including growth from equity affiliates and acquisitions, partially offset by the divestiture of non-core gathering and processing assets and a $37 million non-recurring benefit associated with a customer agreement in the first quarter of 2025. Midstream segment adjusted EBITDA was also impacted by increased derivative losses of $53 million. 40 Table of Contents Renewable Diesel The following includes key financial and operating data for the second quarter of 2026 compared to the second quarter of 2025 and the six months ended June 30, 2026 compared to the six months ended June 30, 2025. (a) Includes intersegment sales to the Refining & Marketing segment. (b) Includes Dickinson facility production and purchased product from our Martinez Renewables JV. Second Quarter 2026 Compared to Second Quarter 2025 Renewable Diesel segment revenues increased $620 million, primarily due to higher sales prices and increased renewable diesel sales volume of 91 thousand gallons per day. Renewable Diesel segment adjusted EBITDA increased $277 million, primarily due to an increase in Renewable Diesel margin from $321 million for the second quarter of 2026 compared to $49 million for the second quarter of 2025, driven by improved regulatory credit values. Six Months Ended June 30, 2026 Compared to Six Months Ended June 30, 2025 Renewable Diesel segment revenues increased $573 million, mainly due to higher sales prices partially offset by decreased renewable diesel sales volume of 44 thousand gallons per day largely due to planned turnaround activity at our Martinez Renewables JV in the first quarter of 2026. Renewable Diesel segment adjusted EBITDA increased $357 million primarily due to an increase in Renewable Diesel margin from $454 million in the first six months of 2026 compared to $75 million in the first six months of 2025, driven by improved regulatory credit values. This was partially offset by decreased utilization due to planned downtime at our Martinez Renewables JV. See “Non-GAAP Financial Measures” section for a reconciliation of Renewable Diesel margin. 41 Table of Contents Corporate (millions of dollars) Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 Corporate(a) $ (256) $ (243) $ (530) $ (453) (a)Corporate costs consist primarily of MPC’s corporate administrative expenses and costs related to certain non-operating assets, except for corporate overhead expenses attributable to MPLX, which are included in the Midstream segment. Corporate costs include depreciation and amortization of $25 million and $17 million for the second quarter of 2026 and 2025, respectively, and $49 million and $35 million for the six months ended June 30, 2026 and 2025, respectively. Six Months Ended June 30, 2026 Compared to Six Months Ended June 30, 2025 Corporate expenses increased $77 million in the first six months of 2026 primarily due to the fair-value remeasurement of outstanding performance-based stock compensation of $25 million driven by recent stock performance, environmental remediation expense related to historical operations at the Martinez refinery of $23 million and increased employee related costs of $18 million. Items not Allocated to Segments (millions of dollars) Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 Items not allocated to segments: Clean fuel production tax credit $ — $ — $ 32 $ — Six Months Ended June 30, 2026 Compared to Six Months Ended June 30, 2025 Items not allocated to segments in the first six months of 2026 are the recognition of 2025 clean fuel production tax credits as a result of proposed regulatory guidance issued in February 2026, which clarified the qualification criteria for 45Z credits. 42 Table of Contents Non-GAAP Financial Measures Management uses financial measures to evaluate our operating performance that are calculated and presented on the basis of methodologies other than in accordance with GAAP. The non-GAAP financial measures we use are as follows: Refining & Marketing Margin Refining & Marketing margin is defined as sales revenue less cost of refinery inputs and purchased products, which includes impacts from derivative activity. We use and believe our investors use this non-GAAP financial measure to evaluate our Refining & Marketing segment’s operating and financial performance as it is the most comparable measure to the industry’s market reference product margins. This measure should not be considered a substitute for, or superior to, Refining & Marketing gross margin or other measures of financial performance prepared in accordance with GAAP, and our calculations thereof may not be comparable to similarly titled measures reported by other companies. Reconciliation of Refining & Marketing segment adjusted EBITDA to Refining & Marketing gross margin and Refining & Marketing margin Three Months Ended June 30, Six Months Ended June 30, (Millions of dollars) 2026 2025 2026 2025 Refining & Marketing segment adjusted EBITDA $ 6,655 $ 1,890 $ 8,032 $ 2,379 Plus (Less): Depreciation and amortization (410) (405) (797) (811) Refining planned turnaround costs (275) (250) (805) (704) Selling, general and administrative expenses 686 667 1,336 1,291 Income from equity method investments (12) (3) (10) (8) Other income (29) (51) (130) (119) Refining & Marketing gross margin 6,615 1,848 7,626 2,028 Plus (Less): Operating expenses (excluding depreciation and amortization) 2,939 2,803 6,187 5,787 Depreciation and amortization 410 405 797 811 Gross margin excluded from and other income included in Refining & Marketing margin(a) (173) (98) (217) (168) Other taxes included in Refining & Marketing margin (56) (63) (108) (133) Refining & Marketing margin $ 9,735 $ 4,895 $ 14,285 $ 8,325 (a)Reflects the gross margin, excluding depreciation and amortization, of other related operations included in the Refining & Marketing segment and processing of credit card transactions on behalf of certain of our marketing customers, net of other income. 43 Table of Contents Renewable Diesel Margin Renewable Diesel margin is defined as sales revenue plus value attributable to qualifying regulatory credits earned during the period less cost of renewable inputs and costs for purchased product, including from our Martinez Renewables JV. We use, and believe our investors use, this non-GAAP financial measure to evaluate our Renewable Diesel segment’s operating and financial performance. This measure should not be considered a substitute for, or superior to, Renewable Diesel gross margin or other measures of financial performance prepared in accordance with GAAP, and our calculation thereof may not be comparable to similarly titled measures reported by other companies. Reconciliation of Renewable Diesel segment adjusted EBITDA to Renewable Diesel gross margin and Renewable Diesel margin Three Months Ended June 30, Six Months Ended June 30, (Millions of dollars) 2026 2025 2026 2025 Renewable Diesel segment adjusted EBITDA $ 258 $ (19) $ 296 $ (61) Plus (Less): Depreciation and amortization (16) (18) (32) (36) Renewable Diesel JV depreciation and amortization(a) (23) (23) (45) (45) Renewable Diesel planned turnaround costs (1) (25) (2) (36) Renewable Diesel JV planned turnaround costs(a) (1) (2) (30) (10) Selling, general and administrative expenses 8 9 16 18 Income from equity method investments (39) (18) (10) (34) Other income (26) (8) (54) (11) Renewable Diesel gross margin 160 (104) 139 (215) Plus (Less): Operating expenses (excluding depreciation and amortization) 123 114 240 212 Depreciation and amortization 16 18 32 36 Martinez Renewables JV depreciation and amortization 22 21 43 42 Renewable Diesel margin $ 321 $ 49 $ 454 $ 75 (a) Represents MPC’s pro-rata share of expenses from joint ventures included within the Renewable Diesel segment. LIQUIDITY AND CAPITAL RESOURCES Cash Flows Our consolidated cash and cash equivalents balance was approximately $7.77 billion at June 30, 2026 compared to $3.67 billion at December 31, 2025. Net cash provided by (used in) operating activities, investing activities and financing activities are presented in the following table. Six Months Ended June 30, (Millions of dollars) 2026 2025 Net cash provided by (used in): Operating activities $ 11,448 $ 2,575 Investing activities (2,441) (1,897) Financing activities (4,912) (2,215) Total increase (decrease) in cash $ 4,095 $ (1,537) Operating Activities Net cash provided by operating activities increased $8.87 billion in the first six months of 2026 compared to the first six months of 2025. The change in net cash provided by operating activities was primarily due to an increase in operating results and a favorable change in working capital of $4.23 billion, when comparing the change in working capital in both periods. 44 Table of Contents For the first six months of 2026, changes in working capital, excluding changes in short-term debt, were a net $3.19 billion source of cash mainly due to the effects of changes in energy commodity prices and volumes, including derivatives. Accounts payable increased primarily due to increases in crude oil prices and volumes. Current receivables increased primarily due to increases in crude oil prices and volumes in addition to an increase in refined product prices. Inventories decreased largely due to decreases in crude oil and material and supplies inventory volumes, partially offset by an increase in refined product inventory volumes. For the first six months of 2025, changes in working capital, excluding changes in short-term debt, were a net $1.04 billion use of cash mainly due to the effects of changes in energy commodity prices and volumes at the end of the period. Accounts payable decreased primarily due to decreases in crude oil prices, partially offset by increases in crude oil volumes. Inventories increased largely due to increases in crude oil and refined product inventory volumes. Current receivables decreased primarily due to decreases in crude oil prices, partially offset by increases in crude oil volumes and refined product prices. Investing Activities Investing activities were a net $2.44 billion use of cash in the first six months of 2026 compared to a net $1.90 billion use of cash in the first six months of 2025. •Additions to property, plant and equipment increased $741 million. See the Capital Requirements section for additional information on our capital expenditures and investments. •Cash used for acquisitions of $237 million in the first six months of 2025 was due to an acquisition in our Midstream segment. •Cash used in net investments was $507 million for the first six months of 2026 compared to $428 million for the first six months of 2025. In the first six months of 2026, investments primarily included contributions to MPLX and Renewable Diesel equity method investments. The first six months of 2025 primarily included contributions to MPLX equity method investments. The Consolidated Statements of Cash Flows exclude changes to the Consolidated Balance Sheets that did not affect cash. A reconciliation of additions to property, plant and equipment per the Consolidated Statements of Cash Flows to reported total capital expenditures and investments follows. Six Months Ended June 30, (Millions of dollars) 2026 2025 Additions to property, plant and equipment per the Consolidated Statements of Cash Flows $ 2,099 $ 1,358 Increase (decrease) in capital accruals 94 (5) Total capital expenditures 2,193 1,353 Investments in equity method investees(a) 445 488 Total capital expenditures and investments $ 2,638 $ 1,841 (a)Excludes $62 million of funding to the Martinez Renewables JV due to turnaround costs in the first quarter of 2026 expected to be recovered through subsequent distributions from the JV during 2026. Financing Activities Financing activities were a net $4.91 billion use of cash in the first six months of 2026 compared to a net $2.22 billion use of cash in the first six months of 2025. •Long-term debt borrowings and repayments were a net $106 million use of cash in the first six months of 2026 compared to a net $919 million source of cash in the first six months of 2025. During the first six months of 2026, MPLX issued $1.5 billion aggregate principal amount of senior notes and repaid $1.5 billion aggregate principal amount of senior notes that were due in March 2026. During the first six months of 2025, MPC issued $2.0 billion aggregate principal amount of senior notes and repaid $1.25 billion aggregate principal amount of senior notes. During the first six months of 2025, MPLX issued $2.0 billion aggregate principal amount of senior notes and repaid $1.70 billion aggregate principal amount of senior notes. •During the first six months of 2026, we borrowed and repaid $3.86 billion under our commercial paper program. During the first six months of 2025, we had net borrowings of $210 million under our commercial paper program. •Cash used in common stock repurchases, including fees and expenses, totaled $3.28 billion in the first six months of 2026 compared to $1.84 billion in the first six months of 2025. See the Capital Requirements section for further discussion of our stock repurchases. •Cash used in dividend payments increased $21 million for the first six months of 2026 compared to the first six months of 2025 due to an increase in per share dividends, partially offset by a reduction of shares outstanding resulting from share repurchases. •Cash used in distributions to noncontrolling interests increased $75 million for the first six months of 2026 compared to the first six months of 2025 primarily due to an increase in MPLX’s distribution per common unit. 45 Table of Contents •Cash used in repurchases of noncontrolling interests was $100 million in the first six months of 2026 and $200 million in the first six months of 2025 related to the repurchase of MPLX common units. See Note 3 to the unaudited consolidated financial statements for further discussion of MPLX. Derivative Instruments See Item 3. Quantitative and Qualitative Disclosures about Market Risk for a discussion of derivative instruments and associated market risk. Capital Resources MPC, Excluding MPLX We control MPLX through our ownership of the general partner; however, the creditors of MPLX do not have recourse to MPC’s general credit through guarantees or other financial arrangements, except as noted. MPC has effectively guaranteed certain indebtedness of LOOP and LOCAP, in which MPLX holds an interest. Therefore, in the following table, we present the liquidity of MPC, excluding MPLX. MPLX liquidity is discussed in the following section. Our liquidity, excluding MPLX, totaled $11.7 billion at June 30, 2026 consisting of: June 30, 2026 (Millions of dollars) Total Capacity Outstanding Borrowings Outstanding Letters of Credit Available Capacity Bank revolving credit facility $ 5,000 $ — $ 1 $ 4,999 Trade receivables facility(a) 100 — 100 — Total $ 5,100 $ — $ 101 $ 4,999 Cash and cash equivalents and short-term investments(b) 6,737 Total liquidity $ 11,736 (a)The committed borrowing and letter of credit issuance capacity under the trade receivables securitization facility is $100 million. In addition, the facility allows for the issuance of letters of credit in excess of the committed capacity at the discretion of the issuing banks. As of June 30, 2026, letters of credit in the total amount of $1.626 billion were issued and outstanding under the facility to secure contracts awarded by the U.S. Department of Energy to purchase crude oil from the SPR. (b) Excludes $1.03 billion of MPLX cash and cash equivalents. We have a commercial paper program that allows us to have a maximum of $2.0 billion in commercial paper outstanding. We do not intend to have outstanding commercial paper borrowings in excess of available capacity under our bank revolving credit facility. At June 30, 2026, we had no borrowings outstanding under the commercial paper program. Because of the alternatives available to us, including internally generated cash flow, availability under our credit facilities, access to capital markets and a commercial paper program, we believe that our short-term and long-term liquidity is adequate to fund not only our current operations, but also our near-term (less than twelve months) and long-term funding requirements, including capital spending programs, the repurchase of shares of our common stock, dividend payments, defined benefit plan contributions, repayment of debt maturities and other amounts that may ultimately be paid in connection with contingencies. On April 7, 2026, MPC entered into a new revolving credit facility to replace its previously existing revolving credit facility, which was scheduled to expire July 2027. The new facility is for a five-year term which will expire April 2031. MPC’s total capacity under the revolving credit facility agreement remains at $5.0 billion, and includes sub-facilities for swing-line loans of up to $300 million and letters of credit of up to $2.0 billion. MPC’s bank revolving credit facility and trade receivables facility contain representations and warranties, affirmative and negative covenants and restrictions, including financial covenants, and events of default that we consider usual and customary for agreements of a similar type and nature. As of June 30, 2026, we were in compliance with such covenants and restrictions. Our intention is to maintain an investment-grade credit profile. As of June 30, 2026, the credit ratings on our senior unsecured debt are as follows. Company Rating Agency Rating MPC Moody’s Baa2 (stable outlook) Standard & Poor’s BBB (stable outlook) Fitch BBB (stable outlook) 46 Table of Contents The ratings reflect the respective views of the rating agencies and should not be interpreted as a recommendation to buy, sell or hold our securities. Although it is our intention to maintain a credit profile that supports an investment grade rating, there is no assurance that these ratings will continue for any given period of time. The ratings may be revised or withdrawn entirely by the rating agencies if, in their respective judgments, circumstances so warrant. A rating from one rating agency should be evaluated independently of ratings from other rating agencies. The agreements governing MPC’s debt obligations do not contain credit rating triggers that would result in the acceleration of interest, principal or other payments in the event that our credit ratings are downgraded. However, any downgrades of our senior unsecured debt could increase the applicable interest rates, yields and other fees payable under such agreements and may limit our flexibility to obtain financing in the future, including to refinance existing indebtedness. In addition, a downgrade of our senior unsecured debt rating to below investment-grade levels could, under certain circumstances, impact our ability to purchase crude oil on an unsecured basis and could result in us having to post letters of credit or other security under existing transportation services or other agreements. See Note 16 to the unaudited consolidated financial statements for further discussion of our debt. MPLX MPLX’s liquidity totaled $5.0 billion at June 30, 2026 consisting of: June 30, 2026 (Millions of dollars) Total Capacity Outstanding Borrowings Outstanding Letters of Credit Available Capacity MPLX LP - bank revolving credit facility $ 2,500 $ — $ — $ 2,500 MPC intercompany loan agreement 1,500 — — 1,500 Total $ 4,000 $ — $ — $ 4,000 Cash and cash equivalents 1,031 Total liquidity $ 5,031 On February 12, 2026, MPLX issued $1.0 billion aggregate principal amount of 5.300 percent senior notes due 2036 (the “2036 Senior Notes”) and $500 million aggregate principal amount of 6.100 percent senior notes due 2056 (the “2056 Senior Notes”) in an underwritten public offering, The 2036 Senior Notes were offered at a price to the public of 99.678 percent of par, with interest payable semi-annually in arrears, commencing on October 1, 2026. The 2056 Senior Notes were offered at a price to the public of 98.453 percent of par, with interest payable semi-annually in arrears, commencing on October 1, 2026. In March 2026, MPLX repaid all of MPLX’s outstanding $1.5 billion aggregate principal amount of 1.750 percent senior notes due March 2026 at maturity. On April 7, 2026, MPLX entered into a new revolving credit facility to replace its previously existing revolving credit facility, which was scheduled to expire July 2027. The new facility is for a five-year team which will expire April 2031. MPLX’s total capacity under the new revolving credit facility was increased from $2.0 billion to $2.5 billion, and includes sub-facilities for swing-line loans of up to $150 million and letters of credit of up to $150 million. MPLX’s bank revolving credit facility contains certain representations and warranties, covenants and restrictions, including financial covenants, and events of default that we consider to be usual and customary for an agreement of this type. As of June 30, 2026, MPLX was in compliance with such covenants. Our intention is to maintain an investment-grade credit profile for MPLX. As of June 30, 2026, the credit ratings on MPLX’s senior unsecured debt are as follows. Company Rating Agency Rating MPLX Moody’s Baa2 (stable outlook) Standard & Poor’s BBB (stable outlook) Fitch BBB (stable outlook) The ratings reflect the respective views of the rating agencies and should not be interpreted as a recommendation to buy, sell or hold MPLX securities. Although it is our intention to maintain a credit profile that supports an investment grade rating for MPLX, there is no assurance that these ratings will continue for any given period of time. The ratings may be revised or withdrawn entirely by the rating agencies if, in their respective judgments, circumstances so warrant. A rating from one rating agency should be evaluated independently of ratings from other rating agencies. The agreements governing MPLX’s debt obligations do not contain credit rating triggers that would result in the acceleration of interest, principal or other payments in the event that MPLX credit ratings are downgraded. However, any downgrades of MPLX 47 Table of Contents senior unsecured debt to below investment-grade ratings could increase the applicable interest rates, yields and other fees payable under such agreements. In addition, a downgrade of MPLX senior unsecured debt ratings to below investment-grade levels may limit MPLX’s ability to obtain future financing, including to refinance existing indebtedness. See Note 16 to the unaudited consolidated financial statements for further discussion of MPLX’s debt. Capital Requirements Capital Expenditures and Investments Capital expenditures and investments in affiliates during the six months ended June 30, 2026 were primarily for Refining & Marketing segment and Midstream segment projects. Major Refining & Marketing segment projects include continued investments at our Galveston Bay, Robinson, El Paso, and Garyville refineries having expected high returns. In addition to these multi-year investments, we are executing shorter-term projects that offer high anticipated returns through margin enhancement and cost reduction. Our capital investment outlook for Marketing includes continuing to expand the reach and presence of our branded stations in support of strong value capture. Our Midstream segment capital expenditures and investments in affiliates were primarily focused on expanding our Permian to Gulf Coast integrated value chain, progressing long-haul pipeline growth projects to support producer activity, and investing in new gas processing plants in the Marcellus and Permian. The remainder of our Midstream capital plan targets the debottlenecking of existing assets to meet customer demand. We continuously evaluate our capital plan and make changes as conditions warrant. As a result, MPLX increased its 2026 growth capital spending outlook by $500 million to $2.9 billion, primarily reflecting the accelerated execution of the expansion of Gulf Coast fractionation and export facilities to meet global demand for U.S. energy. Capital expenditures and investments for MPC and MPLX are summarized below. Six Months Ended June 30, (Millions of dollars) 2026 2025 Capital expenditures and investments:(a) MPC, excluding MPLX Refining & Marketing $ 653 $ 709 Midstream - Other 25 12 Renewable Diesel(b) — 2 Corporate and Other(c) 9 15 Total MPC, excluding MPLX $ 687 $ 738 Midstream - MPLX(d) $ 1,888 $ 1,065 (a) Capital expenditures include changes in capital accruals. (b) Excludes $62 million of funding to the Martinez Renewables JV due to turnaround costs in the first quarter of 2026 expected to be recovered through subsequent distributions from the JV during 2026. (c) Excludes capitalized interest of $63 million and $38 million for the six months ended June 30, 2026 and 2025, respectively. (d) Includes reimbursable capital of $93 million and $87 million for the six months ended June 30, 2026 and 2025, respectively Share Repurchases Total share repurchases were as follows for the respective periods: Three Months Ended June 30, Six Months Ended June 30, (In millions, except per share data) 2026 2025 2026 2025 Number of shares repurchased 9 5 13 12 Cash paid for shares repurchased(a) $ 2,500 $ 692 $ 3,250 $ 1,749 Average cost per share(b) $ 258.36 $ 146.43 $ 246.41 $ 147.29 (a) 2026 excludes $33 million paid in 2026 for excise tax on 2025 share repurchases. 2025 excludes $88 million paid in 2025 for excise tax on 2024 share repurchases. (b) The average cost per share includes excise tax on share repurchases resulting from the Inflation Reduction Act of 2022, but the excise tax does not reduce the remaining share repurchase authorization. 48 Table of Contents From January 1, 2012 through June 30, 2026, our board of directors had approved $65.05 billion in total share repurchase authorizations, and we have repurchased a total of $58.92 billion of our common stock. As of June 30, 2026, we had $6.13 billion remaining under the share repurchase authorizations. We may utilize various methods to effect the repurchases, which could include open market repurchases, negotiated block transactions, accelerated share repurchases, tender offers or open market solicitations for shares, some of which may be effected through Rule 10b5-1 plans. The timing and amount of future repurchases, if any, will depend upon several factors, including market and business conditions, and such repurchases may be suspended, discontinued or restarted at any time. See Note 8 to the unaudited consolidated financial statements for further discussion of our share repurchase authorizations. MPLX Unit Repurchases Total unit repurchases were as follows for the respective periods: Three Months Ended June 30, Six Months Ended June 30, (In millions, except per unit data) 2026 2025 2026 2025 Number of common units repurchased 1 2 2 4 Cash paid for common units repurchased $ 50 $ 100 $ 100 $ 200 Average cost per unit $ 56.01 $ 50.31 $ 56.32 $ 51.38 As of June 30, 2026, MPLX had $1.02 billion remaining under the unit repurchase authorizations. MPLX may utilize various methods to effect the repurchases, which could include open market repurchases, negotiated block transactions, accelerated unit repurchases, tender offers or open market solicitations for units, some of which may be effected through Rule 10b5-1 plans. The timing and amount of future repurchases, if any, will depend upon several factors, including market and business conditions, and such repurchases may be suspended, discontinued or restarted at any time. Cash Commitments Contractual Obligations As of June 30, 2026, our purchase commitments primarily consist of obligations to purchase and transport crude oil used in our refining operations. During the first six months of 2026, there were no material changes to our contractual obligations outside the ordinary course of business since December 31, 2025. Our other contractual obligations primarily consist of long-term debt and pension and post-retirement obligations, for which additional information is included in Notes 16 and 21, respectively, to the unaudited consolidated financial statements, and financing and operating leases. Other Cash Commitments On July 29, 2026, our board of directors declared a dividend of $1.00 per share on common stock. The dividend is payable September 10, 2026 to shareholders of record as of the close of business on August 19, 2026. We may, from time to time, repurchase our senior notes in the open market, in tender offers, in privately negotiated transactions or otherwise in such volumes, at such prices and upon such other terms as we deem appropriate. ENVIRONMENTAL MATTERS AND COMPLIANCE COSTS We have incurred and may continue to incur substantial capital, operating and maintenance, and remediation expenditures as a result of environmental laws and regulations. If these expenditures, as with all costs, are not ultimately reflected in the prices of our products and services, our operating results will be adversely affected. We believe that substantially all of our competitors must comply with similar environmental laws and regulations. However, the specific impact on each competitor may vary depending on a number of factors, including the age and location of its operating facilities, marketing areas, production processes and whether it is also engaged in the petrochemical business or the marine transportation of crude oil and refined products. As previously disclosed in our Annual Report on Form 10-K for the year ended December 31, 2025, actual expenditures may vary as the number and scope of environmental projects are revised as a result of improved technology or changes in regulatory requirements. There have been no material changes to our environmental matters and compliance costs during the six months ended June 30, 2026. 49 Table of Contents CRITICAL ACCOUNTING ESTIMATES As of June 30, 2026, there have been no significant changes to our critical accounting estimates since our Annual Report on Form 10-K for the year ended December 31, 2025. ACCOUNTING STANDARDS NOT YET ADOPTED As discussed in Note 2 to the unaudited consolidated financial statements, certain new financial accounting pronouncements will be effective for our financial statements in the future.